Near-surface Q field generation method, device, equipment and medium

Abstract

The present application provides a near-surface Q field generation method, device, equipment, and medium, belonging to the field of seismic data processing technology. The method includes: intercepting the first arrival waves of multiple seismic channels from the seismic data of the target area; statistically processing the amplitude of the first arrival wave of each seismic channel to obtain the root mean square amplitude corresponding to each seismic channel; decomposing the root mean square amplitude corresponding to each seismic channel to obtain the shot point amplitude component and the detection point amplitude component corresponding to each seismic channel; based on the shot point amplitude component and the detection point amplitude component of the seismic channel, determining the relative absorption attenuation coefficient of the shot point and the relative absorption attenuation coefficient of the detection point corresponding to the seismic channel; based on the relative absorption attenuation coefficient of each shot point and the near-surface vertical one-way propagation time, the relative absorption attenuation coefficient of each detection point and the near-surface vertical one-way propagation time, generating the near-surface Q field of the target area. This solution improves the accuracy of the near-surface Q field.

Description

Technical Field

[0001] The present application relates to the technical field of seismic data processing, and in particular to a near-surface Q field generation method, device, equipment and medium. Background Art

[0002] In the field of oil and gas exploration, the precision requirements for exploration targets are becoming increasingly stringent, which demands wide bandwidth and high resolution for seismic data. However, as seismic waves propagate through strata, their energy is absorbed and attenuated by the strata. This is especially true in the porous medium near the surface, where absorption and attenuation of seismic waves can severely reduce the bandwidth and resolution of seismic data. Currently, the bandwidth and resolution of seismic data can be improved by generating a near-surface Q field and compensating the seismic data based on this near-surface Q field.

[0003] In related technologies, the method for generating the near-surface Q field is: obtaining dual-well micro-logging data, using the spectral ratio method or the frequency shift method to calculate the Q values ​​of multiple single points on the well, and interpreting the dual-well micro-logging data to obtain the velocity of each single point, fitting a curve showing the relationship between the Q value and the velocity, and based on the curve showing the relationship between the Q value and the velocity, converting the near-surface velocity model into the near-surface Q field.

[0004] Since there is a certain error in the fitted curve of the relationship between Q value and velocity, the accuracy of the generated near-surface Q field is poor. Summary of the Invention

[0005] The embodiments of the present application provide a method, apparatus, device, and medium for generating a near-surface Q field, which improves the accuracy of the near-surface Q field. The technical solution is as follows:

[0006] In one aspect, a near-surface Q field generation method is provided, the method comprising:

[0007] Extracting first arrival waves of multiple seismic traces from seismic data of the target area, where each seismic trace corresponds to a shot point and a detector point. The first arrival wave of the seismic trace is the first seismic wave detected by the detector point of the seismic trace after the shot point of the seismic trace excites the earthquake, and includes amplitudes corresponding to multiple acquisition points.

[0008] Performing statistical processing on the amplitudes corresponding to multiple acquisition points in the first arrival wave of each seismic trace to obtain the root mean square amplitude corresponding to each seismic trace;

[0009] Decomposing the root mean square amplitude corresponding to each seismic trace to obtain a shot point amplitude component and a receiver point amplitude component corresponding to each seismic trace, wherein the shot point amplitude component is used to represent the influence of the near surface on the downgoing seismic wave, and the receiver point amplitude component is used to represent the influence of the near surface on the upgoing reflected wave;

[0010] For each seismic trace, determining a relative absorption attenuation coefficient of the shot point corresponding to the seismic trace based on the shot point amplitude component of the seismic trace, and determining a relative absorption attenuation coefficient of the detection point corresponding to the seismic trace based on the detection point amplitude component of the seismic trace, wherein the relative absorption attenuation coefficient is used to represent the absorption attenuation of seismic waves by the near surface;

[0011] Determining the near-surface vertical one-way propagation time corresponding to each shot point and each receiver point based on a near-surface velocity model of the target area, wherein the near-surface vertical one-way propagation time is the time required for a seismic wave to propagate vertically once between the upper and lower surfaces of the near-surface;

[0012] generating a near-surface Q field of the target area based on the relative absorption attenuation coefficient of each shot point, the near-surface vertical one-way propagation time corresponding to each shot point, the relative absorption attenuation coefficient of each detection point, and the near-surface vertical one-way propagation time corresponding to each detection point;

[0013] Processing is performed based on the near-surface Q field of the target area.

[0014] In one possible implementation, generating the near-surface Q field of the target area based on the relative absorption attenuation coefficient of each shot point, the near-surface vertical one-way propagation time corresponding to each shot point, the relative absorption attenuation coefficient of each detection point, and the near-surface vertical one-way propagation time corresponding to each detection point includes:

[0015] Determining a Q value corresponding to each shot point based on a relative absorption attenuation coefficient of each shot point, a near-surface vertical one-way propagation time corresponding to each shot point, and a dominant frequency of the seismic data;

[0016] Determine the Q value corresponding to each detection point based on the relative absorption attenuation coefficient of each detection point, the near-surface vertical one-way propagation time corresponding to each detection point, and the main frequency of the seismic data;

[0017] A near-surface Q field of the target area is generated based on the Q value corresponding to each shot point and the Q value corresponding to each detection point.

[0018] In a possible implementation, the relationship between the relative absorption attenuation coefficient, the near-surface vertical one-way propagation time, the main frequency of the seismic data, and the Q value is as follows:

[0019] Q = -πft / LN(R);

[0020] Where Q is the Q value corresponding to the shot point or the Q value corresponding to the receiver point, is pi, f is the main frequency of the seismic data, t is the near-surface vertical one-way propagation time corresponding to the shot point or the near-surface vertical one-way propagation time corresponding to the receiver point, LN is the natural logarithm function, and R is the relative absorption attenuation coefficient of the shot point or the relative absorption attenuation coefficient of the receiver point.

[0021] In a possible implementation, intercepting first arrival waves of multiple seismic traces from seismic data in a target area includes:

[0022] Picking up the first arrival times of multiple seismic traces from the seismic data of the target area, where the first arrival time of the seismic trace is the time when the first seismic wave is detected by the receiver point of the seismic trace after the shot point of the seismic trace excites the earthquake;

[0023] Based on the first arrival times of the multiple seismic traces, first arrival waves of the multiple seismic traces are intercepted from the seismic data of the target area.

[0024] In a possible implementation, intercepting first arrival waves of multiple seismic traces from seismic data in the target area based on the first arrival time includes:

[0025] Displaying a first-break wave interception interface, the first-break wave interception interface including the seismic data, the first-break times of the multiple seismic traces, and a first duration input box and a second duration input box;

[0026] Based on the first duration input box, obtain the first duration input, and based on the second duration input box, obtain the second duration input;

[0027] For any seismic trace, a third time obtained by subtracting the first time length from the first arrival time of the seismic trace is used as the start time of the first arrival wave interception time window of the seismic trace, and a fourth time obtained by adding the second time length to the first arrival time of the seismic trace is used as the end time of the first arrival wave interception time window of the seismic trace;

[0028] The first arrival waves of the plurality of seismic traces are intercepted from the seismic data of the target area based on the first arrival wave interception time window of the plurality of seismic traces.

[0029] In one possible implementation, determining the relative absorption attenuation coefficient of the shot point corresponding to the seismic trace based on the shot point amplitude component of the seismic trace, and determining the relative absorption attenuation coefficient of the detection point corresponding to the seismic trace based on the detection point amplitude component of the seismic trace, includes:

[0030] The shot point amplitude component of the seismic trace and the detection point amplitude component of the seismic trace are normalized to obtain the relative absorption attenuation coefficient of the shot point and the relative absorption attenuation coefficient of the detection point corresponding to the seismic trace.

[0031] In one possible implementation, before normalizing the shot point amplitude component of the seismic trace and the receiver point amplitude component of the seismic trace to obtain the relative absorption attenuation coefficient of the shot point and the relative absorption attenuation coefficient of the receiver point corresponding to the seismic trace, the method further includes at least one of the following:

[0032] Performing outlier elimination processing on the shot point amplitude component of the seismic trace and the detection point amplitude component of the seismic trace;

[0033] interpolating the shot point amplitude component of the seismic trace and the receiver point amplitude component of the seismic trace;

[0034] Smoothing is performed on the shot point amplitude component of the seismic trace and the detection point amplitude component of the seismic trace.

[0035] In another aspect, a near-surface Q-field generating device is provided, the device comprising:

[0036] An interception module is used to intercept the first arrival waves of multiple seismic traces from the seismic data of the target area. One seismic trace corresponds to one shot point and one detection point. The first arrival wave of the seismic trace is the first seismic wave detected by the detection point of the seismic trace after the shot point of the seismic trace excites the earthquake, including the amplitudes corresponding to multiple acquisition points.

[0037] A statistical module is used to perform statistical processing on the amplitudes corresponding to multiple acquisition points in the first arrival wave of each seismic trace, so as to obtain the root mean square amplitude corresponding to each seismic trace;

[0038] a decomposition module, configured to decompose the root mean square amplitude corresponding to each seismic trace to obtain a shot point amplitude component and a receiver point amplitude component corresponding to each seismic trace, wherein the shot point amplitude component is used to represent the influence of the near surface on the downgoing seismic wave, and the receiver point amplitude component is used to represent the influence of the near surface on the upgoing reflected wave;

[0039] a coefficient determination module configured to determine, for each seismic trace, a relative absorption attenuation coefficient of a shot point corresponding to the seismic trace based on a shot point amplitude component of the seismic trace, and a relative absorption attenuation coefficient of a detection point corresponding to the seismic trace based on a detection point amplitude component of the seismic trace, wherein the relative absorption attenuation coefficient is used to represent the absorption attenuation of seismic waves by the near surface;

[0040] a time determination module for determining the near-surface vertical one-way propagation time corresponding to each shot point and the near-surface vertical one-way propagation time corresponding to each receiver point based on the near-surface velocity model of the target area, wherein the near-surface vertical one-way propagation time is the time required for a seismic wave to propagate vertically once between the upper and lower surfaces of the near-surface;

[0041] a generating module, configured to generate a near-surface Q field of the target area based on the relative absorption attenuation coefficient of each shot point, the near-surface vertical one-way propagation time corresponding to each shot point, the relative absorption attenuation coefficient of each detection point, and the near-surface vertical one-way propagation time corresponding to each detection point;

[0042] A processing module is used to perform processing based on the near-surface Q field of the target area.

[0043] In one possible implementation, the generation module is configured to determine a Q value corresponding to each shot point based on a relative absorption attenuation coefficient of each shot point, a near-surface vertical one-way propagation time corresponding to each shot point, and a dominant frequency of the seismic data; determine a Q value corresponding to each detection point based on a relative absorption attenuation coefficient of each detection point, a near-surface vertical one-way propagation time corresponding to each detection point, and a dominant frequency of the seismic data; and generate a near-surface Q field of the target area based on the Q value corresponding to each shot point and the Q value corresponding to each detection point.

[0044] In a possible implementation, the relationship between the relative absorption attenuation coefficient, the near-surface vertical one-way propagation time, the main frequency of the seismic data, and the Q value is as follows:

[0045] Q = -πft / LN(R);

[0046] Where Q is the Q value corresponding to the shot point or the Q value corresponding to the receiver point, π is pi, f is the dominant frequency of the seismic data, t is the near-surface vertical one-way propagation time corresponding to the shot point or the receiver point, LN is the natural logarithm function, and R is the relative absorption attenuation coefficient of the shot point or the receiver point.

[0047] In a possible implementation, the interception module includes:

[0048] a time determination unit, configured to extract first arrival times of a plurality of seismic traces from the seismic data of the target area, wherein the first arrival time of the seismic trace is the time when the first seismic wave is detected by the receiver point of the seismic trace after the shot point of the seismic trace excites the earthquake;

[0049] The interception unit is used to intercept the first arrival waves of multiple seismic traces from the seismic data of the target area based on the first arrival times of the multiple seismic traces.

[0050] In a possible implementation, the interception unit is used to display a first arrival wave interception interface, which includes the seismic data, the first arrival times of the multiple seismic traces, and a first time length input box and a second time length input box; based on the first time length input box, the input first time length is obtained, and based on the second time length input box, the input second time length is obtained; for any seismic trace, the third time obtained by subtracting the first time length from the first arrival time of the seismic trace is used as the starting time of the first arrival wave interception time window of the seismic trace, and the fourth time obtained by adding the second time length to the first arrival time of the seismic trace is used as the ending time of the first arrival wave interception time window of the seismic trace; based on the first arrival wave interception time windows of the multiple seismic traces, the first arrival waves of the multiple seismic traces are intercepted from the seismic data of the target area.

[0051] In one possible implementation, the coefficient determination module is used to normalize the shot point amplitude component of the seismic trace and the detection point amplitude component of the seismic trace to obtain the relative absorption attenuation coefficient of the shot point corresponding to the seismic trace and the relative absorption attenuation coefficient of the corresponding detection point.

[0052] In a possible implementation, the apparatus further includes a preprocessing module, configured to perform at least one of the following:

[0053] Performing outlier elimination processing on the shot point amplitude component of the seismic trace and the detection point amplitude component of the seismic trace;

[0054] interpolating the shot point amplitude component of the seismic trace and the receiver point amplitude component of the seismic trace;

[0055] Smoothing is performed on the shot point amplitude component of the seismic trace and the detection point amplitude component of the seismic trace.

[0056] On the other hand, a computer device is provided, comprising a processor and a memory, wherein the memory stores at least one program code, and the at least one program code is loaded and executed by the processor to implement the near-surface Q field generation method as described in any of the above implementations.

[0057] On the other hand, a computer-readable storage medium is provided, in which at least one program code is stored. The at least one program code is loaded and executed by a processor to implement the near-surface Q field generation method as described in any of the above implementations.

[0058] On the other hand, a computer program product is provided, comprising at least one program code, wherein the at least one program code is loaded and executed by a processor to implement the near-surface Q field generation method as described in any of the above implementations.

[0059] The beneficial effects of the technical solutions provided by the embodiments of the present application include at least:

[0060] The present invention provides a method for generating a near-surface Q field. The method decomposes the root mean square amplitude of the first arrival wave to obtain the amplitude components of the shot point and the receiver point. The amplitude components of the shot point and the receiver point are then determined based on the amplitude components of the shot point and the receiver point, and the relative absorption attenuation coefficients of the shot point and the receiver point are determined. The near-surface Q field is generated based on the relative absorption attenuation coefficients of the shot point and the receiver point and the vertical one-way propagation time of the seismic wave in the near-surface. Since the first arrival wave is not reflected by the underground interface but is excited by the shot point and then reaches the receiver point through the near-surface, it is primarily affected by the near-surface and thus contains rich near-surface absorption attenuation information, ensuring the accuracy of the relative absorption attenuation coefficients of the shot point and the receiver point. Since the near-surface vertical one-way propagation time of the seismic wave is also affected by the near-surface geology, the near-surface Q field can be more accurately obtained by combining the relative absorption attenuation coefficients of the shot point and the receiver point and the vertical one-way propagation time of the seismic wave in the near-surface, thereby improving the accuracy of the near-surface Q field. BRIEF DESCRIPTION OF THE DRAWINGS

[0061] In order to more clearly illustrate the technical solutions in the embodiments of the present application, the following briefly introduces the drawings required for use in the description of the embodiments. Obviously, the drawings described below are only some embodiments of the present application. For ordinary technicians in this field, other drawings can be obtained based on these drawings without any creative work.

[0062] Figure 1 This is a flow chart of a near-surface Q field generation method provided in an embodiment of the present application;

[0063] Figure 2 This is a flow chart of a near-surface Q field generation method provided in an embodiment of the present application;

[0064] Figure 3 This is a schematic diagram of the distribution of shot points and receiver points in a target area provided in an embodiment of the present application;

[0065] Figure 4 Schematic diagram of a first arrival wave interception interface provided in an embodiment of the present application;

[0066] Figure 5 This is a partial enlarged diagram of seismic data and first arrival positions provided in an embodiment of the present application;

[0067] Figure 6 is a schematic diagram of the root mean square amplitude of multiple seismic traces provided in an embodiment of the present application;

[0068] Figure 7This is a schematic diagram of relative absorption attenuation coefficients of multiple shot points and multiple detection points provided in an embodiment of the present application;

[0069] Figure 8 Schematic diagram of vertical one-way propagation time near the surface of a target area provided in an embodiment of the present application;

[0070] Figure 9 is a schematic diagram of a near-surface Q field of a target area provided in an embodiment of the present application;

[0071] Figure 10 Schematic diagram of the structure of a near-surface Q field generating device provided in an embodiment of the present application;

[0072] Figure 11 Schematic diagram of the structure of a near-surface Q field generating device provided in an embodiment of the present application;

[0073] Figure 12 This is a schematic diagram of the structure of a terminal provided in an embodiment of the present application;

[0074] Figure 13 This is a structural diagram of a server provided in an embodiment of the present application. DETAILED DESCRIPTION

[0075] In order to make the objectives, technical solutions and advantages of this application clearer, the implementation methods of this application will be further described in detail below with reference to the accompanying drawings.

[0076] The terms "first," "second," "third," and "fourth," etc. in the specification and claims of this application and the accompanying drawings are used to distinguish different objects, not to describe a specific order. In addition, the terms "including" and "having," and any variations thereof, are intended to cover non-exclusive inclusions. For example, a process, method, system, product, or apparatus comprising a series of steps or elements is not limited to the listed steps or elements, but may optionally include steps or elements not listed, or may optionally include other steps or elements inherent to the process, method, product, or apparatus.

[0077] Figure 1 This is a flowchart of a near-surface Q field generation method provided by an embodiment of the present application. This embodiment of the present application is illustrated by taking a computer device as an example. Figure 1 , the method comprising:

[0078] 101. The computer equipment intercepts the first arrival waves of multiple seismic channels from the seismic data of the target area. One seismic channel corresponds to a shot point and a detection point. The first arrival wave of the seismic channel is the first seismic wave detected by the detection point of the seismic channel after the shot point of the seismic channel excites the earthquake, including the amplitudes corresponding to multiple acquisition points.

[0079] The target area can be any area, and the embodiments of the present application do not limit the target area. The seismic data is seismic data of multiple seismic channels, where each seismic channel corresponds to a shot point and a detection point. The seismic data of the seismic channel is the data of the seismic waves received at the detection point after the earthquake is excited by the shot point.

[0080] 102. The computer device performs statistical processing on the amplitudes corresponding to multiple acquisition points in the first arrival wave of each seismic channel to obtain the root mean square amplitude corresponding to each seismic channel.

[0081] In the embodiment of the present application, the amplitudes corresponding to multiple acquisition points in any first arrival wave can be statistically processed according to the root mean square amplitude statistical criterion to obtain the root mean square amplitude corresponding to the first arrival wave, which is also the root mean square amplitude corresponding to the seismic channel to which the first arrival wave belongs, providing a basis for subsequent amplitude decomposition.

[0082] 103. The computer equipment decomposes the root mean square amplitude corresponding to each seismic channel to obtain the shot point amplitude component and the detection point amplitude component corresponding to each seismic channel. The shot point amplitude component is used to represent the influence of the near surface on the downgoing seismic wave, and the detection point amplitude component is used to represent the influence of the near surface on the upgoing reflected wave.

[0083] Since the first arrival wave is excited by the shot point and then passes through the near surface before reaching the receiver point, the first arrival wave is mainly affected by the near surface. By decomposing the root mean square of the seismic trace (that is, the root mean square of the first arrival wave of the seismic trace), the influence of the near surface on the first arrival wave is divided into the influence on the process of the first arrival wave from the shot point to the near surface reflection surface and the influence on the process of the first arrival wave from the near surface reflection surface to the receiver point. Among them, the shot point amplitude component is used to represent the influence of the near surface on the process of the first arrival wave from the shot point to the near surface reflection surface, that is, it is used to represent the influence of the near surface on the downgoing seismic wave; the receiver point amplitude component is used to represent the influence of the near surface on the process of the first arrival wave from the near surface reflection surface to the receiver point, that is, it is used to represent the influence of the near surface on the upgoing reflection wave.

[0084] 104. For each seismic channel, the computer equipment determines the relative absorption attenuation coefficient of the shot point corresponding to the seismic channel based on the amplitude component of the shot point of the seismic channel, and determines the relative absorption attenuation coefficient of the detection point corresponding to the seismic channel based on the amplitude component of the detection point of the seismic channel. The relative absorption attenuation coefficient is used to represent the absorption and attenuation of seismic waves by the near surface.

[0085] The dielectric properties of the near-surface layer vary at different locations within the target area. Therefore, the shot-point amplitude component of a seismic trace can only be used to represent the effect of the near-surface at that shot-point location on downgoing seismic waves, while the receiver-point amplitude component of a seismic trace can only be used to represent the effect of the near-surface at that receiver-point location on upgoing reflected waves. Consequently, the relative absorption attenuation coefficient of a shot-point, determined based on the shot-point amplitude component of a seismic trace, represents the absorption attenuation of seismic waves by the near-surface at that shot-point location, while the relative absorption attenuation coefficient of a receiver-point, determined based on the receiver-point amplitude component of a seismic trace, represents the absorption attenuation of seismic waves by the near-surface at that receiver-point location.

[0086] 105. Based on the near-surface velocity model of the target area, the computer equipment determines the near-surface vertical one-way propagation time corresponding to each shot point and the near-surface vertical one-way propagation time corresponding to each detection point. The near-surface vertical one-way propagation time is the time required for the seismic wave to propagate vertically between the upper and lower surfaces of the near-surface.

[0087] The near-surface velocity model of the target region can be used to represent the seismic wave propagation velocity at multiple locations within the target region. Based on this near-surface velocity model and the near-surface thickness, the time required for a seismic wave to propagate vertically once between the upper and lower surfaces of the near-surface can be determined, i.e., the near-surface vertical one-way propagation time. Similarly, since the dielectric properties of the near-surface layers at different locations within the target region vary, in order to obtain an accurate near-surface Q field, it is also necessary to determine the near-surface vertical one-way propagation time at different near-surface locations. Since the relative absorption attenuation coefficients of each shot point and each receiver point were determined in step 104 above, when determining the near-surface vertical one-way propagation time, the near-surface vertical one-way propagation time at each shot point and each receiver point can be determined. This allows the near-surface Q field of the target region to be determined by combining the relative absorption attenuation coefficients and the near-surface vertical one-way propagation time at each shot point and each receiver point.

[0088] 106. The computer device generates the near-surface Q field of the target area based on the relative absorption attenuation coefficient of each shot point, the near-surface vertical one-way propagation time corresponding to each shot point, the relative absorption attenuation coefficient of each detection point, and the near-surface vertical one-way propagation time corresponding to each detection point.

[0089] The near-surface Q field of the target area includes near-surface Q values ​​at multiple locations within the target area. This Q value is a formation quality factor, a parameter used to characterize the strength of seismic wave attenuation in the medium. Because the near-surface Q field of the target area is generated based on the relative absorption attenuation coefficient of each shot point, the near-surface vertical one-way propagation time corresponding to each shot point, the relative absorption attenuation coefficient of each receiver point, and the near-surface vertical one-way propagation time corresponding to each receiver point, the near-surface Q field of the target area includes the Q value at each shot point and the Q value at each receiver point.

[0090] 107. The computer equipment performs processing based on the near-surface Q field of the target area.

[0091] In practical applications, the near-surface Q field of the target area can be processed as needed. In some embodiments, the near-surface Q field is used for compensation processing. The computer device processes based on the near-surface Q field of the target area, including: the computer device performs compensation processing on the seismic data of the target area based on the near-surface Q field of the target area. Since the medium near the surface is relatively loose, the absorption and attenuation of seismic waves are relatively serious, and the near-surface Q field includes the attenuation strength parameters of seismic waves at multiple locations in the target area in the near surface. Therefore, the near-surface Q field can provide exact parameters for the energy and frequency compensation processing of seismic waves. Based on the near-surface Q field of the target area, the seismic data of the target area can be compensated, which can accurately and effectively improve the resolution of the seismic data.

[0092] In other embodiments, a computer device processes a target region based on a near-surface Q field, including displaying the target region's near-surface Q field. The near-surface Q field includes formation quality factors at multiple near-surface locations. Displaying the near-surface Q field allows a user to intuitively visualize the near-surface formation quality of the target region.

[0093] It should be noted that the embodiments of the present application are merely illustrative of the processing of the near-surface Q field, and do not limit the processing based on the near-surface Q field.

[0094] The near-surface Q-field generation method provided in the embodiments of the present application decomposes the root mean square amplitude of the first arrival wave to obtain the amplitude components of the shot point and the receiver point. Based on the amplitude components of the shot point and the receiver point, the amplitude components of the shot point and the receiver point are determined, and the relative absorption attenuation coefficients of the shot point and the receiver point are determined. The near-surface Q-field is generated based on the relative absorption attenuation coefficients of the shot point and the receiver point and the vertical one-way propagation time of the seismic wave in the near-surface. Since the first arrival wave is not reflected by the underground interface but is excited by the shot point and then reaches the receiver point through the near-surface, it is primarily affected by the near-surface and thus contains rich near-surface absorption attenuation information, ensuring the accuracy of the relative absorption attenuation coefficients of the shot point and the receiver point. Since the near-surface vertical one-way propagation time of the seismic wave is also affected by the near-surface geology, the near-surface Q-field can be more accurately obtained by combining the relative absorption attenuation coefficients of the shot point and the receiver point and the vertical one-way propagation time of the seismic wave in the near-surface, thereby improving the accuracy of the near-surface Q-field.

[0095] In one possible implementation, the near-surface Q field of the target area is generated based on the relative absorption attenuation coefficient of each shot point, the near-surface vertical one-way propagation time corresponding to each shot point, the relative absorption attenuation coefficient of each receiver point, and the near-surface vertical one-way propagation time corresponding to each receiver point, including:

[0096] The Q value corresponding to each shot point is determined based on the relative absorption attenuation coefficient of each shot point, the near-surface vertical one-way propagation time corresponding to each shot point, and the dominant frequency of the seismic data;

[0097] Determine the Q value corresponding to each detection point based on the relative absorption attenuation coefficient of each detection point, the near-surface vertical one-way propagation time corresponding to each detection point, and the main frequency of the seismic data;

[0098] Based on the Q value corresponding to each shot point and the Q value corresponding to each receiver point, the near-surface Q field of the target area is generated.

[0099] In one possible implementation, the relationship between the relative absorption attenuation coefficient, the near-surface vertical one-way propagation time, the dominant frequency of the seismic data, and the Q value is as follows:

[0100] Q = -πft / LN(R);

[0101] Where Q is the Q value corresponding to the shot point or the Q value corresponding to the receiver point, π is pi, f is the dominant frequency of the seismic data, t is the near-surface vertical one-way propagation time corresponding to the shot point or the receiver point, LN is the natural logarithm function, and R is the relative absorption attenuation coefficient of the shot point or the receiver point.

[0102] In one possible implementation, first arrival waves of multiple seismic traces are intercepted from seismic data in a target area, including:

[0103] The first arrival time of multiple seismic traces is picked up from the seismic data of the target area. The first arrival time of a seismic trace is the time when the first seismic wave is detected by the receiver point of the seismic trace after the shot point of the seismic trace triggers the earthquake;

[0104] Based on the first arrival time, the first arrival waves of multiple seismic traces are intercepted from the seismic data of the target area.

[0105] In one possible implementation, first arrival waves of multiple seismic traces are intercepted from seismic data in a target area based on first arrival times, including:

[0106] Display the first arrival wave interception interface, which includes seismic data, the first arrival time of multiple seismic traces, and the first duration input box and the second duration input box;

[0107] Based on the first duration input box, obtain the first duration input, and based on the second duration input box, obtain the second duration input;

[0108] For any seismic trace, the third time obtained by subtracting the first time length from the first arrival time of the seismic trace is used as the start time of the first arrival wave interception window of the seismic trace, and the fourth time obtained by adding the second time length to the first arrival time of the seismic trace is used as the end time of the first arrival wave interception window of the seismic trace;

[0109] Based on the first arrival wave interception time window of multiple seismic traces, the first arrival waves of multiple seismic traces are intercepted from the seismic data of the target area.

[0110] In one possible implementation, determining a relative absorption attenuation coefficient of a shot point corresponding to a seismic trace based on a shot point amplitude component of the seismic trace, and determining a relative absorption attenuation coefficient of a receiver point corresponding to the seismic trace based on a receiver point amplitude component of the seismic trace include:

[0111] The shot point amplitude component of the seismic trace and the receiver point amplitude component of the seismic trace are normalized to obtain the relative absorption attenuation coefficient of the shot point and the relative absorption attenuation coefficient of the corresponding receiver point of the seismic trace.

[0112] In one possible implementation, before normalizing the shot point amplitude component and the receiver point amplitude component of the seismic trace to obtain the relative absorption attenuation coefficient of the shot point and the relative absorption attenuation coefficient of the receiver corresponding to the seismic trace, the method further includes at least one of the following:

[0113] Perform outlier elimination processing on the amplitude components of the shot points and the amplitude components of the receiver points of the seismic trace;

[0114] Perform interpolation processing on the shot point amplitude component of the seismic trace and the receiver point amplitude component of the seismic trace;

[0115] The amplitude components of the shot points and the amplitude components of the receiver points of the seismic trace are smoothed.

[0116] All of the above optional technical solutions can be combined in any way to form optional embodiments of the present application, and will not be described in detail here.

[0117] Figure 2 This is a flowchart of a near-surface Q field generation method provided in an embodiment of the present application. The embodiment of the present application is illustrated by taking a computer device as an example. Figure 2 , the method comprising:

[0118] 201. The computer equipment picks up the first arrival time of multiple seismic traces from the seismic data of the target area. The first arrival time of the seismic trace is the time when the detection point of the seismic trace detects the first seismic wave after the shot point of the seismic trace excites the earthquake.

[0119] Among them, one seismic channel corresponds to one shot point and one detection point. The seismic data corresponding to one seismic channel is the data of the seismic wave received from the detection point after the earthquake is excited by the shot point. Multiple shot points and multiple detection points can be set in the target area (such as Figure 3 As shown, the vertical straight line is used to represent the receiving point of the seismic wave, that is, the detection point, and the random points on the vertical line are the excitation points of the seismic wave, that is, the shot point). At least one earthquake is excited in sequence at multiple shot points, and the data of the seismic waves received by multiple detection points constitute the seismic data of the target area in the above step 201.

[0120] In the above step 201, the computer device can use any method such as extreme value method, energy ratio method, waveform correlation method, AI model, etc. to pick up the first arrival time of multiple seismic traces from the seismic data. The embodiment of the present application does not limit this and only uses the energy ratio method as an example for illustrative explanation.

[0121] In some embodiments, a computer device uses an energy ratio method to extract the first arrival times of multiple seismic traces from seismic data. The computer device extracts the first arrival times of multiple seismic traces from seismic data in a target area, including: dividing the seismic data of any seismic trace into multiple units according to a target time window, summing the energy of the acquisition points of the seismic data in each unit to obtain the energy sum corresponding to each unit, dividing the energy sum of the latter unit by the energy sum of the former unit and taking the square root to obtain the energy ratio within the previous and subsequent time windows; determining the maximum energy ratio, and determining the time corresponding to the maximum energy ratio as the first arrival time.

[0122] 202. The computer device intercepts the first arrival waves of the multiple seismic traces from the seismic data of the target area based on the first arrival times of the multiple seismic traces.

[0123] Because the first arrival time is the time when the first arrival wave is detected at a detector point, the first arrival waves of multiple seismic traces can be intercepted from the seismic data of the target area based on the first arrival time. In one possible implementation, a first arrival interception time window for any seismic trace can be determined based on the first arrival time of that trace. Based on this first arrival interception time window, seismic data within the first arrival interception time window is intercepted from the seismic data of that seismic trace to obtain the first arrival wave.

[0124] For example, if the first arrival interception time window is from 10:53:04:20 milliseconds to 10:53:04:60 milliseconds, then the seismic data collected between 10:53:04:20 milliseconds and 10:53:04:60 milliseconds are intercepted from the seismic data of the seismic track to obtain the first arrival wave.

[0125] In some embodiments, when determining the first arrival wave interception window of any seismic trace based on the first arrival time of the seismic trace, the first arrival time can be used as the starting time of the first arrival wave interception window, and the first preset time length can be superimposed on the first arrival time to obtain the end time of the first arrival wave interception window; the first arrival time can also be used as the middle time of the first arrival wave interception window, and the second preset time length can be subtracted from the first arrival time to obtain the starting time of the first arrival wave interception window, and the second preset time length can be added to the first arrival time to obtain the end time of the first arrival wave interception window, or the third preset time length can be subtracted from the first arrival time to obtain the starting time of the first arrival wave interception window, and the fourth preset time length can be added to the first arrival time to obtain the end time of the first arrival wave interception window; the first arrival time can also be used as the end time of the first arrival wave interception window, and the fifth preset time length can be subtracted from the first arrival time to obtain the end time of the first arrival wave interception window; the first arrival time can also be displayed to the user, and the user can set the first arrival wave interception window based on the seismic data of the seismic trace.

[0126] Among them, the first preset time length, the second preset time length, the third preset time length, the fourth preset time length and the fifth preset time length are any preset time lengths, which can be set by technicians, or can be empirical values, or can be input by users. The embodiments of this application do not limit this.

[0127] Next, taking "displaying the first arrival time to the user and allowing the user to set the first arrival wave interception time window based on the seismic data of the seismic channel" as an example, the process of intercepting the first arrival waves of multiple seismic channels is illustrated.

[0128] In one possible implementation, a computer device intercepts the first arrival waves of multiple seismic traces from seismic data in a target area based on the first arrival times of the multiple seismic traces, including: the computer device displays a first arrival wave interception interface, the first arrival wave interception interface includes seismic data, the first arrival times of the multiple seismic traces, and a first time length input box and a second time length input box; based on the first time length input box, the input first time length is obtained, and based on the second time length input box, the input second time length is obtained; for any seismic trace, a third time obtained by subtracting the first time length from the first arrival time of the seismic trace is used as the starting time of the first arrival wave interception time window of the seismic trace, and a fourth time obtained by adding the second time length to the first arrival time of the seismic trace is used as the ending time of the first arrival wave interception time window of the seismic trace; based on the first arrival wave interception time window of the multiple seismic traces, the first arrival waves of the multiple seismic traces are intercepted from the seismic data in the target area.

[0129] like Figure 4 As shown, Figure 4 A first arrival interception interface is provided, which displays the first arrival times of multiple seismic traces. Users can determine the first arrival interception time window based on the seismic data and the first arrival time. For example, the range from 30ms before to 10ms after the first arrival time is determined as the first arrival interception time window. The first arrival interception time window is represented by a dotted line. Figure 4 middle. Figure 5 yes Figure 4 A partial enlarged view based on Figure 5 You can clearly see the waveform of the seismic data collected by the seismic trace and the position of the first arrival time in the seismic data. Therefore, based on the seismic data and the first arrival time, the user can easily determine the first arrival wave interception time window. Figure 5 The gray line in the figure represents the first arrival time of the seismic trace. Figure 5 The rectangular box in represents the first arrival wave interception time window of the seismic trace determined based on the first arrival time.

[0130] 203. The computer device performs statistical processing on the amplitudes corresponding to multiple acquisition points in the first arrival wave of each seismic channel to obtain the root mean square amplitude corresponding to each seismic channel.

[0131] In some embodiments, the computer device may use the following formula to perform statistical processing on the amplitudes corresponding to multiple acquisition points in the first arrival wave to obtain the root mean square amplitude corresponding to each seismic trace:

[0132]

[0133] Where P(z) is the root mean square amplitude corresponding to the z-th seismic trace, z is the trace number, k is the acquisition point number, a(k) is the amplitude corresponding to the k-th acquisition point, N is the number of acquisition points for the first arrival wave, and ∑ is the summation function.

[0134] For example, Figure 6 The RMS amplitude of multiple seismic traces corresponding to a shot in the target area is shown in Figure 1, where Figure 6 The horizontal axis is the offset distance (that is, the distance between the shot point and the receiver point of the seismic trace), and the vertical axis is the root mean square amplitude.

[0135] 204. The computer equipment decomposes the root mean square amplitude corresponding to each seismic channel to obtain the shot point amplitude component and the detection point amplitude component corresponding to each seismic channel. The shot point amplitude component is used to represent the influence of the near surface on the downgoing seismic wave, and the detection point amplitude component is used to represent the influence of the near surface on the upgoing reflected wave.

[0136] In some embodiments, the RMS amplitude can be decomposed based on the surface-consistent decomposition theory. This theory assumes that within the near-surface, the influence of the near-surface at the shot point manifests solely as the energy difference caused by the shot point, independent of the signal's recording location. Similarly, the influence of the near-surface at the receiver point manifests solely as the energy difference caused by the receiver point, independent of the signal's excitation location. Based on this assumption, surface-consistent amplitude decomposition can be performed to obtain the shot point amplitude component and the receiver point amplitude component, and thus the relative absorption attenuation coefficients of the shot point and the receiver point.

[0137] In some embodiments, based on the impact on the amplitude, when the computer device performs surface consistency decomposition on the root mean square amplitude corresponding to each seismic channel, the root mean square amplitude can be decomposed into a shot point item (that is, a shot point amplitude component), a detection point item (that is, a detection point amplitude component), and an offset distance item (that is, an offset distance amplitude component). Afterwards, only the shot point item and the detection point item are used for subsequent processing.

[0138] The relationship between the root mean square amplitude, shot point amplitude component, receiver point amplitude component, and offset amplitude component corresponding to the seismic trace can be expressed as follows:

[0139] P(z)=S i G j O x ;

[0140] Where z = i, j, which means the zth seismic trace corresponds to the i-th shot point and the j-th receiver point, S i is the amplitude component of the shot point, G j is the amplitude component of the detection point, O x is the offset amplitude component, x is the offset number, which can be any integer.

[0141] It should be noted that P(z)=S i G j O x In, S i , Gj and O x All of them are unknown quantities, and we also need to find S i , G j and O x In some embodiments, P(z)=S i G j O x Taking the logarithms of the left and right sides, we get the following relationship:

[0142] logP(z)=logS i +logG j +logo x ;

[0143] Then the iterative formula of Gauss-Seidel method can be used to solve it, so that logP(z) and logS i +logG j +logo x The energy error is the smallest. The iterative formula of the Gauss-Seidel method can be shown as follows:

[0144]

[0145]

[0146]

[0147] Among them, S i is the amplitude component of the shot point, G j is the amplitude component of the detection point, O x is the offset amplitude component, x is the offset number, which can be any integer. i Indicates the number of shot points, N j Indicates the number of detection points, N x represents the number of offsets, and log represents the logarithmic function.

[0148] 205. For each seismic channel, the computer equipment determines the relative absorption attenuation coefficient of the shot point corresponding to the seismic channel based on the amplitude component of the shot point of the seismic channel, and determines the relative absorption attenuation coefficient of the detection point corresponding to the seismic channel based on the amplitude component of the detection point of the seismic channel. The relative absorption attenuation coefficient is used to represent the absorption and attenuation of seismic waves by the near surface.

[0149] In some embodiments, both the shot point amplitude component and the relative absorption attenuation coefficient of the shot point are used to represent the absorption attenuation of seismic waves by the near surface, but the relative absorption attenuation coefficient is a coefficient between 0 and 1. Alternatively, determining the relative absorption attenuation coefficient of the shot point corresponding to the seismic trace based on the shot point amplitude component of the seismic trace and determining the relative absorption attenuation coefficient of the detection point corresponding to the seismic trace based on the detection point amplitude component of the seismic trace includes: normalizing the shot point amplitude component of the seismic trace and the detection point amplitude component of the seismic trace to obtain the relative absorption attenuation coefficient of the shot point corresponding to the seismic trace and the relative absorption attenuation coefficient of the corresponding detection point.

[0150] In order to obtain a more accurate relative absorption attenuation coefficient based on the shot point amplitude component and the detection point amplitude component, before normalizing the shot point amplitude component of the seismic trace and the detection point amplitude component of the seismic trace to obtain the relative absorption attenuation coefficient of the shot point corresponding to the seismic trace and the relative absorption attenuation coefficient of the corresponding detection point, the shot point amplitude component and the detection point amplitude component can also be preprocessed. The method includes: removing outliers from the shot point amplitude component of the seismic trace and the detection point amplitude component of the seismic trace; interpolating the shot point amplitude component of the seismic trace and the detection point amplitude component of the seismic trace; and smoothing the shot point amplitude component of the seismic trace and the detection point amplitude component of the seismic trace.

[0151] For example, Figure 7 The relative absorption attenuation coefficients corresponding to multiple shot points and multiple detection points are shown. Figure 7 Different grayscale values ​​are used to represent different relative absorption attenuation coefficients. In practical applications, different colors can also be used to represent different relative absorption attenuation coefficients, which is a heat map showing the relative absorption attenuation coefficients.

[0152] 206. Based on the near-surface velocity model of the target area, the computer equipment determines the near-surface vertical one-way propagation time corresponding to each shot point and the near-surface vertical one-way propagation time corresponding to each detection point. The near-surface vertical one-way propagation time is the time required for the seismic wave to propagate vertically between the upper and lower surfaces of the near-surface.

[0153] In some embodiments, the near-surface velocity model is determined based on the first arrival time. After executing step 201 to obtain the first arrival time, the first arrival time can be processed using a reflection method or a tomography method to obtain the near-surface velocity model of the target area.

[0154] For example, a computer device uses a reflection method to generate a near-surface velocity model of a target area. The generation process may include: the computer device uses an interchange algorithm to process the first arrival time to obtain the velocity of the refraction layer; based on the velocity and the first arrival time of the refraction layer, the delay time of the shot point and the delay time of the detection point of the corresponding seismic trace are determined; based on the delay time of the shot point and the delay time of the detection point and the near-surface thickness, the near-surface velocity model is generated.

[0155] For another example, a computer device uses a tomographic method to generate a near-surface velocity model of a target area. The generation process may include: generating an initial near-surface velocity model, which is a gradient field; based on the near-surface velocity model, simulating the excitation from the shot point and the reception at the receiver point to obtain a first propagation time; based on the difference between the first propagation time and the corresponding first arrival time, correcting the near-surface velocity model to obtain the near-surface velocity model of the target area.

[0156] For example, Figure 8 The vertical one-way propagation time near the surface of multiple locations in the target area is shown, where: Figure 8 Different grayscale values ​​are used to represent different near-surface vertical one-way travel times. In practical applications, different colors can also be used to represent different near-surface vertical one-way travel times, that is, a heat map showing the near-surface vertical one-way travel time.

[0157] 207. The computer device generates the near-surface Q field of the target area based on the relative absorption attenuation coefficient of each shot point, the near-surface vertical one-way propagation time corresponding to each shot point, the relative absorption attenuation coefficient of each detection point, and the near-surface vertical one-way propagation time corresponding to each detection point.

[0158] In one possible implementation, assuming that the amplitude of the unattenuated first arrival wave is A0, and the amplitude of the first arrival wave recorded on the ground after near-surface attenuation is A, the following relationship exists between the two: Where R is the relative absorption attenuation coefficient, π is pi, f is the dominant frequency of the seismic data, t is the near-surface vertical one-way propagation time corresponding to the shot point or the near-surface vertical one-way propagation time corresponding to the receiver point, and Q is the formation quality factor.

[0159] Accordingly, the computer device generates a near-surface Q field of the target area based on the relative absorption attenuation coefficient of each shot point, the near-surface vertical one-way propagation time corresponding to each shot point, the relative absorption attenuation coefficient of each detection point, and the near-surface vertical one-way propagation time corresponding to each detection point, including: determining the Q value corresponding to each shot point based on the relative absorption attenuation coefficient of each shot point, the near-surface vertical one-way propagation time corresponding to each shot point, and the dominant frequency of the seismic data; determining the Q value corresponding to each detection point based on the relative absorption attenuation coefficient of each detection point, the near-surface vertical one-way propagation time corresponding to each detection point, and the dominant frequency of the seismic data; and generating the near-surface Q field of the target area based on the Q value corresponding to each shot point and the Q value corresponding to each detection point.

[0160] In some embodiments, the relationship between the relative absorption attenuation coefficient, the near-surface vertical one-way propagation time, the main frequency of the seismic data, and the Q value is as follows:

[0161] Q = -πft / LN(R);

[0162] Where Q is the Q value corresponding to the shot point or the Q value corresponding to the receiver point, π is pi, f is the dominant frequency of the seismic data, t is the near-surface vertical one-way propagation time corresponding to the shot point or the receiver point, LN is the natural logarithm function, and R is the relative absorption attenuation coefficient of the shot point or the receiver point.

[0163] For example, Figure 9 shows a near-surface Q field of a target area, where Figure 9 Different grayscale values ​​are used to represent different Q values. In practical applications, different colors can also be used to represent different Q values, that is, a heat map of the near-surface Q field of the target area is displayed.

[0164] It should be noted that the embodiment of the present application is only an illustrative illustration of the above-mentioned step 207, and does not limit the method of generating the near-surface Q field. In other embodiments, a near-surface Q field generation model can be trained based on the sample relative absorption attenuation coefficient of each sample shot point, the sample near-surface vertical one-way propagation time corresponding to each sample shot point, the sample relative absorption attenuation coefficient of each sample detection point, and the sample near-surface vertical one-way propagation time corresponding to each sample detection point, and the sample near-surface Q field of the sample area. The computer device processes the relative absorption attenuation coefficient of each shot point, the near-surface vertical one-way propagation time corresponding to each shot point, the relative absorption attenuation coefficient of each detection point, and the corresponding near-surface vertical one-way propagation time of each detection point through the near-surface Q field generation model to obtain the near-surface Q field of the target area.

[0165] 208. The computer device performs processing based on the near-surface Q field of the target area.

[0166] In practical applications, the near-surface Q field of the target area can be processed as needed. In some embodiments, the near-surface Q field is used for compensation processing. The computer device processes based on the near-surface Q field of the target area, including: the computer device performs compensation processing on the seismic data of the target area based on the near-surface Q field of the target area. Since the medium near the surface is relatively loose, the absorption and attenuation of seismic waves are relatively serious, and the near-surface Q field includes the attenuation strength parameters of seismic waves at multiple locations in the target area in the near surface. Therefore, the near-surface Q field can provide exact parameters for the energy and frequency compensation processing of seismic waves. Based on the near-surface Q field of the target area, the seismic data of the target area can be compensated, which can accurately and effectively improve the resolution of the seismic data.

[0167] In other embodiments, a computer device performs processing based on a near-surface Q field of a target area, including displaying the near-surface Q field of the target area by the computer device. The near-surface Q field includes formation quality factors at multiple near-surface locations. By displaying the near-surface Q field, a user can intuitively see the near-surface formation quality of the target area, change the positions of shot points and receiver points, minimize the impact of low-velocity layers on seismic waves, effectively improve the signal-to-noise ratio of seismic data, and enhance the quality of seismic data.

[0168] It should be noted that the embodiments of the present application are merely illustrative of the processing of the near-surface Q field, and do not limit the processing based on the near-surface Q field.

[0169] The near-surface Q-field generation method provided in the embodiments of the present application decomposes the root mean square amplitude of the first arrival wave to obtain the amplitude components of the shot point and the receiver point. Based on the amplitude components of the shot point and the receiver point, the amplitude components of the shot point and the receiver point are determined, and the relative absorption attenuation coefficients of the shot point and the receiver point are determined. The near-surface Q-field is generated based on the relative absorption attenuation coefficients of the shot point and the receiver point and the vertical one-way propagation time of the seismic wave in the near-surface. Since the first arrival wave is not reflected by the underground interface but is excited by the shot point and then reaches the receiver point through the near-surface, it is primarily affected by the near-surface and thus contains rich near-surface absorption attenuation information, ensuring the accuracy of the relative absorption attenuation coefficients of the shot point and the receiver point. Since the near-surface vertical one-way propagation time of the seismic wave is also affected by the near-surface geology, the near-surface Q-field can be more accurately obtained by combining the relative absorption attenuation coefficients of the shot point and the receiver point and the vertical one-way propagation time of the seismic wave in the near-surface, thereby improving the accuracy of the near-surface Q-field.

[0170] Figure 10 Schematic diagram of a near-surface Q field generating device provided in an embodiment of the present application. Figure 10 As shown, the device includes:

[0171] The interception module 1001 is used to intercept the first arrival waves of multiple seismic traces from the seismic data of the target area. One seismic trace corresponds to one shot point and one receiver point. The first arrival wave of a seismic trace is the first seismic wave detected by the receiver point of the seismic trace after the shot point of the seismic trace excites the earthquake, including the amplitudes corresponding to multiple acquisition points.

[0172] The statistical module 1002 is used to perform statistical processing on the amplitudes corresponding to multiple acquisition points in the first arrival wave of each seismic trace, and obtain the root mean square amplitude corresponding to each seismic trace;

[0173] Decomposition module 1003, configured to decompose the root mean square amplitude corresponding to each seismic trace to obtain a shot point amplitude component and a receiver point amplitude component corresponding to each seismic trace. The shot point amplitude component is used to represent the influence of the near surface on the downgoing seismic wave, and the receiver point amplitude component is used to represent the influence of the near surface on the upgoing reflected wave.

[0174] A coefficient determination module 1004 is configured to determine, for each seismic trace, a relative absorption attenuation coefficient of the shot point corresponding to the seismic trace based on the shot point amplitude component of the seismic trace, and a relative absorption attenuation coefficient of the receiver point corresponding to the seismic trace based on the receiver point amplitude component of the seismic trace. The relative absorption attenuation coefficient is used to represent the absorption attenuation of seismic waves by the near surface.

[0175] The time determination module 1005 is used to determine the near-surface vertical one-way propagation time corresponding to each shot point and each receiver point based on the near-surface velocity model of the target area. The near-surface vertical one-way propagation time is the time required for a seismic wave to propagate vertically once between the upper and lower surfaces of the near-surface.

[0176] A generating module 1006 is configured to generate a near-surface Q field of the target area based on the relative absorption attenuation coefficient of each shot point, the near-surface vertical one-way propagation time corresponding to each shot point, the relative absorption attenuation coefficient of each receiver point, and the near-surface vertical one-way propagation time corresponding to each receiver point;

[0177] The processing module 1007 is configured to perform processing based on the near-surface Q field of the target area.

[0178] like Figure 11 As shown, in one possible implementation, the generation module 1006 is used to determine the Q value corresponding to each shot point based on the relative absorption attenuation coefficient of each shot point, the near-surface vertical one-way propagation time corresponding to each shot point, and the dominant frequency of the seismic data; determine the Q value corresponding to each detection point based on the relative absorption attenuation coefficient of each detection point, the near-surface vertical one-way propagation time corresponding to each detection point, and the dominant frequency of the seismic data; and generate the near-surface Q field of the target area based on the Q value corresponding to each shot point and the Q value corresponding to each detection point.

[0179] In one possible implementation, the relationship between the relative absorption attenuation coefficient, the near-surface vertical one-way propagation time, the dominant frequency of the seismic data, and the Q value is as follows:

[0180] Q = -πft / LN(R);

[0181] Where Q is the Q value corresponding to the shot point or the Q value corresponding to the receiver point, π is pi, f is the dominant frequency of the seismic data, t is the near-surface vertical one-way propagation time corresponding to the shot point or the receiver point, LN is the natural logarithm function, and R is the relative absorption attenuation coefficient of the shot point or the receiver point.

[0182] In a possible implementation, the interception module 1001 includes:

[0183] The time determination unit 1011 is used to extract the first arrival time of multiple seismic traces from the seismic data of the target area. The first arrival time of a seismic trace is the time when the first seismic wave is detected by the receiver point of the seismic trace after the shot point of the seismic trace excites the earthquake;

[0184] The interception unit 1021 is configured to intercept the first arrival waves of the multiple seismic traces from the seismic data of the target area based on the first arrival times of the multiple seismic traces.

[0185] In a possible implementation, the interception unit 1021 is used to display a first arrival wave interception interface, which includes seismic data, the first arrival times of multiple seismic traces, and a first time length input box and a second time length input box; based on the first time length input box, the input first time length is obtained, and based on the second time length input box, the input second time length is obtained; for any seismic trace, the third time obtained by subtracting the first time length from the first arrival time of the seismic trace is used as the starting time of the first arrival wave interception time window of the seismic trace, and the fourth time obtained by adding the second time length to the first arrival time of the seismic trace is used as the ending time of the first arrival wave interception time window of the seismic trace; based on the first arrival wave interception time windows of multiple seismic traces, the first arrival waves of multiple seismic traces are intercepted from the seismic data of the target area.

[0186] In one possible implementation, the coefficient determination module 1004 is used to normalize the shot point amplitude component and the detection point amplitude component of the seismic trace to obtain the relative absorption attenuation coefficient of the shot point and the relative absorption attenuation coefficient of the corresponding detection point of the seismic trace.

[0187] In one possible implementation, the apparatus further includes a preprocessing module 1008, which is configured to perform at least one of the following:

[0188] Perform outlier elimination processing on the amplitude components of the shot points and the amplitude components of the receiver points of the seismic trace;

[0189] Perform interpolation processing on the shot point amplitude component of the seismic trace and the receiver point amplitude component of the seismic trace;

[0190] The amplitude components of the shot points and the amplitude components of the receiver points of the seismic trace are smoothed.

[0191] It should be noted that the aforementioned embodiments provide only examples of the division of the aforementioned functional modules when generating the near-surface Q field by the near-surface Q field generation device. In actual applications, the aforementioned functions can be assigned to different functional modules as needed, i.e., the internal structure of the computer device can be divided into different functional modules to perform all or part of the functions described above. Furthermore, the near-surface Q field generation device and the near-surface Q field generation method embodiments provided in the aforementioned embodiments share the same concept. The specific implementation process is detailed in the method embodiments and will not be further elaborated here.

[0192] In some embodiments, the computer device is provided as a terminal. Figure 12 1 is a block diagram of a terminal 1200 provided in an embodiment of the present application. The terminal 1200 includes: a processor 1201 and a memory 1202.

[0193] The processor 1201 may include one or more processing cores, such as a 4-core processor, an 8-core processor, etc. The processor 1201 may be implemented in at least one hardware form of DSP (Digital Signal Processing), FPGA (Field-Programmable Gate Array), or PLA (Programmable Logic Array). The processor 1201 may also include a main processor and a coprocessor. The main processor is a processor for processing data in the awake state, also known as a CPU (Central Processing Unit); the coprocessor is a low-power processor for processing data in the standby state. In some embodiments, the processor 1201 may be integrated with a GPU (Graphics Processing Unit), which is responsible for rendering and drawing the content to be displayed on the display screen. In some embodiments, the processor 1201 may also include an AI (Artificial Intelligence) processor, which is used to process computing operations related to machine learning.

[0194] Memory 1202 may include one or more computer-readable storage media, which may be non-transitory. Memory 1202 may also include high-speed random access memory and non-volatile memory, such as one or more disk storage devices and flash memory storage devices. In some embodiments, the non-transitory computer-readable storage medium in memory 1202 is used to store at least one program code, which is executed by processor 1201 to implement the near-surface Q field generation method provided in the method embodiment of the present application.

[0195] In some embodiments, terminal 1200 may optionally include a peripheral device interface 1203 and at least one peripheral device. The processor 1201, memory 1202, and peripheral device interface 1203 may be connected via a bus or signal lines. Each peripheral device may be connected to peripheral device interface 1203 via a bus, signal lines, or circuit boards. Specifically, the peripheral device may include at least one of a radio frequency circuit 1204, a display screen 1205, a camera 1206, an audio circuit 1207, a positioning component 1208, and a power supply 1209.

[0196] The peripheral device interface 1203 can be used to connect at least one I / O (Input / Output)-related peripheral device to the processor 1201 and the memory 1202. In some embodiments, the processor 1201, the memory 1202, and the peripheral device interface 1203 are integrated on the same chip or circuit board; in some other embodiments, any one or two of the processor 1201, the memory 1202, and the peripheral device interface 1203 can be implemented on separate chips or circuit boards, which is not limited in this embodiment.

[0197] The display screen 1205 is used to display a UI (User Interface). The UI may include graphics, text, icons, videos, and any combination thereof. When the display screen 1205 is a touch screen display, the display screen 1205 also has the ability to collect touch signals on the surface or above the surface of the display screen 1205. The touch signal can be input as a control signal to the processor 1201 for processing. In this case, the display screen 1205 can also be used to provide virtual buttons and / or virtual keyboards, also known as soft buttons and / or soft keyboards. In some embodiments, there can be one display screen 1205, which is set on the front panel of the terminal 1200; in other embodiments, there can be at least two display screens 1205, which are respectively set on different surfaces of the terminal 1200 or in a folding design; in still other embodiments, the display screen 1205 can be a flexible display screen, which is set on the curved surface or folding surface of the terminal 1200. Even more, the display screen 1205 can be set as a non-rectangular irregular shape, that is, a special-shaped screen. The display screen 1205 can be made of materials such as LCD (Liquid Crystal Display) and OLED (Organic Light-Emitting Diode).

[0198] Power supply 1209 is used to power various components in terminal 1200. Power supply 1209 can be AC ​​power, DC power, a disposable battery, or a rechargeable battery. When power supply 1209 includes a rechargeable battery, the rechargeable battery can support wired charging or wireless charging. The rechargeable battery can also be used to support fast charging technology.

[0199] Those skilled in the art will understand that Figure 12 The structure shown in the figure does not constitute a limitation on the terminal 1200, and the terminal 1200 may include more or fewer components than shown in the figure, or combine certain components, or adopt a different component arrangement.

[0200] In some embodiments, the computer device is provided as a server. Figure 13 1 is a schematic diagram of the structure of a server provided in an embodiment of the present application. The server 1300 may vary significantly due to different configurations or performances, and may include one or more processors (Central Processing Units, CPU) 1301 and one or more memories 1302, wherein the memories 1302 store at least one program code, which is loaded and executed by the processor 1301 to implement the methods provided in the above-mentioned various method embodiments. Of course, the server may also have components such as a wired or wireless network interface, a keyboard, and an input / output interface for input and output. The server may also include other components for implementing device functions, which will not be described in detail here.

[0201] In some embodiments, computer devices are provided as terminals and servers, and the terminals and servers cooperate with each other to complete the above-mentioned near-surface Q field generation method. The embodiments of the present application do not limit the steps performed by the terminals and servers respectively during the near-surface Q field generation process.

[0202] An embodiment of the present application also provides a computer-readable storage medium, which stores at least one program code, and the at least one program code is loaded and executed by a processor to implement the near-surface Q field generation method as described in any of the above implementation methods.

[0203] An embodiment of the present application further provides a computer program product, which includes at least one program code, and the at least one program code is loaded and executed by a processor to implement the near-surface Q field generation method as described in any of the above implementations.

[0204] In some embodiments, the computer program involved in the embodiments of the present application may be deployed and executed on a computer device, or on multiple computer devices located at one location, or on multiple computer devices distributed at multiple locations and interconnected through a communication network. Multiple computer devices distributed at multiple locations and interconnected through a communication network may constitute a blockchain system.

[0205] The above are only optional embodiments of the present application and are not intended to limit the present application. Any modifications, equivalent replacements, improvements, etc. made within the spirit and principles of the present application should be included in the scope of protection of the present application.

Claims

1. A near-surface Q field generation method, characterized in that: The method comprises: Extracting first arrival waves of multiple seismic traces from seismic data of the target area, where each seismic trace corresponds to a shot point and a detector point. The first arrival wave of the seismic trace is the first seismic wave detected by the detector point of the seismic trace after the shot point of the seismic trace excites the earthquake, and includes amplitudes corresponding to multiple acquisition points. Performing statistical processing on the amplitudes corresponding to multiple acquisition points in the first arrival wave of each seismic trace to obtain the root mean square amplitude corresponding to each seismic trace; Decomposing the root mean square amplitude corresponding to each seismic trace to obtain a shot point amplitude component and a receiver point amplitude component corresponding to each seismic trace, wherein the shot point amplitude component is used to represent the influence of the near surface on the downgoing seismic wave, and the receiver point amplitude component is used to represent the influence of the near surface on the upgoing reflected wave; For each seismic trace, determining a relative absorption attenuation coefficient of the shot point corresponding to the seismic trace based on the shot point amplitude component of the seismic trace, and determining a relative absorption attenuation coefficient of the detection point corresponding to the seismic trace based on the detection point amplitude component of the seismic trace, wherein the relative absorption attenuation coefficient is used to represent the absorption attenuation of seismic waves by the near surface; Determining the near-surface vertical one-way propagation time corresponding to each shot point and each receiver point based on a near-surface velocity model of the target area, wherein the near-surface vertical one-way propagation time is the time required for a seismic wave to propagate vertically once between the upper and lower surfaces of the near-surface; generating a near-surface Q field of the target area based on the relative absorption attenuation coefficient of each shot point, the near-surface vertical one-way propagation time corresponding to each shot point, the relative absorption attenuation coefficient of each detection point, and the near-surface vertical one-way propagation time corresponding to each detection point; Processing is performed based on the near-surface Q field of the target area.

2. The method according to claim 1, characterized in that Generating the near-surface Q field of the target area based on the relative absorption attenuation coefficient of each shot point, the near-surface vertical one-way propagation time corresponding to each shot point, the relative absorption attenuation coefficient of each detection point, and the near-surface vertical one-way propagation time corresponding to each detection point includes: Determining a Q value corresponding to each shot point based on a relative absorption attenuation coefficient of each shot point, a near-surface vertical one-way propagation time corresponding to each shot point, and a dominant frequency of the seismic data; Determine the Q value corresponding to each detection point based on the relative absorption attenuation coefficient of each detection point, the near-surface vertical one-way propagation time corresponding to each detection point, and the main frequency of the seismic data; A near-surface Q field of the target area is generated based on the Q value corresponding to each shot point and the Q value corresponding to each detection point.

3. The method according to claim 2, characterized in that The relationship between the relative absorption attenuation coefficient, the near-surface vertical one-way propagation time, the main frequency of the seismic data, and the Q value is as follows: Q = -πft / LN(R); Where Q is the Q value corresponding to the shot point or the Q value corresponding to the receiver point, π is pi, f is the dominant frequency of the seismic data, t is the near-surface vertical one-way propagation time corresponding to the shot point or the receiver point, LN is the natural logarithm function, and R is the relative absorption attenuation coefficient of the shot point or the receiver point.

4. The method according to claim 1, wherein The method of intercepting first arrival waves of a plurality of seismic traces from seismic data of a target area includes: Picking up the first arrival times of multiple seismic traces from the seismic data of the target area, where the first arrival time of the seismic trace is the time when the first seismic wave is detected by the receiver point of the seismic trace after the shot point of the seismic trace excites the earthquake; Based on the first arrival times of the multiple seismic traces, first arrival waves of the multiple seismic traces are intercepted from the seismic data of the target area.

5. The method according to claim 4, characterized in that The method of extracting first arrival waves of a plurality of seismic traces from the seismic data of the target area based on the first arrival time includes: Displaying a first-break wave interception interface, the first-break wave interception interface including the seismic data, the first-break times of the multiple seismic traces, and a first duration input box and a second duration input box; Based on the first duration input box, obtain the first duration input, and based on the second duration input box, obtain the second duration input; For any seismic trace, a third time obtained by subtracting the first time length from the first arrival time of the seismic trace is used as the start time of the first arrival wave interception time window of the seismic trace, and a fourth time obtained by adding the second time length to the first arrival time of the seismic trace is used as the end time of the first arrival wave interception time window of the seismic trace; The first arrival waves of the plurality of seismic traces are intercepted from the seismic data of the target area based on the first arrival wave interception time window of the plurality of seismic traces.

6. The method according to claim 1, characterized in that The step of determining the relative absorption attenuation coefficient of the shot point corresponding to the seismic trace based on the shot point amplitude component of the seismic trace, and determining the relative absorption attenuation coefficient of the detection point corresponding to the seismic trace based on the detection point amplitude component of the seismic trace, comprises: The shot point amplitude component of the seismic trace and the detection point amplitude component of the seismic trace are normalized to obtain the relative absorption attenuation coefficient of the shot point and the relative absorption attenuation coefficient of the detection point corresponding to the seismic trace.

7. The method according to claim 6, characterized in that Before normalizing the shot point amplitude component of the seismic trace and the detection point amplitude component of the seismic trace to obtain the relative absorption attenuation coefficient of the shot point and the relative absorption attenuation coefficient of the detection point corresponding to the seismic trace, the method further includes at least one of the following: Performing outlier elimination processing on the shot point amplitude component of the seismic trace and the detection point amplitude component of the seismic trace; interpolating the shot point amplitude component of the seismic trace and the receiver point amplitude component of the seismic trace; Smoothing is performed on the shot point amplitude component of the seismic trace and the detection point amplitude component of the seismic trace.

8. A near-surface Q-field generating device, characterized in that: The device comprises: An interception module is used to intercept the first arrival waves of multiple seismic traces from the seismic data of the target area. One seismic trace corresponds to one shot point and one detection point. The first arrival wave of the seismic trace is the first seismic wave detected by the detection point of the seismic trace after the shot point of the seismic trace excites the earthquake, including the amplitudes corresponding to multiple acquisition points. A statistical module is used to perform statistical processing on the amplitudes corresponding to multiple acquisition points in the first arrival wave of each seismic trace, so as to obtain the root mean square amplitude corresponding to each seismic trace; a decomposition module, configured to decompose the root mean square amplitude corresponding to each seismic trace to obtain a shot point amplitude component and a receiver point amplitude component corresponding to each seismic trace, wherein the shot point amplitude component is used to represent the influence of the near surface on the downgoing seismic wave, and the receiver point amplitude component is used to represent the influence of the near surface on the upgoing reflected wave; a coefficient determination module configured to determine, for each seismic trace, a relative absorption attenuation coefficient of a shot point corresponding to the seismic trace based on a shot point amplitude component of the seismic trace, and a relative absorption attenuation coefficient of a detection point corresponding to the seismic trace based on a detection point amplitude component of the seismic trace, wherein the relative absorption attenuation coefficient is used to represent the absorption attenuation of seismic waves by the near surface; a time determination module for determining the near-surface vertical one-way propagation time corresponding to each shot point and the near-surface vertical one-way propagation time corresponding to each receiver point based on the near-surface velocity model of the target area, wherein the near-surface vertical one-way propagation time is the time required for a seismic wave to propagate vertically once between the upper and lower surfaces of the near-surface; a generating module, configured to generate a near-surface Q field of the target area based on the relative absorption attenuation coefficient of each shot point, the near-surface vertical one-way propagation time corresponding to each shot point, the relative absorption attenuation coefficient of each detection point, and the near-surface vertical one-way propagation time corresponding to each detection point; A processing module is used to perform processing based on the near-surface Q field of the target area.

9. A computer device, characterized in that: The computer device includes a processor and a memory, wherein the memory stores at least one program code, and the at least one program code is loaded and executed by the processor to implement the near-surface Q field generation method according to any one of claims 1 to 7.

10. A computer-readable storage medium, characterized in that The computer-readable storage medium stores at least one program code, and the at least one program code is loaded and executed by a processor to implement the near-surface Q field generation method according to any one of claims 1 to 7.

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