Methods, devices, computer equipment, and storage media for velocity processing of seismic data

Abstract

This application provides a method, apparatus, computer equipment, and storage medium for velocity processing of seismic data, belonging to the field of seismic data processing technology. The method performs stacking velocity analysis on P-wave seismic data from seabed nodes to obtain the optimal P-wave stacking velocity and P-wave anisotropy parameters under two reference planes. These are then converted to a unified reference plane, and velocity migration is performed based on the pre-stack time migration velocity parameters of the P-waves under both reference planes. This fully considers the differences in conditions between acquiring P-wave seismic data from seabed nodes and land nodes, resulting in accurate velocity analysis results and improving the accuracy of seismic data velocity processing.

Description

Technical Field

[0001] This application relates to the field of seismic data processing technology, and in particular to a method, apparatus, computer equipment, and storage medium for velocity processing of seismic data. Background Technology

[0002] OBN (Ocean Bottom Node) seismic exploration technology employs a sea surface excitation and seabed reception method for seismic exploration. For land P-wave seismic data, it is assumed that the shot point and receiver are on the same horizontal plane, the propagation path of the seismic wave from the excitation point to the receiver is symmetrical, and the midpoint of the shot-receiver point is also the location of the reflection point. Therefore, the common reflection point gather for land P-waves is also a common center point gather, meaning the location of the reflection point of land P-waves depends only on the positions of the shot point and receiver, as well as the offset, and is independent of factors such as the depth and velocity of the reflection interface. However, in OBN seismic exploration, the excitation point and receiver are not on the same horizontal plane, and there are at least two layers of medium above the reflection point, which differs from the assumption that the medium above the reflection interface on land is homogeneous. During propagation, the seismic wave first passes through the seawater layer and then penetrates into the formation at the seabed interface. Due to the non-parallel horizontal plane of the shot-receiver point and the presence of the water layer, the reflection point location of the P-wave is no longer simply the midpoint of the shot-receiver point, and the common reflection point gather is no longer a common center point gather. Currently, seismic data processing is based on the assumption that shot and receiver points are located on the same horizontal plane, which obviously leads to inaccurate velocity processing results for seismic data. Summary of the Invention

[0003] This application provides a method, apparatus, computer device, and storage medium for velocity processing of seismic data, which can improve the accuracy of the velocity processing results of seismic data. The technical solution is as follows.

[0004] On the one hand, a velocity processing method for seismic data is provided, the method comprising:

[0005] Acquire P-wave seismic data of the seabed nodes in the target work area;

[0006] By using the first correspondence, the stacking velocity analysis is performed on the P-wave seismic data to obtain the P-wave stacking velocity and P-wave anisotropy parameters under the dual reference plane. The first correspondence is the correspondence between the P-wave seismic data, the P-wave stacking velocity and the P-wave anisotropy parameters under the dual reference plane.

[0007] By using the second correspondence, the P-wave stacking velocity and P-wave anisotropy parameter under the dual reference plane are transformed to obtain the P-wave pre-stack time migration velocity parameter under the unified reference plane. The second correspondence is the correspondence between the P-wave stacking velocity and P-wave anisotropy parameter under the dual reference plane and the P-wave pre-stack time migration velocity parameter under the unified reference plane. The P-wave pre-stack time migration parameter includes the P-wave migration velocity and the P-wave anisotropy parameter.

[0008] By transforming the P-wave pre-stack time migration velocity parameter under the unified reference plane through the third correspondence, the P-wave pre-stack time migration parameter under the seabed reference plane is obtained. The third correspondence is the correspondence between the P-wave pre-stack time migration velocity parameter under the unified reference plane and the P-wave pre-stack time migration parameter under the seabed reference plane.

[0009] Pre-stack time migration is performed on the P-wave pre-stack time migration parameters under the unified reference plane and the P-wave pre-stack time migration parameters under the seabed reference plane to obtain common imaging point gathers.

[0010] Based on the common imaging point gather, the P-wave stacking velocity and P-wave anisotropy parameters under the dual reference planes are corrected.

[0011] Based on the corrected P-wave stacking velocity and P-wave anisotropy parameters under the dual reference planes, the steps of obtaining common imaging point gathers are repeated until a common imaging point gather with the phase axis flattened is obtained. The pre-stack time migration parameters of P-waves under the seabed reference plane corresponding to the pre-stack time migration parameters of the common imaging point gather with the phase axis flattened are output as target P-wave pre-stack time migration parameters. The target P-wave pre-stack time migration parameters are used for P-wave pre-stack time migration imaging.

[0012] In some embodiments, the pre-stack time migration of the P-wave pre-stack time migration parameters under the unified reference plane and the P-wave pre-stack time migration parameters under the seabed reference plane to obtain a common imaging point gather includes:

[0013] Based on the P-wave pre-stack time migration parameters under the unified reference plane, the P-wave pre-stack time migration parameters under the seabed reference plane, the first horizontal distance, the second horizontal distance, the downgoing P-wave travel time, and the upgoing P-wave travel time, the P-wave travel time is obtained through the P-wave scattering equation. The P-wave scattering equation is the relationship equation between the P-wave pre-stack time migration parameters under the unified reference plane, the P-wave pre-stack time migration parameters under the seabed reference plane, the first horizontal distance, the second horizontal distance, the downgoing P-wave travel time, the upgoing P-wave travel time, and the P-wave travel time. The first horizontal distance is the horizontal distance between the scattering point and the shot point, and the second horizontal distance is the horizontal distance between the scattering point and the receiver point.

[0014] The common imaging point gather is obtained based on the longitudinal wave travel time.

[0015] In some embodiments, the method further includes:

[0016] For each seismic trace in the common imaging point set, determine the smoothed depth of the detector point of the seismic trace;

[0017] Determine the quotient of the smoothed depth and the shallow longitudinal wave replacement velocity;

[0018] The difference between the downlink P-wave travel time and the quotient is determined as the uplink P-wave travel time.

[0019] In some embodiments, determining the smoothed depth of the receiver points of the seismic trace includes:

[0020] Based on a preset radius, multiple common center points on the seabed are divided to obtain multiple common center points within multiple circular regions;

[0021] The average depth of multiple common center points within each circular region is indeed the smoothed depth of the circular region;

[0022] If the depth fluctuation value of the seabed is not greater than the preset value, the depth of the detector point is smoothed to the depth after smoothing the corresponding common center point.

[0023] When the depth fluctuation value of the seabed is greater than the preset value, the smoothed depth of the circular region where the detector point is located is determined as the smoothed depth of the detector point.

[0024] In some embodiments, the method further includes:

[0025] Based on the third horizontal distance and the shot-receiver distance, a fourth horizontal distance is determined. The third horizontal distance is the horizontal distance between the shot point and the incident point on the seabed, and the fourth horizontal distance is the horizontal distance between the incident point and the receiver point.

[0026] Based on the fourth horizontal distance, a fifth horizontal distance is determined, which is the horizontal distance between the incident point and the reflection point;

[0027] Based on the water layer velocity, water layer depth, target layer depth, underground equivalent velocity, and the fifth horizontal distance of the target work area, the angle of incidence between the shot point and the reflection point is determined;

[0028] Based on the incident angle, update the third horizontal distance; based on the updated third horizontal distance, update the fourth horizontal distance; based on the updated fourth horizontal distance, update the fifth horizontal distance; based on the updated fifth horizontal distance, update the incident angle.

[0029] The steps of updating the third horizontal distance, the fourth horizontal distance, the fifth horizontal distance, and the incident angle are executed iteratively until the iteration stop condition is met, and the target third horizontal distance, the target fourth horizontal distance, and the target fifth horizontal distance are obtained.

[0030] Based on the third and fifth horizontal distances of the target, a sixth horizontal distance is obtained, which is the horizontal distance between the shot point and the reflection point; based on the sixth horizontal distance, the first horizontal distance is obtained.

[0031] Based on the fourth horizontal distance and the fifth horizontal distance of the target, a seventh horizontal distance is obtained, which is the horizontal distance between the detector point and the reflection point; based on the seventh horizontal distance, a second horizontal distance is obtained.

[0032] In some embodiments, correcting the P-wave stacking velocity and P-wave anisotropy parameters under the dual reference planes based on the common imaging point gather includes:

[0033] Based on the remaining time difference in the common imaging point gather, the P-wave stacking velocity and P-wave anisotropy parameters under the dual reference plane are corrected through the first correspondence to obtain the corrected P-wave stacking velocity and P-wave anisotropy parameters under the dual reference plane. The remaining time difference is the difference between the time value on the common imaging point gather and the time value when the in-phase axis is leveled.

[0034] On the other hand, a velocity processing apparatus for seismic data is provided, the apparatus comprising:

[0035] The acquisition module is used to acquire P-wave seismic data of the seabed nodes in the target work area;

[0036] The analysis module is used to perform stacking velocity analysis on the P-wave seismic data through a first correspondence relationship to obtain the P-wave stacking velocity and P-wave anisotropy parameters under the dual reference planes. The first correspondence relationship is the correspondence between the P-wave seismic data, the P-wave stacking velocity and the P-wave anisotropy parameters under the dual reference planes.

[0037] The transformation module is used to transform the P-wave stacking velocity and P-wave anisotropy parameters under the dual reference planes through a second correspondence relationship to obtain the P-wave pre-stack time migration velocity parameters under a unified reference plane. The second correspondence relationship is the correspondence between the P-wave stacking velocity and P-wave anisotropy parameters under the dual reference planes and the P-wave pre-stack time migration velocity parameters under the unified reference plane. The P-wave pre-stack time migration parameters include the P-wave migration velocity and the P-wave anisotropy parameters.

[0038] The transformation module is also used to transform the pre-stack time migration velocity parameter of the P-wave under the unified reference plane through a third correspondence relationship to obtain the pre-stack time migration parameter of the P-wave under the seabed reference plane. The third correspondence relationship is the correspondence between the pre-stack time migration velocity parameter of the P-wave under the unified reference plane and the pre-stack time migration parameter of the P-wave under the seabed reference plane.

[0039] The analysis module is also used to perform pre-stack time migration on the pre-stack time migration parameters of P-waves under the unified reference plane and the pre-stack time migration parameters of P-waves under the seabed reference plane to obtain common imaging point gathers.

[0040] The correction module is used to correct the P-wave stacking velocity and P-wave anisotropy parameters under the dual reference planes based on the common imaging point gather.

[0041] The determination module is used to repeatedly obtain the common imaging point gather based on the P-wave stacking velocity and P-wave anisotropy parameters under the corrected dual reference planes until a common imaging point gather with the phase axis flattened is obtained. The P-wave pre-stack time migration parameters under the seabed reference plane corresponding to the common imaging point gather with the phase axis flattened are output as target P-wave pre-stack time migration parameters, which are used for P-wave pre-stack time migration imaging.

[0042] In some embodiments, the analysis module is configured to:

[0043] Based on the P-wave pre-stack time migration parameters under the unified reference plane, the P-wave pre-stack time migration parameters under the seabed reference plane, the first horizontal distance, the second horizontal distance, the downgoing P-wave travel time, and the upgoing P-wave travel time, the P-wave travel time is obtained through the P-wave scattering equation. The P-wave scattering equation is the relationship equation between the P-wave pre-stack time migration parameters under the unified reference plane, the P-wave pre-stack time migration parameters under the seabed reference plane, the first horizontal distance, the second horizontal distance, the downgoing P-wave travel time, the upgoing P-wave travel time, and the P-wave travel time. The first horizontal distance is the horizontal distance between the scattering point and the shot point, and the second horizontal distance is the horizontal distance between the scattering point and the receiver point.

[0044] The common imaging point gather is obtained based on the longitudinal wave travel time.

[0045] In some embodiments, the determining module is further configured to:

[0046] For each seismic trace in the common imaging point set, determine the smoothed depth of the detector point of the seismic trace;

[0047] Determine the quotient of the smoothed depth and the shallow longitudinal wave replacement velocity;

[0048] The difference between the downlink P-wave travel time and the quotient is determined as the uplink P-wave travel time.

[0049] In some embodiments, the determining module is configured to:

[0050] Based on a preset radius, multiple common center points on the seabed are divided to obtain multiple common center points within multiple circular regions;

[0051] The average depth of multiple common center points within each circular region is indeed the smoothed depth of the circular region;

[0052] If the depth fluctuation value of the seabed is not greater than the preset value, the depth of the detector point is smoothed to the depth after smoothing the corresponding common center point.

[0053] When the depth fluctuation value of the seabed is greater than the preset value, the smoothed depth of the circular region where the detector point is located is determined as the smoothed depth of the detector point.

[0054] In some embodiments, the determining module is further configured to:

[0055] Based on the third horizontal distance and the shot-receiver distance, a fourth horizontal distance is determined. The third horizontal distance is the horizontal distance between the shot point and the incident point on the seabed, and the fourth horizontal distance is the horizontal distance between the incident point and the receiver point.

[0056] Based on the fourth horizontal distance, a fifth horizontal distance is determined, which is the horizontal distance between the incident point and the reflection point;

[0057] Based on the water layer velocity, water layer depth, target layer depth, underground equivalent velocity, and the fifth horizontal distance of the target work area, the angle of incidence between the shot point and the reflection point is determined;

[0058] Based on the incident angle, update the third horizontal distance; based on the updated third horizontal distance, update the fourth horizontal distance; based on the updated fourth horizontal distance, update the fifth horizontal distance; based on the updated fifth horizontal distance, update the incident angle.

[0059] The steps of updating the third horizontal distance, the fourth horizontal distance, the fifth horizontal distance, and the incident angle are executed iteratively until the iteration stop condition is met, and the target third horizontal distance, the target fourth horizontal distance, and the target fifth horizontal distance are obtained.

[0060] Based on the third and fifth horizontal distances of the target, a sixth horizontal distance is obtained, which is the horizontal distance between the shot point and the reflection point; based on the sixth horizontal distance, the first horizontal distance is obtained.

[0061] Based on the fourth horizontal distance and the fifth horizontal distance of the target, a seventh horizontal distance is obtained, which is the horizontal distance between the detector point and the reflection point; based on the seventh horizontal distance, a second horizontal distance is obtained.

[0062] In some embodiments, the correction module is configured to:

[0063] Based on the remaining time difference in the common imaging point gather, the P-wave stacking velocity and P-wave anisotropy parameters under the dual reference plane are corrected through the first correspondence to obtain the corrected P-wave stacking velocity and P-wave anisotropy parameters under the dual reference plane. The remaining time difference is the difference between the time value on the common imaging point gather and the time value when the in-phase axis is leveled.

[0064] On the other hand, a computer device is provided, the computer device including one or more processors and one or more memories, the one or more memories storing at least one piece of program code, the at least one piece of program code being loaded and executed by the one or more processors to implement the seismic data velocity processing method described in any of the above implementations.

[0065] On the other hand, a computer-readable storage medium is provided, wherein at least one piece of program code is stored in the computer-readable storage medium, the at least one piece of program code being loaded and executed by a processor to implement the seismic data velocity processing method described in any of the above implementations.

[0066] On the other hand, a computer program product is provided, the computer program product including computer program code stored in a computer-readable storage medium, a processor of a computer device reading the computer program code from the computer-readable storage medium, the processor executing the computer program code, causing the computer device to perform the seismic data velocity processing method described in any of the above implementations.

[0067] The beneficial effects of the technical solutions provided in this application include at least the following:

[0068] This application provides a velocity processing method for seismic data. The method performs stacking velocity analysis on P-wave seismic data from seabed nodes to obtain the optimal P-wave stacking velocity and P-wave anisotropy parameters under two reference planes. Then, it converts these parameters to a unified reference plane and performs velocity migration based on the pre-stack time migration velocity parameters of the P-waves under the two reference planes. This fully considers the differences between the conditions when acquiring P-wave seismic data from seabed nodes and those when acquiring P-wave seismic data from land nodes, and can obtain accurate velocity analysis results, thereby improving the accuracy of the velocity processing results of seismic data. Attached Figure Description

[0069] To more clearly illustrate the technical solutions in the embodiments of this application, the accompanying drawings used in the description of the embodiments will be briefly introduced below. Obviously, the accompanying drawings described below are only some embodiments of this application. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0070] Figure 1 This is a schematic diagram of an implementation environment provided in an embodiment of this application;

[0071] Figure 2 This is a flowchart of a velocity processing method for seismic data provided in an embodiment of this application;

[0072] Figure 3 This is a flowchart illustrating the calculation of a reflection point position according to an embodiment of this application;

[0073] Figure 4 This is an analysis flowchart of an initial velocity model for pre-stack time migration of longitudinal waves provided in an embodiment of this application;

[0074] Figure 5 This is a flowchart illustrating the analysis of pre-stack time migration velocity of longitudinal waves provided in an embodiment of this application;

[0075] Figure 6 This is a schematic diagram illustrating the velocity analysis effect under a unified reference plane provided in an embodiment of this application;

[0076] Figure 7 This is a schematic diagram illustrating the velocity analysis effect under dual reference planes provided in an embodiment of this application;

[0077] Figure 8 This is a block diagram of a velocity processing device for seismic data provided in an embodiment of this application;

[0078] Figure 9 This is a block diagram of a terminal provided in an embodiment of this application;

[0079] Figure 10 This is a block diagram of a server provided in an embodiment of this application. Detailed Implementation

[0080] To make the objectives, technical solutions, and advantages of this application clearer, the embodiments of this application will be described in further detail below with reference to the accompanying drawings.

[0081] It should be noted that the user information involved in this application (including but not limited to user device information, user personal information, etc.) is information authorized by the user or fully authorized by all parties.

[0082] The terms "first," "second," "third," and "fourth," etc., used in the specification, claims, and accompanying drawings of this application are used to distinguish different objects, not to describe a specific order. Furthermore, the terms "comprising" and "having," and any variations thereof, are intended to cover non-exclusive inclusion. For example, a process, method, system, product, or apparatus that includes a series of steps or units is not limited to the listed steps or units, but may optionally include steps or units not listed, or may optionally include other steps or units inherent to these processes, methods, products, or apparatuses.

[0083] Figure 1 This is a schematic diagram illustrating the implementation environment of a velocity processing method for seismic data provided in this application. See also... Figure 1 The implementation environment includes: computer equipment; the computer equipment can be provided as terminal 101, or as terminal 101 and server 102, without specific limitation. If the computer equipment is provided as terminal 101, the target application is installed on terminal 101, and the user can log in to the target application and then determine the processing of seismic data using the method provided in this application. If the computer equipment is provided as terminal 101 and server 102, terminal 101 and server 102 can be connected via a wireless or wired network. Accordingly, the target application is installed on terminal 101, and server 102 is the server corresponding to the target application. The user processes seismic data through the target application, and server 102 provides background services.

[0084] Among them, terminal 101 is at least one of the following: mobile phone, tablet computer, PC (Personal Computer) device, intelligent voice interaction device, and vehicle terminal. Server 102 is at least one of the following: a single server, a server cluster consisting of multiple servers, a cloud server, a cloud computing platform, and a virtualization center.

[0085] This application provides a velocity processing method for seismic data; see [link to previous document]. Figure 2 The methods include:

[0086] 201. Computer equipment acquires P-wave seismic data of seabed nodes in the target work area.

[0087] In this embodiment, the P-wave seismic data is obtained using the OBN observation method, meaning the shot point is at sea level and the receiver point is on the seabed. For example, the average water depth in the target area is 50 meters, indicating relatively flat seabed conditions. The equivalent underground velocity in the target area is 2500 m / s, the water velocity is 1500 m / s, and the target layer is 2000 meters below the seabed.

[0088] In some embodiments, after acquiring P-wave seismic data, the P-wave seismic data undergoes the following preprocessing: loading the observation system, static correction, wavefield separation, pre-stack denoising, amplitude recovery, and sorting into common center point gathers, etc.

[0089] In some embodiments, the computer equipment also pre-sets common reflection point trace numbers for the P-wave seismic data, i.e., calculates the location of the common reflection points according to the OBN observation method. Specifically, given the water layer depth, water layer velocity, target layer depth, and equivalent subsurface velocity, the horizontal distance between the shot point and the reflection point is iteratively solved. This process continuously updates the incident angle of the water layer propagating subsurface, which is also the angle between the line connecting the shot point and the reflection point and the vertical line. The iterative process is described in the following steps.

[0090] The computer equipment determines a fourth horizontal distance based on the third horizontal distance and the shot-receiver distance. The third horizontal distance is the horizontal distance between the shot point and the incident point on the seabed, and the fourth horizontal distance is the horizontal distance between the incident point on the seabed and the receiver point. Based on the fourth horizontal distance, a fifth horizontal distance is determined, which is the horizontal distance between the incident point on the seabed and the reflection point. Based on the water layer velocity, water layer depth, target layer depth, subsurface equivalent velocity, and the fifth horizontal distance, the angle of incidence between the shot point and the reflection point is determined. Based on the angle of incidence, the third horizontal distance is updated; based on the updated third horizontal distance, the fourth horizontal distance is updated; and based on the updated fourth horizontal distance, the fifth horizontal distance is updated. Based on the updated fifth horizontal distance, the incident angle is updated; the steps of updating the third, fourth, fifth horizontal distances and the incident angle are iteratively executed until the iteration stop condition is met, resulting in the target's third, fourth, and fifth horizontal distances; based on the target's third and fifth horizontal distances, the sixth horizontal distance is obtained, which is the horizontal distance between the shot point and the reflection point; based on the sixth horizontal distance, the first horizontal distance is obtained; based on the target's fourth and fifth horizontal distances, the seventh horizontal distance is obtained, which is the horizontal distance between the receiver point and the reflection point; based on the seventh horizontal distance, the second horizontal distance is obtained.

[0091] Specifically, the difference between the shot-receiver distance x and the third horizontal distance x0 is defined as the fourth horizontal distance x1. The initial third horizontal distance is set to 0, and the initial fourth horizontal distance is then the shot-receiver distance.

[0092] In some embodiments, if the seismic wave is set to propagate in a homogeneous medium, then, exemplarily, the fifth horizontal distance is obtained by the following formula (1).

[0093]

[0094] in, This represents the initial fifth horizontal distance. This represents the initial fourth horizontal distance.

[0095] In some embodiments, based on the water layer velocity, water layer depth, target layer depth, underground equivalent velocity and fifth horizontal distance of the target work area, the incident angle in the nth iteration process is obtained by the following formula (2).

[0096]

[0097] Where, θ n V represents the angle of incidence during the nth iteration; p0 V represents the velocity of the water layer. p1 The value represents the equivalent velocity underground; z represents the depth of the target layer, which can be selected as the depth from the target layer to the seabed. This represents the fifth horizontal distance in the (n-1)th iteration.

[0098] In some embodiments, the third horizontal distance in the nth iteration is obtained based on the incident angle using the following formula (3).

[0099]

[0100] in, h0 represents the third horizontal distance in the nth iteration; h0 represents the depth from the unified datum to the seabed datum.

[0101] In some embodiments, the fifth horizontal distance in the nth iteration is obtained based on the fourth horizontal distance using the following formula (4).

[0102]

[0103] in, This represents the fifth horizontal distance during the nth iteration. This represents the fourth horizontal distance in the nth iteration.

[0104] In some embodiments, the sixth horizontal distance is obtained based on the target third horizontal distance and the target fifth horizontal distance using the following formula (5).

[0105]

[0106] Where, x p This indicates the sixth horizontal distance.

[0107] Since the location of the shot point is known, the location of the reflection point can be obtained based on the sixth horizontal distance and the location of the shot point.

[0108] See Figure 3 , Figure 3This is a flowchart illustrating a method for calculating the location of a reflection point, as provided in an embodiment of this application. First, an initial reflection point location is calculated. Then, the effective seabed shot-receiver distance is obtained, and the reflection point location is calculated using a method specifying the target layer depth. This step is iteratively executed to obtain the final reflection point location.

[0109] In some embodiments, the iteration stopping condition is reaching a preset number of iterations, or the iteration stopping condition is that the horizontal distance converges, that is, the difference between two calculation results is less than a preset difference.

[0110] In some embodiments, the sixth horizontal distance is directly used as the first horizontal distance, that is, the reflection point is used as the scattering point. Similarly, the seventh horizontal distance can be directly used as the second horizontal distance. In other embodiments, the first and second horizontal distances can also be obtained based on other implementation methods, which are not specifically limited here.

[0111] In some embodiments, the computer device also smooths the seabed depth. This can be achieved by using a parameter with a large radius, distributed along common midpoints, and averaging the depths of all common midpoints within that radius to obtain the smoothed common midpoint depth; or by using multiple CMP lines (Common Middle Point Lines), where a rectangular region is formed by the CMPs, and the depths of all common midpoints within that rectangular region are averaged to obtain the smoothed common midpoint depth.

[0112] In this embodiment, the use of a radius parameter is taken as an example for explanation. Then, depending on the degree of seabed undulation—that is, whether the seabed undulation is small or large—different detector depths are selected to correct to the seabed. This process is described in the following steps.

[0113] The computer equipment divides the seabed into multiple common center points based on a preset radius, obtaining multiple common center points within multiple circular regions; the average depth of the multiple common center points within each circular region is confirmed as the smoothed depth of the circular region; if the seabed depth fluctuation value is not greater than a preset value, the depth of the detector point is smoothed to the smoothed depth of the corresponding common center point; if the seabed depth fluctuation value is greater than the preset value, the smoothed depth of the circular region where the detector point is located is determined as the smoothed depth of the detector point.

[0114] Each circular region includes multiple common midpoints, which are the horizontal center points of the shot point and the receiver point. The smoothed depth of the circular region is the smoothed depth of the common midpoints belonging to that circular region and the smoothed area of ​​the receiver point within that circular region.

[0115] The preset value can be set as needed, such as 100 meters. Here, "seabed" refers to the seabed of the target work area. The seabed undulation value refers to the difference between the highest and lowest points of the seabed.

[0116] Accordingly, if the seabed depth fluctuation value is not greater than the preset value, the time correction amount of the seismic trace corresponding to the receiver point is obtained by the following formula (6).

[0117] T i =-(H c -H g ) / V WP (6);

[0118] Among them, T i Indicates the time correction amount; H g H represents the original depth of the detector point; c V represents the smoothed depth of the common center point corresponding to the detector point; WP This represents the shallow longitudinal wave replacement velocity, exemplarily taken as 1500 m / s.

[0119] Accordingly, when the seabed depth fluctuation value is greater than the preset value, the time correction amount of the seismic trace corresponding to the receiver point is obtained by the following formula (7).

[0120] T i =-(H cg -H g ) / V WP (7);

[0121] Among them, H cg This indicates the depth of the detector point after smoothing.

[0122] In some embodiments, after obtaining the time correction amount, the time data in the P-wave seismic data is corrected to obtain the corrected time, and then velocity migration analysis is performed based on the corrected time. In some embodiments, after obtaining the smoothed depth of the receiver points, the up-wave travel time is determined based on the smoothed velocity of the receiver points.

[0123] 202. The computer equipment performs stacking velocity analysis on the P-wave seismic data through the first correspondence relationship to obtain the P-wave stacking velocity and P-wave anisotropy parameters under the dual reference plane. The first correspondence relationship is the correspondence between the P-wave seismic data, the P-wave stacking velocity and the P-wave anisotropy parameters under the dual reference plane.

[0124] In this embodiment of the application, the stacking velocity analysis of P-wave seismic data is based on the following theoretical basis: on the shot-receiver plane where the shot point and receiver point are located, the P-wave stacking velocity controls the phase axis of the near offset reflected wave, and the P-wave anisotropy parameter controls the phase axis of the mid-to-far offset wave, so that the phase axis is completely flattened. If it is not flattened, the values ​​of these two parameters are modified again until the phase axis is flattened, so as to obtain the final P-wave stacking velocity, P-wave anisotropy parameter and P-wave stacking profile.

[0125] Among them, the P-wave anisotropy parameter is used to describe the variation of the physical properties of the medium in different directions. In anisotropic media, the propagation velocity and reflection coefficient of P-waves change with the direction of propagation. For example, in transversely anisotropic media, when the P-wave propagation direction is perpendicular to the axis of symmetry of the medium, its velocity and reflection coefficient will differ from those in other directions. Furthermore, azimuthal anisotropy inversion techniques can infer the direction and intensity of underground fractures by analyzing the propagation characteristics of P-waves.

[0126] For example, the first correspondence is shown in the following formula (8).

[0127]

[0128] in, Indicates the longitudinal wave travel time under dual reference planes; Indicates the vertical two-way travel time of the P-wave under dual reference planes; x represents the shot-receiver distance; This represents the superposition velocity of longitudinal waves under dual reference planes; This represents the longitudinal wave anisotropy parameter under dual reference planes.

[0129] Based on formula (8), the superposition energy or similarity coefficient is calculated using the amplitude of seismic data along the first correspondence relationship. This yields the relationship curve between P-wave travel time, P-wave superposition velocity, and P-wave anisotropy parameters. The P-wave superposition velocity and P-wave anisotropy parameters with the largest values ​​(i.e., when the phase axis is leveled) are used as the final P-wave superposition velocity and P-wave anisotropy parameters under the dual reference plane. In other words, the P-wave superposition velocity is obtained by scanning the velocity spectrum using small-range source data, and then the P-wave anisotropy parameters are scanned using large-range source data. These parameters correspond to the velocities corresponding to the points with the largest superposition energy or similarity coefficient on the velocity spectrum. The P-wave superposition velocity controls the phase axis of the near-offset emitted wave, while the P-wave anisotropy parameters control the phase axis of the mid-to-far offset wave.

[0130] 203. The computer equipment transforms the P-wave stacking velocity and P-wave anisotropy parameters under the dual reference planes through the second correspondence relationship to obtain the P-wave pre-stack time migration velocity parameters under the unified reference plane. The second correspondence relationship is the correspondence between the P-wave stacking velocity and P-wave anisotropy parameters under the dual reference planes and the P-wave pre-stack time migration velocity parameters under the unified reference plane. The P-wave pre-stack time migration parameters include the P-wave migration velocity and the P-wave anisotropy parameters.

[0131] For example, the second correspondence is shown in formulas (9) and (10) below.

[0132]

[0133] Among them, t p0 V represents the two-way travel time of the ascending P-wave under a unified reference plane; p2 This represents the root mean square velocity under a unified reference plane, which is also the P-wave migration velocity in the pre-stack time migration parameters of the P-waves. This represents the longitudinal wave velocity of the seawater layer, exemplarily taken as 1500 m / s; When indicating water layer travel, H0 represents the depth from the uniform datum to the seabed datum.

[0134]

[0135] Where, η eff This represents the anisotropy parameter of the longitudinal wave under a unified reference plane.

[0136] For example, see Figure 4 , Figure 4 This is a flowchart illustrating the analysis of an initial velocity model for pre-stack time migration of P-waves provided in an embodiment of this application. The process includes acquiring P-wave (PP wave) seismic data, smoothing the seabed, and correcting the receiver depth. Stacking velocity analysis is performed on two reference planes to obtain the P-wave stacking velocity and P-wave anisotropy parameters under the two reference planes. These are then corrected to a unified reference plane to obtain the pre-stack time migration velocity parameters of the P-waves under the unified reference plane.

[0137] 204. The computer equipment transforms the pre-stack time migration velocity parameters of P-waves under a unified reference plane through the third correspondence relationship to obtain the pre-stack time migration parameters of P-waves under the seabed reference plane. The third correspondence relationship is the correspondence between the pre-stack time migration velocity parameters of P-waves under the unified reference plane and the pre-stack time migration parameters of P-waves under the seabed reference plane.

[0138] For example, the third correspondence is shown in formulas (11) and (12) below.

[0139]

[0140] in, Indicates the two-way travel time of the ascending longitudinal wave below the seabed reference level; This represents the dynamic correction velocity below the seabed reference plane, also known as the offset velocity parameter.

[0141]

[0142] in, This represents the anisotropy parameter of the longitudinal waves below the seabed reference plane.

[0143] 205. The computer equipment performs pre-stack time migration on the P-wave pre-stack time migration parameters under the unified reference plane and the P-wave pre-stack time migration parameters under the seabed reference plane to obtain common imaging point gathers.

[0144] In some embodiments, step 205 above includes the following steps: The computer device obtains the P-wave travel time using the P-wave scattering equation, based on the P-wave pre-stack time migration parameters under a unified reference plane, the P-wave pre-stack time migration parameters under a seabed reference plane, the first horizontal distance, the second horizontal distance, the downgoing P-wave travel time, and the upgoing P-wave travel time. The P-wave scattering equation is the relationship equation between the P-wave pre-stack time migration parameters under a unified reference plane, the P-wave pre-stack time migration parameters under a seabed reference plane, the first horizontal distance, the second horizontal distance, the downgoing P-wave travel time, the upgoing P-wave travel time, and the P-wave travel time. The first horizontal distance is the horizontal distance between the scattering point and the shot point, and the second horizontal distance is the horizontal distance between the scattering point and the receiver point. Based on the P-wave travel time, a common imaging point gather is obtained.

[0145] For example, the longitudinal wave scattering equation is given by the following formula (13).

[0146]

[0147] in, Indicates the P-wave travel time under dual reference planes; x p This represents the first horizontal distance, that is, the horizontal distance between the shot point and the scattering point; x r This represents the second horizontal distance, which is the horizontal distance between the detector point and the scattering point; V p2 This represents the longitudinal wave offset velocity under a unified reference plane; η represents the longitudinal wave displacement velocity below the seabed reference plane. rff Represents the anisotropic parameters of longitudinal waves under a unified reference plane; The parameter t represents the anisotropy of P-waves below the seabed reference plane. p0 Indicating the travel time of the downwave, This indicates the travel time of an upward wave.

[0148] In some embodiments, the up-wave travel time is determined by the following steps: for each seismic trace in the common imaging point set, the computer device determines the smoothed depth of the receiver point of the seismic trace; determines the quotient of the smoothed depth and the shallow P-wave replacement velocity; and determines the difference between the down-wave travel time and the quotient as the up-wave travel time.

[0149] The process of determining the depth after smoothing the detector point is the same as that in step 201 above, and will not be repeated here.

[0150] Accordingly, when the depth fluctuation value of the seabed is not greater than the preset value, the travel time of the upward longitudinal wave is obtained by the following formula (14).

[0151]

[0152] in, Indicates the travel time of the upward longitudinal wave; t p0 Indicates the travel time of the downlink longitudinal wave; H cR V represents the smoothed depth of the detector point; WP This indicates the shallow longitudinal wave replacement velocity.

[0153] Accordingly, when the seabed depth fluctuation value is greater than the preset value, the travel time of the upward longitudinal wave is obtained by the following formula (15).

[0154]

[0155] in, Indicates the travel time of the upward longitudinal wave; t p0 Indicates the travel time of the downlink longitudinal wave; H Rm V represents the smoothed depth of the detector point; WP This indicates the shallow longitudinal wave replacement velocity.

[0156] 206. The computer equipment corrects the P-wave stacking velocity and P-wave anisotropy parameters under dual reference planes based on the common imaging point gather.

[0157] In some embodiments, step 206 above includes the following steps: the computer device corrects the P-wave stacking velocity and P-wave anisotropy parameter under the dual reference plane based on the remaining time difference in the common imaging point gather and through the first correspondence relationship, to obtain the corrected P-wave stacking velocity and P-wave anisotropy parameter under the dual reference plane, where the remaining time difference is the difference between the time value on the common imaging point gather and the time value when the in-phase axis is leveled.

[0158] Among them, since the first correspondence is the correspondence between P-wave travel time, P-wave superposition velocity, and P-wave anisotropy parameter, the relationship curve between P-wave travel time, P-wave superposition velocity, and P-wave anisotropy parameter established based on the first correspondence, and then after updating the P-wave travel time based on the remaining time difference, the P-wave superposition velocity and P-wave anisotropy parameter can be modified based on the updated P-wave travel time.

[0159] 207. The computer equipment, based on the corrected P-wave stacking velocity and P-wave anisotropy parameters under the dual reference planes, repeats the steps of obtaining common imaging point gathers until a common imaging point gather with the phase axis flattened is obtained. The P-wave pre-stack time migration parameters under the seabed reference plane corresponding to the common imaging point gather with the phase axis flattened are output as target P-wave pre-stack time migration parameters. The target P-wave pre-stack time migration parameters are used for P-wave pre-stack time migration imaging.

[0160] In this embodiment, the P-wave seismic data is subjected to stacking velocity analysis to obtain the pre-stack time migration velocity parameters of the P-waves under a unified reference plane. Then, the pre-stack time migration velocity parameters of the P-waves under dual reference planes are obtained through the reference plane transformation formulas, namely formulas (11) and (12). The P-waves are then pre-stacked using the P-wave scattering equation. The residual time difference analysis is performed on the obtained common imaging point gathers and corrected by analysis. After multiple iterations of P-wave pre-stack time migration and residual time difference analysis, the phase axis of the obtained common imaging point gathers is flattened, and the optimal velocity analysis result is obtained. Among them, multiple iterations of P-wave pre-stack time migration and residual time difference analysis refer to the fact that the common imaging point gathers generated by each P-wave pre-stack time migration are dual reference plane gathers, with the shot point on the unified reference plane and the receiver point on the seabed reference plane. The residual time difference is analyzed on the common imaging point gathers through the first correspondence relationship, namely formula (8), to obtain the corrected P-wave stacking velocity and P-wave anisotropy parameters under dual reference planes. Furthermore, the pre-stack time migration velocity parameters of P-waves under the dual reference planes can be directly calculated through the third correspondence, namely formulas (11) and (12), without having to use the conversion formula of the pre-stack time migration velocity parameters of P-waves under the dual reference planes again.

[0161] In this embodiment of the application, the velocity model for P-wave pre-stack time migration imaging is accurately determined through steps 201-207 described above. For example, see... Figure 5 , Figure 5This is a flowchart illustrating the analysis of P-wave pre-stack time migration velocity according to an embodiment of this application. The process involves acquiring initial P-wave migration velocities and P-wave anisotropy parameters, i.e., P-wave pre-stack time migration parameters under a unified reference plane, and converting them to the seafloor reference plane. P-wave (PP) data from the P-wave seismic data is acquired, and the depth of the seafloor receiver points is smoothed. Then, based on these data, pre-stack time migration (PPTM) is generated to obtain a migration imaging (CIP) gather. The phase axis in the gather is checked for flattening. If not flattened, the P-wave stacking velocity and P-wave anisotropy parameters under the dual reference planes are updated, and a new gather is obtained. If the phase axis in the gather is flattened, anisotropic PPTM (target P-wave pre-stack time migration parameters) is obtained.

[0162] For example, see Figure 6 and Figure 7 , Figure 6 This is a schematic diagram illustrating the velocity analysis effect under a unified reference plane, provided in an embodiment of this application. Figure 7 This is a schematic diagram illustrating the velocity analysis effect under dual reference planes provided in an embodiment of this application. As can be seen from the comparison, the solution provided in this embodiment can achieve accurate velocity analysis.

[0163] This application implements an OBN (On-Board Noise) P-wave seismic data velocity analysis method. It iteratively calculates the reflection point location under dual-reference-plane conditions, improving the accuracy of common-reflection point gather sorting. The method smooths the seabed based on its undulations and corrects the receiver points to the smoothed seabed, adapting to different seabed receiving conditions. The dual-reference-plane velocity and anisotropy transformation formulas enable velocity analysis using special acquisition conditions with different excitation planes. This effectively improves the accuracy of OBN data velocity analysis results and reduces processing costs and complexity. Model data testing also demonstrates the effectiveness of this method. It achieves simple, efficient, and high-precision P-wave OBN velocity analysis, providing technical support for obtaining high-quality stacked profiles and migration imaging.

[0164] This application also provides a velocity processing device for seismic data, see [link to relevant documentation]. Figure 8 The device includes:

[0165] The acquisition module 801 is used to acquire P-wave seismic data of the seabed nodes in the target work area;

[0166] Analysis module 802 is used to perform stacking velocity analysis on P-wave seismic data through a first correspondence relationship to obtain the P-wave stacking velocity and P-wave anisotropy parameters under the dual reference plane. The first correspondence relationship is the correspondence between P-wave seismic data, P-wave stacking velocity and P-wave anisotropy parameters under the dual reference plane.

[0167] The transformation module 803 is used to transform the P-wave stacking velocity and P-wave anisotropy parameters under the dual reference planes through the second correspondence relationship to obtain the P-wave pre-stack time migration velocity parameters under the unified reference plane. The second correspondence relationship is the correspondence between the P-wave stacking velocity and P-wave anisotropy parameters under the dual reference planes and the P-wave pre-stack time migration velocity parameters under the unified reference plane. The P-wave pre-stack time migration parameters include the P-wave migration velocity and the P-wave anisotropy parameters.

[0168] The transformation module 803 is also used to transform the pre-stack time migration velocity parameter of P-wave under the unified reference plane through the third correspondence relationship to obtain the pre-stack time migration parameter of P-wave under the seabed reference plane. The third correspondence relationship is the correspondence between the pre-stack time migration velocity parameter of P-wave under the unified reference plane and the pre-stack time migration parameter of P-wave under the seabed reference plane.

[0169] Analysis module 802 is also used to perform pre-stack time migration on the P-wave pre-stack time migration parameters under a unified reference plane and the P-wave pre-stack time migration parameters under a seabed reference plane to obtain common imaging point gathers.

[0170] Correction module 804 is used to correct the P-wave stacking velocity and P-wave anisotropy parameters under dual reference planes based on the common imaging point gather.

[0171] The determination module 805 is used to repeatedly obtain the common imaging point gather based on the P-wave stacking velocity and P-wave anisotropy parameters under the corrected dual reference planes until the common imaging point gather with the phase axis flattened is obtained. The P-wave pre-stack time migration parameters under the seabed reference plane corresponding to the common imaging point gather with the phase axis flattened are output as the target P-wave pre-stack time migration parameters. The target P-wave pre-stack time migration parameters are used for P-wave pre-stack time migration imaging.

[0172] In some embodiments, the analysis module 802 is configured to:

[0173] Based on the P-wave scattering equation, the P-wave pre-stack time migration parameters under a unified reference plane, the P-wave pre-stack time migration parameters under a seabed reference plane, the first horizontal distance, the second horizontal distance, the downgoing P-wave travel time, and the upgoing P-wave travel time, the P-wave travel time is obtained. The P-wave scattering equation is the relationship equation between the P-wave pre-stack time migration parameters under a unified reference plane, the P-wave pre-stack time migration parameters under a seabed reference plane, the first horizontal distance, the second horizontal distance, the downgoing P-wave travel time, the upgoing P-wave travel time, and the P-wave travel time. The first horizontal distance is the horizontal distance between the scattering point and the shot point, and the second horizontal distance is the horizontal distance between the scattering point and the receiver point.

[0174] Based on the longitudinal wave travel time, the common imaging point gather is obtained.

[0175] In some embodiments, the determining module 805 is further configured to:

[0176] For each seismic trace in the common imaging point set, determine the smoothed depth of the detector point of the seismic trace;

[0177] Determine the quotient of the smoothed depth and the shallow P-wave replacement velocity;

[0178] The difference between the downlink P-wave travel time and the quotient is determined as the uplink P-wave travel time.

[0179] In some embodiments, the determining module 805 is configured to:

[0180] Based on a preset radius, multiple common center points on the seabed are divided to obtain multiple common center points within multiple circular regions;

[0181] The average depth of multiple common center points within each circular region is indeed the smoothed depth of the circular region;

[0182] If the depth fluctuation value of the seabed is not greater than the preset value, the depth of the detector point will be smoothed to the depth after smoothing the corresponding common center point.

[0183] When the depth fluctuation value of the seabed is greater than the preset value, the smoothed depth of the circular area where the detector point is located is determined as the smoothed depth of the detector point.

[0184] In some embodiments, the determining module 805 is further configured to:

[0185] Based on the third horizontal distance and the shot-receiver distance, the fourth horizontal distance is determined. The third horizontal distance is the horizontal distance between the shot point and the incident point on the seabed, and the fourth horizontal distance is the horizontal distance between the incident point and the receiver point.

[0186] Based on the fourth horizontal distance, the fifth horizontal distance is determined, which is the horizontal distance between the incident point and the reflection point.

[0187] Based on the water layer velocity, water layer depth, target layer depth, underground equivalent velocity, and fifth horizontal distance of the target work area, the incident angle between the shot point and the reflection point is determined;

[0188] Based on the angle of incidence, update the third horizontal distance; based on the updated third horizontal distance, update the fourth horizontal distance; based on the updated fourth horizontal distance, update the fifth horizontal distance; based on the updated fifth horizontal distance, update the angle of incidence.

[0189] Iteratively execute the steps of updating the third horizontal distance, fourth horizontal distance, fifth horizontal distance and incident angle until the iteration stop condition is met, and obtain the target third horizontal distance, target fourth horizontal distance and target fifth horizontal distance;

[0190] Based on the target's third and fifth horizontal distances, the sixth horizontal distance is obtained, which is the horizontal distance between the shot point and the reflection point; based on the sixth horizontal distance, the first horizontal distance is obtained.

[0191] Based on the fourth and fifth horizontal distances of the target, the seventh horizontal distance is obtained, which is the horizontal distance between the detector point and the reflection point; based on the seventh horizontal distance, the second horizontal distance is obtained.

[0192] In some embodiments, the correction module 804 is configured to:

[0193] Based on the residual time difference in the common imaging point gather, the P-wave stacking velocity and P-wave anisotropy parameters under the dual reference plane are corrected through the first correspondence relationship, and the corrected P-wave stacking velocity and P-wave anisotropy parameters under the dual reference plane are obtained. The residual time difference is the difference between the time value on the common imaging point gather and the time value when the in-phase axis is leveled.

[0194] Figure 9 A structural block diagram of a computer device 900 provided in an exemplary embodiment of this application is shown.

[0195] Typically, computer device 900 includes a processor 901 and a memory 902.

[0196] Processor 901 may include one or more processing cores, such as a quad-core processor or an octa-core processor. Processor 901 may be implemented using at least one hardware form selected from DSP (Digital Signal Processing), FPGA (Field-Programmable Gate Array), and PLA (Programmable Logic Array). Processor 901 may also include a main processor and a coprocessor. The main processor, also known as a CPU (Central Processing Unit), is used to process data in the wake-up state; the coprocessor is a low-power processor used to process data in the standby state. In some embodiments, processor 901 may integrate a GPU (Graphics Processing Unit), which is responsible for rendering and drawing the content to be displayed on the screen. In some embodiments, processor 901 may also include an AI (Artificial Intelligence) processor, which is used to handle computational operations related to machine learning.

[0197] The memory 902 may include one or more computer-readable storage media, which may be non-transitory. The memory 902 may also include high-speed random access memory and non-volatile memory, such as one or more disk storage devices or flash memory devices. In some embodiments, the non-transitory computer-readable storage media in the memory 902 are used to store at least one computer program, which is executed by the processor 901 to implement the seismic data velocity processing method provided in the method embodiments of this application.

[0198] In some embodiments, the computer device 900 may optionally include a peripheral device interface 903 and at least one peripheral device. The processor 901, memory 902, and peripheral device interface 903 can be connected via a bus or signal line. Each peripheral device can be connected to the peripheral device interface 903 via a bus, signal line, or circuit board. Specifically, the peripheral device includes at least one of the following: a radio frequency circuit 904, a display screen 905, a camera assembly 906, an audio circuit 907, and a power supply 908.

[0199] Peripheral device interface 903 can be used to connect at least one I / O (Input / Output) related peripheral device to processor 901 and memory 902. In some embodiments, processor 901, memory 902 and peripheral device interface 903 are integrated on the same chip or circuit board; in some other embodiments, any one or two of processor 901, memory 902 and peripheral device interface 903 can be implemented on separate chips or circuit boards, which is not limited in this embodiment.

[0200] The radio frequency (RF) circuit 904 is used to receive and transmit RF (Radio Frequency) signals, also known as electromagnetic signals. The RF circuit 904 communicates with communication networks and other communication devices via electromagnetic signals. The RF circuit 904 converts electrical signals into electromagnetic signals for transmission, or converts received electromagnetic signals back into electrical signals. Optionally, the RF circuit 904 includes: an antenna system, an RF transceiver, one or more amplifiers, a tuner, an oscillator, a digital signal processor, a codec chipset, a user identity module card, etc. The RF circuit 904 can communicate with other computer devices through at least one wireless communication protocol. This wireless communication protocol includes, but is not limited to: the World Wide Web, metropolitan area networks, intranets, various generations of mobile communication networks (2G, 3G, 4G, and 5G), wireless local area networks, and / or WiFi (Wireless Fidelity) networks. In some embodiments, the RF circuit 904 may also include circuitry related to NFC (Near Field Communication), which is not limited in this application.

[0201] Display screen 905 is used to display a UI (User Interface). This UI may include graphics, text, icons, multimedia resources, and any combination thereof. When display screen 905 is a touch display screen, it also has the ability to collect touch signals on or above its surface. These touch signals can be input as control signals to processor 901 for processing. In this case, display screen 905 can also be used to provide virtual buttons and / or a virtual keyboard, also known as soft buttons and / or a soft keyboard. In some embodiments, there may be one display screen 905, disposed on the front panel of computer device 900; in other embodiments, there may be at least two display screens 905, disposed on different surfaces of computer device 900 or in a folded design; in still other embodiments, display screen 905 may be a flexible display screen, disposed on a curved or folded surface of computer device 900. Furthermore, display screen 905 may be configured as a non-rectangular, irregular shape, i.e., a non-rectangular screen. Display screen 905 may be made of materials such as LCD (Liquid Crystal Display) or OLED (Organic Light-Emitting Diode).

[0202] The camera assembly 906 is used to acquire images or multimedia resources. Optionally, the camera assembly 906 includes a front-facing camera and a rear-facing camera. Typically, the front-facing camera is located on the front panel of the computer device, and the rear-facing camera is located on the back of the computer device. In some embodiments, there are at least two rear-facing cameras, which are any one of a main camera, a depth-sensing camera, a wide-angle camera, and a telephoto camera, to achieve background blurring by fusion of the main camera and the depth-sensing camera, panoramic shooting by fusion of the main camera and the wide-angle camera, VR (Virtual Reality) shooting, or other fusion shooting functions. In some embodiments, the camera assembly 906 may also include a flash. The flash can be a single-color temperature flash or a dual-color temperature flash. A dual-color temperature flash refers to a combination of a warm light flash and a cool light flash, which can be used for light compensation at different color temperatures.

[0203] The audio circuit 907 may include a microphone and a speaker. The microphone is used to collect sound waves from the user and the environment, converting the sound waves into electrical signals that are input to the processor 901 for processing, or input to the radio frequency circuit 904 for voice communication. For stereo sound acquisition or noise reduction purposes, multiple microphones may be used, each located in a different part of the computer device 900. The microphone may also be an array microphone or an omnidirectional microphone. The speaker is used to convert electrical signals from the processor 901 or the radio frequency circuit 904 into sound waves. The speaker may be a conventional diaphragm speaker or a piezoelectric ceramic speaker. When the speaker is a piezoelectric ceramic speaker, it can convert electrical signals not only into audible sound waves but also into inaudible sound waves for purposes such as distance measurement. In some embodiments, the audio circuit 907 may also include a headphone jack.

[0204] Power supply 908 is used to supply power to the various components in computer device 900. Power supply 908 can be AC ​​power, DC power, a disposable battery, or a rechargeable battery. When power supply 908 includes a rechargeable battery, the rechargeable battery can be a wired rechargeable battery or a wireless rechargeable battery. A wired rechargeable battery is a battery that is charged via a wired line, while a wireless rechargeable battery is a battery that is charged via a wireless coil. The rechargeable battery can also be used to support fast charging technology.

[0205] In some embodiments, the computer device 900 further includes one or more sensors 909. The one or more sensors 909 include, but are not limited to, an accelerometer 910, a gyroscope 911, a pressure sensor 912, an optical sensor 913, and a proximity sensor 914.

[0206] Accelerometer 910 can detect the magnitude of acceleration along the three coordinate axes of a coordinate system established by computer device 900. For example, accelerometer 910 can be used to detect the components of gravitational acceleration along the three coordinate axes. Processor 901 can control display screen 905 to display the user interface in either a landscape or portrait view based on the gravitational acceleration signal acquired by accelerometer 910. Accelerometer 910 can also be used for games or for acquiring user motion data.

[0207] The gyroscope sensor 911 can detect the orientation and rotation angle of the computer device 900. The gyroscope sensor 911, in conjunction with the accelerometer sensor 910, can collect 3D motion data from the user on the computer device 900. Based on the data collected by the gyroscope sensor 911, the processor 901 can perform the following functions: motion sensing (e.g., changing the UI based on the user's tilt), image stabilization during shooting, game control, and inertial navigation.

[0208] The pressure sensor 912 can be disposed on the side bezel of the computer device 900 and / or on the lower layer of the display screen 905. When the pressure sensor 912 is disposed on the side bezel of the computer device 900, it can detect the user's grip signal on the computer device 900, and the processor 901 can perform left / right hand recognition or quick operation based on the grip signal collected by the pressure sensor 912. When the pressure sensor 912 is disposed on the lower layer of the display screen 905, the processor 901 can control the operable controls on the UI interface based on the user's pressure operation on the display screen 905. The operable controls include at least one of button controls, scroll bar controls, icon controls, and menu controls.

[0209] An optical sensor 913 is used to collect ambient light intensity. In one embodiment, the processor 901 can control the display brightness of the display screen 905 based on the ambient light intensity collected by the optical sensor 913. Specifically, when the ambient light intensity is high, the display brightness of the display screen 905 is increased; when the ambient light intensity is low, the display brightness of the display screen 905 is decreased. In another embodiment, the processor 901 can also dynamically adjust the shooting parameters of the camera assembly 906 based on the ambient light intensity collected by the optical sensor 913.

[0210] A proximity sensor 914, also known as a distance sensor, is typically located on the front panel of a computer device 900. The proximity sensor 914 is used to detect the distance between the user and the front of the computer device 900. In one embodiment, when the proximity sensor 914 detects that the distance between the user and the front of the computer device 900 is gradually decreasing, the processor 901 controls the display screen 905 to switch from a screen-on state to a screen-off state; when the proximity sensor 914 detects that the distance between the user and the front of the computer device 900 is gradually increasing, the processor 901 controls the display screen 905 to switch from a screen-off state to a screen-on state.

[0211] Those skilled in the art will understand that Figure 9 The structure shown does not constitute a limitation on the computer device 900, and may include more or fewer components than shown, or combine certain components, or use different component arrangements.

[0212] Figure 10This is a block diagram of a server provided in an embodiment of this disclosure. The server 1000 can vary significantly due to differences in configuration or performance. It may include one or more Central Processing Units (CPUs) 1001 and one or more memories 1002. The memories 1002 are used to store executable program code, and the processors 1001 are configured to execute the executable program code to implement the seismic data velocity processing method provided in the various method embodiments described above. Of course, the server may also have wired or wireless network interfaces, a keyboard, and input / output interfaces for input and output. The server may also include other components for implementing device functions, which will not be elaborated here.

[0213] In an exemplary embodiment, a storage medium including program code is also provided, such as a memory 1002 including program code, which can be executed by the processor 1001 of the server 1000 to complete the aforementioned seismic data speed processing method. Optionally, the storage medium can be a non-transitory computer-readable storage medium, such as ROM (Read-Only Memory), RAM (Random Access Memory), CD-ROM (Compact Disc Read-Only Memory), magnetic tape, floppy disk, and optical data storage device.

[0214] This application also provides a computer-readable storage medium storing at least one piece of program code, which is loaded and executed by a processor to implement the seismic data speed processing method of any of the above implementations.

[0215] This application also provides a computer program product, which includes computer program code stored in a computer-readable storage medium. The processor of a computer device reads the computer program code from the computer-readable storage medium and executes the computer program code, causing the computer device to execute the seismic data velocity processing method of any of the above implementations.

[0216] In some embodiments, the computer program product involved in the present application can be deployed and executed on a computer device, or on multiple computer devices located in one location, or on multiple computer devices distributed in multiple locations and interconnected through a communication network. Multiple computer devices distributed in multiple locations and interconnected through a communication network can form a blockchain system.

[0217] The above are merely optional embodiments of this application and are not intended to limit this application. Any modifications, equivalent substitutions, or improvements made within the spirit and principles of this application should be included within the scope of protection of this application. It should be noted that the information (including but not limited to user device information, user personal information, etc.), data (including but not limited to data used for analysis, stored data, displayed data, etc.), and signals involved in this application are all authorized by the user or fully authorized by all parties, and the collection, use, and processing of related data must comply with the relevant laws, regulations, and standards of the relevant countries and regions. For example, the P-wave seismic data involved in this application were obtained under fully authorized conditions.

[0218] All the above-mentioned optional technical solutions can be combined in any way to form the optional embodiments of this application, and will not be described in detail here. The above are only optional embodiments of this application and are not intended to limit this application. Any modifications, equivalent substitutions, improvements, etc., made within the spirit and principles of this application should be included within the protection scope of this application.

Claims

1. A method for velocity processing of seismic data, characterized in that, The method includes: Acquire P-wave seismic data of the seabed nodes in the target work area; By using the first correspondence, the stacking velocity analysis is performed on the P-wave seismic data to obtain the P-wave stacking velocity and P-wave anisotropy parameters under the dual reference plane. The first correspondence is the correspondence between the P-wave seismic data, the P-wave stacking velocity and the P-wave anisotropy parameters under the dual reference plane. By using the second correspondence, the P-wave stacking velocity and P-wave anisotropy parameter under the dual reference plane are transformed to obtain the P-wave pre-stack time migration velocity parameter under the unified reference plane. The second correspondence is the correspondence between the P-wave stacking velocity and P-wave anisotropy parameter under the dual reference plane and the P-wave pre-stack time migration velocity parameter under the unified reference plane. The P-wave pre-stack time migration parameter includes the P-wave migration velocity and the P-wave anisotropy parameter. By transforming the P-wave pre-stack time migration velocity parameter under the unified reference plane through the third correspondence, the P-wave pre-stack time migration parameter under the seabed reference plane is obtained. The third correspondence is the correspondence between the P-wave pre-stack time migration velocity parameter under the unified reference plane and the P-wave pre-stack time migration parameter under the seabed reference plane. Pre-stack time migration is performed on the P-wave pre-stack time migration parameters under the unified reference plane and the P-wave pre-stack time migration parameters under the seabed reference plane to obtain common imaging point gathers. Based on the common imaging point gather, the P-wave stacking velocity and P-wave anisotropy parameters under the dual reference planes are corrected. Based on the corrected P-wave stacking velocity and P-wave anisotropy parameters under the dual reference planes, the steps of obtaining common imaging point gathers are repeated until a common imaging point gather with the phase axis flattened is obtained. The pre-stack time migration parameters of P-waves under the seabed reference plane corresponding to the pre-stack time migration parameters of the common imaging point gather with the phase axis flattened are output as target P-wave pre-stack time migration parameters. The target P-wave pre-stack time migration parameters are used for P-wave pre-stack time migration imaging.

2. The method according to claim 1, characterized in that, The pre-stack time migration of the P-wave pre-stack time migration parameters under the unified reference plane and the P-wave pre-stack time migration parameters under the seabed reference plane is performed to obtain the common imaging point gather, including: Based on the P-wave pre-stack time migration parameters under the unified reference plane, the P-wave pre-stack time migration parameters under the seabed reference plane, the first horizontal distance, the second horizontal distance, the downgoing P-wave travel time, and the upgoing P-wave travel time, the P-wave travel time is obtained through the P-wave scattering equation. The P-wave scattering equation is the relationship equation between the P-wave pre-stack time migration parameters under the unified reference plane, the P-wave pre-stack time migration parameters under the seabed reference plane, the first horizontal distance, the second horizontal distance, the downgoing P-wave travel time, the upgoing P-wave travel time, and the P-wave travel time. The first horizontal distance is the horizontal distance between the scattering point and the shot point, and the second horizontal distance is the horizontal distance between the scattering point and the receiver point. The common imaging point gather is obtained based on the longitudinal wave travel time.

3. The method according to claim 2, characterized in that, The method further includes: For each seismic trace in the common imaging point set, determine the smoothed depth of the detector point of the seismic trace; Determine the quotient of the smoothed depth and the shallow longitudinal wave replacement velocity; The difference between the downlink P-wave travel time and the quotient is determined as the uplink P-wave travel time.

4. The method according to claim 3, characterized in that, Determining the smoothed depth of the receiver points in the seismic trace includes: Based on a preset radius, multiple common center points on the seabed are divided to obtain multiple common center points within multiple circular regions; The average depth of multiple common center points within each circular region is indeed the smoothed depth of the circular region; If the depth fluctuation value of the seabed is not greater than the preset value, the depth of the detector point is smoothed to the depth after smoothing the corresponding common center point. When the depth fluctuation value of the seabed is greater than the preset value, the smoothed depth of the circular region where the detector point is located is determined as the smoothed depth of the detector point.

5. The method according to claim 3, characterized in that, The method further includes: Based on the third horizontal distance and the shot-receiver distance, a fourth horizontal distance is determined. The third horizontal distance is the horizontal distance between the shot point and the incident point on the seabed, and the fourth horizontal distance is the horizontal distance between the incident point and the receiver point. Based on the fourth horizontal distance, a fifth horizontal distance is determined, which is the horizontal distance between the incident point and the reflection point; Based on the water layer velocity, water layer depth, target layer depth, underground equivalent velocity, and the fifth horizontal distance of the target work area, the angle of incidence between the shot point and the reflection point is determined; Based on the incident angle, update the third horizontal distance; based on the updated third horizontal distance, update the fourth horizontal distance; based on the updated fourth horizontal distance, update the fifth horizontal distance; based on the updated fifth horizontal distance, update the incident angle. The steps of updating the third horizontal distance, the fourth horizontal distance, the fifth horizontal distance, and the incident angle are executed iteratively until the iteration stop condition is met, and the target third horizontal distance, the target fourth horizontal distance, and the target fifth horizontal distance are obtained. Based on the third and fifth horizontal distances of the target, a sixth horizontal distance is obtained, which is the horizontal distance between the shot point and the reflection point; based on the sixth horizontal distance, the first horizontal distance is obtained. Based on the fourth horizontal distance and the fifth horizontal distance of the target, a seventh horizontal distance is obtained, which is the horizontal distance between the detector point and the reflection point; based on the seventh horizontal distance, a second horizontal distance is obtained.

6. The method according to claim 1, characterized in that, The correction of the P-wave stacking velocity and P-wave anisotropy parameters under the dual reference planes based on the common imaging point gather includes: Based on the remaining time difference in the common imaging point gather, the P-wave stacking velocity and P-wave anisotropy parameters under the dual reference plane are corrected through the first correspondence to obtain the corrected P-wave stacking velocity and P-wave anisotropy parameters under the dual reference plane. The remaining time difference is the difference between the time value on the common imaging point gather and the time value when the in-phase axis is leveled.

7. A velocity processing device for seismic data, characterized in that, The device includes: The acquisition module is used to acquire P-wave seismic data of the seabed nodes in the target work area; The analysis module is used to perform stacking velocity analysis on the P-wave seismic data through a first correspondence relationship to obtain the P-wave stacking velocity and P-wave anisotropy parameters under the dual reference planes. The first correspondence relationship is the correspondence between the P-wave seismic data, the P-wave stacking velocity and the P-wave anisotropy parameters under the dual reference planes. The transformation module is used to transform the P-wave stacking velocity and P-wave anisotropy parameters under the dual reference planes through a second correspondence relationship to obtain the P-wave pre-stack time migration velocity parameters under a unified reference plane. The second correspondence relationship is the correspondence between the P-wave stacking velocity and P-wave anisotropy parameters under the dual reference planes and the P-wave pre-stack time migration velocity parameters under the unified reference plane. The P-wave pre-stack time migration parameters include the P-wave migration velocity and the P-wave anisotropy parameters. The transformation module is also used to transform the pre-stack time migration velocity parameter of the P-wave under the unified reference plane through a third correspondence relationship to obtain the pre-stack time migration parameter of the P-wave under the seabed reference plane. The third correspondence relationship is the correspondence between the pre-stack time migration velocity parameter of the P-wave under the unified reference plane and the pre-stack time migration parameter of the P-wave under the seabed reference plane. The analysis module is also used to perform pre-stack time migration on the pre-stack time migration parameters of P-waves under the unified reference plane and the pre-stack time migration parameters of P-waves under the seabed reference plane to obtain common imaging point gathers. The correction module is used to correct the P-wave stacking velocity and P-wave anisotropy parameters under the dual reference planes based on the common imaging point gather. The determination module is used to repeatedly obtain the common imaging point gather based on the P-wave stacking velocity and P-wave anisotropy parameters under the corrected dual reference planes until a common imaging point gather with the phase axis flattened is obtained. The P-wave pre-stack time migration parameters under the seabed reference plane corresponding to the common imaging point gather with the phase axis flattened are output as target P-wave pre-stack time migration parameters, which are used for P-wave pre-stack time migration imaging.

8. A computer device, characterized in that, The computer device includes one or more processors and one or more memories, wherein at least one piece of program code is stored in the one or more memories, and the at least one piece of program code is loaded and executed by the one or more processors to implement the speed processing method for seismic data as described in any one of claims 1 to 6.

9. A computer-readable storage medium, characterized in that, The storage medium stores at least one piece of program code, which is loaded and executed by a processor to implement the seismic data speed processing method as described in any one of claims 1 to 6.

10. A computer program product, characterized in that, The computer program product includes computer program code stored in a computer-readable storage medium. A processor of a computer device reads the computer program code from the computer-readable storage medium and executes the computer program code, causing the computer device to perform the velocity processing method for seismic data as described in any one of claims 1 to 6.

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