Method and device for determining anisotropic parameters in stratum and storage medium

Abstract

The invention discloses a method and device for determining anisotropic parameters in a stratum and a storage medium. The method comprises the following steps: determining a detection point; excitation points around the detection point are controlled to excite waves, detection first arrival time corresponding to the excitation points is obtained at a preset receiving depth position below the detection point, the receiving depth position is located in a corresponding preset stratum, and the detection first arrival time is the time needed by waves excited by the excitation points to reach the receiving depth position for the first time; determining a plurality of preset candidate anisotropy parameters; based on a preset target direction angle, determining reflected wave durations respectively corresponding to the plurality of candidate anisotropic parameters in the receiving depth position; and determining a target anisotropy parameter of the predetermined stratum in the target direction angle based on the reflected wave durations corresponding to the plurality of candidate anisotropy parameters and the detection first arrival duration. The technical problem that the accuracy of the anisotropic parameters is not ideal in the prior art is solved.

Description

Technical Field

[0001] The present invention relates to the technical field of seismic exploration data acquisition, and in particular to a method, a device and a storage medium for determining anisotropic parameters in a stratum. Background Art

[0002] Seismic exploration is the main method for finding and exploring oil and gas. Conventional seismic data processing methods are all based on the assumption of an isotropic medium model. However, research and exploration have shown that azimuthal velocity anisotropy is ubiquitous in strata, that is, the velocity of seismic waves propagating in the medium will vary depending on the propagation direction. With the gradual improvement of exploration accuracy, seismic data processing based on isotropic media can no longer meet the requirements for accurate description of complex underground structures. Especially in areas with complex surface conditions, such as piedmont transition zones and deserts, there will be strong anisotropy in the shallow surface, which will lead to inaccurate anisotropic parameters.

[0003] To address the above-mentioned problems, no effective solution has been proposed yet. Summary of the invention

[0004] The embodiments of the present invention provide a method, device and storage medium for determining anisotropic parameters in a formation, so as to at least solve the technical problem that the accuracy of anisotropic parameters in the related art is not ideal.

[0005] According to one aspect of an embodiment of the present invention, a method for determining anisotropic parameters in a stratum is provided, comprising: determining a detection point; controlling an excitation point around the detection point to excite waves, and obtaining a detection first arrival time corresponding to the excitation point at a predetermined receiving depth position below the detection point, wherein the receiving depth position is in a corresponding predetermined stratum, and the detection first arrival time is the time required for the wave excited by the excitation point to reach the receiving depth position for the first time; determining a plurality of preset candidate anisotropic parameters; based on a preset target direction angle, determining the reflection wave durations corresponding to the plurality of candidate anisotropic parameters in the receiving depth position; based on the reflection wave durations corresponding to the plurality of candidate anisotropic parameters and the detection first arrival time, determining the target anisotropic parameters of the predetermined stratum at the target direction angle.

[0006] Optionally, determining the target anisotropy parameters of the predetermined stratum at the target direction angle based on the reflection wave durations respectively corresponding to the multiple candidate anisotropy parameters and the detection first arrival time includes: performing elevation difference correction on the detection first arrival time of the receiving depth position to obtain the corrected first arrival time of the receiving depth position; determining the target anisotropy parameters based on the reflection wave durations respectively corresponding to the multiple candidate anisotropy parameters at the receiving depth position and the corrected first arrival time of the receiving depth position.

[0007] Optionally, there are multiple excitation points, and performing elevation difference correction on the detection first arrival time of the receiving depth position to obtain the corrected first arrival time of the receiving depth position includes: determining the direction angles of multiple excitation points toward the detection point; determining a first number of excitation points in a predetermined angle range based on the direction angles corresponding to the multiple excitation points, wherein the predetermined angle range is determined based on the target direction angle; determining the detection first arrival times corresponding to the first number of excitation points; performing elevation difference correction on the detection first arrival times corresponding to the first number of excitation points based on the first elevation of the detection point, the second elevation of the excitation point, and the vertical average velocity to obtain the first first arrival times corresponding to the first number of excitation points, wherein the vertical average velocity is the average velocity from the surface of the detection point to the receiving depth position; determining the corrected first arrival time based on the first first arrival times corresponding to the first number of excitation points.

[0008] Optionally, determining the target anisotropic parameter of the predetermined stratum at the target direction angle based on the reflection wave durations respectively corresponding to the multiple candidate anisotropic parameters and the detection first arrival time includes: determining the duration error values ​​respectively corresponding to the multiple candidate anisotropic parameters at the receiving depth position based on the reflection wave durations respectively corresponding to the multiple candidate anisotropic parameters and the detection first arrival time obtained at the receiving depth position; when there are multiple receiving depth positions, determining the average error values ​​respectively corresponding to the multiple candidate anisotropic parameters based on the duration error values ​​respectively corresponding to the multiple candidate anisotropic parameters at each receiving depth position included in the multiple receiving depth positions; and determining the candidate anisotropic parameter with the smallest average error value as the target anisotropic parameter.

[0009] Optionally, determining the detection point includes: determining a three-dimensional work area obtained by performing three-dimensional modeling on the work area where the detection point is located, wherein the three-dimensional work area is composed of a plurality of sub-areas, the plurality of sub-areas respectively correspond to sub-area gathers, and the sub-area gathers are composed of common center point gathers of the corresponding sub-areas; performing ellipse fitting on the plurality of sub-area gathers respectively, and determining the ellipse major axis and the ellipse minor axis corresponding to the plurality of sub-area gathers respectively; determining the apparent anisotropy strength corresponding to the plurality of sub-areas respectively based on the ellipse major axis and the ellipse minor axis corresponding to the plurality of sub-area gathers respectively; and determining the detection point based on the apparent anisotropy strength corresponding to the plurality of sub-areas respectively.

[0010] Optionally, after determining the detection point, the method further includes: obtaining formation thicknesses and layer velocities corresponding to a plurality of formations at the location of the detection point, wherein the plurality of formations include the predetermined formation; based on the formation thicknesses and layer velocities corresponding to the plurality of formations, and a predetermined high-speed layer velocity, determining the well source distance between the detection point and the excitation point on the surface.

[0011] Optionally, the isotropic medium characteristics at the detection point match the characteristics of the transversely isotropic medium of the horizontal column symmetry axis, and the target anisotropic parameters include a first parameter and a second parameter, the first parameter is used to represent the velocity difference between the longitudinal wave in a direction parallel to the symmetry axis and a direction perpendicular to the symmetry axis, and the second parameter is used to represent the velocity difference between the longitudinal wave in a direction perpendicular to the symmetry axis and a direction parallel to the symmetry axis.

[0012] According to another aspect of an embodiment of the present invention, a device for determining anisotropic parameters in a stratum is provided, comprising: a positioning module for determining a detection point; an excitation module for controlling excitation points around the detection point to excite waves, and obtaining a detection first arrival time corresponding to the excitation point at a predetermined receiving depth position below the detection point, wherein the receiving depth position is in a corresponding predetermined stratum, and the detection first arrival time is the time required for the wave excited by the excitation point to reach the receiving depth position for the first time; a first determination module for determining a plurality of preset candidate anisotropic parameters; a calculation module for determining, based on a preset target direction angle, the reflection wave time corresponding to each of the plurality of candidate anisotropic parameters in the receiving depth position; and a second determination module for determining a target anisotropic parameter of the predetermined stratum at the target direction angle based on the reflection wave time corresponding to each of the plurality of candidate anisotropic parameters and the detection first arrival time.

[0013] According to another aspect of an embodiment of the present invention, a non-volatile storage medium is provided, wherein the non-volatile storage medium stores a plurality of instructions, wherein the instructions are suitable for being loaded by a processor and executing any one of the methods for determining anisotropic parameters in a formation.

[0014] According to another aspect of an embodiment of the present invention, an electronic device is provided, comprising: one or more processors and a memory, the memory being used to store one or more programs, wherein when the one or more programs are executed by the one or more processors, the one or more processors implement any one of the methods for determining anisotropic parameters in a formation.

[0015] In the embodiment of the present invention, by determining a detection point; controlling the excitation points around the detection point to excite waves, and obtaining the detection first arrival time corresponding to the excitation point at a predetermined receiving depth position below the detection point, wherein the receiving depth position is in the corresponding predetermined stratum, and the detection first arrival time is the time required for the wave excited by the excitation point to reach the receiving depth position for the first time; determining a plurality of preset candidate anisotropic parameters; based on a preset target direction angle, determining the reflection wave time corresponding to the plurality of candidate anisotropic parameters in the receiving depth position; based on the reflection wave time corresponding to the plurality of candidate anisotropic parameters, and the detection first arrival time, determining the target anisotropic parameters of the predetermined stratum at the target direction angle. The purpose of obtaining the anisotropic parameters corresponding to the plurality of strata respectively by inversion layer by layer is achieved, and the technical effect of improving the accuracy of the anisotropic parameters is achieved, thereby solving the technical problem of the unsatisfactory accuracy of the anisotropic parameters in the related art. BRIEF DESCRIPTION OF THE DRAWINGS

[0016] The drawings described herein are used to provide a further understanding of the present invention and constitute a part of this application. The exemplary embodiments of the present invention and their descriptions are used to explain the present invention and do not constitute an improper limitation of the present invention. In the drawings:

[0017] Figure 1 is a flow chart of an optional method for determining anisotropic parameters in a formation provided according to an embodiment of the present invention;

[0018] Figure 2 is a schematic diagram of an ellipse fitting of an optional method for determining anisotropic parameters in a formation provided according to an embodiment of the present invention;

[0019] Figure 3 is a schematic diagram of apparent anisotropy intensity of an optional method for determining anisotropy parameters in a formation provided according to an embodiment of the present invention;

[0020] Figure 4 is a detection schematic diagram of an optional method for determining anisotropic parameters in a formation provided according to an embodiment of the present invention;

[0021] Figure 5 is a schematic diagram of the direction angle of an optional method for determining anisotropic parameters in a formation provided according to an embodiment of the present invention;

[0022] Figure 6 is a schematic diagram of a formation according to an optional method for determining anisotropic parameters in a formation provided by an embodiment of the present invention;

[0023] Figure 7 is a schematic diagram of an application of an optional method for determining anisotropic parameters in a formation provided according to an embodiment of the present invention;

[0024] Figure 8 is a first arrival time correction diagram of an optional method for determining anisotropic parameters in a formation provided according to an embodiment of the present invention;

[0025] Fig. 9 is a schematic diagram of errors of an optional method for determining anisotropic parameters in a formation provided according to an embodiment of the present invention;

[0026] Fig.10 is a schematic diagram of the effect of an optional method for determining anisotropic parameters in a formation provided according to an embodiment of the present invention; and

[0027] Fig.11 It is a schematic diagram of an optional device for determining anisotropic parameters in a formation provided according to an embodiment of the present invention. DETAILED DESCRIPTION

[0028] In order to enable those skilled in the art to better understand the scheme of the present invention, the technical scheme in the embodiments of the present invention will be clearly and completely described below in conjunction with the drawings in the embodiments of the present invention. Obviously, the described embodiments are only part of the embodiments of the present invention, not all of the embodiments. Based on the embodiments of the present invention, all other embodiments obtained by ordinary technicians in this field without creative work should fall within the scope of protection of the present invention.

[0029] It should be noted that the terms "first", "second", etc. in the specification and claims of the present invention and the above-mentioned drawings are used to distinguish similar objects, and are not necessarily used to describe a specific order or sequence. It should be understood that the data used in this way can be interchanged where appropriate, so that the embodiments of the present invention described herein can be implemented in an order other than those illustrated or described herein. 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 device that includes a series of steps or units is not necessarily limited to those steps or units that are clearly listed, but may include other steps or units that are not clearly listed or inherent to these processes, methods, products or devices.

[0030] For the convenience of description, some nouns or terms involved in the embodiments of the present application are explained below:

[0031] Common Midpoint Gather (CMP Gather) refers to a gather consisting of seismic data recorded from different shot points (also called excitation points) and receiver positions based on the same center point. In three-dimensional exploration, multiple shot points and receiver positions are usually used for observation, and each combination corresponds to a common midpoint gather. The common midpoint gather records seismic wave data at different positions and can be used to analyze the characteristics and structure of underground media.

[0032] Subarea gathers refer to a rectangular area composed of two adjacent detection lines and shot lines in a three-dimensional exploration area as a subarea. The gathers composed of all the common center point gathers in the subarea are called subarea gathers. Subarea gathers contain seismic data at different locations in the subarea and can be used for seismic data processing, imaging and interpretation. The division of subarea gathers is to facilitate the analysis and processing of local areas to improve the accuracy and reliability of geological structure interpretation. By using subarea gathers, the seismic data of local areas can be analyzed in more detail and meticulously, thereby obtaining more accurate underground medium information.

[0033] Anisotropy parameters, where the term anisotropy refers to the different characteristics or behaviors of physical properties in the formation in different directions. Simply put, anisotropy means that the formation responds differently to a certain physical measurement indicator (such as wave velocity, resistivity, etc.) in different directions. This difference can be caused by factors such as geological structure, rock structure, and stress state. Anisotropy parameters are very important in formation exploration. It can provide information about rock types, fracture and pore properties, stress distribution, etc. in the formation, and has important guiding significance for oil and gas exploration, mineral resource assessment, geological disaster research, etc. In addition, for technologies such as seismic exploration, geoelectric exploration, and geothermal exploration, considering anisotropy can improve the accuracy and reliability of exploration interpretation.

[0034] Shot Interval refers to the distance between two adjacent shot points (excitation points) in seismic exploration. In seismic exploration, a series of shot points are usually arranged on the surface. Each shot point will emit seismic energy once, which will propagate through the underground medium and then be recorded by the seismic receiver (seismograph). The choice of shot interval will affect the resolution and signal-to-noise ratio of seismic data. The larger the shot interval, the greater the depth of seismic wave propagation, but the resolution and signal-to-noise ratio will be reduced accordingly. The choice of shot interval needs to comprehensively consider factors such as the characteristics of the underground medium, the exploration target, and the actual exploration conditions.

[0035] The apparent anisotropy intensity refers to the degree of change in the properties of underground rocks or strata in different directions during geological exploration. It describes the anisotropic response ability of geological media to the propagation of seismic waves. When underground rocks or strata are isotropic, the changes in their properties in different directions are the same, and the speed and propagation path of seismic waves are also uniform. However, when underground rocks or strata are anisotropic, their properties change differently in different directions, and the speed and propagation path of seismic waves will change. The apparent anisotropy intensity describes the magnitude of this change. It can be used to explain the non-uniformity of the speed and path of seismic wave propagation underground, which is of great significance for geological exploration, earthquake source location, seismic waveform analysis, etc.

[0036] According to an embodiment of the present invention, a method embodiment for determining anisotropic parameters in a formation is provided. It should be noted that the steps shown in the flowchart of the accompanying drawings can be executed in a computer system such as a set of computer executable instructions, and although a logical order is shown in the flowchart, in some cases, the steps shown or described can be executed in an order different from that shown here.

[0037] Figure 1 is a flow chart of a method for determining anisotropic parameters in a formation according to an embodiment of the present invention. Figure 1 As shown, the method comprises the following steps:

[0038] Step S102, determining a detection point;

[0039] It can be understood that the above detection points are used to detect anisotropic parameters in the shallow layer of the work area.

[0040] In an optional embodiment, the isotropic medium characteristics at the detection point match the characteristics of the transversely isotropic medium of the horizontal column symmetry axis, and the target anisotropic parameters include a first parameter and a second parameter, the first parameter is used to represent the velocity difference between the longitudinal wave in the direction parallel to the symmetry axis and the direction perpendicular to the symmetry axis, and the second parameter is used to represent the velocity difference between the longitudinal wave in the direction perpendicular to the symmetry axis and the direction parallel to the symmetry axis.

[0041] It can be understood that the azimuthal velocity anisotropy of the stratum is ubiquitous, that is, the velocity of the seismic wave propagating in the medium will vary depending on the propagation direction. Anisotropic media mainly include orthogonal anisotropic media and transversely isotropic media. Transversely isotropic media (TI media for short) refers to media with a cylindrical symmetry axis, which is the most widely used anisotropic media model in the field of exploration seismology. According to whether its symmetry axis is oriented vertically, horizontally, or inclined in space, they are called VTI media, HTI media, and TTI media, respectively. The isotropic medium characteristics at the detection point position match the characteristics of the transversely isotropic medium with a horizontal cylindrical symmetry axis, and can be expressed as HTI media. In order to characterize the anisotropy intensity, anisotropic parameters are used for description. The first parameter can be expressed as ε, which is used to represent the difference in velocity of the longitudinal wave in the direction parallel to the symmetry axis and perpendicular to the symmetry axis, reflecting the strength of the longitudinal wave anisotropy. ε = 0 means no longitudinal wave anisotropy. The second parameter can be expressed as δ, which is used to represent the velocity difference between the longitudinal wave in the direction perpendicular to the symmetry axis and the direction parallel to the symmetry axis, and describes the strength of the anisotropy of the longitudinal wave velocity near the direction perpendicular to the symmetry axis.

[0042] It should be noted that there are other types of anisotropy parameters, such as φ and γ. φ represents the angle between the symmetry axis and the vertical axis. φ = 0 represents VTI medium, and φ = 90 represents HTI medium. γ represents the difference in the velocity of the shear wave in the direction parallel to the symmetry axis and in the direction perpendicular to the symmetry axis, reflecting the strength of the shear wave anisotropy. γ = 0 represents no shear wave anisotropy.

[0043] In an optional embodiment, determining the detection point includes: determining a three-dimensional work area obtained by performing three-dimensional modeling on the work area where the detection point is located, wherein the three-dimensional work area is composed of a plurality of sub-areas, the plurality of sub-areas respectively correspond to sub-area gathers, and the sub-area gathers are composed of common center point gathers of the corresponding sub-areas; performing ellipse fitting on the plurality of sub-area gathers respectively, and determining the ellipse major axis and the ellipse minor axis corresponding to the plurality of sub-area gathers respectively; determining the apparent anisotropy strength corresponding to the plurality of sub-areas respectively based on the ellipse major axis and the ellipse minor axis corresponding to the plurality of sub-area gathers respectively; and determining the detection point based on the apparent anisotropy strength corresponding to the plurality of sub-areas respectively.

[0044] It can be understood that the location selection of the above detection points has a great influence on the determination of the anisotropy parameters. It is not subjectively selected, but determined based on the simulation of the three-dimensional work area. The above three-dimensional work area is composed of multiple sub-areas, each of which is a rectangular area composed of two adjacent detection lines and shot lines, and the sub-area gathers are composed of the common center point gathers of the corresponding sub-areas. In order to determine the apparent anisotropy intensity in each sub-area, ellipse fitting processing can be performed separately to determine the major axis and minor axis of the ellipse corresponding to the multiple sub-area gathers. According to the major axis and minor axis of the ellipse corresponding to the multiple sub-area gathers, the apparent anisotropy intensity corresponding to the multiple sub-areas can be determined. Positions with high anisotropy intensity are often accompanied by complex changes in the strata, and this complexity will have a significant impact on the propagation of seismic waves. Therefore, selecting positions with high anisotropy intensity to set detection points can improve the resolution and accuracy of anisotropy parameters.

[0045] It should be noted that in geological exploration, the receiver line refers to the connection line of multiple seismic detectors (seismic detectors are set at predetermined detection points) arranged on the ground. Seismic detectors can be seismic recorders, seismic sensors, etc., which are used to receive information such as reflection, refraction, and scattering during the propagation of seismic waves. Through multiple detectors on the receiver line, the reception of seismic waves at different positions can be recorded and analyzed to obtain underground geological information. The shot line, or shot line, refers to the connection line of multiple seismic energy sources (seismic energy sources are set at predetermined excitation points) arranged on the ground. The seismic energy source will generate seismic waves, propagate through the underground medium, and reflect, refract, and scatter at the interfaces of different layers underground. The layout of the shot line usually intersects with the receiver line so as to obtain information on the underground geological structure through the propagation and reflection of seismic waves underground. Detection lines and shot lines are often used together in geological exploration. By setting up excitation points and detection points, the propagation and reflection of seismic waves underground are recorded to obtain information on the underground geological structure, including the thickness, lithology, and structure of the strata.

[0046] Optionally, for one of the multiple sub-areas, in order to determine the first arrival time and the corresponding azimuth within a specified offset range in the corresponding sub-area gather, the offset range may be processed in the following manner:

[0047] offset∈[(2×H-Δx / 2), (2×H+Δx / 2)]

[0048] Among them, H represents the total thickness of the low velocity reduction layer in the shallow layer, and Δx is the diagonal half length of one of the multiple sub-areas. It can be understood that H is the total thickness of the multiple strata at the location of the detection point, and the multiple strata are the low velocity reduction layer in the shallow layer.

[0049] Optionally, for one of the multiple sub-areas, an ellipse fitting is performed on the sub-area gathers with the center point of the corresponding sub-area gathers as the pole, the azimuth as the polar angle, and the first arrival time as the polar axis length to obtain the ellipse major axis L of the fitted ellipse. a and the minor axis L of the ellipse b The apparent anisotropy strength S of the sub-region is obtained by Anti .

[0050]

[0051] Figure 2 Schematic diagram of ellipse fitting of an optional method for determining anisotropic parameters in a formation provided according to an embodiment of the present invention. The units of the horizontal and vertical coordinates are 500m (meters)*10 4 , Figure 2 The small ellipses in the figure are obtained by fitting the ellipses of multiple sub-area gathers. The major axis and minor axis of each small ellipse are marked. According to the apparent anisotropy strength, it can be understood that the major axis L a The larger the ellipse minor axis L b The smaller the anisotropy strength S Anti The bigger.

[0052] Figure 3 is a schematic diagram of apparent anisotropy intensity of an optional method for determining anisotropy parameters in a formation provided according to an embodiment of the present invention, and the apparent anisotropy intensity corresponding to all sub-areas is visually marked, such as Figure 3 As shown, the irregular area marked with oblique lines is the area with larger apparent anisotropy intensity, and the center point of the sub-area gather with the largest apparent anisotropy intensity is marked with concentric circles as the selected detection point.

[0053] In an optional embodiment, after determining the detection point, the method further includes: obtaining the formation thickness and layer velocity corresponding to multiple formations at the location of the detection point, wherein the multiple formations include a predetermined formation; based on the formation thickness and layer velocity corresponding to the multiple formations, and the predetermined high-speed layer velocity, determining the well source distance between the detection point and the excitation point on the surface.

[0054] It can be understood that the distance between the detection point and the excitation point is called the well-source distance, and its size determines the nature of the wave received by the detection point. In order to ensure that the first arrival wave is a transmitted wave and avoid the first arrival wave being a refracted wave, it is necessary to determine the well-source distance based on the formation thickness and layer velocity corresponding to the multiple formations where the detection point is located, as well as the predetermined high-speed layer velocity. Through the above method, the distance between the detection point and the excitation point can be set accurately, which is conducive to improving the accuracy of the anisotropic parameters.

[0055] It should be noted that the velocity of the high-speed layer refers to the speed at which waves propagate within the high-speed layer. These high-speed layers are usually composed of solid rock and have faster speeds. By measuring the arrival time of seismic waves received at different locations, the velocity of the underground high-speed layer can be calculated.

[0056] It is still necessary to explain that transmission waves and refracted waves are two different types of fluctuations that occur when seismic waves propagate in underground media. Transmission waves refer to the fluctuations that seismic waves directly enter another medium through the medium interface when they propagate from one medium to another. When seismic waves propagate from one medium to another, part of the wave energy will pass through the medium interface and continue to propagate in the other medium. The propagation direction of the transmission wave is the same as that of the incident wave. Refracted waves refer to the fluctuations that are deflected during the propagation of seismic waves due to changes in medium density and velocity. When seismic waves propagate from one medium to another, the wave velocity changes due to the different densities and velocities of the two media, resulting in a deflection in the propagation direction of the wave. The propagation direction of the refracted wave is different from that of the incident wave. The difference between the two is that transmission waves are fluctuations that seismic waves directly enter another medium through the medium interface, while refracted waves are fluctuations that are deflected during the propagation of seismic waves in the medium due to changes in medium density and velocity. The propagation direction of the transmission wave is the same as that of the incident wave, while the propagation direction of the refracted wave is different from that of the incident wave. It can be understood that the propagation paths and propagation speeds of transmitted waves and refracted waves are different because the physical properties of the medium vary between different media. Transmitted waves and refracted waves have different characteristics in seismic exploration and have different meanings and roles in studying the properties and structure of underground media.

[0057] Optionally, the above-mentioned multiple strata belong to shallow layers in the geological structure, and multiple strata belong to low velocity reduction layers, which are distinguished from predetermined high velocity layers.

[0058] Optionally, the well source distance X is determined by:

[0059]

[0060] Among them, NL represents the total number of layers at the detection point (multiple layers belong to low velocity reduction layers), H r represents the thickness of the rth stratum, V r represents the interval velocity of the rth formation, V NL+1 Indicates the predetermined high-speed layer speed, and floor indicates the rounding-down function.

[0061] Optionally, in the case where there are multiple excitation points, the distances between the multiple excitation points and the detection point are all well-source distances, which can be regarded as the radius.

[0062] Step S104, controlling the excitation points around the detection point to excite waves, and obtaining the detection first arrival time corresponding to the excitation point at a predetermined receiving depth position below the detection point, wherein the receiving depth position is in a corresponding predetermined stratum, and the detection first arrival time is the time required for the wave excited by the excitation point to reach the receiving depth position for the first time;

[0063] It can be understood that the excitation points around the detection point are controlled to excite waves, and the waves can be understood as seismic waves. At the receiving depth position in the stratum below the detection point, the first arrival time of the wave excited by the excitation point can be received. The detection first arrival time can indicate the propagation speed in the predetermined stratum, which is very important for analyzing the structural parameters in the predetermined stratum.

[0064] Optionally, before controlling the excitation process, the performance of the controllable seismic source set at the excitation point and the performance of the detector are detected, and when it is determined that the performance meets the predetermined equipment conditions, the excitation process of the seismic wave is performed.

[0065] Optionally, a variety of seismic detectors, such as fiber optic detectors, can be set at the detection point to conduct detection in the predetermined formation along the micro-well wellhead set at the detection point. Gravel buried well coupling can also be used to set micro-wells at the detection point, which can also be called the source well method. Figure 4 FIG. 1 is a detection schematic diagram of an optional method for determining anisotropic parameters in a formation provided according to an embodiment of the present invention, such as Figure 4 As shown, the detector is shown downward from the detection point as a schematic diagram of the wave excited by the excitation point, the intersection of the excitation point on the detector is a schematic diagram of the receiving depth position, and the plane where the detection point and the excitation point are located is a schematic diagram of the ground surface.

[0066] Step S106, determining a plurality of preset candidate anisotropy parameters;

[0067] It can be understood that a plurality of candidate anisotropy parameters may be set for a predetermined formation.

[0068] Step S108, determining the reflection wave durations corresponding to the plurality of candidate anisotropy parameters at the receiving depth position based on the preset target direction angle;

[0069] It can be understood that the target direction angle indicates that the anisotropy parameter in the direction needs to be detected, and the reflection wave durations corresponding to the multiple candidate anisotropy parameters in the receiving depth position can be obtained.

[0070] Step S110, determining a target anisotropy parameter of a predetermined stratum at a target direction angle based on the reflection wave durations corresponding to a plurality of candidate anisotropy parameters and the detection first arrival durations.

[0071] It can be understood that by taking the target direction angle as the orientation and using the reflection wave durations corresponding to the multiple determined candidate anisotropic parameters, the measured detection first arrival durations can be compared, so as to improve the accuracy of characterizing the multiple candidate anisotropic parameters.

[0072] In an optional embodiment, based on the reflection wave durations corresponding to multiple candidate anisotropy parameters and the detection first arrival time, the target anisotropy parameters of the predetermined stratum at the target direction angle are determined, including: performing elevation difference correction on the detection first arrival time of the receiving depth position to obtain the corrected first arrival time of the receiving depth position; based on the reflection wave durations corresponding to multiple candidate anisotropy parameters at the receiving depth position and the corrected first arrival time of the receiving depth position, the target anisotropy parameters are determined.

[0073] It can be understood that there may be a surface elevation difference between the detection point and the excitation point in a specific application environment, and it is difficult for them to be directly in the same horizontal plane, so the detection time of the seismic wave will be affected. This is because refraction and reflection will occur when the wave propagates in different media, and the elevation difference will cause the seismic wave to be deflected or reflected on the propagation path, thereby changing the detection time of the seismic wave. Therefore, it is necessary to consider the elevation difference between the detection point and the excitation point to obtain the target anisotropy parameters more accurately. The detection time of the receiving depth position is corrected by the elevation difference to obtain the corrected first arrival time of the receiving depth position, reducing the interference caused by the elevation difference. Then, based on the reflection wave duration corresponding to multiple candidate anisotropy parameters at the receiving depth position, and the corrected first arrival time of the receiving depth position, the target anisotropy parameters with better accuracy are determined.

[0074] It should be noted that if the detection point is at a higher position relative to the excitation point, the seismic wave needs to overcome more gravitational potential energy before reaching the detection point, and the propagation speed will slow down, resulting in a longer first arrival time. On the contrary, if the detection point is at a lower position, the seismic wave will propagate downhill before reaching the detection point, and the propagation speed will increase, resulting in a shorter first arrival time. In addition, the elevation difference will also cause the seismic wave to reflect on the propagation path, so that the seismic wave needs to bypass obstacles or propagate a longer distance along the surface, thereby extending the first arrival time. Conversely, if there are no obstacles on the seismic wave propagation path, the impact of the elevation difference on the first arrival time may be smaller.

[0075] In an optional embodiment, there are multiple excitation points, and the detection first arrival time of the receiving depth position is corrected by elevation difference to obtain the corrected first arrival time of the receiving depth position, including: determining the direction angles of the multiple excitation points toward the detection point; determining a first number of excitation points in a predetermined angle range based on the direction angles corresponding to the multiple excitation points, wherein the predetermined angle range is determined based on the target direction angle; determining the detection first arrival times corresponding to the first number of excitation points; based on the first elevation of the detection point, the second elevation of the excitation point, and the vertical average speed, performing elevation difference correction on the detection first arrival times corresponding to the first number of excitation points, respectively, to obtain the first first arrival times corresponding to the first number of excitation points, wherein the vertical average speed is the average speed from the surface of the detection point to the receiving depth position; determining the corrected first arrival times based on the first first arrival times corresponding to the first number of excitation points.

[0076] It can be understood that there can be multiple excitation points, and the corresponding direction angle of each excitation point relative to the detection point can be determined. The predetermined angle range is determined based on the target direction angle, and the first number of excitation points that meet the predetermined angle range can be selected according to the direction angles corresponding to the multiple excitation points. Using the first elevation of the detection point, the second elevation of the excitation point, and the vertical average velocity, the elevation difference correction is performed on the detection first arrival time corresponding to the first number of excitation points, and the first first arrival time corresponding to the first number of excitation points is obtained. Based on the first first arrival time corresponding to the first number of excitation points, the corrected first arrival time can be determined. Through the above processing, the processing of the corrected first arrival time of the receiving depth position can be completed using the first number of excitation points that are adjacent in position within the predetermined angle range.

[0077] Optionally, the first number is an integer greater than or equal to 2.

[0078] Optionally, the direction angles corresponding to the multiple excitation points are determined as an azimuth fitting method in the following manner, denoted as

[0079]

[0080] Among them, X R and Y R Respectively represent the east and north coordinates of the detection point, and denote the east and north coordinates of the i-th excitation point, respectively, atan denotes the inverse tangent function, represents the azimuth corresponding to the i-th excitation point.

[0081] Assume that 5° equally spaced azimuths are given in the range [0°,90°] It can be expressed as:

[0082]

[0083] Figure 5 is a schematic diagram of the direction angle of an optional method for determining anisotropic parameters in a formation according to an embodiment of the present invention, wherein the target direction angle is set to k0∈k, the predetermined angle range can be determined as Figure 5 For the sake of clarity, only some of the excitation points are marked. Figure 5 The predetermined angle range is marked in dashed lines. The first number of excitation points selected in the predetermined angle range is represented as m∈[k0-1,k0+1], the first first arrival durations corresponding to the first number of excitation points are determined in the following manner and recorded as:

[0084]

[0085] Among them, T m,j represents the first arrival time of the jth receiving depth position at the mth excitation point, represents the elevation of the ith excitation point, E R Indicates the elevation of the detection point, Vav j represents the vertical distance from the surface to the jth receiving depth position

[0086] Towards average speed, T' m,j It represents the first arrival time of the jth receiving depth position at the mth excitation point.

[0087] At the target direction angle, the corrected first arrival time of the jth receiving depth position can be obtained by the following method, recorded as T” k0,j :

[0088] T” k0,j =mean(T' m,j )

[0089] Among them, mean represents the mean value function.

[0090] In an optional embodiment, based on the reflection wave durations corresponding to multiple candidate anisotropic parameters and the detection first arrival time, the target anisotropic parameters of the predetermined stratum at the target direction angle are determined, including: based on the reflection wave durations corresponding to multiple candidate anisotropic parameters and the detection first arrival time obtained at the receiving depth position, the duration error values ​​corresponding to multiple candidate anisotropic parameters in the receiving depth position are determined; in the case of multiple receiving depth positions, based on the duration error values ​​corresponding to multiple candidate anisotropic parameters of each receiving depth position included in the multiple receiving depth positions, the average error values ​​corresponding to multiple candidate anisotropic parameters are determined; and the candidate anisotropic parameter with the smallest average error value is determined as the target anisotropic parameter.

[0091] It can be understood that, with the horizontal layer where the receiving depth position is located as the reflection interface, the duration of the reflection wave corresponding to the multiple candidate anisotropic parameters and the first arrival duration of the detection obtained at the receiving depth position can be used to determine the duration error values ​​corresponding to the multiple candidate anisotropic parameters in the receiving depth position. There can be multiple receiving depth positions in the same predetermined formation, and the corresponding duration error value can be determined by using multiple candidate anisotropic parameters at each receiving depth position, and then the same processing is performed on the multiple receiving depth positions to determine the average error values ​​corresponding to the multiple candidate anisotropic parameters. The one with the smallest average error value among the multiple candidate anisotropic parameters is determined as the target anisotropic parameter of the predetermined formation.

[0092] Optionally, the detection first arrival time obtained at the receiving depth position may be corrected for elevation difference to obtain a corrected first arrival time.

[0093] Optionally, the predetermined stratum may be any one of a plurality of strata, and the plurality of strata may be processed in the same manner as the predetermined stratum. The plurality of strata may respectively correspond to different stratum depths or stratum velocities, so as to obtain target anisotropic parameters corresponding to the plurality of strata respectively. Figure 6 is a schematic diagram of a formation according to an optional method for determining anisotropic parameters in a formation provided by an embodiment of the present invention, Figure 6 It indicates that there may be corresponding reflection interfaces according to the receiving depth position, and illustrates the reflection process of the waves emitted from the excitation point on the above reflection interfaces.

[0094] Optionally, the predetermined stratum may be assumed to be the first stratum starting from the surface and having a maximum stratum depth of D1. There may be multiple receiving depth positions in the predetermined stratum. Assuming there are J receiving depth positions, the jth receiving depth position may be expressed as D j , D j∈[0,D1]. In the case where the anisotropic parameter includes the first parameter and the second parameter, the first layer has a preset anisotropic parameter range, the range of the first parameter is [-0.5,0), and the range of the second parameter is [-0.5,0). There can be multiple (set to Q) candidate first parameters in the range of the first parameter, the step size is selected as a predetermined value, and the qth candidate first parameter is recorded as ε q , ε q ∈[-0.5,0). There can be multiple (set to W) candidate second parameters in the range of the second parameter, the step size is selected as a predetermined value, and the wth candidate second parameter is recorded as δ w , δ w ∈[-0.5,0).

[0095] For the jth receiving depth position in the predetermined formation, at the target direction angle In the direction, using the qth candidate first parameter and the wth candidate second parameter, and taking twice the well-source distance as the reflection path length, the reflection wave duration can be obtained:

[0096] The difference between the duration of the reflected wave at each receiving depth position and the duration of the first arrival of the detection at the receiving depth position is taken as the duration error value corresponding to the anisotropic parameter value. The duration error values ​​corresponding to the anisotropic parameter values ​​at multiple receiving depth positions are accumulated to obtain the average error value under the anisotropic parameter value. At the jth receiving depth position, for the anisotropic parameter value ε q and δ w The average error value in the case can be expressed as follows:

[0097]

[0098] Among them, error q,w Indicates that when using ε q and δ w The average error value in the case of T k0,j is the corrected first arrival time of the jth receiving depth position.

[0099] It can be understood that there are at most Q*W ways to take the value of the anisotropic parameter. Q*W average error values ​​can be obtained at the j-th receiving depth position. Similarly, the J receiving depth positions are processed in the same way as the j-th receiving depth position. For a predetermined formation, there can be Q*W*J average error values. Among the Q*W*J values, the value of the anisotropic parameter with the smallest average error value is selected, such as ε1 and δ1, as the target anisotropic parameter.

[0100] Optionally, the target anisotropy parameters obtained above can be applied to a variety of application scenarios, such as shallow imaging, deep imaging, or shallow surface horizontal velocity. Figure 7 FIG. 1 is a schematic diagram of an optional method for determining anisotropic parameters in a formation according to an embodiment of the present invention. Figure 7 As shown, the inverted anisotropic parameters are used to calculate the horizontal velocity at the detection point, which is used for subsequent calibration of three-dimensional anisotropic velocity modeling and other applications.

[0101] Through the above steps S102 to S110, the purpose of obtaining anisotropic parameters corresponding to multiple strata by layer-by-layer inversion is achieved, the technical effect of improving the accuracy of anisotropic parameters is achieved, and the technical problem of unsatisfactory accuracy of anisotropic parameters in related technologies is solved.

[0102] Based on the above embodiments and optional embodiments, the present invention proposes an optional implementation mode, which is applied to a shallow surface HTI medium in a basin landform.

[0103] Step S1, determine the target work area, collect the three-dimensional seismic acquisition data of the target work area, including the first arrival time, perform ellipse fitting based on multiple sub-areas in the target work area, and determine the detection point with the largest apparent anisotropy intensity. Set a micro well at the detection point, and set a fiber optic detector in the well. With the wellhead as the center, 72 excitation points are arranged in a circular ring at an equal interval of 5 degrees. The distance between the well source and the well is 100 meters, and the fiber optic detector receives the whole well section in the well.

[0104] Step S2, excite the excitation points one by one, and obtain the detection first arrival time of the seismic wave excited by each excitation point at the receiving depth position. Use the detection point and the excitation point to correct the height difference of the detection first arrival time to obtain the corrected first arrival time. Figure 8 is a first arrival time correction diagram of an optional method for determining anisotropic parameters in a formation provided according to an embodiment of the present invention, such as Figure 8 As shown in the figure, by making all the excitation points at the same horizontal position and reducing the problems caused by measurement errors and receiving well inclination, the first arrival time needs to be corrected according to the equally spaced azimuths. Figure 7 The comparison between the first arrival time before correction (i.e., the detection first arrival time) and the first arrival time after correction (i.e., the correction first arrival time) is given in Figure 1. It can be seen that the same change trend exists before and after correction.

[0105] Step S3, there are multiple strata in the shallow layer, and each stratum is set with a value range of anisotropic parameters, which may include a first parameter ε and a second parameter δ. Starting from the first stratum, the average error values ​​corresponding to multiple candidate anisotropic parameters can be determined based on the first arrival time of the detection, and the target anisotropic parameters of the stratum are obtained, and other strata are processed in the same way. Fig. 9 It is an error diagram of an optional method for determining anisotropic parameters in a formation provided according to an embodiment of the present invention. The time error value generated by the anisotropic parameter is visualized, and the grayscale legend from dark to shallow can be represented as the time error value from small to large.

[0106] Fig.10 FIG. 1 is a schematic diagram showing the effect of an optional method for determining anisotropic parameters in a formation according to an embodiment of the present invention. Fig.10 As shown, it is shown that for azimuth angles ranging from 0 degrees to 360 degrees, the variation trends between the first arrival time of detection and the reflection wave time are basically consistent, which can reflect the reliability of the target anisotropic parameters.

[0107] The optional implementation at least achieves the effect of improving the accuracy of determining anisotropic parameters, which is beneficial to the improvement of the processing means for applying anisotropic parameters.

[0108] It should be noted that the steps shown in the flowcharts of the accompanying drawings can be executed in a computer system such as a set of computer executable instructions, and that, although a logical order is shown in the flowcharts, in some cases, the steps shown or described can be executed in an order different from that shown here.

[0109] In this embodiment, a device for determining anisotropic parameters in a formation is also provided, and the device is used to implement the above-mentioned embodiments and preferred implementation modes, and the descriptions that have been made will not be repeated. As used below, the terms "module" and "device" can implement a combination of software and / or hardware for a predetermined function. Although the devices described in the following embodiments are preferably implemented in software, the implementation of hardware, or a combination of software and hardware, is also possible and conceivable.

[0110] According to an embodiment of the present invention, there is also provided an embodiment of a device for implementing a method for determining anisotropic parameters in a formation. Fig.11 is a schematic diagram of a device for determining anisotropic parameters in a formation according to an embodiment of the present invention. Fig.11 As shown, the above-mentioned device for determining anisotropic parameters in the formation includes: a positioning module 1102, an excitation module 1104, a first determination module 1106, a calculation module 1108, and a second determination module 1110. The device is described below.

[0111] A positioning module 1102 is used to determine a detection point;

[0112] The excitation module 1104 is connected to the positioning module 1102, and is used to control the excitation points around the detection point to excite the wave, and obtain the detection first arrival time corresponding to the excitation point at a predetermined receiving depth position below the detection point, wherein the receiving depth position is in the corresponding predetermined stratum, and the detection first arrival time is the time required for the wave excited by the excitation point to reach the receiving depth position for the first time;

[0113] A first determination module 1106, connected to the excitation module 1104, for determining a plurality of preset candidate anisotropy parameters;

[0114] The calculation module 1108 is connected to the first determination module 1106 and is used to determine the reflection wave durations corresponding to the plurality of candidate anisotropic parameters at the receiving depth position based on a preset target direction angle;

[0115] The second determination module 1110 is connected to the calculation module 1108, and determines the target anisotropy parameter of the predetermined stratum at the target direction angle based on the reflection wave durations corresponding to the plurality of candidate anisotropy parameters and the detection first arrival durations.

[0116] In a device for determining anisotropic parameters in a stratum provided by an embodiment of the present invention, by setting a positioning module 1102, an excitation module 1104, a first determination module 1106, a calculation module 1108, and a second determination module 1110, the purpose of obtaining anisotropic parameters corresponding to multiple strata respectively by inversion layer by layer is achieved, and the technical effect of improving the accuracy of anisotropic parameters is achieved, thereby solving the technical problem of unsatisfactory accuracy of anisotropic parameters in related technologies.

[0117] It should be noted that the above modules can be implemented by software or hardware. For example, for the latter, it can be implemented in the following ways: the above modules can be located in the same processor; or the above modules can be located in different processors in any combination.

[0118] It should be noted that the positioning module 1102, the excitation module 1104, the first determination module 1106, the calculation module 1108, and the second determination module 1110 correspond to steps S102 to S110 in the embodiment, and the examples and application scenarios implemented by the modules and the corresponding steps are the same, but are not limited to the contents disclosed in the above embodiment. It should be noted that the modules as part of the device can be run in a computer terminal.

[0119] It should be noted that the optional or preferred implementation of this embodiment can refer to the relevant description in the embodiment, which will not be repeated here.

[0120] The above-mentioned device for determining anisotropic parameters in the formation may also include a processor and a memory. The positioning module 1102, the excitation module 1104, the first determination module 1106, the calculation module 1108, the second determination module 1110, etc. are all stored in the memory as program units, and the processor executes the above-mentioned program units stored in the memory to realize the corresponding functions.

[0121] The processor includes a kernel, which retrieves the corresponding program unit from the memory. There can be one or more kernels. The memory may include non-permanent memory in a computer-readable medium, random access memory (RAM) and / or non-volatile memory, such as read-only memory (ROM) or flash RAM, and the memory includes at least one storage chip.

[0122] An embodiment of the present invention provides a non-volatile storage medium on which a program is stored. When the program is executed by a processor, a method for determining anisotropic parameters in a formation is implemented.

[0123] An embodiment of the present invention provides an electronic device, which includes a processor, a memory, and a program stored in the memory and can be run on the processor. When the processor executes the program, the following steps are implemented: determining a detection point; controlling the excitation points around the detection point to excite waves, and obtaining the detection first arrival time corresponding to the excitation point at a predetermined receiving depth position below the detection point, wherein the receiving depth position is in a corresponding predetermined stratum, and the detection first arrival time is the time required for the wave excited by the excitation point to reach the receiving depth position for the first time; determining a plurality of preset candidate anisotropy parameters; based on a preset target direction angle, determining the reflection wave time corresponding to the plurality of candidate anisotropy parameters in the receiving depth position; based on the reflection wave time corresponding to the plurality of candidate anisotropy parameters, and the detection first arrival time, determining the target anisotropy parameters of the predetermined stratum at the target direction angle. The device in this article can be a server, a PC, etc.

[0124] The present invention also provides a computer program product, which, when executed on a data processing device, is suitable for executing a program that is initialized with the following method steps: determining a detection point; controlling the excitation points around the detection point to excite waves, and obtaining the detection first arrival time corresponding to the excitation point at a predetermined receiving depth position below the detection point, wherein the receiving depth position is in a corresponding predetermined stratum, and the detection first arrival time is the time required for the wave excited by the excitation point to reach the receiving depth position for the first time; determining a plurality of preset candidate anisotropy parameters; based on a preset target direction angle, determining the reflection wave durations corresponding to the plurality of candidate anisotropy parameters in the receiving depth position; based on the reflection wave durations corresponding to the plurality of candidate anisotropy parameters and the detection first arrival time, determining the target anisotropy parameters of the predetermined stratum at the target direction angle.

[0125] Those skilled in the art will appreciate that embodiments of the present invention may be provided as methods, systems, or computer program products. Therefore, the present invention may take the form of a complete hardware embodiment, a complete software embodiment, or an embodiment combining software and hardware. Moreover, the present invention may take the form of a computer program product implemented on one or more computer-usable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0126] The present invention is described with reference to flowcharts and / or block diagrams of methods, devices (systems), and computer program products according to embodiments of the present invention. It should be understood that each process and / or block in the flowchart and / or block diagram, as well as the combination of processes and / or blocks in the flowchart and / or block diagram, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, a special-purpose computer, an embedded processor, or other programmable data processing device to produce a machine, so that the instructions executed by the processor of the computer or other programmable data processing device generate instructions for implementing the processes in the flowchart and / or block diagram. Figure 1 A process or multiple processes and / or boxes Figure 1 A device that provides the functions specified in a block or multiple blocks.

[0127] These computer program instructions may also be stored in a computer-readable memory capable of directing a computer or other programmable data processing device to operate in a specific manner, so that the instructions stored in the computer-readable memory produce an article of manufacture comprising an instruction device, which implements the process Figure 1 A process or multiple processes and / or boxes Figure 1 A function specified in one or more boxes.

[0128] These computer program instructions can also be loaded onto a computer or other programmable data processing device so that a series of operating steps are executed on the computer or other programmable device to produce a computer-implemented process, thereby providing instructions for implementing the process in the computer or other programmable device. Figure 1 A process or multiple processes and / or boxes Figure 1 The steps for the functions specified in one or more boxes.

[0129] In a typical configuration, a computing device includes one or more processors (CPU), input / output interfaces, network interfaces, and memory.

[0130] The memory may include non-permanent memory in a computer-readable medium, random access memory (RAM) and / or non-volatile memory in the form of read-only memory (ROM) or flash RAM. The memory is an example of a computer-readable medium.

[0131] Computer readable media include permanent and non-permanent, removable and non-removable media that can be implemented by any method or technology to store information. Information can be computer readable instructions, data structures, program modules or other data. Examples of computer storage media include, but are not limited to, phase change memory (PRAM), static random access memory (SRAM), dynamic random access memory (DRAM), other types of random access memory (RAM), read-only memory (ROM), electrically erasable programmable read-only memory (EEPROM), flash memory or other memory technology, compact disk read-only memory (CD-ROM), digital versatile disk (DVD) or other optical storage, magnetic cassettes, magnetic tape disk storage or other magnetic storage devices or any other non-transmission media that can be used to store information that can be accessed by a computing device. As defined herein, computer readable media does not include temporary computer readable media (transitory media), such as modulated data signals and carrier waves.

[0132] It should also be noted that the terms "include", "comprises" or any other variations thereof are intended to cover non-exclusive inclusion, so that a process, method, commodity or device including a series of elements includes not only those elements, but also other elements not explicitly listed, or also includes elements inherent to such process, method, commodity or device. In the absence of more restrictions, the elements defined by the sentence "comprises a ..." do not exclude the existence of other identical elements in the process, method, commodity or device including the elements.

[0133] It will be appreciated by those skilled in the art that embodiments of the present invention may be provided as methods, systems or computer program products. Therefore, the present invention may take the form of a complete hardware embodiment, a complete software embodiment or an embodiment combining software and hardware. Moreover, the present invention may take the form of a computer program product implemented on one or more computer-usable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) containing computer-usable program codes.

[0134] The above are only embodiments of the present invention and are not intended to limit the present invention. For those skilled in the art, the present invention may have various modifications and variations. Any modification, equivalent substitution, improvement, etc. made within the spirit and principle of the present invention should be included in the scope of the claims of the present invention.

Claims

1. A method for determining anisotropic parameters in a formation, characterized in that: include: Determine the detection point; Controlling the excitation points around the detection point to excite waves, and obtaining the detection first arrival time corresponding to the excitation point at a predetermined receiving depth position below the detection point, wherein the receiving depth position is in a corresponding predetermined stratum, and the detection first arrival time is the time required for the wave excited by the excitation point to reach the receiving depth position for the first time; Determining a plurality of preset candidate anisotropy parameters; Based on a preset target direction angle, determining the reflection wave durations corresponding to the plurality of candidate anisotropy parameters at the receiving depth position; Based on the reflection wave durations respectively corresponding to the multiple candidate anisotropy parameters and the detection first arrival duration, the target anisotropy parameter of the predetermined stratum at the target direction angle is determined.

2. The method according to claim 1, characterized in that: The step of determining the target anisotropy parameter of the predetermined stratum at the target direction angle based on the reflection wave durations respectively corresponding to the plurality of candidate anisotropy parameters and the first arrival duration of the detection comprises: Performing elevation difference correction on the detected first arrival time of the receiving depth position to obtain a corrected first arrival time of the receiving depth position; The target anisotropy parameter is determined based on the reflection wave durations respectively corresponding to the multiple candidate anisotropy parameters at the receiving depth position and the corrected first-arrival duration at the receiving depth position.

3. The method according to claim 2, characterized in that There are multiple excitation points, and performing elevation difference correction on the detected first arrival time of the receiving depth position to obtain the corrected first arrival time of the receiving depth position includes: Determine the direction angles of the multiple excitation points toward the detection point respectively; Determine a first number of excitation points in a predetermined angle range based on the direction angles respectively corresponding to the plurality of excitation points, wherein the predetermined angle range is determined based on the target direction angle; Determine the detection first arrival durations corresponding to the first number of excitation points respectively; Based on the first elevation of the detection point, the second elevation of the excitation point, and the vertical average velocity, the elevation difference correction is performed on the detection first arrival times corresponding to the first number of excitation points to obtain the first first arrival times corresponding to the first number of excitation points, wherein the vertical average velocity is the average velocity from the surface of the detection point to the receiving depth position; The corrected first-arrival duration is determined based on the first first-arrival durations respectively corresponding to the first number of excitation points.

4. The method according to claim 1, characterized in that: The step of determining the target anisotropy parameter of the predetermined stratum at the target direction angle based on the reflection wave durations respectively corresponding to the plurality of candidate anisotropy parameters and the first arrival duration of the detection comprises: Determine the duration error values ​​corresponding to the multiple candidate anisotropy parameters at the receiving depth position based on the reflection wave durations corresponding to the multiple candidate anisotropy parameters and the detection first arrival durations obtained at the receiving depth position; In the case where there are multiple receiving depth positions, determining average error values ​​respectively corresponding to the multiple candidate anisotropy parameters based on the duration error values ​​respectively corresponding to the multiple candidate anisotropy parameters of each receiving depth position included in the multiple receiving depth positions; The one with the smallest average error value among the multiple candidate anisotropic parameters is determined as the target anisotropic parameter.

5. The method according to claim 1, characterized in that Determining the detection point includes: Determine a three-dimensional work area obtained by three-dimensionally modeling the work area where the detection point is located, wherein the three-dimensional work area is composed of a plurality of sub-areas, the plurality of sub-areas respectively correspond to sub-area gathers, and the sub-area gathers are composed of common center point gathers of the corresponding sub-areas; Performing ellipse fitting on the plurality of sub-area gathers respectively to determine the ellipse major axis and the ellipse minor axis respectively corresponding to the plurality of sub-area gathers; Determining apparent anisotropy intensities corresponding to the plurality of sub-areas respectively based on the ellipse major axes and the ellipse minor axes respectively corresponding to the plurality of sub-area gathers; The detection point is determined based on the apparent anisotropy intensities respectively corresponding to the multiple sub-areas.

6. The method according to claim 1, characterized in that After determining the detection point, the method further includes: Acquire the formation thickness and formation velocity respectively corresponding to a plurality of formations at the location of the detection point, wherein the plurality of formations include the predetermined formation; Based on the formation thicknesses and layer velocities respectively corresponding to the multiple formations and a predetermined high-speed layer velocity, a well source distance between the detection point and the excitation point on the surface is determined.

7. The method according to any one of claims 1 to 6, characterized in that: The isotropic medium characteristics at the detection point match the characteristics of the transverse isotropic medium of the horizontal column symmetry axis. The target anisotropic parameters include a first parameter and a second parameter. The first parameter is used to represent the velocity difference between the longitudinal wave in the direction parallel to the symmetry axis and the direction perpendicular to the symmetry axis. The second parameter is used to represent the velocity difference between the longitudinal wave in the direction perpendicular to the symmetry axis and the direction parallel to the symmetry axis.

8. A device for determining anisotropic parameters in a formation, characterized in that: include: Positioning module, used to determine the detection point; An excitation module, used for controlling the excitation points around the detection point to excite waves, and obtaining the detection first arrival time corresponding to the excitation point at a predetermined receiving depth position below the detection point, wherein the receiving depth position is in a corresponding predetermined stratum, and the detection first arrival time is the time required for the wave excited by the excitation point to reach the receiving depth position for the first time; A first determination module, used to determine a plurality of preset candidate anisotropy parameters; A calculation module, used to determine the reflection wave durations corresponding to the plurality of candidate anisotropy parameters at the receiving depth position based on a preset target direction angle; The second determination module determines the target anisotropy parameter of the predetermined stratum at the target direction angle based on the reflection wave durations respectively corresponding to the multiple candidate anisotropy parameters and the detection first arrival duration.

9. A non-volatile storage medium, characterized in that: The non-volatile storage medium stores a plurality of instructions, and the instructions are suitable for being loaded by a processor and executed by the method for determining anisotropic parameters in a formation as described in any one of claims 1 to 7.

10. An electronic device, characterized in that: include: One or more processors and a memory, wherein the memory is used to store one or more programs, wherein when the one or more programs are executed by the one or more processors, the one or more processors implement the method for determining anisotropic parameters in a formation as described in any one of claims 1 to 7.

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