CN115561813A - Method and device for determining crack parameters and computer storage medium - Google Patents

Method and device for determining crack parameters and computer storage medium Download PDF

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CN115561813A
CN115561813A CN202110745402.4A CN202110745402A CN115561813A CN 115561813 A CN115561813 A CN 115561813A CN 202110745402 A CN202110745402 A CN 202110745402A CN 115561813 A CN115561813 A CN 115561813A
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seismic data
wave
wave seismic
target
converted
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岳媛媛
孙鹏远
宋强功
张建磊
李建峰
张红英
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China National Petroleum Corp
BGP Inc
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China National Petroleum Corp
BGP Inc
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    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
    • G01V1/28—Processing seismic data, e.g. analysis, for interpretation, for correction
    • G01V1/30—Analysis
    • G01V1/306—Analysis for determining physical properties of the subsurface, e.g. impedance, porosity or attenuation profiles
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V2210/00—Details of seismic processing or analysis
    • G01V2210/60—Analysis
    • G01V2210/62—Physical property of subsurface

Abstract

The embodiment of the application discloses a method and a device for determining fracture parameters and a computer storage medium, and belongs to the technical field of seismic exploration. The method comprises the following steps: when the detector receives multi-wave seismic data comprising pure transverse wave seismic data, PSV converted wave seismic data and SVP converted wave seismic data, the excitation direction of a transverse wave seismic source is reversed due to the fact that a seismic source vehicle turns back and forth, and therefore polarity adjustment processing can be conducted on the transverse wave source seismic data; and then, determining a shear wave splitting analysis time window corresponding to the multi-wave seismic data in each target layer according to the seismic data imaging section corresponding to the multi-wave seismic data, and determining the fracture parameters of each target layer through the shear wave splitting analysis time window corresponding to each target layer of the multi-wave seismic data. According to the embodiment of the application, shear wave splitting analysis is carried out through combination of converted waves and pure shear waves, and uniqueness and reliability of crack parameters are guaranteed.

Description

Determination method and device of crack parameters and computer storage medium
Technical Field
The embodiment of the application relates to the technical field of seismic exploration, in particular to a method and a device for determining crack parameters and a computer storage medium.
Background
With the development of multi-wave and multi-quantity seismic exploration technology, people have more and more deep knowledge of anisotropy phenomena. When seismic exploration is carried out, transverse waves can be excited by a transverse wave source to carry out exploration, transverse wave splitting can occur when the transverse waves obliquely pass through an azimuth anisotropic medium, and information such as crack directions and crack strength is carried by fast and slow transverse waves of splitting. Therefore, fracture parameters such as the direction of development and the density of the fracture can be obtained by shear wave splitting analysis.
At present, when analyzing shear wave splitting phenomenon, it is possible to perform shear wave splitting analysis by converting shear wave seismic data using PSV, or to perform pure shear wave splitting analysis using pure shear wave data. For the anisotropic medium in the same direction, the corresponding fracture parameters should be unique, but when the anisotropic medium in the same direction is analyzed by the two methods, the fracture parameters obtained by the two analyses may be different due to the difference in signal to noise ratio and the like in the above data, so that the underground fracture information is not unique, and the reliability of determining the fracture parameters is reduced.
Disclosure of Invention
The embodiment of the application provides a method and a device for determining a crack parameter and a computer storage medium, which can be used for solving the problem of low reliability of the crack parameter in the related technology. The technical scheme is as follows:
in one aspect, a method for determining fracture parameters is provided, and the method includes:
when multi-wave seismic data are received through a geophone, adjusting the multi-wave seismic data, wherein the multi-wave seismic data comprise pure transverse wave seismic data, PSV converted wave seismic data and SVP converted wave seismic data;
determining a shear wave splitting analysis time window corresponding to each target layer of the multi-wave seismic data according to the processed multi-wave seismic data;
and determining fracture parameters of each target layer according to the processed multi-wave seismic data and a shear wave splitting analysis time window corresponding to the multi-wave seismic data in each target layer.
In some embodiments, the adjusting the multi-wave seismic data when the multi-wave seismic data is received by the geophone includes:
when receiving transverse wave source seismic data through the detector, determining seismic data with a seismic source direction opposite to a target direction, wherein the target direction is an excitation direction specified when seismic source excitation is carried out on seismic source equipment, and the transverse wave source seismic data comprise the pure transverse wave seismic data and the SVP converted wave seismic data;
performing reversed polarity processing on the amplitude value of the transverse wave source seismic data with the seismic source direction opposite to the target direction to obtain transverse wave source seismic data with consistent excitation directions;
acquiring an azimuth angle of the multi-wave seismic data;
and performing alford rotation on the four-component seismic data of the pure transverse wave seismic data received by the horizontal component of the detector, performing horizontal component rotation on the two-component seismic data of the PSV converted wave seismic data received by the horizontal component of the detector, and performing horizontal seismic source rotation on the two-component seismic data of the SVP converted wave seismic data received by the vertical component of the detector according to the azimuth angle.
In some embodiments, the determining, according to the processed multi-wave seismic data, a shear wave splitting analysis time window corresponding to each destination layer of the multi-wave seismic data includes:
stacking or migration imaging processing is carried out on the processed multi-wave seismic data to obtain seismic data imaging results corresponding to the pure transverse wave seismic data, the PSV converted wave seismic data and the SVP converted wave seismic data respectively;
and carrying out horizon calibration in the seismic data imaging result to determine the shear wave splitting analysis time window of the pure shear wave seismic data, the PSV converted wave seismic data and the SVP converted wave seismic data in each target horizon.
In some embodiments, the determining fracture parameters of each target layer according to the processed multi-wave seismic data and a shear wave splitting analysis time window corresponding to the multi-wave seismic data at each target layer includes:
obtaining each effective component signal of the processed multi-wave seismic data in each destination layer, wherein the effective component signal comprises a specific component signal, the specific component signal comprises a SrRt component signal and an StRr component signal of the pure transverse wave seismic data, a PSRt component signal of the PSV converted wave seismic data and an StP component signal of the SVP converted wave seismic data, and the amplitude of the specific component signal in the destination layer is not 0;
and determining the fracture parameters of each target layer according to the effective component signals of the processed multi-wave seismic data in each target layer and the shear wave splitting analysis time window corresponding to each target layer.
In some embodiments, the determining fracture parameters of each destination layer according to the effective component signals of the processed multi-wave seismic data in each destination layer and the corresponding shear wave splitting analysis time window of each destination layer includes:
determining the amplitude energy of the specific component signal after transverse wave splitting correction in each target layer according to each effective component signal of the processed multi-wave seismic data in each target layer and a transverse wave splitting analysis time window corresponding to each target layer;
and determining a target fracture parameter as a fracture parameter of a target stratum, wherein the target stratum is any one stratum in the stratum transmitted by the multi-wave seismic data, and the target fracture parameter is a fracture parameter corresponding to the minimum amplitude energy of the specific component signal in the target stratum.
In another aspect, an apparatus for determining fracture parameters is provided, the apparatus comprising:
the adjusting module is used for adjusting and processing the multi-wave seismic data when the multi-wave seismic data are received by the geophone, and the multi-wave seismic data comprise pure transverse wave seismic data, PSV converted wave seismic data and SVP converted wave seismic data;
the first determining module is used for determining a transverse wave splitting analysis time window corresponding to each target layer of the multi-wave seismic data according to the processed multi-wave seismic data;
and the second determination module is used for determining the fracture parameters of each target layer according to the processed multi-wave seismic data and the corresponding shear wave splitting analysis time window of the multi-wave seismic data in each target layer.
In some embodiments, the adjustment module comprises:
the first determining submodule is used for determining seismic data with a seismic source direction opposite to a target direction when the transverse wave source seismic data are received through the detector, the target direction is an excitation direction specified when seismic source excitation is carried out on seismic source equipment, and the transverse wave source seismic data comprise the pure transverse wave seismic data and the SVP converted wave seismic data;
the processing submodule is used for carrying out reverse polarity processing on the amplitude value of the transverse wave source seismic data with the seismic source direction opposite to the target direction to obtain the transverse wave source seismic data with consistent excitation directions;
the first acquisition sub-module is used for acquiring the azimuth angle of the multi-wave seismic data;
and the rotation sub-module is used for performing alford rotation on the four-component seismic data of the pure transverse wave seismic data received by the horizontal component of the detector, performing horizontal component rotation on the two-component seismic data of the PSV converted wave seismic data received by the horizontal component of the detector, and performing horizontal seismic source rotation on the two-component seismic data of the SVP converted wave seismic data received by the vertical component of the detector according to the azimuth angle.
In some embodiments, the first determining module comprises:
the imaging submodule is used for carrying out superposition or migration imaging processing on the processed multi-wave seismic data to obtain seismic data imaging sections corresponding to the pure transverse wave seismic data, the PSV converted wave seismic data and the SVP converted wave seismic data respectively;
and the calibration sub-module is used for carrying out horizon calibration in the seismic data imaging section so as to determine the transverse wave splitting analysis time windows of the pure transverse wave seismic data, the PSV converted wave seismic data and the SVP converted wave seismic data in each target layer respectively.
In some embodiments, the second determining module comprises:
a second obtaining sub-module, configured to obtain each effective component signal of the processed multi-wave seismic data in each destination layer, where the effective component signal includes a specific component signal, where the specific component signal includes a SrRt component signal and a StRr component signal of the pure transverse wave seismic data, a PSRt component signal of the PSV converted wave seismic data, and a StP component signal of the SVP converted wave seismic data, and an amplitude of the specific component signal in the destination layer is not 0;
and the second determining submodule is used for determining the fracture parameters of the stratum of each layer according to the effective component signals of the processed multi-wave seismic data in each target layer and the shear wave splitting analysis time window corresponding to each target layer.
In some embodiments, the second determination submodule is to:
determining the amplitude energy of the specific component signal after transverse wave splitting correction in each target layer according to each effective component signal of the processed multi-wave seismic data in each target layer and a corresponding transverse wave splitting analysis time window in each target layer;
and determining a target fracture parameter as a fracture parameter of a target stratum, wherein the target stratum is any one stratum in the stratum transmitted by the multi-wave seismic data, and the target fracture parameter is a fracture parameter corresponding to the minimum amplitude energy of the specific component signal in the target stratum.
In another aspect, a computer-readable storage medium is provided, having instructions stored thereon, which when executed by a processor, implement any of the above-described methods of determining fracture parameters.
The beneficial effects brought by the technical scheme provided by the embodiment of the application at least comprise:
in the embodiment of the application, the fracture parameters of each target layer can be determined through the pure transverse wave seismic data, the PSV converted wave seismic data and the SVP converted wave seismic data, so that different fracture parameters are avoided from being obtained after being analyzed through converted waves or pure transverse waves independently, namely, transverse wave splitting analysis is carried out through the combination of the converted waves and the pure transverse waves, the uniqueness of the fracture parameters is ensured, and the reliability of determining the fracture parameters is improved.
Drawings
In order to more clearly illustrate the technical solutions in the embodiments of the present application, the drawings needed to be used in the description of the embodiments are briefly introduced below, and it is obvious that the drawings in the following description are only some embodiments of the present application, and it is obvious for those skilled in the art to obtain other drawings based on these drawings without creative efforts.
FIG. 1 is a flow chart of a method for determining fracture parameters according to an embodiment of the present disclosure;
FIG. 2 is a flow chart of another method for determining fracture parameters provided in the embodiments of the present application;
FIG. 3 is a schematic illustration of the results of seismic data imaging provided by an embodiment of the present application;
fig. 4 is a schematic structural diagram of a crack parameter determination apparatus provided in an embodiment of the present application;
fig. 5 is a schematic structural diagram of an adjusting module according to an embodiment of the present disclosure;
fig. 6 is a schematic structural diagram of a first determining module provided in an embodiment of the present application;
FIG. 7 is a schematic structural diagram of a second determining module provided in an embodiment of the present application;
fig. 8 is a schematic structural diagram of a terminal according to an embodiment of the present application.
Detailed Description
To make the objects, technical solutions and advantages of the embodiments of the present application more clear, the embodiments of the present application will be further described in detail with reference to the accompanying drawings.
Before explaining a method for determining a crack parameter provided in the embodiment of the present application in detail, an application scenario provided in the embodiment of the present application is first explained.
When the seismic exploration is carried out, the exploration can be carried out by a longitudinal wave source, and the exploration can also be carried out by exciting a transverse wave through a transverse wave source. Shear wave splitting occurs when the shear wave is skewed through an azimuthally anisotropic medium and can be recorded by a detector. The energy of the transverse wave is mainly recorded in two horizontal components of the three-component detector, if the two horizontal components are respectively parallel to and perpendicular to the crack direction, one horizontal component records the fast transverse wave, and the other horizontal component records the slow transverse wave; otherwise, the wave fields of the fast transverse wave and the slow transverse wave which are mixed together are recorded by the two horizontal components, so that the transverse wave reflection from the same reflection interface on each horizontal component repeatedly occurs at different times, and the transverse wave imaging result is poor and even the wrong imaging result is caused. Therefore, in order to avoid erroneous imaging results, it is common to perform shear wave splitting analysis by PSV conversion of shear wave seismic data, or to perform pure shear wave splitting analysis by using pure shear wave data, thereby separating fast and slow shear waves or performing shear wave splitting correction processing according to fast and slow shear wave time differences. However, when the anisotropic media in the same direction are analyzed by the two methods, the fracture parameters obtained by the two analyses may be different due to the difference in signal-to-noise ratio and the like, so that the underground fracture information is not unique, and the reliability of determining the fracture parameters is reduced.
Based on the application scenario, the embodiment of the application provides a crack parameter determination method capable of improving reliability and accuracy of crack parameter determination.
Fig. 1 is a flowchart of a method for determining a crack parameter provided in an embodiment of the present application, where the method for determining a crack parameter may include the following steps:
step 101: and when the multi-wave seismic data are received by the geophone, adjusting the multi-wave seismic data, wherein the multi-wave seismic data comprise pure transverse wave seismic data, PSV converted wave seismic data and SVP converted wave seismic data.
Step 102: and determining the shear wave splitting analysis time window corresponding to each target layer of the multi-wave seismic data according to the processed multi-wave seismic data.
Step 103: and determining the fracture parameters of each target layer according to the processed multi-wave seismic data and the shear wave splitting analysis time window of the multi-wave seismic data corresponding to each target layer.
In the embodiment of the application, the fracture parameters of each target layer can be determined through the pure transverse wave seismic data, the PSV converted wave seismic data and the SVP converted wave seismic data, so that different fracture parameters are avoided being obtained after being analyzed through converted waves or pure transverse waves independently, namely, transverse wave splitting analysis is carried out through the combination of the converted waves and the pure transverse waves, the uniqueness of the fracture parameters is ensured, and the reliability of determining the fracture parameters is improved.
In some embodiments, upon receiving the multi-wave seismic data by the geophone, the multi-wave seismic data is conditioned, including:
when the detector receives transverse wave source seismic data, determining seismic data with a seismic source direction opposite to a target direction, wherein the target direction is a specified excitation direction when seismic source excitation is carried out on seismic source equipment;
carrying out reverse polarity processing on the amplitude value of the transverse wave source seismic data with the seismic source direction opposite to the target direction to obtain transverse wave source seismic data with consistent excitation directions;
acquiring an azimuth angle of the multi-wave seismic data;
according to the azimuth angle, performing alford rotation on the four-component seismic data of the pure transverse wave seismic data received by the horizontal component of the detector, performing horizontal component rotation on the two-component seismic data of the PSV converted wave seismic data received by the horizontal component of the detector, and performing horizontal seismic source rotation on the two-component seismic data of the SVP converted wave seismic data received by the vertical component of the detector.
In some embodiments, determining, from the processed multi-wave seismic data, a shear wave splitting analysis time window corresponding to each destination layer of the multi-wave seismic data includes:
stacking or migration imaging processing is carried out on the processed multi-wave seismic data to obtain seismic data imaging sections corresponding to the pure transverse wave seismic data, the PSV converted wave seismic data and the SVP converted wave seismic data respectively;
and carrying out horizon calibration in the seismic data imaging section to determine the shear wave splitting analysis time windows of the pure shear wave seismic data, the PSV converted wave seismic data and the SVP converted wave seismic data in each target horizon respectively.
In some embodiments, determining fracture parameters of each target layer according to the processed multi-wave seismic data and the corresponding shear wave splitting analysis time window of the multi-wave seismic data at each target layer includes:
obtaining effective component signals of the processed multi-wave seismic data in each target layer, wherein the effective component signals comprise specific component signals, the specific component signals comprise SrRt component signals and StRr component signals of pure transverse wave seismic data, PSRt component signals of PSV converted wave seismic data and StP component signals of SVP converted wave seismic data, and the amplitude of the specific component signals in the target layer is not 0;
and determining the fracture parameters of each target layer according to each effective component signal of the processed multi-wave seismic data in each target layer and a transverse wave splitting analysis time window corresponding to each target layer.
In some embodiments, determining fracture parameters of each target layer according to the effective component signals of the processed multi-wave seismic data in each target layer and the corresponding shear wave splitting analysis time window of each target layer comprises:
determining the amplitude energy of the specific component signal after transverse wave splitting correction in each target layer according to each effective component signal of the processed multi-wave seismic data in each target layer and a transverse wave splitting analysis time window corresponding to each target layer;
and determining a target fracture parameter as a fracture parameter of a target stratum, wherein the target stratum is any one stratum in the stratum transmitted by the multi-wave seismic data, and the target fracture parameter is a fracture parameter corresponding to the minimum amplitude energy of the specific component signal in the target stratum.
All the optional technical solutions can be combined arbitrarily to form an optional embodiment of the present application, which is not described in detail herein.
Fig. 2 is a flowchart of a method for determining a crack parameter provided in an embodiment of the present application, which is illustrated by applying the method for determining a crack parameter to a terminal in this embodiment, where the method for determining a crack parameter may include the following steps:
step 201: and the terminal acquires multi-wave seismic data through the detector.
It should be noted that the 3D9C multi-wave seismic data is a complete multi-wave seismic data, the 3D9C multi-wave seismic data is seismic data obtained by respectively exciting 2 horizontal seismic sources (sometimes called shear wave seismic sources) and 1 vertical seismic source (sometimes called longitudinal wave seismic sources), and each excitation is received and recorded by a 3-component detector. The multi-wave seismic data comprises longitudinal wave source seismic data and transverse wave source seismic data, wherein the transverse wave source seismic data comprise 4 components of pure transverse wave seismic data and 2 components of SVP converted wave seismic data, and the longitudinal wave source seismic data comprise 2 horizontal components of PSV converted wave seismic data.
Because the shear wave can generate a shear wave splitting phenomenon in the process of the propagation of the azimuth anisotropic medium, a pure shear wave field and a converted wave field become abnormal and complex, and the imaging quality of subsequent seismic data can be influenced, the shear wave splitting analysis is needed to obtain fracture parameters representing the underground anisotropic condition, so that the fast and slow wave separation or the shear wave splitting correction can be carried out on the pure shear wave and the converted wave seismic data according to the fracture parameters. The detailed operation is described in the following steps 202-204.
As an example, the terminal can actively receive the multi-wave seismic data sent by the geophone, that is, when the geophone detects the multi-wave seismic data, the detected multi-wave seismic data can be actively sent to the terminal, so that the terminal acquires the multi-wave seismic data. The terminal can also passively acquire the multi-wave seismic data, namely, the terminal can receive the acquisition instruction and acquire the multi-wave seismic data through the detector when receiving the acquisition instruction.
It should be noted that the obtaining instruction can be triggered when the staff acts on the terminal through a specified operation, and the specified operation can be a click operation, a slide operation, a voice operation, and the like.
Step 202: and when the terminal receives the multi-wave seismic data through the wave detector, the multi-wave seismic data are adjusted and processed.
The adjustment processing of the multi-wave seismic data includes performing polarity adjustment processing on the shear wave source seismic data and performing rotation processing on the multi-wave seismic data.
The vertical seismic source excitation direction can be kept consistent no matter whether a seismic source vehicle (a seismic source device) is turned around or not, and adjustment is not needed. The transverse wave source seismic data have the polarity problem due to the fact that the excitation directions of the transverse wave sources are not consistent, and therefore in order to improve the accuracy of the follow-up crack parameter determination, the problem of the polarity inconsistency of the transverse wave source seismic data needs to be eliminated.
As an example, when the terminal receives the multi-wave seismic data through the geophone, the operation of performing adjustment processing on the multi-wave seismic data at least comprises the following operations: when the transverse wave seismic source seismic data are received through the detector, determining seismic data with the seismic source direction opposite to the target direction, wherein the target direction is the specified excitation direction when seismic source excitation is carried out on seismic source equipment; performing reversed polarity processing on the amplitude value of the transverse wave source seismic data with the seismic source direction opposite to the target direction to obtain transverse wave source seismic data with consistent excitation directions; acquiring an azimuth angle of the multi-wave seismic data; performing alford rotation on the four-component seismic data of the pure transverse wave seismic data received by the horizontal component of the detector according to the azimuth angle, performing horizontal component rotation on the two-component seismic data of the PSV converted wave seismic data received by the horizontal component of the detector, and performing horizontal seismic source rotation on the two-component seismic data of the SVP converted wave seismic data received by the vertical component of the detector.
In some embodiments, the terminal can acquire the receive line direction directly from the stored field construction records, determine the azimuth of the multi-wave seismic data by shot (a source device) and geophone coordinates.
In one implementation, the source device can excite transverse waves through a horizontally vibrating vibroseis, and the terminal can invert amplitude values of shot records (seismic data, wherein the seismic data comprise x, y and z components) excited in the opposite direction (opposite to the direction of the target direction). For example, the process of performing the reverse polarity processing on the seismic data is expressed by the following first formula.
Figure BDA0003144197940000091
It should be noted that, in the first formula (1), sx represents that the excitation direction of the shear wave source corresponding to the shear wave source seismic data is parallel to the x direction, i.e., inline direction, sy represents that the excitation direction of the shear wave source corresponding to the shear wave source seismic data is parallel to the y-axis direction, i.e., corssline direction, rx, ry, and Rz represent three components of the detector, including two horizontal components, i.e., x component and y component, during the construction process, the x component is parallel to the inline direction, the y component is parallel to the crossline direction, and a vertical component, i.e., three component directions of the detector are respectively parallel to the x axis, the y axis, and the z axis, and SxRx, sxRy, sxRz, syRy, and SyRz are the amplitude values of the components of the shear wave source seismic data detected under the above conditions.
In one embodiment, the terminal can subtract an angle corresponding to a survey line direction from an azimuth angle to obtain an adjustment angle, perform alford rotation on pure transverse wave seismic data through the adjustment angle, perform horizontal component rotation on PSV converted wave seismic data, and perform horizontal seismic source rotation on SVP converted wave seismic data.
It should be noted that, the terminal performs the alford rotation on the pure transverse wave seismic data, so as to rotate both the seismic source excitation direction and the receiving direction of the horizontal component of the detector to the shot-geophone connecting line direction and the vertical direction thereof. And the terminal performs horizontal component rotation on the PSV converted wave seismic data so as to rotate the receiving direction of the horizontal component of the detector to the shot-geophone connecting line direction and the vertical direction thereof. The terminal performs horizontal seismic source rotation on the SVP converted wave seismic data so as to rotate the excitation direction of the shear wave seismic source to the shot-geophone link direction and the vertical direction of the shot-geophone link direction.
In one implementation, the operation of the terminal to perform the alford rotation on the pure shear wave seismic data is represented by the following second formula, the operation of performing the horizontal component rotation on the PSV converted wave seismic data is represented by the following third formula, and the operation of performing the horizontal source rotation on the SVP converted wave seismic data is represented by the following fourth formula.
Figure BDA0003144197940000101
Figure BDA0003144197940000102
Figure BDA0003144197940000103
In the second equation (2), sxRx, sxRy, syRx, and SyRy are four seismic data components (also referred to as four-component seismic data) of the pure shear wave seismic data, srRr, srRt, stRr, and StRt are amplitude values of the four seismic data components obtained by performing alford rotation on the four seismic data components of the pure shear wave seismic data, and β is an adjustment angle. In the third formula (3), PSRx and PSRy are two seismic-data components (also referred to as two-component seismic data) of PSV converted-wave seismic data, PSRr and PSRt are amplitude values of the two seismic-data components obtained by performing horizontal-component rotation on the two seismic-data components (also referred to as two-component seismic data) of the PSV converted-wave seismic data, and β is an adjustment angle. In the fourth formula (4), sxP and SyP are two transverse-wave source converted seismic data components of the SVP converted-wave seismic data, srP and StP are amplitude values of two seismic data components (also referred to as two-component seismic data) obtained by performing horizontal seismic source rotation on the two transverse-wave source seismic data components of the SVP converted-wave seismic data, and β is an adjustment angle.
Step 203: and the terminal determines the shear wave splitting analysis time window corresponding to the multi-wave seismic data in each target layer according to the processed multi-wave seismic data.
Because the arrival time of the multi-wave seismic data in each target layer is different, the terminal needs to determine the shear wave splitting analysis time window corresponding to the multi-wave seismic data in each target layer according to the processed multi-wave seismic data.
As an example, the operation of the terminal determining, according to the processed multi-wave seismic data, a shear wave splitting analysis time window corresponding to each destination layer of the multi-wave seismic data at least includes: stacking or migration imaging processing is carried out on the processed multi-wave seismic data to obtain seismic data imaging sections corresponding to the pure transverse wave seismic data, the PSV converted wave seismic data and the SVP converted wave seismic data respectively; and carrying out horizon calibration in the seismic data imaging section to help determine a transverse wave splitting analysis time window of the pure transverse wave seismic data, the PSV converted wave seismic data and the SVP converted wave seismic data in each target horizon respectively.
It should be noted that, since the multi-wave seismic data relate to shear waves including pure shear wave seismic data, PSV converted wave seismic data and SVP converted wave seismic data, the terminal can perform stack or migration imaging processing on the pure shear wave seismic data, PSV converted wave seismic data and SVP converted wave seismic data to obtain a seismic data imaging section. The operation of the terminal for performing superposition or migration imaging processing on the multi-wave seismic data can refer to related technologies, and the description thereof is omitted in the embodiments of the present application.
In one embodiment, aiming at the same target layer, the terminal can respectively determine the layer time when the pure transverse wave seismic data, the PSV converted wave seismic data and the SVP converted wave seismic data reach the stratum, determine a transverse wave splitting analysis time window corresponding to the pure transverse wave seismic data according to the layer time corresponding to the pure transverse wave seismic data and the target layer thickness, and determine a transverse wave splitting analysis time window corresponding to the PSV converted wave seismic data and the SVP converted wave seismic data according to the layer time corresponding to the PSV converted wave seismic data and the SVP converted wave seismic data and the target layer thickness.
In one embodiment, the terminal starts from the first layer of azimuthal anisotropy layer according to a sequence from shallow to deep for the same destination layer, and the terminal operation criteria include: at the pure transverse wave reflection time corresponding to the destination layer, the time when the pure transverse wave SrRt component and StRr component start to appear obvious effective signals is the level time of the pure transverse wave, and at the converted wave reflection time corresponding to the destination layer, the time when the PSV converted wave PSRt component starts to appear obvious effective signals is the level time of the PSV converted wave, and the time when the SVP converted wave StP component starts to appear obvious effective signals is the level time of the SVP converted wave. And recording the level time of the PSV converted wave and the SVP converted wave as wnct, for example, as w1ct if the first layer is formed, and recording the level time corresponding to the SS pure transverse wave as wnst, for example, as w1st if the first layer is formed. And determining the thickness of the pure transverse wave target layer according to the transverse wave splitting characteristic and the corresponding relation between the pure transverse wave and the converted wave, namely the window height hsn and the window height hcn, wherein the half heights of the corresponding time windows are hsn/2 and hcn/2 respectively. Thus, the start time wnst-hsn/2 and the end time wnst + hsn/2 of the pure shear wave splitting analysis time window with the pure shear wave horizon time as the center can be determined, and the start time wnct-hcn/2 and the end time wnct + hcn/2 of the converted shear wave splitting analysis time window with the converted wave horizon time as the center can be determined at the same time.
In an implementation environment, the terminal performs polarity adjustment and rotation processing on the multi-wave seismic data and then sorts the multi-wave seismic data according to azimuth angles to obtain seismic data as shown in fig. 3, wherein a shallow-to-deep box in the diagram is a shear wave splitting analysis time window. Wherein, the horizon time of the PSV converted wave seismic data and the SVP converted wave seismic data is wnct, the horizon time of the pure transverse wave seismic data is wnst, n is the number of fracture layers of the stratum, hsn is the time window height of the current pure transverse wave target layer, hcn is the time window height of the converted wave target layer, for example, when n is 1, the 1st fracture layer is shown, for the first fracture layer, the horizon time of the PSV converted wave seismic data and the SVP converted wave seismic data is w1ct, the horizon time of the pure transverse wave seismic data is w1st, hs1 is the time window height of a first pure transverse wave target layer, hc1 is the time window height of a first converted wave target layer, the starting time of a transverse wave splitting analysis time window corresponding to the pure transverse wave seismic data is w1st-hs1/2, the ending time is w1st + hs1/2, the starting time of a transverse wave splitting analysis time window corresponding to the PSV converted wave seismic data and the SVP converted wave seismic data is w1ct-hc1/2, and the ending time is w1ct + hc1/2.
Step 204: and the terminal determines the fracture parameters of each target layer according to the processed multi-wave seismic data and the transverse wave splitting analysis time window of the multi-wave seismic data corresponding to each target layer.
As an example, the operation of determining, by the terminal, the fracture parameter of each destination layer according to the processed multi-wave seismic data and the shear wave splitting analysis time window corresponding to the multi-wave seismic data at each destination layer at least includes: acquiring effective component signals of the processed multi-wave seismic data including specific component signals in each target layer, wherein the specific component signals comprise SrRt component signals and StRr component signals of pure transverse wave seismic data, PSRt component signals of PSV converted wave seismic data and StP component signals of SVP converted wave seismic data, and the amplitude of the specific component signals in the target layer is not 0; and determining the fracture parameters of each target layer according to the effective component signals of the processed multi-wave seismic data in each target layer and the corresponding shear wave splitting analysis time window of each target layer.
In some embodiments, the determining, by the terminal, fracture parameters of each target interval according to the effective component signals of the processed multi-wave seismic data in each target interval and a corresponding shear wave splitting analysis time window of each target interval includes: determining the amplitude energy of the specific component signal after transverse wave splitting correction in each target layer according to each effective component signal of the processed multi-wave seismic data in each target layer and a transverse wave splitting analysis time window corresponding to each target layer; and determining the target fracture parameters as the fracture parameters of a target stratum, wherein the target stratum is any azimuth anisotropic stratum in the stratum transmitted by the multi-wave seismic data, and the target fracture parameters are the fracture parameters corresponding to the minimum amplitude energy of the specific component signals in the target stratum.
It should be noted that when the amplitude of the specific component signal in the target layer is 0, the shear wave splitting correction is not required.
In some embodiments, the terminal may obtain a reference fracture parameter of each target layer, where the reference fracture parameter is a fracture parameter assumed for each target layer, and then, for a target formation, determine, according to each effective component signal of the processed multi-wave seismic data in the target formation and a corresponding shear wave splitting analysis time window in the target formation, when the fracture parameter of the target formation is the reference fracture parameter, amplitude energy of a specific component signal after shear wave splitting correction is performed on the multi-wave seismic data, and determine, as the fracture parameter of the target formation, the reference fracture parameter corresponding to the minimum amplitude energy of the specific component signal.
When the target layer having the azimuthal anisotropy is subjected to the transverse wave splitting, the amplitude of the specific component signal is not 0, but the amplitude of the specific component signal after the transverse wave splitting correction is 0, that is, the amplitude energy of the specific component signal after the transverse wave splitting correction is minimum. When the amplitude energy is minimum, the amplitude energy is 0.
In some embodiments, the terminal determines fracture information of each target layer according to the effective component signals of the processed multi-wave seismic data in each target layer and a corresponding shear wave splitting analysis time window in each layer of stratum by the following fifth formula.
Figure BDA0003144197940000131
In the fifth equation (5), the relevant parameters are expressed by the following sixth equation and seventh equation:
Figure BDA0003144197940000141
Figure BDA0003144197940000142
it should be noted that, in the fifth equation (5), the sixth equation (6) and the seventh equation (7), U represents the amplitude of different seismic data, and different seismic data components correspond to different angle marks, for example, U 0SrRt 、U 0StRr 、U 0PSRt 、U 0StP Etc. respectively represent the corresponding amplitudes, U, of the specific component signals of the different seismic data 0Sr Comprises a U 0SrRr And U 0SrRt 2 component, U 0St Comprises a U 0StRr And U 0StRt 2 component, U 0PS Comprises U 0PSRr And U 0PSRt 2 components, U 0SP Comprises U 0SrP And U 0StP 2 components; u shape Sr Comprises U SrRr And U SrRt 2 components; u shape St Comprises U StRr And U StRt 2 component, U PS Comprises U PSRr And U PSRt 2 components, U SP Comprises a U SrP And U StP 2 components; the operation matrixes of R, D and the like are shown in a formula (6) and a formula (7); t is used for representing different time points of the shear wave splitting analysis time window; theta denotes the crack direction and theta n For indicating the fracture direction of the nth stratum; Δ t is used to represent the time difference between fast and slow waves and Δ t n Is used for representing the time difference between the fast and slow transverse waves of the n-th stratum, alpha is used for representing the azimuth of a seismic trace, wnct-hcn/2 is the transverse wave splitting analysis time window starting time corresponding to the PSV converted wave seismic data and the SVP converted wave seismic data, and wnct + hcn/2 is the transverse wave corresponding to the PSV converted wave seismic data and the SVP converted wave seismic dataThe end time of the splitting analysis time window, wnst-hsn/2 is the start time of the shear wave splitting analysis time window corresponding to the pure shear wave seismic data, and the end time of the shear wave splitting analysis time window corresponding to the wnst + hsn/2 pure shear wave seismic data, A (theta) n ，Δt n ) The sum of the amplitude energy of a specific component signal in the multi-wave seismic data in the nth stratum is shown, i is an imaginary number, and omega is frequency.
In some embodiments, at A (θ) n ，Δt n ) And when the minimum value is reached, the terminal can determine fracture parameters of the nth stratum, wherein the fracture parameters comprise the time difference between the fracture direction and the fast and slow transverse waves.
In some embodiments, the terminal can prompt the crack parameters through prompt information after determining the crack parameters.
The prompt information can be in the form of voice, text, video, and the like.
In the embodiment of the application, the terminal can determine the fracture parameters of each target layer through the pure transverse wave seismic data, the PSV converted wave seismic data and the SVP converted wave seismic data, so that the condition that different fracture parameters are obtained after the converted waves and the pure transverse waves are independently analyzed is avoided, namely, the converted waves and the pure transverse waves are jointly used for transverse wave splitting analysis, the uniqueness of the fracture parameters is ensured, and the reliability of determining the fracture parameters is improved.
Fig. 4 is a schematic structural diagram of a crack parameter determination apparatus provided in an embodiment of the present application, where the crack parameter determination apparatus may be implemented by software, hardware, or a combination of the two. The fracture parameter determination device may include: an adjustment module 401, a first determination module 402 and a second determination module 403.
The adjusting module 401 is configured to perform adjustment processing on multi-wave seismic data when the multi-wave seismic data are received by a geophone, where the multi-wave seismic data include pure transverse wave seismic data, PSV converted wave seismic data, and SVP converted wave seismic data;
a first determining module 402, configured to determine, according to the processed multi-wave seismic data, a shear wave splitting analysis time window corresponding to each destination layer of the multi-wave seismic data;
a second determining module 403, configured to determine a fracture parameter of each destination layer according to the processed multi-wave seismic data and a shear wave splitting analysis time window corresponding to each destination layer of the multi-wave seismic data.
In some embodiments, referring to fig. 5, the adjustment module 401 comprises:
the first determining sub-module 4011 is configured to determine, when the shear wave source seismic data is received by the detector, seismic data with a seismic source direction opposite to a target direction, where the target direction is an excitation direction specified when the seismic source is excited by seismic source equipment, and the shear wave source seismic data includes the pure shear wave seismic data and the SVP converted wave seismic data;
the processing sub-module 4012 is configured to perform reverse polarity processing on the amplitude value of the transverse wave source seismic data in the seismic source direction opposite to the target direction, so as to obtain transverse wave source seismic data with consistent excitation directions;
the first obtaining submodule 4013 is configured to obtain an azimuth angle of the multi-wave seismic data;
the rotation sub-module 4014 is configured to perform, according to the azimuth, alford rotation on the four-component seismic data of the pure transverse wave seismic data received by the horizontal component of the detector, perform horizontal component rotation on the two-component seismic data of the PSV converted wave seismic data received by the horizontal component of the detector, and perform horizontal seismic source rotation on the two-component seismic data of the SVP converted wave seismic data received by the vertical component of the detector.
In some embodiments, referring to fig. 6, the first determining module 402 comprises:
the imaging submodule 4021 is configured to perform stacking or migration imaging processing on the processed multi-wave seismic data to obtain seismic data imaging sections corresponding to the pure transverse wave seismic data, the PSV converted wave seismic data, and the SVP converted wave seismic data, respectively;
the calibration sub-module 4022 is configured to perform horizon calibration on the seismic data imaging section to determine a shear wave splitting analysis time window of each target horizon for the pure shear wave seismic data, the PSV converted wave seismic data, and the SVP converted wave seismic data.
In some embodiments, referring to fig. 7, the second determining module 403 comprises:
a second obtaining sub-module 4031, configured to obtain each effective component signal of the processed multi-wave seismic data in each destination layer, where the effective component signal includes a specific component signal, where the specific component signal includes a SrRt component signal and a StRr component signal of the pure transverse wave seismic data, a PSRt component signal of the PSV converted wave seismic data, and a StP component signal of the SVP converted wave seismic data, and an amplitude of the specific component signal in the destination layer is not 0;
a second determining submodule 4032, configured to determine a fracture parameter of each target layer according to each effective component signal of the processed multi-wave seismic data in each target layer and a corresponding shear wave splitting analysis time window in each target layer.
In some embodiments, the second determination sub-module 4032 is configured to:
determining the amplitude energy of the specific component signal after transverse wave splitting correction in each target layer according to each effective component signal of the processed multi-wave seismic data in each target layer and a corresponding transverse wave splitting analysis time window in each target layer;
and determining a target fracture parameter as a fracture parameter of a target stratum, wherein the target stratum is any one stratum in the stratum transmitted by the multi-wave seismic data, and the target fracture parameter is a fracture parameter corresponding to the minimum amplitude energy of the specific component signal in the target stratum.
In the embodiment of the application, the terminal can determine the fracture parameters of each target layer through the pure transverse wave seismic data, the PSV converted wave seismic data and the SVP converted wave seismic data, so that the situation that different fracture parameters are obtained after the analysis is carried out through converted waves or pure transverse waves independently is avoided, namely, the transverse wave splitting analysis is carried out through the combination of the converted waves and the pure transverse waves, the uniqueness of the fracture parameters is ensured, and the reliability of determining the fracture parameters is improved.
It should be noted that: in the above embodiment, when determining the crack parameter, the determination apparatus for determining the crack parameter is only illustrated by dividing the functional modules, and in practical applications, the function distribution may be completed by different functional modules according to needs, that is, the internal structure of the apparatus is divided into different functional modules to complete all or part of the functions described above. In addition, the crack parameter determination device and the crack parameter determination method provided in the above embodiments belong to the same concept, and specific implementation processes thereof are described in the method embodiments and are not described herein again.
Fig. 8 shows a block diagram of a terminal 800 according to an exemplary embodiment of the present application. The terminal 800 may be: a smart phone, a tablet computer, an MP3 player (Moving Picture Experts Group Audio Layer III, motion video Experts compression standard Audio Layer 3), an MP4 player (Moving Picture Experts Group Audio Layer IV, motion video Experts compression standard Audio Layer 4), a notebook computer, or a desktop computer. The terminal 800 may also be referred to by other names such as user equipment, portable terminal, laptop terminal, desktop terminal, etc.
In general, the terminal 800 includes: a processor 801 and a memory 802.
The processor 801 may include one or more processing cores, such as a 4-core processor, an 8-core processor, and so forth. The processor 801 may be implemented in at least one hardware form of a DSP (Digital Signal Processing), an FPGA (Field-Programmable Gate Array), and a PLA (Programmable Logic Array). The processor 801 may also include a main processor and a coprocessor, where the main processor is a processor for Processing data in an awake state, and is also called a Central Processing Unit (CPU); a coprocessor is a low power processor for processing data in a standby state. In some embodiments, the processor 801 may be integrated with a GPU (Graphics Processing Unit) that is responsible for rendering and drawing content that the display screen needs to display. In some embodiments, the processor 801 may further include an AI (Artificial Intelligence) processor for processing computing operations related to machine learning.
Memory 802 may include one or more computer-readable storage media, which may be non-transitory. Memory 802 can also include high-speed random access memory, as well as non-volatile memory, such as one or more magnetic disk storage devices, flash memory storage devices. In some embodiments, a non-transitory computer readable storage medium in memory 802 is used to store at least one instruction for execution by processor 801 to implement the method of determining fracture parameters provided by the method embodiments herein.
In some embodiments, the terminal 800 may further optionally include: a peripheral interface 803 and at least one peripheral. The processor 801, memory 802 and peripheral interface 803 may be connected by bus or signal lines. Various peripheral devices may be connected to the peripheral interface 803 by a bus, signal line, or circuit board. Specifically, the peripheral device includes: at least one of a radio frequency circuit 804, a display 805, a camera assembly 806, an audio circuit 807, a positioning assembly 808, and a power supply 809.
The peripheral interface 803 may be used to connect at least one peripheral device related to I/O (Input/Output) to the processor 801 and the memory 802. In some embodiments, the processor 801, memory 802, and peripheral interface 803 are integrated on the same chip or circuit board; in some other embodiments, any one or two of the processor 801, the memory 802, and the peripheral interface 803 may be implemented on separate chips or circuit boards, which is not limited by the present embodiment.
The Radio Frequency circuit 804 is used for receiving and transmitting RF (Radio Frequency) signals, also called electromagnetic signals. The radio frequency circuitry 804 communicates with communication networks and other communication devices via electromagnetic signals. The radio frequency circuit 804 converts an electrical signal into an electromagnetic signal to transmit, or converts a received electromagnetic signal into an electrical signal. Optionally, the radio frequency circuit 804 includes: an antenna system, an RF transceiver, one or more amplifiers, a tuner, an oscillator, a digital signal processor, a codec chipset, a subscriber identity module card, and so forth. The radio frequency circuit 804 may communicate with other terminals via at least one wireless communication protocol. The wireless communication protocols include, but are not limited to: metropolitan area networks, various generation mobile communication networks (2G, 3G, 4G, and 5G), wireless local area networks, and/or WiFi (Wireless Fidelity) networks. In some embodiments, the radio frequency circuit 804 may further include NFC (Near Field Communication) related circuits, which are not limited in this application.
The display screen 805 is used to display a UI (User Interface). The UI may include graphics, text, icons, video, and any combination thereof. When the display 805 is a touch display, the display 805 also has the ability to capture touch signals on or above the surface of the display 805. The touch signal may be input to the processor 801 as a control signal for processing. At this point, the display 805 may also be used to provide virtual buttons and/or a virtual keyboard, also referred to as soft buttons and/or a soft keyboard. In some embodiments, the display 805 may be one, providing the front panel of the terminal 800; in other embodiments, the display 805 may be at least two, respectively disposed on different surfaces of the terminal 800 or in a folded design; in other embodiments, the display 805 may be a flexible display disposed on a curved surface or a folded surface of the terminal 800. Even further, the display 805 may be configured as a non-rectangular irregular figure, i.e., a shaped screen. The Display 805 can be made of LCD (Liquid Crystal Display), OLED (Organic Light-Emitting Diode), and other materials.
The camera assembly 806 is used to capture images or video. Optionally, camera assembly 806 includes a front camera and a rear camera. Generally, a front camera is disposed at a front panel of the terminal, and a rear camera is disposed at a rear surface of the terminal. In some embodiments, the number of the rear cameras is at least two, and each rear camera is any one of a main camera, a depth-of-field camera, a wide-angle camera and a telephoto camera, so that the main camera and the depth-of-field camera are fused to realize a background blurring function, the main camera and the wide-angle camera are fused to realize panoramic shooting and a VR (Virtual Reality) shooting function or other fusion shooting functions. In some embodiments, camera head assembly 806 may also include a flash. The flash lamp can be a monochrome temperature flash lamp or a bicolor temperature flash lamp. The double-color-temperature flash lamp is a combination of a warm-light flash lamp and a cold-light flash lamp, and can be used for light compensation at different color temperatures.
The audio circuit 807 may include a microphone and a speaker. The microphone is used for collecting sound waves of a user and the environment, converting the sound waves into electric signals, and inputting the electric signals to the processor 801 for processing or inputting the electric signals to the radio frequency circuit 804 to achieve voice communication. The microphones may be provided in a plurality, respectively, at different portions of the terminal 800 for the purpose of stereo sound collection or noise reduction. The microphone may also be an array microphone or an omni-directional acquisition microphone. The speaker is used to convert electrical signals from the processor 801 or the radio frequency circuit 804 into sound waves. The loudspeaker can be a traditional film loudspeaker and can also be a piezoelectric ceramic loudspeaker. When the speaker is a piezoelectric ceramic speaker, the speaker can be used for purposes such as converting an electric signal into a sound wave audible to a human being, or converting an electric signal into a sound wave inaudible to a human being to measure a distance. In some embodiments, the audio circuitry 807 may also include a headphone jack.
The positioning component 808 is used to locate the current geographic position of the terminal 800 for navigation or LBS (Location Based Service). The Positioning component 808 may be a Positioning component based on a Global Positioning System (GPS) in the united states, a beidou System in china, a grignard System in russia, or a galileo System in the european union.
A power supply 809 is used to supply power to the various components in the terminal 800. The power supply 809 can be ac, dc, disposable or rechargeable. When power source 809 comprises a rechargeable battery, the rechargeable battery can support wired charging or wireless charging. The rechargeable battery can also be used to support fast charge technology.
In some embodiments, the terminal 800 also includes one or more sensors 810. The one or more sensors 810 include, but are not limited to: acceleration sensor 811, gyro sensor 812, pressure sensor 813, fingerprint sensor 814, optical sensor 815 and proximity sensor 816.
The acceleration sensor 811 may detect the magnitude of acceleration in three coordinate axes of the coordinate system established with the terminal 800. For example, the acceleration sensor 811 may be used to detect components of the gravitational acceleration in three coordinate axes. The processor 801 may control the display 805 to display the user interface in a landscape view or a portrait view according to the gravitational acceleration signal collected by the acceleration sensor 811. The acceleration sensor 811 may also be used for acquisition of motion data of a game or a user.
The gyro sensor 812 may detect a body direction and a rotation angle of the terminal 800, and the gyro sensor 812 may acquire a 3D motion of the user on the terminal 800 in cooperation with the acceleration sensor 811. From the data collected by the gyro sensor 812, the processor 801 may implement the following functions: motion sensing (such as changing the UI according to a user's tilting operation), image stabilization at the time of photographing, game control, and inertial navigation.
Pressure sensors 813 may be disposed on the side frames of terminal 800 and/or underneath display 805. When the pressure sensor 813 is disposed on the side frame of the terminal 800, the holding signal of the user to the terminal 800 can be detected, and the processor 801 performs left-right hand recognition or shortcut operation according to the holding signal collected by the pressure sensor 813. When the pressure sensor 813 is disposed at the lower layer of the display screen 805, the processor 801 controls the operability control on the UI interface according to the pressure operation of the user on the display screen 805. The operability control comprises at least one of a button control, a scroll bar control, an icon control and a menu control.
The fingerprint sensor 814 is used for collecting a fingerprint of the user, and the processor 801 identifies the identity of the user according to the fingerprint collected by the fingerprint sensor 814, or the fingerprint sensor 814 identifies the identity of the user according to the collected fingerprint. Upon identifying that the user's identity is a trusted identity, the processor 801 authorizes the user to perform relevant sensitive operations including unlocking a screen, viewing encrypted information, downloading software, paying for and changing settings, etc. Fingerprint sensor 814 may be disposed on the front, back, or side of terminal 800. When a physical button or a vendor Logo is provided on the terminal 800, the fingerprint sensor 814 may be integrated with the physical button or the vendor Logo.
The optical sensor 815 is used to collect ambient light intensity. In one embodiment, processor 801 may control the display brightness of display 805 based on the ambient light intensity collected by optical sensor 815. Specifically, when the ambient light intensity is high, the display brightness of the display screen 805 is increased; when the ambient light intensity is low, the display brightness of the display 805 is adjusted down. In another embodiment, the processor 801 may also dynamically adjust the shooting parameters of the camera assembly 806 based on the ambient light intensity collected by the optical sensor 815.
A proximity sensor 816, also known as a distance sensor, is typically disposed on a front panel of the terminal 800. The proximity sensor 816 is used to collect the distance between the user and the front surface of the terminal 800. In one embodiment, when the proximity sensor 816 detects that the distance between the user and the front surface of the terminal 800 gradually decreases, the processor 801 controls the display 805 to switch from the bright screen state to the dark screen state; when the proximity sensor 816 detects that the distance between the user and the front surface of the terminal 800 becomes gradually larger, the display 805 is controlled by the processor 801 to switch from the breath-screen state to the bright-screen state.
Those skilled in the art will appreciate that the configuration shown in fig. 8 is not intended to be limiting of terminal 800, and may include more or fewer components than shown, or some components may be combined, or a different arrangement of components may be used.
The embodiments of the present application further provide a non-transitory computer-readable storage medium, and when instructions in the storage medium are executed by a processor of a terminal, the terminal is enabled to execute the method for determining a crack parameter provided in the above embodiments.
The embodiment of the present application further provides a computer program product containing instructions, which when run on a terminal, causes the terminal to execute the method for determining a crack parameter provided in the foregoing embodiment.
It will be understood by those skilled in the art that all or part of the steps for implementing the above embodiments may be implemented by hardware, or may be implemented by a program instructing relevant hardware, where the program may be stored in a computer-readable storage medium, and the above-mentioned storage medium may be a read-only memory, a magnetic disk or an optical disk, etc.
The above description is only a preferred embodiment of the present application and should not be taken as limiting the present application, and any modifications, equivalents, improvements, etc. made within the spirit and principle of the present application should be included in the protection scope of the present application.

Claims (11)

1. A method of determining fracture parameters, the method comprising:
when multi-wave seismic data are received through a geophone, adjusting the multi-wave seismic data, wherein the multi-wave seismic data comprise pure transverse wave seismic data, PSV converted wave seismic data and SVP converted wave seismic data;
determining a shear wave splitting analysis time window corresponding to each target layer of the multi-wave seismic data according to the processed multi-wave seismic data;
and determining fracture parameters of each target layer according to the processed multi-wave seismic data and the shear wave splitting analysis time window corresponding to the multi-wave seismic data in each target layer.
2. The method of claim 1, wherein the conditioning the multi-wave seismic data as it is received by the geophone comprises:
when shear wave source seismic data are received through the detector, determining seismic data with a seismic source direction opposite to a target direction, wherein the target direction is an excitation direction specified when seismic source equipment carries out seismic source excitation, and the shear wave source seismic data comprise the pure shear wave seismic data and the SVP converted wave seismic data;
carrying out reverse polarity processing on the amplitude value of the transverse wave source seismic data with the seismic source direction opposite to the target direction to obtain transverse wave source seismic data with consistent excitation directions;
acquiring an azimuth angle of the multi-wave seismic data;
and performing alford rotation on the four-component seismic data of the pure transverse wave seismic data received by the horizontal component of the detector, performing horizontal component rotation on the two-component seismic data of the PSV converted wave seismic data received by the horizontal component of the detector, and performing horizontal seismic source rotation on the two-component seismic data of the SVP converted wave seismic data received by the vertical component of the detector according to the azimuth angle.
3. The method of claim 1, wherein determining a shear wave splitting analysis time window corresponding to the multi-wave seismic data at each destination layer based on the processed multi-wave seismic data comprises:
stacking or migration imaging processing is carried out on the processed multi-wave seismic data to obtain seismic data imaging sections corresponding to the pure transverse wave seismic data, the PSV converted wave seismic data and the SVP converted wave seismic data respectively;
and carrying out horizon calibration in the seismic data imaging section to determine the shear wave splitting analysis time windows of the pure shear wave seismic data, the PSV converted wave seismic data and the SVP converted wave seismic data in each target horizon respectively.
4. The method of claim 1, wherein the determining fracture parameters of each target interval according to the processed multi-wave seismic data and a shear wave splitting analysis time window corresponding to the multi-wave seismic data in each target interval comprises:
acquiring effective component signals of the processed multi-wave seismic data in each destination layer, wherein the effective component signals comprise specific component signals, the specific component signals comprise SrRt component signals and StRr component signals of the pure transverse wave seismic data, PSRt component signals of the PSV converted wave seismic data and StP component signals of the SVP converted wave seismic data, and the amplitude of the specific component signals in the destination layer is not 0;
and determining the fracture parameters of each target layer according to the effective component signals of the processed multi-wave seismic data in each target layer and the shear wave splitting analysis time window corresponding to each target layer.
5. The method as claimed in claim 4, wherein said determining fracture parameters of each said destination layer from the respective effective component signals of said processed multi-wave seismic data in each said destination layer and the corresponding shear wave splitting analysis time window of each said destination layer comprises:
determining the amplitude energy of the specific component signal after transverse wave splitting correction in each target layer according to each effective component signal of the processed multi-wave seismic data in each target layer and a transverse wave splitting analysis time window corresponding to each target layer;
and determining a target fracture parameter as a fracture parameter of a target stratum, wherein the target stratum is any one stratum in the stratum transmitted by the multi-wave seismic data, and the target fracture parameter is a fracture parameter corresponding to the minimum amplitude energy of the specific component signal in the target stratum.
6. An apparatus for determining fracture parameters, the apparatus comprising:
the adjusting module is used for adjusting and processing the multi-wave seismic data when the multi-wave seismic data are received by the geophone, and the multi-wave seismic data comprise pure transverse wave seismic data, PSV converted wave seismic data and SVP converted wave seismic data;
the first determining module is used for determining a shear wave splitting analysis time window corresponding to each target layer of the multi-wave seismic data according to the processed multi-wave seismic data;
and the second determination module is used for determining the fracture parameters of each target layer according to the processed multi-wave seismic data and the corresponding shear wave splitting analysis time window of the multi-wave seismic data in each target layer.
7. The apparatus of claim 6, wherein the adjustment module comprises:
the first determination sub-module is used for determining seismic data with a seismic source direction opposite to a target direction when shear wave source seismic data are received through the detector, wherein the target direction is an excitation direction specified when seismic source equipment carries out seismic source excitation, and the shear wave source seismic data comprise the pure shear wave seismic data and the SVP converted wave seismic data;
the processing submodule is used for carrying out reverse polarity processing on the amplitude value of the transverse wave source seismic data with the seismic source direction opposite to the target direction to obtain the transverse wave source seismic data with consistent excitation directions;
the first acquisition sub-module is used for acquiring the azimuth angle of the multi-wave seismic data;
and the rotation sub-module is used for performing alford rotation on the four-component seismic data of the pure transverse wave seismic data received by the horizontal component of the detector, performing horizontal component rotation on the two-component seismic data of the PSV converted wave seismic data received by the horizontal component of the detector, and performing horizontal seismic source rotation on the two-component seismic data of the SVP converted wave seismic data received by the vertical component of the detector according to the azimuth angle.
8. The apparatus of claim 6, wherein the first determining module comprises:
the imaging submodule is used for carrying out superposition or migration imaging processing on the processed multi-wave seismic data to obtain seismic data imaging sections corresponding to the pure transverse wave seismic data, the PSV converted wave seismic data and the SVP converted wave seismic data respectively;
and the calibration sub-module is used for carrying out horizon calibration in the seismic data imaging section so as to determine the transverse wave splitting analysis time windows of the pure transverse wave seismic data, the PSV converted wave seismic data and the SVP converted wave seismic data in each target layer respectively.
9. The apparatus of claim 6, wherein the second determining module comprises:
a second obtaining sub-module, configured to obtain effective component signals of the processed multi-wave seismic data in each destination layer, where the effective component signals include a SrRt component signal and an StRr component signal of the pure transverse-wave seismic data, a PSRt component signal of the PSV converted-wave seismic data, and an StP component signal of the SVP converted-wave seismic data, and an amplitude of the effective component signals in the destination layer where the effective component signals are located is not 0;
and the second determining submodule is used for determining the fracture parameters of each target layer according to each effective component signal of the processed multi-wave seismic data in each target layer and the shear wave splitting analysis time window corresponding to each target layer.
10. The apparatus of claim 9, wherein the second determination submodule is to:
determining the amplitude energy of the specific component signal after transverse wave splitting correction in each target layer according to each effective component signal of the processed multi-wave seismic data in each target layer and a transverse wave splitting analysis time window corresponding to each target layer;
and determining a target fracture parameter as a fracture parameter of a target stratum, wherein the target stratum is any one stratum in the stratum transmitted by the multi-wave seismic data, and the target fracture parameter is a fracture parameter corresponding to the minimum amplitude energy of the specific component signal in the target stratum.
11. A computer-readable storage medium having stored thereon instructions which, when executed by a processor, carry out the steps of the method of any of the preceding claims 1 to 5.
CN202110745402.4A 2021-07-01 2021-07-01 Method and device for determining crack parameters and computer storage medium Pending CN115561813A (en)

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