CN113640878B - Method for constructing azimuth-apparent velocity radar chart by utilizing virtual seismic source scanning - Google Patents
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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
- G01V1/303—Analysis for determining velocity profiles or travel times
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- 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
- G01V2210/622—Velocity, density or impedance
- G01V2210/6222—Velocity; travel time
Abstract
The invention discloses a method for constructing an azimuth-apparent velocity radar chart by utilizing virtual seismic source scanning. The method takes the earthquake waves incident from different vertical angles as the theoretical basis of different horizontal viewing speeds, calculates the earthquake wave propagation time from the virtual earthquake source to each wave detector in the receiving arrangement under the condition of different viewing speeds through the virtual earthquake source in different directions of the plane circumference, extracts the superposition energy of the earthquake waves in the corresponding time period, and obtains a radar chart capable of reflecting the plane propagation direction and the viewing speed of the earthquake waves. The method can intuitively reflect the spatial distribution of various seismic waves, provides a good data analysis means for noise source analysis, detector combination parameter design and the like, and can greatly improve the accuracy of seismic wave apparent velocity analysis on the premise of not changing the field production mode.
Description
Technical Field
The invention relates to the field of seismic exploration, in particular to a method for establishing a virtual seismic source by utilizing an analysis shot point, then constructing an azimuth-apparent velocity radar chart by utilizing virtual seismic source scanning, and finally completing interference wave analysis.
Background
The high-density square receiving arrangement (also called box wave) is a field interference wave investigation means commonly used in artificial seismic exploration, and has receiving density which is several times higher than that of normal production receiving arrangement, and 360-degree dead angle-free receiving data on a plane, so that various seismic waves transmitted in all directions can be collected at high density, and the method is generally constructed before formal seismic operation, is used for determining the source of interference waves in a working area and is used for assisting in designing the combination parameters of a detector. The existing box wave analysis means generally extracts seismic traces from a receiving arrangement according to azimuth angles to form a series of angle trace sets, and then performs view velocity data superposition scanning or view velocity data correlation scanning on data in each angle trace set, and draws a two-dimensional radar chart according to the superposition or correlation coefficient value. However, the existing methods still suffer from several drawbacks: 1. the actual receiving arrangement is generally distributed at equal intervals according to the square, so that the number of the seismic channels in the channel set extracted according to the angle channels is not uniform, and the azimuth analysis precision is reduced; 2. the seismic waves are propagated in the stratum sphere instead of the plane, and the nonlinear in-phase axis form in the seismic records reduces the apparent velocity analysis precision; 3. the spherical propagation brings about inconsistent energy received by different detectors in the array due to different distances from the shot point, and the superposition or correlation analysis precision is reduced.
Disclosure of Invention
In view of the above technical problems, the present invention aims to overcome the defects of the prior art, and provides a method for scanning azimuth angle-apparent velocity, which can complete the seismic apparent velocity scanning operation under different horizontal azimuth angles with high precision and high efficiency on the basis of not changing the existing acquisition and layout scheme.
In order to achieve the technical purpose, the invention adopts the following technical scheme:
step S1: taking high-density square arranged received seismic data, preprocessing the seismic data, and acquiring offset coordinate relation in the seismic process;
step S2: taking the centers of high-density square arrangement as circle centers, taking the distance between a shot point and the circle centers as a radius, and simultaneously setting a virtual source at certain angles on the circumference;
step S3: calculating the distance between the virtual seismic source and all detectors in the high-density square arrangement;
step S4: scanning with different apparent speeds to obtain the propagation time of a virtual source to any detector, and extracting all seismic data of the corresponding time window in the step S1 according to the propagation time and the fixed time window length;
step S5: performing inter-channel superposition on the seismic data in the step S4;
step S6: and repeating the steps S3-S5 until the processing of all the virtual seismic sources is completed, and drawing a superposition energy distribution radar chart at each angle and each radial distance by taking the apparent speed as the radial distance.
The beneficial effects of the invention are as follows: compared with the conventional method for directly extracting the angle gathers by the visual velocity scanning, the method adopts a mode of circumferentially arranging virtual seismic sources, ensures that all detectors can be adopted to participate in operation on any plane angle, and has uniform gathers and high operation precision; compared with the method that the conventional view velocity scanning can only slide a linear scanning time window on a limited number of data tracks in the angle gather, the method determines the time window on all gather data of a plane, the time window position is determined by dividing the plane offset by the scanning view velocity, the method is nonlinear, the method accords with the spherical propagation rule of the seismic waves, the time window extraction position is more accurate, and the analysis precision is high; the invention can greatly improve the accuracy of the analysis of the apparent velocity of the seismic waves on the premise of not changing the field production mode by combining the pretreatment operation of static correction and energy balance between channels.
Drawings
FIG. 1 is a block diagram of a computational flow of the present invention;
FIG. 2 is a simplified schematic representation of seismic waves incident on detectors at different vertical angles in the subsurface on a seismic record;
FIG. 3 is a schematic representation of the morphology of seismic source excitation waves propagating along a surface plane;
FIG. 4 is a schematic diagram showing the relative coordinate relationship between a shot and a receiving arrangement according to SPS, wherein S is the shot, G is the detector, and R is the distance from the shot to the center of the receiving arrangement;
FIG. 5 is a schematic view of a virtual source along a shot radius, where virtual sources may be placed at each azimuth of the plane, each virtual source may calculate its distance to each detector in the receiving array;
FIG. 6 is an example of a set of field high density square receiving arrangements for use with the calculation data of this patent;
FIG. 7 is a view of a partially displayed high-density square array of raw seismic data (FIG. 7 a), statics corrected seismic data (FIG. 7 b), and energy balanced between traces (FIG. 7 c);
FIG. 8 is a graph of the analysis time window at 315℃horizontal azimuth, 300m/s, 900m/s, 3000m/s view velocity and the analysis time window at 135℃horizontal azimuth, 900m/s view velocity;
FIG. 9 is a superimposed waveform at 200ms analysis time, 135 DEG, 315 DEG horizontal azimuth, 300m/s to 6000m/s apparent velocity scanning, and a superimposed waveform at 600ms analysis time, 135 DEG, 315 DEG horizontal azimuth, 300m/s to 6000m/s apparent velocity scanning, each corresponding to one apparent velocity superimposed result, scan velocity interval 100m/s;
fig. 10 analyzes azimuth-apparent velocity scan radar maps for times 200ms and 600 ms.
Detailed Description
In order to make the technical scheme and technical advantages of the present invention more clear, the technical scheme in the implementation process of the present invention will be clearly and completely described below with reference to the embodiments and the accompanying drawings.
FIG. 2 illustrates the cause of the time difference in the seismic waves of the same kind received by adjacent detectors in a seismic record-the subsurface seismic waves have dip angles when they are incident on the detectors. The horizontal distance of the plane adjacent detectors divided by the time difference is called the apparent velocity, and it is obvious that the vertical incidence seismic waves have almost no time difference on the seismic record, and the apparent velocity tends to infinity; and the closer to parallel incidence the smaller the apparent velocity of the seismic wave.
The seismic waves propagate in spherical form in the subsurface, are mapped to the surface, and are propelled forward in a circular arc shape, as shown in fig. 3. In the conventional view velocity scanning algorithm, seismic waves are set to be plane waves, the plane waves arrive at G1, G5, G9 and G13 detectors at the same time, and received data of the four detectors are extracted in time, so that inaccurate pickup of analysis time windows is caused; the method describes the spherical propagation form by equal offset, the arrival time of the seismic waves is earlier than the arrival time of the seismic waves G5 and G9 and G1 and G13, and the time difference is taken into consideration when the time window is picked up, so that a more accurate analysis time window is obtained.
Figures 2 and 3 illustrate the reason why the error is greater and the result of the present invention is more accurate when the conventional method is employed.
Fig. 1 is a block diagram of the steps of the present embodiment, as shown in fig. 1, in which most of the seismic data are SPS files, and therefore, offset coordinates are first extracted from the SPS files, offset distances are calculated, and then the time for the seismic waves at different apparent velocities to propagate between offsets is calculated, then data in a time window related to the time are extracted from the preprocessed seismic data, and finally root mean square energy is obtained by superimposing the data in the time window, and the two-dimensional radar chart is drawn.
Specifically, first, the present embodiment needs to use box wavelet data, and the box wavelet is also called a high-density square receiving arrangement, and the requirements of the high-density square receiving arrangement in the present invention are: the number of the detectors in the vertical and horizontal directions is greater than 10, and meanwhile, the specific distribution situation of the detectors in the vertical and horizontal directions is not required, for example, the embodiment can be applied to a high-density square receiving arrangement with the detector distribution of 30×30 and a high-density square receiving arrangement with the detector distribution of 10×30, but it should be noted that when the method of the embodiment is applied, the larger the difference between the numbers of the detectors in the vertical and horizontal directions is, the worse the final measured result is; the receiving interval between two adjacent detectors is not more than 5m.
It should be noted that although the flow chart of the present embodiment is described as "inputting an SPS" file and then extracting corresponding data from the SPS file, those skilled in the art should understand that the data file type is not limited to the SPS file in some cases, and other files in the remaining format, in which the data needed by the present embodiment is stored, are also within the protection scope of the present invention.
Meanwhile, the offset coordinate relation is extracted from the seismic data, and comprises shot point coordinates, detector coordinates and offset relation.
For the embodiment, the real seismic data of a certain place in southwest of China is adopted for trial calculation, 33 detectors in longitudinal and transverse directions are adopted for receiving data, the receiving interval is 3m, and each gun focus can be excited at 9216m 2 The receiving of 1089 data is completed in area, and the coordinate relation between the test calculated shot point and the detection point is shown in fig. 6.
Meanwhile, the seismic data received in the high-density square array is extracted and preprocessed, and fig. 7a shows a part of the seismic data actually received, which is the first 4 of the 33 receiving arrays (the detectors arranged on a straight line form a receiving array as shown in fig. 6), and 33 detectors are arranged on each array to form 33 receiving data, and each data shows a time length of 0-1500 ms. As shown in the analysis of fig. 2, since the inclination angle exists when the seismic waves enter the detector, the time difference exists in sequence between the received waveforms of each channel on the array, and a plurality of sets of in-phase axes with different inclination degrees exist from top to bottom, which indicates that a plurality of sets of seismic wave types with different viewing speeds exist.
Looking at fig. 7a, the arrival time of the seismic waves in the time window 1 on the adjacent receiving channels is not smooth, and there is a vertical dislocation, which is caused by the difference of the receiving altitudes of the detection points, and the seismic waves belong to interference items in the azimuth-apparent velocity analysis, and need to be eliminated in advance. The step of excluding is called statics correction during seismic data processing, and statics corrected data is shown in fig. 7 b. Comparing the time window 1 in fig. 7a and 7b, it can be seen that the vertical dislocation of the adjacent channel seismic waveform is eliminated through static correction, and the inclined in-phase axis is smoother.
Looking at time window 2 in fig. 7b, as the detector points are far from the shot point (from left to right in the time window), the received seismic energy gradually decreases, and the amplitude of the wave form traversing between adjacent channels gradually decreases, which is caused by spherical diffusion, stratum absorption and other reasons in the seismic wave propagation process. Because the algorithm adopts adjacent channel superposition in the analysis time window to realize scanning analysis, the inconsistency of adjacent channel waveform energy influences the final superposition waveform form, thereby reducing the analysis precision, and therefore, the method also needs to be eliminated in advance as an interference item. The effect of completing the energy equalization of each lane according to equations 1-3 is shown in fig. 7c, where the energy similarity between lanes is greatly increased.
Wherein x is i,t Seismic data values, E, for the t time sample point of the i-th trace i For each channel root mean square energy, N is the number of detectors (the number of all participating superimposed channels),the energy is averaged for each lane.
Next, as shown in fig. 6, a circle is drawn by taking the center of the high-density square receiving arrangement as the center of a circle, selecting a shot from all shots as an analysis shot, analyzing the distance between the shot and the center of the circle as the radius, and setting a virtual source at regular angles along 0-360 degrees on the circumference. These virtual sources represent sources of seismic fluctuations of different horizontal azimuth angles equivalent to the range of the analysis cannon, the angular interval of which can be set according to the needs of the user. Meanwhile, the step can be combined with the view velocity scanning to analyze the noise source: it is assumed that each virtual source is a source of "noise", the distances d 1-d 9 between the virtual source and all detectors are calculated, and if energy focusing occurs during the scanning process of the apparent velocity, it is indicated that there is indeed a noise source with such apparent velocity in the direction, and if there is no energy focusing phenomenon, it is indicated that the noise source is not established, thereby completing the noise source analysis.
In this case, the distance of the virtual source from all detectors also needs to be calculated.
In this embodiment, fig. 4 shows a schematic view of calculation of relative coordinates of offset, and the calculation steps are as follows: 1) Reading the coordinate position of each detector from the SPS file, searching the central position coordinates of all detectors, and recalculating the relative coordinates of all detectors by taking the coordinates as (0, 0) points; 2) Reading and analyzing coordinates of the cannon points from the SPS file, and calculating and analyzing relative coordinates of the cannon points relative to the central coordinates of the detector; 3) And calculating and analyzing the distance R between the shot point and the center of the detector.
Scanning with different apparent speeds to obtain the propagation time of the virtual source to any detector, and extracting the seismic data corresponding to the propagation time and positioned in the initial seismic data. Since a plurality of detectors are included, the data of each detector corresponding to the propagation time needs to be extracted.
Fig. 8 shows the variation of the analysis time window during the view velocity scan. Referring to the horizontal azimuthal coordinate convention of FIG. 5, FIG. 8 shows the time window values for three view speeds 300m/s (FIG. 8 a), 900m/s (FIG. 8 b), 3000m/s (FIG. 8 c) at the 315 azimuthal angle of the third quadrant and the time window value for the view speed 900m/s (FIG. 8 d) at the 135 azimuthal angle of the second quadrant. The cutting form of the time window in each channel is changed from the starting position t of the variable time window in each channel Initiation i And a fixed window width t Window length The determination is specifically shown in the formulas 4-6.
t Initiation i ＝t Analysis +t Propagation of 4. The method is to
t Cut-off i ＝t Initiation i +t Window length 5. The method is to
t Analysis The fixed analysis time set by the user is, for example, 200ms when calculated in fig. 8, but this time is not particularly defined, and is generally set by observing the earliest time setting of a certain tilt phase axis in fig. 7, and the number of axes to be analyzed is not changed during calculation once the setting is made. t is t Propagation of i For the plane propagation time of the seismic wave from the shot to the ith receiver, the time being the horizontal propagation distance d from the virtual source to the receiver i i And propagation apparent velocity v Vision device And (5) dividing to obtain the product. t is t Analysis And t Propagation of i Together form the upper edge t of each analysis time window Initiation i . Lower edge t of analysis time window Cut-off i Then it extends downwards from the upper edge by a fixed time window length t Window length The length is specified by the user, and it is generally preferable to include a positive peak and two negative valleys of a common phase axis.
After the virtual source at one horizontal angle completes all the view velocity scans, it switches to the virtual source at the next horizontal angle until the view velocity scans of the preset sources at all the circles are completed, as shown in FIG. 5 b.
The scanning analysis calculation process comprises the following steps: determining offset distance d given an azimuth angle i Then continuously changing the visual speed, and calculating the propagation time t of each channel Propagation of i Calculating the starting and stopping positions t of each analysis time window according to the time Initiation i 、t Cut-off i And extracting data in the time window from the original data, and switching to the next azimuth angle to repeat the process after superposition and root mean square energy extraction calculation, so as to sequentially finish calculation under all azimuth angles.
And superposing the seismic data of each receiving channel extracted in the process: and superposing the received seismic data extracted from the same azimuth, taking an average value, and calculating root mean square energy according to the time direction of the average seismic channel. The seismic wave has good in-phase superposition and weakening, and the root mean square energy is accumulated along the time direction, and the energy value is used for representing the existence and strength of the seismic wave under the azimuth angle and the apparent velocity.
After the energy superposition of one horizontal angle is completed, switching to the next horizontal angle, and repeating the steps until all virtual seismic sources on the circumference of 0-360 degrees complete the energy superposition.
In this embodiment, fig. 9 shows the effect of the superposition of data in the time window in fig. 8, each graph is the result of increasing the apparent velocity of 300m/s to 3000m/s from left to right by 100m/s each time, and the length of the analysis time window is set to 100ms. As shown in formula 7, the superposition is that adding all the seismic traces into 1 trace in a time window, and taking an average value, if the apparent velocity is selected correctly, the time window can contain one same phase axis in an equal phase manner, as shown in fig. 8b, the average energy after superposition is enhanced, and the amplitude of the seismic wave is maximum corresponding to the seismic trace at the 900m/s position in fig. 9 b; if the apparent velocity is selected incorrectly, the energy after superposition is attenuated to a different extent, such as 300m/s, 3000m/s in FIG. 9b, and 900m/s in FIG. 9a, with smaller seismic wave amplitudes. Fig. 9c and 9d show the superposition results obtained by 600ms analysis time, and it can also be seen that the superposition energy of different viewing speeds at different azimuth angles is different.
Wherein x is i,t The seismic data value for the t time sample point of the ith trace, N is the number of detectors (the number of all participating stacking traces),is the seismic data value of the t-th time sampling point on the average seismic trace.
And (3) overlapping the seismic data corresponding to each virtual seismic source until all virtual seismic sources with 0-360 degrees on the circumference are overlapped, normalizing the overlapped energy, and establishing a two-dimensional circular radar chart with radial apparent velocity and horizontal azimuth as the circumference.
In the present embodiment, each data in fig. 9 is accumulated with energy along the time direction to obtain an energy value E associated with a certain horizontal azimuth angle α and a certain apparent velocity v α,v After the energy values of all horizontal azimuth angles and viewing speeds are calculated, the energy values are normalized to be [0,1 ] by adopting a formula shown in the formulas 8-9]A two-dimensional map can be drawn for the interval with the horizontal azimuth angle as the circumference and the apparent velocity as the radial distance, as shown in fig. 10. The graph is colored with color, and the color values are mapped from [0,1 ]]The interval and the color change reflect the existence and intensity of the view velocity seismic wave in the azimuth angle.
In the method, in the process of the invention,for averaging the seismic data values at the t-th time sample point on the seismic trace, t Window length To analyze the width of the time window, E α,v For the corresponding root mean square energy value at horizontal azimuth angle alpha, apparent velocity v, E α,v norm The normalized horizontal azimuth angle alpha and the corresponding root mean square energy value at the apparent velocity v.
The above embodiments are only some of the embodiments of the present invention, and are used for describing the basic principles, implementation purposes and detailed procedures of the present invention, and do not limit the scope of the present invention. Any modification, equivalent variation and modification made to the above embodiments according to the technical substance of the present invention fall within the scope of the technical solution of the present invention. The present invention has been disclosed in the foregoing description of preferred embodiments, but it will be understood by those skilled in the art that these embodiments are merely for the purpose of describing the present invention and should not be construed as limiting the scope of the present invention. Further modifications of the invention without departing from the principles of the invention are also considered to be within the scope of the invention.
Claims (7)
1. A method for constructing an azimuth-apparent velocity radar map using virtual source sweep, comprising the steps of:
step S1: taking high-density square arranged received seismic data, preprocessing the seismic data, and acquiring offset coordinate relation in the seismic process;
step S2: taking the center of the high-density square arrangement as the circle center, selecting a shot point as an analysis shot point, taking the distance between the analysis shot point and the circle center as the radius, making a circle, and setting a virtual seismic source on the circumference at certain angles at intervals;
step S3: calculating the distance between the virtual seismic source and all detectors in the high-density square arrangement;
step S4: scanning with different apparent speeds to obtain the propagation time of a virtual source to any detector, and extracting all seismic data of the corresponding time window in the step S1 according to the propagation time and the fixed time window length;
step S5: performing inter-channel superposition on the seismic data in the step S4;
step S6: repeating the steps S3-S5 until the processing of all virtual seismic sources is completed, and drawing a superposition energy distribution radar chart at each angle and each radial distance by taking the visual speed as the radial distance;
the high-density square arrangement refers to: the detectors are distributed in a square shape, the number of the detectors in the square shape in the longitudinal and transverse directions is more than 10, and the receiving distance between two adjacent detectors is not more than 5m.
2. The method of claim 1, wherein the preprocessing of the seismic data in step S1 comprises statics correction, inter-trace energy equalization processing.
3. The method of claim 1, wherein in step S1, the offset coordinate relationship comprises shot coordinates, geophone coordinates, and an offset relationship.
4. The method of claim 1, wherein in step S2, the virtual source angles are disposed over the entire circumference.
5. The method according to claim 1, wherein in step S4, the propagation time is calculated according to the formula:wherein t is Propagation of i For propagation time d i For the horizontal propagation distance between the virtual source and the detector i, V Vision device Is the viewing speed.
6. The method according to claim 1, wherein in step S4, the cutting pattern of the time window is defined by a variable time window starting position t Initiation i And a fixed time window length t Window length Determining, wherein t Initiation i ＝t Analysis +t Propagation of i ，t Cut-off i ＝t Initiation i +t Window length Wherein t is Cut-off i Is the end position of the variable time window.
7. The method according to claim 1, wherein the specific operation of step S5 is: and (3) superposing the seismic data of each receiving channel extracted in the step (S4), taking an average value, and calculating root mean square energy according to the time direction of the average seismic channel.
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