CN107807391B - Seismic data processing method, device, electronic equipment and computer storage medium - Google Patents
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Abstract
The invention aims to provide a seismic data processing method, a seismic data processing device, an electronic device and a computer storage medium, wherein the method comprises the following steps: acquiring first seismic data, wherein the first seismic data comprise primary waves and multiple waves; performing dynamic correction processing on the seismic data according to the specified speed to obtain second seismic data; wherein the designated velocity comprises a numerical value of the primary velocity, a numerical value of the multiple velocity, or a numerical value between a numerical value of the primary velocity and a numerical value of the multiple velocity; performing preset processing on the second seismic data to obtain third seismic data; the presetting comprises reducing the offset distance in the second seismic data according to a specified rule, and/or increasing the time in the second seismic data according to a specified rule. The implementation mode of the invention can better distinguish the primary wave from the multiple wave, thereby obtaining better multiple wave filtering effect.
Description
Technical Field
The present invention relates to the field of seismic exploration, and in particular, to a method and an apparatus for processing seismic data, an electronic device, and a computer storage medium.
Background
Typically, multiples are considered in seismic data processing as coherent noise that severely interferes with primaries. The multiple waves and the primary waves are overlapped together and are difficult to separate, so that the signal to noise ratio of seismic data is reduced, the authenticity and the reliability of seismic imaging are seriously influenced, and the subsequent interpretation work is adversely affected.
The existing method for suppressing multiples generally adopts a filtering method to perform suppression according to the difference between multiples and primaries, such as Radon transform, frequency-wavenumber (F-K frequency-wavenumber) transform, prediction deconvolution, and the like. Because the time difference between the multiple and the primary wave is possibly very small, especially the difference between the multiple and the primary wave between layers is very small, and the filtering effect is influenced.
Disclosure of Invention
An object of embodiments of the present description is to provide a seismic data processing method, apparatus, electronic device, and computer storage medium, which can suppress multiples effectively.
To achieve the above object, embodiments of the present specification provide a seismic data processing method, including: acquiring first seismic data, wherein the first seismic data comprise primary waves and multiple waves; performing dynamic correction processing on the seismic data according to the specified speed to obtain second seismic data; wherein the designated velocity comprises a numerical value of the primary velocity, a numerical value of the multiple velocity, or a numerical value between a numerical value of the primary velocity and a numerical value of the multiple velocity; the second seismic data comprises a plurality of dimensions, the plurality of dimensions comprising offset and time; performing preset processing on the second seismic data to obtain third seismic data; the presetting comprises reducing the offset distance in the second seismic data according to a specified rule, and/or increasing the time in the second seismic data according to a specified rule. In the second seismic data, the primary waves are clearly separated from the multiples.
To achieve the above object, embodiments of the present specification further provide a seismic data processing apparatus, including: the system comprises an acquisition unit, a processing unit and a processing unit, wherein the acquisition unit is used for acquiring first seismic data, and the first seismic data comprises primary waves and multiple waves; the first processing unit is used for performing dynamic correction processing on the seismic data according to the specified speed to obtain second seismic data; wherein the designated velocity comprises a numerical value of the primary velocity, a numerical value of the multiple velocity, or a numerical value between a numerical value of the primary velocity and a numerical value of the multiple velocity; the second seismic data comprises a plurality of dimensions, the plurality of dimensions comprising offset and time; the second processing unit is used for carrying out preset processing on the second seismic data to obtain third seismic data; the presetting comprises reducing the offset distance in the second seismic data according to a specified rule, and/or increasing the time in the second seismic data according to a specified rule.
To achieve the above object, an embodiment of the present specification further provides an electronic device, including: an input device, a memory, a processor; the input device is used for acquiring first seismic data, wherein the first seismic data comprises primary waves and multiple waves; the processor is used for performing dynamic correction processing on the seismic data according to the specified speed to obtain second seismic data; wherein the designated velocity comprises a numerical value of the primary velocity, a numerical value of the multiple velocity, or a numerical value between a numerical value of the primary velocity and a numerical value of the multiple velocity; the second seismic data comprises a plurality of dimensions, the plurality of dimensions comprising offset and time; performing preset processing on the second seismic data to obtain third seismic data; the presetting comprises reducing the offset distance in the second seismic data according to a specified rule and/or increasing the time in the second seismic data according to a specified rule; the memory is used to access data including the input or acquired seismic data, intermediate data processed by the processor, and result data.
To achieve the above object, the present specification further provides a computer storage medium storing computer program instructions, which when executed, implement: acquiring first seismic data, wherein the first seismic data comprise primary waves and multiple waves; performing dynamic correction processing on the seismic data according to the specified speed to obtain second seismic data; wherein the designated velocity comprises a numerical value of the primary velocity, a numerical value of the multiple velocity, or a numerical value between a numerical value of the primary velocity and a numerical value of the multiple velocity; the second seismic data comprises a plurality of dimensions, the plurality of dimensions comprising offset and time; performing preset processing on the second seismic data to obtain third seismic data; the presetting comprises reducing the offset distance in the second seismic data according to a specified rule, and/or increasing the time in the second seismic data according to a specified rule.
To achieve the above object, embodiments of the present specification further provide a seismic data processing method, including: acquiring first seismic data, wherein the first seismic data comprise primary waves and multiple waves; determining a designated speed according to the wave speed of the primary wave and the wave speed of the multiple wave; the specified speed is between the wave speed of the primary wave and the wave speed of the multiple wave; and performing dynamic correction processing on the seismic data according to the specified speed to obtain second seismic data. In the second seismic data, the primary waves are substantially separated from the multiples.
To achieve the above object, embodiments of the present specification further provide a seismic data processing apparatus, including: the system comprises an acquisition unit, a processing unit and a processing unit, wherein the acquisition unit is used for acquiring first seismic data, and the first seismic data comprises primary waves and multiple waves; a first determining unit, configured to determine a specified speed according to a wave speed of the primary wave and a wave speed of the multiple, where the specified speed is between the wave speed of the primary wave and the wave speed of the multiple; and the first determining unit is used for performing dynamic correction processing on the seismic data according to the specified speed to obtain second seismic data.
It can be seen from the above technical solution provided by the present application embodiment, the present application embodiment mainly provides conditions for the subsequent method of suppressing multiples by determining the specified velocity, which is between the velocity of the primary wave and the velocity of the multiple wave to perform dynamic correction, roughly separating the primary wave from the multiple wave, and then reducing the offset distance in the second seismic data, and/or increasing the time parameter in the second seismic data to further separate the primary wave from the multiple wave. The method utilizes the principle that on the basis of conventional dynamic correction, the primary waves are overcorrected by utilizing the specified speed, the multiples are undercorrected, the primary waves and the multiples are separated, the multiples are further separated through the change of offset or time, and the effect of suppressing the multiples better can be realized.
Drawings
In order to more clearly illustrate the embodiments of the present specification or the technical solutions in the prior art, the drawings needed to be used in the description of the embodiments or the prior art will be briefly introduced below, it is obvious that the drawings in the following description are only some embodiments described in the specification, and other drawings can be obtained by those skilled in the art without inventive labor.
FIG. 1 is a flow chart of seismic data processing as provided herein;
FIG. 2 is a schematic illustration of seismic data including two sets of primaries and multiples provided herein;
FIG. 3 is a schematic illustration of seismic data after dynamic correction of the seismic data as provided herein;
FIG. 4 is a schematic diagram of primaries and multiples in a given coordinate system provided herein;
FIG. 5 is another schematic diagram of primaries and multiples in a given coordinate system provided herein;
FIG. 6 is a schematic representation of seismic data after a reactionary correction provided herein;
FIG. 7 is a schematic illustration of another seismic data set after reactive correction provided herein;
FIG. 8 is a diagram illustrating common reflection point gather (CRP common reflexion point) characterization in a practical implementation provided herein;
FIG. 9 is a representation of seismic data after performing a dynamic correction on the seismic data in one implementation provided herein;
FIG. 10 is a representation of seismic data after a plurality of passes in a practical scenario provided herein;
FIG. 11 is a representation of seismic data after reactive correction in one implementation provided herein;
FIG. 12 is a velocity spectrum calculated for multiple-order pre-wavelet data as provided herein;
FIG. 13 is a velocity spectrum calculated for multiple-suppressed data as provided herein;
FIG. 14 is a representation of the results of a direct prestack migration provided herein;
FIG. 15 is a graphical representation of a squashed multiple wave post-prestack migration result provided in the present specification;
fig. 16 is a schematic diagram of an electronic device provided in this specification.
Detailed Description
The technical solutions in the embodiments of the present disclosure will be clearly and completely described below with reference to the drawings in the embodiments of the present disclosure, and it is obvious that the described embodiments are only a part of the embodiments of the present disclosure, and not all of the embodiments. All other embodiments obtained by a person skilled in the art without making any inventive step based on the embodiments in this specification shall fall within the scope of protection of this application.
Please refer to fig. 1. A flow chart of a seismic data processing method is provided herein. The method may include the following steps.
In this embodiment, the object for performing the seismic data processing may be an electronic device having a logical operation function. The electronic devices may be servers and clients. The client can be a desktop computer, a tablet computer, a notebook computer, a workstation and the like. Of course, the client is not limited to the electronic device with certain entities, and may also be software running in the electronic device. It may also be program software formed by program development, which may be run in the above-mentioned electronic device.
Step S10: acquiring first seismic data, wherein the first seismic data comprise primary waves and multiple waves.
In this embodiment, the seismic data refers to raw seismic data acquired by various sensors in a seismic survey, and may also be intermediate processed seismic data, for example, acquired directly from data obtained from a seismic survey. The nature and morphology of the subsurface formations may be inferred by processing and interpreting the seismic data. The seismic data includes primary and multiple waves. The primary wave represents a wave that is reflected once between lower interfaces when arriving at a receiving point (detection point) from the seismic source, and the multiple wave represents a wave that is reflected or refracted many times between underground interfaces when arriving at the receiving point (detection point) from the seismic source. Wherein the velocity of the primary wave is greater than the velocity of the multiple waves.
In this embodiment, the first seismic data may be obtained through input of an input device, where the input device may be a keyboard, a mouse, a voice input device, or the like; or through the input of an external storage device, wherein the external storage device can be a U disk, a mechanical hard disk and the like; or may be received via a network, such as the internet, a local area network; or by reading local data, etc.
Step S12: performing dynamic correction processing on the seismic data according to the specified speed to obtain second seismic data; wherein the designated velocity comprises a numerical value of the primary velocity, a numerical value of the multiple velocity, or a numerical value between a numerical value of the primary velocity and a numerical value of the multiple velocity; the second seismic data includes a plurality of dimensions including offset and time.
In the present embodiment, the predetermined velocity may be a velocity of the primary wave, a velocity of the multiple wave, or a velocity between both. Preferably, the specified velocity may be an average velocity of the primary velocity and the multiple velocity. When the designated speed is the average speed of the primary wave speed and the multiple wave speed, the separation of the primary wave and the multiple wave is facilitated after the dynamic correction processing.
In this embodiment, referring to FIG. 2, the first seismic data is in the first coordinate system, the time-offset coordinate system. The first seismic data includes the reception time of the primary wave, the energy bolus of the primary wave, the running distance of the primary wave, the reception time of the multiples, the energy bolus of the multiples, the running distance of the multiples, and the like. The dynamic correction is to perform moveout correction on time in the first seismic data, so that the second seismic data is still in a time-offset coordinate system, and the second seismic data comprises multiple dimensions including offset and time.
In the present embodiment, the dynamic correction is to correct the arrival time (reception time) of reflected waves from the same interface and the same point on each track having different offset distances to the echo time (reception time) at the common center point. The conventional dynamic correction corrects the reflection time of different offset distances to the reflection time of zero offset distance, and the dynamic correction processing of the seismic data according to the specified velocity is to replace the specified velocity with the velocity in the conventional dynamic correction to perform dynamic correction.
Step S14: performing preset processing on the second seismic data to obtain third seismic data; the presetting comprises reducing the offset distance in the second seismic data according to a specified rule, and/or increasing the time in the second seismic data according to a specified rule.
In this embodiment, the preset processing is processing for amplifying a difference between the primary wave and the multiple wave. The separation degree of the primary waves and the multiples can be increased, and a good foundation is provided for later-stage multiple suppression.
In this embodiment, the pre-setting process includes reducing the offset in the second seismic data according to a specified rule, and/or increasing the time in the second seismic data according to a specified rule. The specified rule may cause scaling up or down. For example, if the offset in the second seismic data is multiplied by 0.3 or 0.5, the offset or time may be exponentially reduced, but if the offset is too large, the curvature range is very large, one of them increases the calculation amount, and both of them are easy to generate spurious, so that the offset may be increased to a degree that can be separated, and it is not preferable that the offset is increased or decreased according to a certain ratio. In a specific embodiment, the reducing the offset in the second seismic data is proportionally reducing the offset in the second seismic data. In another specific embodiment, increasing the time in the second seismic data is increasing the time in the second seismic data by a certain proportion. In another specific embodiment, reducing the offset in the second seismic data according to a specified rule and increasing the time in the second seismic data according to a specified rule are performed simultaneously. And increasing the absolute value of the curvature of the primary wave and the multiple through the preset processing, and further separating the primary wave from the multiple. Referring to fig. 3, in fig. 3, the primary curve rises upward and has a negative curvature, and the multiple curve falls downward and has a positive curvature. By reducing the offset of the corresponding point in the coordinate system of fig. 3, the curve is compressed to the origin of coordinates, the absolute values of the curvature pattern characteristic parameters of the primary wave and the curvature pattern characteristic parameters of the multiples are increased, and the primary wave and the multiples are further separated. Similarly, by increasing the time in the coordinate system of fig. 3, the absolute values of the curvature pattern characteristic parameter of the primary wave and the curvature pattern characteristic parameter of the multiple can also be increased, or two preset processing modes can be combined for use, so that the effect of increasing the absolute values of the curvature pattern characteristic parameter of the primary wave and the curvature pattern characteristic parameter of the multiple can be achieved.
In a specific scenario example, the seismic data processing method provided by the embodiments of the present specification may be implemented by software running in an electronic device.
In the present scenario example, first seismic data is acquired, wherein the first seismic data comprises primary waves and multiple waves; the first seismic data can be obtained through input of an input device, input of an external storage device, network reception, reading of local data and the like. Performing dynamic correction processing on the seismic data according to the specified speed to obtain second seismic data; wherein the specified velocity comprises a numerical value of the primary velocity, a numerical value of the multiple velocity, or a numerical value between a numerical value of the primary velocity and a numerical value of the multiple velocity. The dynamic correction is a dynamic correction implemented by replacing a conventional dynamic correction speed with a specified speed on the basis of a conventional dynamic correction. Performing preset processing on the second seismic data to obtain third seismic data; the presetting comprises reducing the offset distance in the second seismic data according to a specified rule, and/or increasing the time in the second seismic data according to a specified rule. For example, offsets in the second seismic data are multiplied by 0.5, or times in the second seismic data are multiplied by 2. The preset treatment can further separate the curvatures of the primary waves and the multiples, so as to facilitate the filtering of the multiples. In the method, the primary waves and the multiples have different speeds, the primary waves and the multiples are subjected to initial separation by dynamic correction, and the separation degree of the primary waves and the multiples is processed and amplified through preset processing, namely the properties of the primary waves and the multiples in two dimensions of a coordinate system.
In one embodiment, the dynamic correction processing is performed on the seismic data according to the specified velocity to obtain the second seismic data, and the dynamic correction processing comprises: obtaining dynamic correction time difference data corresponding to detection points at different shot-geophone distances according to the specified speed; correcting the travel time received by the wave detection points at different shot-geophone distances and the dynamic correction time difference data to obtain second seismic data; wherein the travel time is the time required after the seismic wave is generated to the wave detection point.
In the present embodiment, the travel time refers to the reflected wave arrival time and also to the reception time of the detector.
In the present embodiment, the motion correction time difference obtained by the conventional horizontal motion correction is obtained according to the following formula:
wherein, the delta t is the dynamic correction time difference, x is the offset, V is the propagation velocity of the seismic source in the medium, namely, the corresponding primary wave velocity or the corresponding multiple wave velocity is expressed, t is0As the time of reception of the self-excited self-acceptance point, i.e. the time of reflection at zero offsetAnd t is the receiving time at the corresponding offset. And processing the seismic data dynamic correction according to the specified velocity and replacing the specified velocity with the V. In other cases, the same manner or principle is used for dynamic correction, and will not be repeated here. When the specified speed is less than the primary wave velocity, when being greater than the multiple wave velocity, primary wave delta t motion correction time difference can increase, multiple wave delta t motion correction time difference can reduce, and the primary wave is overcorrected, and the multiple is undercorrected. This is explained in detail below with reference to fig. 2 and 3. FIG. 2 shows model data containing two sets of primaries and multiples, each set of primaries being close to the multiples and not conducive to suppressing multiples. The data in fig. 2 is dynamically corrected according to the specified velocity, and the output result is shown in fig. 3, wherein the primary wave is over-corrected and the multiple wave is under-corrected. When the designated speed is the primary wave speed, the primary wave correction is normal, and the multiple waves are under-corrected; when the designated speed is the multiple wave speed, the primary wave is corrected, and the method principle is the same as that of dynamic correction processing of the intermediate speed, and the method is not repeated here.
In one embodiment, narrowing the offset in the second seismic data according to the specified rule, and/or increasing the time in the second seismic data according to the specified rule comprises: scaling down the offset in the second seismic data and/or scaling up the time in the second seismic data.
In this embodiment, the curvature may be enlarged by scaling down the offset in the second seismic data and/or scaling up the time in the second seismic data, for example, by multiplying the offset in the second seismic data by 0.3 or 0.5, or by multiplying the time by 2 or 3, or the curvature may be enlarged by scaling down the offset in the second seismic data and scaling up the time in the second seismic data simultaneously. The method does not enlarge the curvature pattern characteristic parameters too much, and avoids overlarge calculation amount and generation of spurious frequency.
In one embodiment, the third seismic data corresponds to at least a first feature that the curvature profile characteristic parameter of the primary wave and the curvature profile characteristic parameter of the multiple are not in the same positive or negative interval; after obtaining the third seismic data, the method further comprises: and according to the first characteristic, performing suppressed multiple wave processing on the third seismic data to obtain suppressed multiple wave-back third seismic data.
Referring to fig. 3, in the present embodiment, when the specified velocity is actively corrected by using the intermediate velocity between the primary and the multiple, the primary is overcorrected, the multiple is undercorrected, the primary curve is upward, and the multiple curve is downward. The primary curvature is negative and the multiple curvature is positive. Similarly, when the specified speed is the speed of the primary wave, the multiple is under-corrected, the curvature pattern characteristic parameter of the multiple is in a positive interval, and the curvature pattern characteristic parameter of the primary wave is not in the positive interval; and when the designated speed adopts the speed of the multiple waves, the primary wave is overcorrected, the curvature pattern characteristic parameter of the primary wave is in a negative interval, and the curvature pattern characteristic parameter of the multiple waves is not in the negative interval. Therefore, the curvature pattern characteristic parameter of the primary wave and the curvature pattern characteristic parameter of the multiple wave are not in the same positive number interval or negative number interval.
In this embodiment, after obtaining the third seismic data, the method further comprises: and according to the first characteristic, performing suppressed multiple wave processing on the third seismic data to obtain suppressed multiple wave-back third seismic data.
In this embodiment, the filtering process is performed on the separated multiples by using curvature pattern characteristic parameters of the primary wave and the multiples which are not in the same interval. In one embodiment, the multiples may be filtered in the Radon domain by a Radon transform.
In one scenario example, obtaining third seismic data suppressed for multiple wave-fronts may include the following steps.
Step S20: mapping the third seismic data to a specified coordinate system to obtain fourth seismic data; the specified coordinate system includes a curvature graph feature dimension and a time dimension. In a particular embodiment, a parabolic Radon transform is performed on the third seismic data according to the following equation.
m(τ，q)＝Σd(x，t＝τ+qx2)
Wherein m (τ, q) is data in a Radon domain (τ, q), d (x, t) is data in a geophone offset-time domain, which is the third seismic data in the first coordinate system, τ is intercept time, and q is a curvature parameter. The curvature of the same phase axis of the offset-time domain in the Radon domain is
Where Δ t ═ tmax-τ，tmaxThe time of the in-phase axis at the maximum offset is given. Specifically, referring to fig. 5, in fig. 5, Radon transformation is performed on the third seismic data obtained by performing preset processing on the second seismic data, as shown in the figure, an abscissa of the specified coordinate system represents curvature, and an ordinate represents time. The characteristic parameter of the primary wave curvature graph is negative, after Radon transformation, the energy clique of the primary wave is in a negative number interval, the characteristic parameter of the multiple curvature graph is positive, and after Radon transformation, the energy clique of the multiple is in a positive number interval, so that filtering processing of the multiple is facilitated.
Step S22: and filtering the fourth seismic data to obtain fourth seismic data after multiple wave suppression. Referring to fig. 5, in one embodiment, the primary wavefronts are in a negative interval, and the multiple-order wavefronts are in a positive interval, and the energy blobs in the positive interval are filtered to obtain a purer primary wavefronts.
Step S24: and performing inverse mapping processing on the fourth seismic data after the multiple wave pressing to obtain the third seismic data after the multiple wave pressing. Specifically, the fourth seismic data is subjected to inverse Radon transform according to the following formula.
d(x,t)＝∑m(q,τ＝t-qx2)
Wherein m (τ, q) is data in Radon domain (τ, q), d (x, t) is data in offset-time domain, i.e. the second data volume in the first coordinate system, τ is intercept time, and q is curvature parameter. The curvature of the same phase axis of the offset-time domain in the Radon domain is
Where Δ t ═ tmax-τ，tmaxThe time of the in-phase axis at the maximum offset is given.
In one embodiment, after obtaining the third seismic data suppressed for multiple wave-backs, further comprising: according to a second specified rule, the offset in the suppressed third seismic data after multiple times of wave processing is amplified, and/or according to a second specified rule, the time in the suppressed third seismic data after multiple times of wave processing is shortened, and suppressed second seismic data after multiple times of wave processing is obtained; wherein the second specified rule is an inverse transform corresponding to the specified rule. For example, when the preset processing mode is to reduce the offset of the first data volume to one third of the original offset, at this time, the offset of the second data volume after being compressed for multiple times is amplified by three times, and is restored to the offset. Similarly, if the preset processing mode is the amplification time, the specified rule is to reduce the corresponding time. Through the processing of the specified rule, the data in the second data body can be restored to the offset and the time under the actual condition.
In one embodiment, after obtaining the second seismic data after suppressing the multiple wave waves, the method further includes: and performing reverse motion correction processing on the second seismic data after being subjected to the multiple wave suppression to obtain the first seismic data after being subjected to the multiple wave suppression. The reflection correction processing corresponds to the dynamic correction processing, that is, the reflection time of different offset distances is restored to the reflection time corresponding to each of the different offset distances from the reflection time of zero offset distance according to the specified speed, so that the seismic data can be processed at a later stage.
A specific exemplary scenario of the present specification is specifically described below with reference to fig. 2 to 7. The seismic data processing method provided by the embodiments of the present specification may be implemented by software running in an electronic device. The seismic data processing method enables the primary waves and the multiples to be better distinguished, so that a better multiple filtering effect is obtained, and the follow-up operation is facilitated.
In the implementation scenario, first seismic data is acquired, where the first seismic data includes primary waves and multiple waves. Referring to FIG. 2, a schematic diagram of seismic data of two sets of primaries and multiples is obtained. Acquiring the first seismic data, wherein the first seismic data can be input through input equipment, and the input equipment can be a keyboard, a mouse, voice input equipment and the like; or through the input of an external storage device, wherein the external storage device can be a U disk, a mechanical hard disk and the like; or may be received via a network, such as the internet, a local area network; or by reading local data, etc.
In the implementation scene, the seismic data are dynamically corrected according to the specified speed, and second seismic data are obtained; wherein the designated velocity comprises a numerical value of the primary velocity, a numerical value of the multiple velocity, or a numerical value between a numerical value of the primary velocity and a numerical value of the multiple velocity; the second seismic data includes a plurality of dimensions including offset and time. The dynamic correction is to correct the arrival time (reception time) of reflected waves from the same interface and the same point on each track with different offset distances to the echo time (reception time) at the common center point. The conventional dynamic correction corrects the reflection time of different offset distances to the reflection time of zero offset distance, and the dynamic correction processing of the seismic data according to the specified velocity is to replace the specified velocity with the velocity in the conventional dynamic correction to perform dynamic correction. Referring to fig. 3, the seismic data in fig. 2 is dynamically corrected by determining the specified velocity, where the specified velocity is an average velocity of the primary velocity and the multi-wave velocity, the primary velocity is overcorrected after dynamic correction, the curvature is negative, and the multi-wave is undercorrected, the curvature is positive.
In the implementation scene, the second seismic data are subjected to preset processing to obtain third seismic data; the presetting comprises reducing the offset distance in the second seismic data according to a specified rule, and/or increasing the time in the second seismic data according to a specified rule. Referring to fig. 5, the data in fig. 3 is subjected to a presetting process, which is to reduce offset and/or increase time, and perform high resolution Radon transform. Specifically, the offset in the second seismic data is simultaneously multiplied by 0.3 or 0.5. And increasing the absolute value of the curvature of the primary wave and the multiple through the preset processing, and further separating the primary wave from the multiple. By reducing the offset of the corresponding point in the coordinate system of fig. 3, the curve is compressed to the origin of coordinates, the absolute values of the curvature pattern characteristic parameters of the primary wave and the curvature pattern characteristic parameters of the multiples are increased, and the primary wave and the multiples are further separated. Similarly, by increasing the time in the coordinate system of fig. 3, the absolute values of the curvature pattern characteristic parameter of the primary wave and the curvature pattern characteristic parameter of the multiple can also be increased, or two preset processing modes can be combined for use, so that the effect of increasing the absolute values of the curvature pattern characteristic parameter of the primary wave and the curvature pattern characteristic parameter of the multiple can be achieved. Comparing fig. 5 with fig. 4, the separation of the primary energy mass from the multiple energy mass is better. Referring to fig. 7, the multiples in the Radon domain of fig. 5 are filtered, then Radon inverse transformation is performed, the offset is amplified and/or the time is reduced according to a designated rule corresponding to the preset processing, the offset and/or the time is restored, then inverse motion correction is performed, and seismic data after being suppressed for multiple times are obtained. Comparing fig. 7 with fig. 6, the multiple-suppression effect is superior to that of fig. 6.
Next, the processing effect of the embodiment of the present specification on actual data will be described in detail with reference to fig. 8 to 14. Referring to fig. 8, fig. 8 shows a specific common reflection point gather (CRP common reflection point), but the present embodiment can also be applied to gathers such as CMP common center gather (CRP common reflection point). The CRP gather shown in fig. 8 was dynamically corrected to obtain the gather shown in fig. 9, and it can be seen that there is undercorrected multiples information. And performing preset processing on the second seismic data to obtain third seismic data. And performing suppressed multiple wave processing on the third seismic data to obtain suppressed multiple wave third seismic data. And processing the third seismic data after multiple wave suppression to obtain second seismic data after multiple wave suppression and obtain a representation diagram after multiple wave suppression shown in FIG. 10. Referring to FIG. 11, a representation of seismic data after multiple passes is obtained by performing inverse kinematics correction on the data of FIG. 10. Comparing fig. 11 with fig. 8, it can be seen that the multiples are well suppressed. Referring to fig. 12 and 13, fig. 12 is a velocity spectrum corresponding to that shown in fig. 8, fig. 13 is a velocity spectrum corresponding to that shown in fig. 11, in which the dashed line represents the pickup line for the velocity of the primary wave, the lower left of the pickup line represents the multiple wave energy, and the multiple wave energy of fig. 13 is significantly filtered out compared to that of the lower left of fig. 12. Referring to fig. 14 and 15, fig. 14 shows the result of directly performing prestack time migration on the data before multiple compression, i.e., the data in fig. 8, and fig. 15 shows the result of performing prestack time migration on the data after multiple compression, i.e., the data in fig. 11. For example, the two same-phase axes in the rectangular frame interfere to a certain degree before multiple suppression; after multiple compression, the two in-phase axes are well separated.
The embodiments of the present specification also provide a seismic data processing apparatus, as described in the following embodiments. Because the principle of solving the problems of a seismic data processing device is similar to that of a seismic data processing method, the implementation of the seismic data processing device can refer to the implementation of the seismic data processing method, and repeated parts are not repeated. As used hereinafter, the term "unit" or "module" may be a combination of software and/or hardware that implements a predetermined function. Although the means described in the embodiments below are preferably implemented in software, an implementation in hardware, or a combination of software and hardware is also possible and contemplated. The device may specifically include: the device comprises an acquisition unit, a first determination unit, a first processing unit and a second processing unit. This structure will be specifically explained below.
The seismic acquisition device comprises an acquisition unit, a processing unit and a processing unit, wherein the acquisition unit is used for acquiring first seismic data, and the first seismic data comprise primary waves and multiple waves.
In this embodiment, the seismic data includes a primary wave velocity and a multiple wave velocity. Wherein the seismic data may be obtained from data obtained from seismic surveys; the primary wave represents a wave that is reflected once between the lower interfaces when arriving at the receiving point from the seismic source, and the multiple wave represents a wave that is reflected or refracted many times between the underground interfaces when arriving at the receiving point from the seismic source.
The first processing unit is used for performing dynamic correction processing on the seismic data according to the specified speed to obtain second seismic data; wherein the designated velocity comprises a numerical value of the primary velocity, a numerical value of the multiple velocity, or a numerical value between a numerical value of the primary velocity and a numerical value of the multiple velocity; the second seismic data includes a plurality of dimensions including offset and time.
In this embodiment, the normal dynamic correction is a process of correcting the reflection time of different offsets to the reflection time of zero offset, and the dynamic correction processing of the seismic data according to the specified velocity is to replace the specified velocity with the velocity in the normal dynamic correction.
The second processing unit is used for carrying out preset processing on the second seismic data to obtain third seismic data; the presetting comprises reducing the offset distance in the second seismic data according to a specified rule, and/or increasing the time in the second seismic data according to a specified rule.
In one embodiment, after the second processing unit, the apparatus further comprises: and the third processing unit is used for obtaining third seismic data after the multiple wave waves are suppressed. The third seismic data at least accord with a first characteristic, and the first characteristic is that the curvature pattern characteristic parameter of the primary wave and the curvature pattern characteristic parameter of the multiple wave are not in the same positive number interval or negative number interval; after obtaining the third seismic data, the method further comprises: and according to the first characteristic, performing suppressed multiple wave processing on the third seismic data to obtain suppressed multiple wave-back third seismic data.
In one embodiment, the third processing unit further includes: and a fourth processing unit. The fourth processing unit amplifies the offset after suppressing the third seismic data after multiple wave cycles according to a second specified rule, and/or reduces the time after suppressing the third seismic data after multiple wave cycles according to a second specified rule, so as to obtain second seismic data after multiple wave cycles; wherein the second specified rule is an inverse transform corresponding to the specified rule.
In one embodiment, the fourth processing unit further includes: a fifth processing unit; and the fifth processing unit performs inverse motion correction processing on the second seismic data after being subjected to the multiple-time wave suppression to obtain the first seismic data after being subjected to the multiple-time wave suppression.
Please refer to fig. 16. There is also provided in an embodiment of the present specification an electronic device, including: an input device, a memory, a processor; the input device is used for acquiring first seismic data, wherein the first seismic data comprises primary waves and multiple waves; the processor is used for performing dynamic correction processing on the seismic data according to the specified speed to obtain second seismic data; wherein the designated velocity comprises a numerical value of the primary velocity, a numerical value of the multiple velocity, or a numerical value between a numerical value of the primary velocity and a numerical value of the multiple velocity; the second seismic data comprises a plurality of dimensions, the plurality of dimensions comprising offset and time; performing preset processing on the second seismic data to obtain third seismic data; the presetting comprises reducing the offset distance in the second seismic data according to a specified rule and/or increasing the time in the second seismic data according to a specified rule; the memory is used to access data including the input or acquired seismic data, intermediate data processed by the processor, and result data.
The input device is one of the primary means of information exchange between a user and a computer system. The input equipment comprises a keyboard, a mouse, a camera, a scanner, a light pen, a handwriting input plate, a voice input device and the like; the input device is used to input raw data and a program for processing the data into the computer. The input device can also acquire and receive data transmitted by other modules, units and devices.
The processor may be implemented in any suitable way. For example, the processor may take the form of, for example, a microprocessor or processor and a computer-readable medium that stores computer-readable program code (e.g., software or firmware) executable by the (micro) processor, logic gates, switches, an Application Specific Integrated Circuit (ASIC), a programmable logic controller, an embedded microcontroller, and so forth.
The memory is a memory device used for storing information in the information technology. The memory comprises a plurality of layers, and in a digital system, the memory can be used as long as binary data can be stored; in an integrated circuit, a circuit without a physical form and with a storage function is also called a memory, such as a RAM, a FIFO and the like; in the system, the storage device in physical form is also called a memory, such as a memory bank, a TF card and the like.
In this embodiment, the functions and effects specifically realized by the electronic device can be explained by comparing with other embodiments, and are not described herein again.
Also provided in embodiments of the present specification is a computer storage medium storing computer program instructions that, when executed, implement: acquiring first seismic data, wherein the first seismic data comprise primary waves and multiple waves; performing dynamic correction processing on the seismic data according to the specified speed to obtain second seismic data; wherein the designated velocity comprises a numerical value of the primary velocity, a numerical value of the multiple velocity, or a numerical value between a numerical value of the primary velocity and a numerical value of the multiple velocity; the second seismic data comprises a plurality of dimensions, the plurality of dimensions comprising offset and time; performing preset processing on the second seismic data to obtain third seismic data; the presetting comprises reducing the offset distance in the second seismic data according to a specified rule, and/or increasing the time in the second seismic data according to a specified rule.
In this embodiment, the Memory includes, but is not limited to, a Random Access Memory (RAM), a Read-Only Memory (ROM), a Cache (Cache), a Hard disk (Hard disk drive, HDD), or a Memory Card (Memory Card). The memory may be used to store computer program instructions. The network communication unit may be an interface for performing network connection communication, which is set in accordance with a standard prescribed by a communication protocol.
In this embodiment, the functions and effects specifically realized by the program instructions stored in the computer storage medium can be explained by comparing with other embodiments, and are not described herein again.
Another seismic data processing method is also provided herein, the method comprising: acquiring first seismic data, wherein the first seismic data comprise primary waves and multiple waves; determining a designated speed according to the wave speed of the primary wave and the wave speed of the multiple wave; the specified speed is between the wave speed of the primary wave and the wave speed of the multiple wave; and performing dynamic correction processing on the seismic data according to the specified speed to obtain second seismic data.
In one embodiment, the second seismic data at least conform to a first characteristic that the curvature pattern characteristic parameter of the primary wave and the curvature pattern characteristic parameter of the multiple are not in the same positive or negative interval; after obtaining the second seismic data, the method further comprises: and according to the first characteristic, carrying out multiple-wave suppressing processing on the second seismic data to obtain the second seismic data after multiple-wave suppressing.
In one embodiment, after obtaining the second seismic data after suppressing the multiple wave waves, the method further includes: and performing reverse motion correction processing on the second seismic data after being subjected to the multiple wave suppression to obtain the first seismic data after being subjected to the multiple wave suppression.
An embodiment of the present specification will be specifically described below with reference to fig. 2, 3, 4, and 6. Referring to FIG. 2, a schematic diagram of seismic data of two sets of primaries and multiples is obtained. Referring to fig. 3, the seismic data in fig. 2 is dynamically corrected by determining the specified velocity, the curvature of the primary wave is negative through correction, and the curvature of the multiple wave is positive through correction. Referring to fig. 4, fig. 4 shows the result of performing high resolution Radon transform on the data of fig. 3, where multiples are separated from primaries as described. Referring to fig. 6, the multiples in the Radon domain of fig. 4 are filtered, then are subjected to Radon inverse transformation, and are subjected to inverse dynamic correction, so that seismic data after being suppressed for multiple waves is obtained, and it can be seen that the multiples are significantly suppressed.
Referring to the first seismic data processing method provided by the specification, the other seismic data processing method provided by the specification does not need to undergo preset processing and corresponding designated rules, and the method is simpler, but the suppression effect of the multiples is not as good as that of seismic data obtained by suppressing multiple waves obtained by the preset processing, and the multiples with near offset distances still remain.
The most essential characteristic of the seismic data processing method provided by the embodiment of the specification is that in one embodiment, the primary wave and the multiple are separated by performing dynamic correction by using the wave velocity of the primary wave and the wave velocity intermediate velocity of the multiple. In another embodiment, the degree of separation of primary and multiples is increased by reducing the offset parameter and/or increasing the time parameter. In a preferred embodiment, the velocity of the primary wave and the velocity intermediate velocity of the multiple are simultaneously used for dynamic correction, and the primary wave and the multiple are separated by reducing the offset parameter and/or increasing the time parameter, so that an improved method is provided for suppressing the multiple in the seismic data.
The present specification also provides a seismic data processing apparatus, the apparatus comprising: the system comprises an acquisition unit, a processing unit and a processing unit, wherein the acquisition unit is used for acquiring first seismic data, and the first seismic data comprises primary waves and multiple waves; a first determining unit, configured to determine a specified speed according to a wave speed of the primary wave and a wave speed of the multiple, where the specified speed is between the wave speed of the primary wave and the wave speed of the multiple; and the first determining unit is used for performing dynamic correction processing on the seismic data according to the specified speed to obtain second seismic data.
Although the present application refers to a seismic data processing method, apparatus, electronic device or computer storage medium, the present application is not limited to the cases described in the industry standards or examples, and the like, and some industry standards or implementations described using custom modes or examples may also achieve the same, equivalent or similar, or expected implementation effects after modifications and variations of the above-described examples. Embodiments employing such modified or transformed data acquisition, processing, output, determination, etc., may still fall within the scope of alternative embodiments of the present application.
Although the present application provides method steps as described in an embodiment or flowchart, more or fewer steps may be included based on conventional or non-inventive means. The order of steps recited in the embodiments is merely one manner of performing the steps in a multitude of orders and does not represent the only order of execution. When an apparatus or client product in practice executes, it may execute sequentially or in parallel (e.g., in a parallel processor or multithreaded processing environment, or even in a distributed data processing environment) according to the embodiments or methods shown in the figures. The terms "comprises," "comprising," or any other variation thereof, are intended to cover a non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements does not include only those elements but may include other elements not expressly listed or inherent to such process, method, article, or apparatus. Without further limitation, the presence of additional identical or equivalent elements in a process, method, article, or apparatus that comprises the recited elements is not excluded.
The devices or modules and the like explained in the above embodiments may be specifically implemented by a computer chip or an entity, or implemented by a product with certain functions. For convenience of description, the above devices are described as being divided into various modules by functions, and are described separately. Of course, in implementing the present application, the functions of each module may be implemented in one or more pieces of software and/or hardware, or a module that implements the same function may be implemented by a combination of a plurality of sub-modules, and the like. The above-described apparatus embodiments are merely illustrative, and for example, the division of the modules is merely a logical division, and other divisions may be realized in practice, for example, a plurality of modules or components may be combined or integrated into another system, or some features may be omitted, or not executed.
Those skilled in the art will also appreciate that, in addition to implementing the controller as pure computer readable program code, the same functionality can be implemented by logically programming method steps such that the controller is in the form of logic gates, switches, application specific integrated circuits, programmable logic controllers, embedded microcontrollers and the like. Such a controller may therefore be considered as a hardware component, and the means included therein for performing the various functions may also be considered as a structure within the hardware component. Or even means for performing the functions may be regarded as being both a software module for performing the method and a structure within a hardware component.
The application may be described in the general context of computer-executable instructions, such as program modules, being executed by a computer. Generally, program modules include routines, programs, objects, components, data structures, classes, etc. that perform particular tasks or implement particular abstract data types. The application may also be practiced in distributed computing environments where tasks are performed by remote processing devices that are linked through a communications network. In a distributed computing environment, program modules may be located in both local and remote computer storage media including memory storage devices.
From the above description of the embodiments, it is clear to those skilled in the art that the present application can be implemented by software plus necessary general hardware platform. Based on such understanding, the technical solutions of the present application may be embodied in the form of a software product, which may be stored in a storage medium, such as a ROM/RAM, a magnetic disk, an optical disk, or the like, and includes several instructions for enabling a computer device (which may be a personal computer, a mobile terminal, a server, or a network device) to execute the method according to the embodiments or some parts of the embodiments of the present application.
The embodiments in the present specification are described in a progressive manner, and the same or similar parts among the embodiments are referred to each other, and each embodiment focuses on the differences from the other embodiments. The application is operational with numerous general purpose or special purpose computing system environments or configurations. For example: personal computers, server computers, hand-held or portable devices, tablet-type devices, multiprocessor systems, microprocessor-based systems, set top boxes, programmable electronic devices, network PCs, minicomputers, mainframe computers, distributed computing environments that include any of the above systems or devices, and the like.
While the present application has been described with examples, those of ordinary skill in the art will appreciate that there are numerous variations and permutations of the present application without departing from the spirit of the application, and it is intended that the appended claims encompass such variations and permutations without departing from the present application.
Claims (10)
1. A method of seismic data processing, the method comprising:
acquiring first seismic data, wherein the first seismic data comprise primary waves and multiple waves;
performing dynamic correction processing on the seismic data according to the specified speed to obtain second seismic data; wherein the designated velocity comprises a numerical value of the primary velocity, a numerical value of the multiple velocity, or a numerical value between a numerical value of the primary velocity and a numerical value of the multiple velocity; the second seismic data comprises a plurality of dimensions, the plurality of dimensions comprising offset and time;
performing preset processing on the second seismic data to obtain third seismic data; the presetting comprises reducing the offset distance in the second seismic data according to a specified rule, and/or increasing the time in the second seismic data according to a specified rule.
2. The method of claim 1, wherein the seismic data dynamic correction processing based on the specified velocity to obtain the second seismic data comprises:
obtaining dynamic correction time difference data corresponding to detection points at different shot-geophone distances according to the specified speed;
correcting the travel time received by the wave detection points at different shot-geophone distances and the dynamic correction time difference data to obtain second seismic data; wherein the travel time is the time required after the seismic wave is generated to the wave detection point.
3. The method of claim 1, wherein narrowing the offset in the second seismic data according to the specified rule, and/or wherein increasing the time in the second seismic data according to the specified rule comprises: scaling down the offset in the second seismic data and/or scaling up the time in the second seismic data.
4. The method of claim 1, wherein the third seismic data corresponds to at least a first characteristic, the first characteristic being that the curvature pattern characteristic of the primary wave and the curvature pattern characteristic of the multiples are not in the same positive or negative interval; after obtaining the third seismic data, the method further comprises: and according to the first characteristic, performing suppressed multiple wave processing on the third seismic data to obtain suppressed multiple wave-back third seismic data.
5. The method of claim 4, wherein performing a wavelet squashing process on the third seismic data to obtain the third seismic data after the wavelet squashing comprises:
mapping the third seismic data to a specified coordinate system to obtain fourth seismic data; the specified coordinate system comprises a curvature graph characteristic dimension and a time dimension;
filtering the fourth seismic data to obtain fourth seismic data after multiple wave suppression;
and performing inverse mapping processing on the fourth seismic data after the multiple wave pressing to obtain the third seismic data after the multiple wave pressing.
6. The method of claim 5, further comprising, after obtaining the third seismic data suppressed for multiple wave-backs:
according to a second specified rule, the offset in the suppressed third seismic data after multiple times of wave processing is amplified, and/or according to a second specified rule, the time in the suppressed third seismic data after multiple times of wave processing is shortened, and suppressed second seismic data after multiple times of wave processing is obtained; wherein the second specified rule is an inverse transform corresponding to the specified rule.
7. The method of claim 6, further comprising, after obtaining the suppressed multi-wave second seismic data:
and performing reverse motion correction processing on the second seismic data after being subjected to the multiple wave suppression to obtain the first seismic data after being subjected to the multiple wave suppression.
8. A seismic data processing apparatus, characterized in that the apparatus comprises:
the system comprises an acquisition unit, a processing unit and a processing unit, wherein the acquisition unit is used for acquiring first seismic data, and the first seismic data comprises primary waves and multiple waves;
the first processing unit is used for performing dynamic correction processing on the seismic data according to the specified speed to obtain second seismic data; wherein the designated velocity comprises a numerical value of the primary velocity, a numerical value of the multiple velocity, or a numerical value between a numerical value of the primary velocity and a numerical value of the multiple velocity; the second seismic data comprises a plurality of dimensions, the plurality of dimensions comprising offset and time;
the second processing unit is used for carrying out preset processing on the second seismic data to obtain third seismic data; the presetting comprises reducing the offset distance in the second seismic data according to a specified rule, and/or increasing the time in the second seismic data according to a specified rule.
9. An electronic device, comprising: an input device, a memory, a processor;
the input device is used for acquiring first seismic data, wherein the first seismic data comprises primary waves and multiple waves;
the processor is used for performing dynamic correction processing on the seismic data according to the specified speed to obtain second seismic data; wherein the designated velocity comprises a numerical value of the primary velocity, a numerical value of the multiple velocity, or a numerical value between a numerical value of the primary velocity and a numerical value of the multiple velocity; the second seismic data comprises a plurality of dimensions, the plurality of dimensions comprising offset and time; performing preset processing on the second seismic data to obtain third seismic data; the presetting comprises reducing the offset distance in the second seismic data according to a specified rule and/or increasing the time in the second seismic data according to a specified rule;
the memory is used to access data including the input or acquired seismic data, intermediate data processed by the processor, and result data.
10. A computer storage medium having computer program instructions stored thereon that when executed implement:
acquiring first seismic data, wherein the first seismic data comprise primary waves and multiple waves;
performing dynamic correction processing on the seismic data according to the specified speed to obtain second seismic data; wherein the designated velocity comprises a numerical value of the primary velocity, a numerical value of the multiple velocity, or a numerical value between a numerical value of the primary velocity and a numerical value of the multiple velocity; the second seismic data comprises a plurality of dimensions, the plurality of dimensions comprising offset and time;
performing preset processing on the second seismic data to obtain third seismic data; the presetting comprises reducing the offset distance in the second seismic data according to a specified rule, and/or increasing the time in the second seismic data according to a specified rule.
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