CN113703039B - Reverse time migration imaging method and device - Google Patents
Reverse time migration imaging method and device Download PDFInfo
- Publication number
- CN113703039B CN113703039B CN202010440148.2A CN202010440148A CN113703039B CN 113703039 B CN113703039 B CN 113703039B CN 202010440148 A CN202010440148 A CN 202010440148A CN 113703039 B CN113703039 B CN 113703039B
- Authority
- CN
- China
- Prior art keywords
- imaging
- seismic data
- reverse time
- wave field
- time
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Active
Links
- 238000003384 imaging method Methods 0.000 title claims abstract description 166
- 238000013508 migration Methods 0.000 title claims abstract description 76
- 230000005012 migration Effects 0.000 title claims abstract description 76
- 238000000034 method Methods 0.000 claims abstract description 26
- 230000006870 function Effects 0.000 claims description 60
- 238000010276 construction Methods 0.000 claims description 49
- 238000000354 decomposition reaction Methods 0.000 claims description 33
- 238000012545 processing Methods 0.000 claims description 20
- 238000004590 computer program Methods 0.000 claims description 13
- 238000012937 correction Methods 0.000 claims description 11
- 230000003068 static effect Effects 0.000 claims description 11
- 238000000605 extraction Methods 0.000 claims description 7
- 238000007781 pre-processing Methods 0.000 claims description 3
- 238000010586 diagram Methods 0.000 description 11
- 238000004321 preservation Methods 0.000 description 11
- 238000004422 calculation algorithm Methods 0.000 description 5
- 238000013213 extrapolation Methods 0.000 description 5
- 230000008569 process Effects 0.000 description 5
- 238000011161 development Methods 0.000 description 4
- 238000005516 engineering process Methods 0.000 description 4
- 230000009977 dual effect Effects 0.000 description 3
- 238000001914 filtration Methods 0.000 description 3
- 230000001629 suppression Effects 0.000 description 3
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- 238000003672 processing method Methods 0.000 description 2
- 238000013459 approach Methods 0.000 description 1
- 238000004364 calculation method Methods 0.000 description 1
- 230000002596 correlated effect Effects 0.000 description 1
- 239000007789 gas Substances 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
- 230000003287 optical effect Effects 0.000 description 1
- 239000003209 petroleum derivative Substances 0.000 description 1
Classifications
-
- 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. for interpretation or for event detection
- G01V1/282—Application of seismic models, synthetic seismograms
-
- 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. for interpretation or for event detection
- G01V1/30—Analysis
- G01V1/303—Analysis for determining velocity profiles or travel times
-
- 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. for interpretation or for event detection
- G01V1/34—Displaying seismic recordings or visualisation of seismic data or attributes
- G01V1/345—Visualisation of seismic data or attributes, e.g. in 3D cubes
Landscapes
- Engineering & Computer Science (AREA)
- Remote Sensing (AREA)
- Physics & Mathematics (AREA)
- Life Sciences & Earth Sciences (AREA)
- Acoustics & Sound (AREA)
- Environmental & Geological Engineering (AREA)
- Geology (AREA)
- General Life Sciences & Earth Sciences (AREA)
- General Physics & Mathematics (AREA)
- Geophysics (AREA)
- Geophysics And Detection Of Objects (AREA)
Abstract
The application discloses a reverse time migration imaging method and device, wherein the method comprises the following steps: acquiring seismic data acquired in the field, and performing pre-stack pretreatment on the seismic data; establishing a velocity model by utilizing the seismic data; extracting an original shot set from the pre-stack pre-processed seismic data according to the acquisition coordinates of the seismic data; developing reverse time migration by using the speed model and the original gun set; the reverse time shift imaging result is constructed using reverse time shift imaging conditions that are constrained together by time and local build slope. The method can ensure that the effective signals of the seismic data are not damaged, so that a section with better amplitude-preserving property is obtained, and an amplitude-preserving imaging result aiming at a lithology target body can be obtained.
Description
Technical Field
The application relates to the technical field of geophysical prospecting of petroleum and natural gas, in particular to a reverse time migration imaging method and device.
Background
This section is intended to provide a background or context to the embodiments of the application that are recited in the claims. The description herein is not admitted to be prior art by inclusion in this section.
In recent years, as oil and gas exploration targets become more complex, conventional seismic imaging methods have failed to achieve accurate imaging of these complex exploration targets, and thus, people have increasingly turned their gaze toward higher precision migration algorithms based on wave equation. Wave equation migration algorithm based on single-pass wave has higher precision than traditional wave-based depth migration algorithm based on rays, it utilizes paraxial approximation theory of wave equation to realize extrapolation of wave field, and can realize good imaging under specific angle, but single-pass wave equation migration algorithm can not obtain good imaging when stratum approaches even exceeds 90 degrees. The prestack reverse time depth migration algorithm based on the double-pass wave breaks through the limit of stratum dip angles, and can well realize more accurate imaging on complex earth surfaces and complex underground geological structures.
The reverse time migration imaging method has very high imaging precision, but the huge calculation amount, memory amount and I/O overhead make the method not realize industrialization quickly. With the continuous development of computer hardware technology in recent years, particularly development of graphics processor (Graphics Processing Unit, GPU) technology breaks through the bottleneck of limiting development of reverse time migration technology, so that the reverse time migration imaging method gradually realizes industrialized development.
The implementation of reverse time shifting generally has two important steps: firstly, extrapolation of wave fields of a seismic source and a receiving point is realized in a time domain; and secondly, constructing a final imaging result by utilizing reasonable imaging conditions. Conventional reverse time offset imaging methods typically employ zero-delay based cross-correlation imaging conditions to construct the imaging result, as shown in equation (1) below:
but zero-delay cross-correlation imaging conditions typically produce a significant amount of low frequency noise. Because the imaging condition based on zero-delay cross-correlation is a single judgment standard based on the wave propagation time, all the positions where the sum of the wave propagation time of the forward extrapolated wave field of the seismic source and the sum of the wave propagation time of the reverse time extrapolated wave field of the receiving point are equal can be imaged. The conditions that the wave source forward extrapolated wave field and the receiving point backward extrapolated wave field are equal in sum of the wave field travel time are met along the whole ray path of wave propagation, and imaging can be generated after the cross-correlation imaging conditions are applied. Since the conventional inter-related imaging conditions are only based on time as the only criterion for judging imaging, if the forward extrapolated wave field and the backward extrapolated wave field in any direction with equal propagation time sum meet, there will be imaging values; while the correlated imaging conditions are such that after cross-correlating the imaging values in image space according to time values, those imaging positions having the same sum of wave field travel times will be coherently emphasized and the other positions will be coherently cancelled out, so that imaging points can be obtained which are independent of the angle of the wave field and thus produce noise.
The main drawback of conventional cross-correlation imaging conditions is that they ignore the spatial coherence of the local structure of the extrapolated seismic wavefield, but instead rely solely on the extrapolated time of the wavefield for imaging, resulting in imaging at the same time between unrelated imaging points, thus creating low frequency noise. The low-frequency noise can be eliminated in the wave field propagation process, can be eliminated by adopting a filtering method after imaging, and can also be eliminated when imaging conditions are applied, however, no matter in which link the low-frequency noise is eliminated, effective signals are damaged more or less, so that the amplitude preservation of the seismic data is damaged.
Disclosure of Invention
The embodiment of the application provides a reverse time migration imaging method, which is used for eliminating low-frequency noise and simultaneously ensuring that effective signals of seismic data are not damaged, so that a section with better amplitude preservation performance is obtained, and an amplitude preservation imaging result aiming at a lithology target body can be obtained, and the method comprises the following steps:
acquiring seismic data acquired in the field, and performing pre-stack pretreatment on the seismic data; establishing a velocity model by utilizing the seismic data; extracting an original shot set from the pre-stack pre-processed seismic data according to the acquisition coordinates of the seismic data; developing reverse time migration by using the speed model and the original gun set; the reverse time shift imaging result is constructed using reverse time shift imaging conditions that are constrained together by time and local build slope.
The embodiment of the application also provides a reverse time migration imaging device, which is used for eliminating low-frequency noise and simultaneously ensuring that the effective signal of the seismic data is not damaged, so that a section with better amplitude preservation performance is obtained, and an amplitude preservation imaging result aiming at a lithology target body can be obtained, and the device comprises:
the acquisition module is used for acquiring the field acquired seismic data and carrying out pre-stack pretreatment on the seismic data; the model construction module is used for constructing a speed model by utilizing the seismic data acquired by the acquisition module; the shot set extraction module is used for extracting an original shot set from the pre-stack preprocessed seismic data according to the acquisition coordinates of the seismic data acquired by the acquisition module; the reverse time migration imaging module is used for carrying out reverse time migration by utilizing the speed model constructed by the model construction module and the original shot set extracted by the shot set extraction module; the reverse time offset imaging module is further configured to construct a reverse time offset imaging result using reverse time offset imaging conditions that are constrained together by time and local build slope.
In the embodiment of the application, the traditional reverse time migration imaging conditions are improved, the local construction slope attribute is increased except the extrapolation time, the reverse time migration imaging conditions are constructed by utilizing the time and local construction slope dual attribute constraint, the imaging result is constructed by utilizing the improved reverse time migration imaging conditions, useless imaging which occurs at the same time can be effectively distinguished, and the imaging points which are particularly required to construct the imaging result are effectively distinguished, so that the effective suppression of low-frequency noise is realized in the process of applying the reverse time migration imaging conditions, meanwhile, the effective signal of the seismic data is not damaged, the profile with better amplitude preservation is obtained, and the amplitude preservation imaging result aiming at the lithology object can be obtained.
Drawings
In order to more clearly illustrate the embodiments of the application or the technical solutions in the prior art, the drawings that are required in the embodiments or the description of the prior art will be briefly described, it being obvious that the drawings in the following description are only some embodiments of the application, and that other drawings may be obtained according to these drawings without inventive effort for a person skilled in the art. In the drawings:
FIG. 1 is a flow chart of a reverse time migration imaging method according to an embodiment of the present application;
FIG. 2 is a schematic diagram of a monoclinic depth-velocity model according to an embodiment of the application;
FIG. 3 is a schematic diagram of a reverse time migration imaging result obtained after second-order Laplacian filtering on the basis of a model data imaging result obtained by using a conventional cross-correlation imaging condition;
FIG. 4 is a schematic diagram of a reverse time migration imaging result obtained by using the reverse time migration imaging method provided in the embodiment of the present application;
FIG. 5 is wave field information for the vertical line labeled position in FIG. 3;
FIG. 6 is wave field information for the vertical line labeled position in FIG. 4;
fig. 7 is a schematic diagram of a reverse time offset imaging device according to an embodiment of the application.
Detailed Description
For the purpose of making the objects, technical solutions and advantages of the embodiments of the present application more apparent, the embodiments of the present application will be described in further detail with reference to the accompanying drawings. The exemplary embodiments of the present application and their descriptions herein are for the purpose of explaining the present application, but are not to be construed as limiting the application.
The embodiment of the application provides a reverse time migration imaging method, as shown in fig. 1, which comprises steps 101 to 105:
and 101, acquiring field acquired seismic data, and performing pre-stack pretreatment on the seismic data.
The pre-stack preprocessing comprises static correction processing, pre-stack denoising processing and frequency boosting processing, and in one implementation mode of the embodiment of the application, the static correction processing can be carried out on the seismic data firstly so as to eliminate the near-surface influence; performing fidelity pre-stack denoising treatment on the seismic data subjected to static correction treatment; and then carrying out frequency-boosting treatment on the seismic data subjected to pre-stack denoising treatment so as to improve the resolution of the seismic data.
The three processing methods of the static correction processing, the pre-stack denoising processing and the frequency-raising processing may be executed in any order, for example, the static correction processing may be executed first, the pre-stack denoising processing may be executed, the frequency-raising processing may be executed last, the pre-stack denoising processing may be executed first, the frequency-raising processing may be executed last, and the execution order of the three processing methods is not limited herein.
Step 102, establishing a velocity model by utilizing the seismic data.
The speed model can be built by adopting a conventional Kirchhoff integral method prestack depth migration method, and a mature technology at present introduces how to build the speed model, and the method is not described in detail herein.
Illustratively, the velocity model is constructed as shown in FIG. 2.
And 103, extracting an original shot set from the pre-stack preprocessed seismic data according to the acquisition coordinates of the seismic data.
The acquisition coordinates of the seismic data are the actual field coordinates of the seismic data.
The original shot set can be extracted by a method provided in the prior art, and details are not described here.
And 104, performing reverse time migration by using the speed model and the original gun set.
Step 105, constructing a reverse time migration imaging result by using a reverse time migration imaging condition, wherein the reverse time migration imaging condition is constrained by the time and the local construction slope.
The inventors found in the study that if imaging results were constructed using both of the time and local construction slope as reverse time offset imaging conditions at the same time, useless imaging occurring at the same time would be effectively distinguished, and based on the study found above, reverse time offset imaging conditions constrained by both of the time and local construction slope attributes together were constructed.
Specifically, the reverse time shift imaging condition is obtained by the following method: respectively carrying out local oblique superposition on the seismic source and the receiving point wave field under four-dimensional coordinates so as to decompose local construction slope and time of the seismic source function and the receiving point wave field function at each imaging point and obtain a seismic source function decomposition result and a receiving point wave field function decomposition result; and constructing an inverse time migration imaging condition constrained by the time and local construction slopes together by using the source function decomposition result and the receiving point wave field function decomposition result.
The local construction slope and time of the decomposition source function at each imaging point are obtained, and the obtained source function decomposition result is as follows:
S(t,X)＝∫W S (p,t,X)dp (2)
decomposing the local construction slope and time of the receiving point wave field function at each imaging point to obtain a receiving point wave field function decomposition result as follows:
R(t,X)＝∫W R (p,t,X)dp (3)
wherein t is a time coordinate representing a vertical depth; x is a transverse coordinate; s (t, X) represents a seismic source; r (t, X) represents a received-point wavefield; w (W) S Representing the source function decomposed according to the local construction slope; w (W) R Representing a received point wave field function decomposed according to a local construction slope; p represents the local build slope at the imaging point.
The inverse time migration imaging condition which is constructed by utilizing the source function decomposition result and the receiving point wave field function decomposition result and is constrained by the time and the local construction slope is as follows:
I(X)＝∫∫W s (p,t,X)W R (p,t,X)dpdt (4)
wherein I (X) represents a reverse time shift imaging result.
The inverse time-shifted imaging condition described by equation (4) above is achieved by decomposing the extrapolated wavefield into partial quantities using the coherence of time and space at each imaging point. The extrapolated wavefield may be decomposed into local components by a number of methods, such as curvelet or seixlet, and in the embodiment of the application, the source and receiver wavefields are decomposed by local dip-stack methods.
In order to more clearly see the difference between the reverse time offset imaging condition and the traditional cross-correlation imaging condition provided by the embodiment of the application, the equation (2) and the equation (3) are respectively brought into the traditional cross-correlation imaging condition equation (1), so that the following results are obtained:
I(X)＝∫[∫W s (p,t,X)dp][∫W R (p,t,X)dp]dt (5)
the difference between the reverse time offset imaging condition and the conventional cross-correlation imaging condition of the embodiment of the present application can be seen by comparing the above equations (4) and (5): in the inverse time-shifted imaging condition described by equation (4), the wavefield of each imaging point takes into account the local construction slope parameter p of the respective wavefield when performing cross-correlation, in which case the wave propagation in different directions is distinct; whereas in the conventional cross-correlation imaging condition described in equation (5), the propagation of waves in different directions is not fully considered, but only the overlapping portions of the wave field are imaged, and the waves in all directions overlap in one data volume, which is a main source of low-frequency noise.
And constructing a reverse time migration imaging result by using a traditional cross-correlation reverse time migration imaging condition, and then eliminating low-frequency noise by using Laplace filtering to obtain the reverse time migration imaging result shown in fig. 3, wherein wave field information of the position marked by a vertical line in the middle of fig. 3 is shown in fig. 5.
The reverse time migration imaging condition provided by the embodiment of the application is utilized to construct a reverse time migration imaging result, and imaging is directly carried out to obtain the reverse time migration imaging result shown in fig. 4, and the wave field information of the position marked by a vertical line in the middle of fig. 4 is shown in fig. 6.
Comparing fig. 2 and fig. 4, it can clearly see the difference between the reverse time migration imaging result obtained by applying the reverse time migration imaging condition provided by the present application and the reverse time migration imaging result obtained by applying the conventional cross-correlation condition, and it can be seen from these comparison diagrams that the imaging result obtained by using the reverse time migration imaging condition in the embodiment of the present application is significantly better than the imaging result obtained by using the conventional cross-correlation imaging condition, and has better fidelity, and in particular, has stronger identification capability for the structure above the strong reflection interface.
In the embodiment of the application, the traditional reverse time migration imaging conditions are improved, the local construction slope attribute is increased except the extrapolation time, the reverse time migration imaging conditions are constructed by utilizing the time and local construction slope dual attribute constraint, the imaging result is constructed by utilizing the improved reverse time migration imaging conditions, useless imaging which occurs at the same time can be effectively distinguished, and the imaging points which are particularly required to construct the imaging result are effectively distinguished, so that the effective suppression of low-frequency noise is realized in the process of applying the reverse time migration imaging conditions, meanwhile, the effective signal of the seismic data is not damaged, the profile with better amplitude preservation is obtained, and the amplitude preservation imaging result aiming at the lithology object can be obtained.
The embodiment of the application also provides a reverse time migration imaging device, as shown in fig. 7, the device 700 comprises an acquisition module 701, a model construction module 702, a shot set extraction module 703 and a reverse time migration imaging module 704.
The acquiring module 701 is configured to acquire seismic data acquired in the field, and perform pre-stack preprocessing on the seismic data.
The model building module 702 is configured to build a velocity model using the seismic data acquired by the acquisition module 701.
The shot gather extraction module 703 is configured to extract an original shot gather from the pre-stack pre-processed seismic data according to the acquisition coordinates of the seismic data acquired by the acquisition module 701.
The reverse time migration imaging module 704 is configured to perform reverse time migration by using the velocity model constructed by the model construction module 702 and the original shot set extracted by the shot set extraction module 703.
The reverse time shift imaging module 704 is further configured to construct a reverse time shift imaging result using a reverse time shift imaging condition, the reverse time shift imaging condition being constrained by both time and local construction slope.
In one implementation of the embodiment of the present application, the obtaining module 701 is configured to:
carrying out static correction processing on the seismic data;
performing prestack denoising treatment on the seismic data subjected to static correction treatment;
and carrying out frequency-raising treatment on the seismic data subjected to prestack denoising treatment.
In one implementation of an embodiment of the present application, the reverse time offset imaging module 704 is configured to:
respectively carrying out local oblique superposition on the seismic source and the receiving point wave field under four-dimensional coordinates so as to decompose local construction slope and time of the seismic source function and the receiving point wave field function at each imaging point and obtain a seismic source function decomposition result and a receiving point wave field function decomposition result;
and constructing an inverse time migration imaging condition constrained by the time and local construction slopes together by using the source function decomposition result and the receiving point wave field function decomposition result.
In one implementation of the embodiment of the present application, the inverse time offset imaging module 704 decomposes the local construction slope and time of the source function at each imaging point to obtain the source function decomposition result as follows: s (t, X) = ≡w S (p, t, X) dp; decomposing the local construction slope and time of the receiving point wave field function at each imaging point to obtain a receiving point wave field function decomposition result as follows: r (t, X) = ≡w R (p, t, X) dp; wherein t is a time coordinate representing a vertical depth; x is a transverse coordinate; s (t, X) represents a seismic source; r (t, X) represents a received-point wavefield; w (W) S Representing the source function decomposed according to the local construction slope; w (W) R Representing a received point wave field function decomposed according to a local construction slope; p represents the local build slope at the imaging point.
In one implementation of an embodiment of the present application, the inverse time migration imaging module 704 constructs inverse time migration imaging conditions constrained by both time and local construction slopes using the source function decomposition results and the receive point wavefield function decomposition results as: i (X) = ≡≡w s (p,t,X)W R (p, t, X) dpdt; wherein I (X) represents a reverse time shift imaging result.
In the embodiment of the application, the traditional reverse time migration imaging conditions are improved, the local construction slope attribute is increased except the extrapolation time, the reverse time migration imaging conditions are constructed by utilizing the time and local construction slope dual attribute constraint, the imaging result is constructed by utilizing the improved reverse time migration imaging conditions, useless imaging which occurs at the same time can be effectively distinguished, and the imaging points which are particularly required to construct the imaging result are effectively distinguished, so that the effective suppression of low-frequency noise is realized in the process of applying the reverse time migration imaging conditions, meanwhile, the effective signal of the seismic data is not damaged, the profile with better amplitude preservation is obtained, and the amplitude preservation imaging result aiming at the lithology object can be obtained.
The embodiment of the application also provides a computer device, which comprises a memory, a processor and a computer program stored on the memory and capable of running on the processor, wherein the processor implements any one of the methods from step 101 to step 105 and various implementations thereof when executing the computer program.
The embodiments of the present application also provide a computer-readable storage medium storing a computer program for executing any one of the methods described in steps 101 to 105 and their various implementations.
It will be appreciated by those skilled in the art that embodiments of the present application may be provided as a method, system, or computer program product. Accordingly, the present application may take the form of an entirely hardware embodiment, an entirely software embodiment or an embodiment combining software and hardware aspects. Furthermore, the present application may take the form of a computer program product embodied on one or more computer-usable storage media (including, but not limited to, disk storage, CD-ROM, optical storage, and the like) having computer-usable program code embodied therein.
The present application is described with reference to flowchart illustrations and/or block diagrams of methods, apparatus (systems) and computer program products according to embodiments of the application. It will be understood that each flow and/or block of the flowchart illustrations and/or block diagrams, and combinations of flows and/or blocks in the flowchart illustrations and/or block diagrams, can be implemented by computer program instructions. These computer program instructions may be provided to a processor of a general purpose computer, special purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, create means for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be stored in a computer-readable memory that can direct a computer or other programmable data processing apparatus to function in a particular manner, such that the instructions stored in the computer-readable memory produce an article of manufacture including instruction means which implement the function specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be loaded onto a computer or other programmable data processing apparatus to cause a series of operational steps to be performed on the computer or other programmable apparatus to produce a computer implemented process such that the instructions which execute on the computer or other programmable apparatus provide steps for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
The foregoing description of the embodiments has been provided for the purpose of illustrating the general principles of the application, and is not meant to limit the scope of the application, but to limit the application to the particular embodiments, and any modifications, equivalents, improvements, etc. that fall within the spirit and principles of the application are intended to be included within the scope of the application.
Claims (6)
1. A reverse time offset imaging method, the method comprising:
acquiring seismic data acquired in the field, and performing pre-stack pretreatment on the seismic data;
establishing a velocity model by utilizing the seismic data;
extracting an original shot set from the pre-stack pre-processed seismic data according to the acquisition coordinates of the seismic data;
developing reverse time migration by using the speed model and the original gun set;
constructing a reverse time migration imaging result by using a reverse time migration imaging condition, wherein the reverse time migration imaging condition is constrained by time and a local construction slope;
the reverse time migration imaging condition is obtained by the following method:
respectively carrying out local oblique superposition on the seismic source and the receiving point wave field under four-dimensional coordinates so as to decompose local construction slope and time of the seismic source function and the receiving point wave field function at each imaging point and obtain a seismic source function decomposition result and a receiving point wave field function decomposition result;
constructing an inverse time migration imaging condition constrained by the time and local construction slopes together by using the source function decomposition result and the receiving point wave field function decomposition result;
decomposing the local construction slope and time of the source function at each imaging point to obtain a source function decomposition result as follows: s (t, X) = ≡w S (p, t, X) dp; decomposing the local construction slope and time of the receiving point wave field function at each imaging point to obtain a receiving point wave field function decomposition result as follows: r (t, X) = ≡w R (p, t, X) dp; wherein t is a time coordinate representing a vertical depth; x is a transverse coordinate; s (t, X) represents a seismic source; r (t, X) represents a received-point wavefield; w (W) S Representing the source function decomposed according to the local construction slope; w (W) R Representing a received point wave field function decomposed according to a local construction slope; p represents the local construction slope at the imaging point;
the inverse time migration imaging condition which is constructed by utilizing the source function decomposition result and the receiving point wave field function decomposition result and is constrained by the time and the local construction slope is as follows: i (X) = ≡≡w s (p,t,X)W R (p, t, X) dpdt; wherein I (X) represents a reverse time shift imaging result.
2. The method of claim 1, wherein pre-stack preprocessing of the seismic data comprises:
carrying out static correction processing on the seismic data;
performing prestack denoising treatment on the seismic data subjected to static correction treatment;
and carrying out frequency-raising treatment on the seismic data subjected to prestack denoising treatment.
3. A reverse time offset imaging apparatus, said apparatus comprising:
the acquisition module is used for acquiring the field acquired seismic data and carrying out pre-stack pretreatment on the seismic data;
the model construction module is used for constructing a speed model by utilizing the seismic data acquired by the acquisition module;
the shot set extraction module is used for extracting an original shot set from the pre-stack preprocessed seismic data according to the acquisition coordinates of the seismic data acquired by the acquisition module;
the reverse time migration imaging module is used for carrying out reverse time migration by utilizing the speed model constructed by the model construction module and the original shot set extracted by the shot set extraction module;
the reverse time migration imaging module is further used for constructing a reverse time migration imaging result by using reverse time migration imaging conditions, and the reverse time migration imaging conditions are constrained by time and local construction slopes;
the reverse time offset imaging module is used for:
respectively carrying out local oblique superposition on the seismic source and the receiving point wave field under four-dimensional coordinates so as to decompose local construction slope and time of the seismic source function and the receiving point wave field function at each imaging point and obtain a seismic source function decomposition result and a receiving point wave field function decomposition result;
constructing an inverse time migration imaging condition constrained by the time and local construction slopes together by using the source function decomposition result and the receiving point wave field function decomposition result;
the inverse time migration imaging module decomposes local construction slope and time of a seismic source function at each imaging point, and the obtained seismic source function decomposition result is as follows: s (t, X) = ≡w S (p, t, X) dp; decomposing the local construction slope and time of the receiving point wave field function at each imaging point to obtain a receiving point wave field function decomposition result as follows: r (t, X) = ≡w R (p, t, X) dp; wherein t is a time coordinate representing a vertical depth; x is a transverse coordinate; s (t, X) represents a seismic source; r (t, X) represents a received-point wavefield; w (W) S Representing the source function decomposed according to the local construction slope; w (W) R Representing a received point wave field function decomposed according to a local construction slope; p represents the local construction slope at the imaging point;
the reverse time migration imaging module utilizes a seismic sourceThe inverse time migration imaging conditions which are constructed by the function decomposition result and the receiving point wave field function decomposition result and are constrained by the time and local construction slope together are as follows: i (X) = ≡≡w s (p,t,X)W R (p, t, X) dpdt; wherein I (X) represents a reverse time shift imaging result.
4. The apparatus of claim 3, wherein the acquisition module is configured to:
carrying out static correction processing on the seismic data;
performing prestack denoising treatment on the seismic data subjected to static correction treatment;
and carrying out frequency-raising treatment on the seismic data subjected to prestack denoising treatment.
5. A computer device comprising a memory, a processor and a computer program stored on the memory and executable on the processor, characterized in that the processor implements the method of claim 1 or 2 when executing the computer program.
6. A computer readable storage medium, characterized in that the computer readable storage medium stores a computer program for executing the method of claim 1 or 2.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202010440148.2A CN113703039B (en) | 2020-05-22 | 2020-05-22 | Reverse time migration imaging method and device |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202010440148.2A CN113703039B (en) | 2020-05-22 | 2020-05-22 | Reverse time migration imaging method and device |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN113703039A CN113703039A (en) | 2021-11-26 |
| CN113703039B true CN113703039B (en) | 2023-09-26 |
Family
ID=78646140
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN202010440148.2A Active CN113703039B (en) | 2020-05-22 | 2020-05-22 | Reverse time migration imaging method and device |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN113703039B (en) |
Citations (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN103091710A (en) * | 2013-01-15 | 2013-05-08 | 中国石油天然气股份有限公司 | Reverse time migration imaging method and device |
| CN103995288A (en) * | 2014-05-13 | 2014-08-20 | 中国石油天然气集团公司 | Gauss beam prestack depth migration method and device |
Family Cites Families (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CA2899796C (en) * | 2013-04-16 | 2019-02-19 | Exxonmobil Upstream Research Company | Seismic velocity model updating and imaging with elastic wave imaging |
-
2020
- 2020-05-22 CN CN202010440148.2A patent/CN113703039B/en active Active
Patent Citations (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN103091710A (en) * | 2013-01-15 | 2013-05-08 | 中国石油天然气股份有限公司 | Reverse time migration imaging method and device |
| CN103995288A (en) * | 2014-05-13 | 2014-08-20 | 中国石油天然气集团公司 | Gauss beam prestack depth migration method and device |
Non-Patent Citations (3)
| Title |
|---|
| "Acquisition aperture correction in the angle domain toward true-reflection reverse time migration";Rui Yan et al.,;《GEOPHYSICS》;第79卷(第6期);第241-250页 * |
| "Time-shift imaging condition in seismic migration";Paul Sava et al.,;《GEOPHYSICS》;第71卷(第6期);第209-217页 * |
| "基于多方向波场分离的逆时偏移成像方法";薛浩 等;《应用地球物理》;第15卷(第2期);第222-233页 * |
Also Published As
| Publication number | Publication date |
|---|---|
| CN113703039A (en) | 2021-11-26 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| US9766357B2 (en) | Seismic image dip decomposition estimation and recomposition | |
| US11550072B2 (en) | Method and apparatus for deblending seismic data using a non-blended dataset | |
| EP2999978B1 (en) | Hybrid deblending method and apparatus | |
| Takougang et al. | Characterization of small faults and fractures in a carbonate reservoir using waveform inversion, reverse time migration, and seismic attributes | |
| CN103499836B (en) | Space-variant-window fusion of many times high precision residual static corrections | |
| WO2015063595A1 (en) | Method and device for deblending seismic data using self-adapting and/or selective radon interpolation | |
| AU2013201072B2 (en) | Method and apparatus for automated noise removal from seismic data | |
| CN103926623A (en) | Method for suppressing reverse time migration low frequency noise | |
| US20220342103A1 (en) | Noise Attenuation Methods Applied During Simultaneous Source Deblending and Separation | |
| WO2016176235A1 (en) | Time lapse seismic data processing | |
| Xue et al. | Reverse-time migration using multidirectional wavefield decomposition method | |
| CN110907989A (en) | Method and system for reconstructing quasi-ground seismic reflection wave imaging | |
| CN113703039B (en) | Reverse time migration imaging method and device | |
| CN112198547A (en) | Deep or ultra-deep seismic data processing method and device | |
| NO20130064A1 (en) | Device and method for estimating time offset. | |
| CN112882101B (en) | Random noise attenuation method and device for pre-stack seismic data | |
| CN111929726B (en) | Seismic coherent data volume processing method and device | |
| CN113917533A (en) | Systematic implementation method of double-linkage omnibearing imaging of TI medium | |
| CN113391348B (en) | Common reflection point gather construction method and device for prestack inversion | |
| Qin | Full-waveform inversion of ground-penetrating radar data and its indirect joint petrophysical inversion with shallow-seismic data | |
| CN112799132B (en) | Micro-local linear noise suppression method and device | |
| CN111562616A (en) | Seismic data scattering noise suppression method and device | |
| Zhang et al. | Direct imaging microseismic data below sources | |
| Zhixin et al. | High-effective vibroseis acquisition simultaneous shooting crosstalk noise suppression technology | |
| CN115639602A (en) | Method and device for improving imaging quality, electronic equipment and readable storage medium |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| GR01 | Patent grant | ||
| GR01 | Patent grant |