CN104391327A - Well-to-well seismic pre-stack reverse-time depth migration imaging method for sea deviated well - Google Patents
Well-to-well seismic pre-stack reverse-time depth migration imaging method for sea deviated well Download PDFInfo
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Abstract
The invention relates to a well-to-well seismic pre-stack reverse-time depth migration imaging method for a sea deviated well. The method includes the following steps: 1) collecting or having field construction acquisition for gathering the well-to-well seismic data of deviated well; 2) taking TTI medium chromatography inversion on the seismic data to obtain the two-dimension TTI medium offset model; 3) taking wave field treatment on the well-to-well seismic data of deviated well to obtain the converted wave field and reflection wave field used for imaging; 4) taking mesh generation on the two-dimension TTI medium offset model; 5) adopting the first-motion wave ray tracing method for calculating the first-motion wave time for each grid; 6) having wave field inverse continuation calculation on the seismic data based on the two-dimension TTI medium offset model to obtain the wave field value of the seismic data at different instants of time; 7) adopting the image-forming condition on the wave field value of the seismic data at different instants of time for imaging in each grid to obtain well-to-well seismic depth migration imaging section of deviated well.
Description
Technical field
The present invention relates to energy exploration development field, particularly about one marine inclined shaft crosshole seismic prestack reverse time depth migration formation method.
Background technology
Crosshole seismic wave field enriches, and existing up reflected wave field, also has downgoing reflection wave field, and wave field separation difficulty is comparatively large, particularly at sea inclined shaft when, because the directed difficulty of three-component seismometer strengthens, the difficulty of wave field separation is just more obvious.Conventional reflection wave stacking image method (as VSP-CDP stacking image method) requires to be input as single wave field, and therefore wave field separation does not totally often cause imaging effect undesirable.In addition, due to the Persisting exploitation in oil field, between well, reservoir change is relatively large, anisotropic problem is more outstanding, therefore there is some problems all the time in conventional depth territory offset imaging method, and it is mainly manifested in two aspects: one is that image-forming condition calculation requirement is more accurate, and speed is faster; Two is that rate pattern requirement is more complicated, and precision is higher.
Generally, Depth Domain offset imaging method is divided into the foundation of skew model, image-forming condition calculating and reverse time depth migration imaging three parts.In image-forming condition, mainly contain dependent imaging condition and firing time image-forming condition two kinds at present.Dependent imaging condition carries out forward modelling and inverting backstepping to wave field, then both be correlated with, and its calculated amount is larger.Firing time image-forming condition is the popularization of time consistency image-forming principle, its be using focal point to imaging region in outward journey time of every bit as the image-forming condition of this point.Calculate the key issue that firing time image-forming condition is wave equation reverse-time migration.The computing method of the normal firing time image-forming condition adopted have ray casting and method of finite difference two kinds at present.Wherein, ray casting be using focal point to imaging region in every bit minimum traveltimes between as the image-forming condition of this point, the method requires that speed and velocity interface are smooth, quite strict requirement is had to the description of speed and velocity interface, and, under certain velocity structure, there is the shadow region that ray does not reach; Method of finite difference is that calculate from focal point, the propagation before analog wave, rate pattern is more complicated ring by ring, and rectangular node needs the thinner of subdivision, and calculated amount is also larger by rectangular node subdivision velocity field.In rate pattern calculating, at present main well logging interpolation model or the isotropic medium direct wave tomography result of adopting is as the mode input of Depth Domain migration imaging, and these two kinds of models all cannot meet the accuracy requirement of current oil and gas development.
Summary of the invention
For the problems referred to above, the object of this invention is to provide a kind of can meet oil and gas development accuracy requirement, take two-dimension elastic titled transversely isotropy (Titled Transversely Isotropic medium is called for short TTI medium) tomographic results as the marine inclined shaft crosshole seismic prestack reverse time depth migration formation method of model.
For achieving the above object, the present invention takes following technical scheme: a kind of marine inclined shaft crosshole seismic prestack reverse time depth migration formation method, comprises the following steps: 1) collect or field construction collection inclined shaft cross-well seismic data; 2) inclined shaft cross-well seismic data is carried out TTI medium tomographic inversion, obtain two-dimentional TTI medium skew model; 3) carry out wave field process to inclined shaft cross-well seismic data, obtain the conversion wave field for imaging and reflected wave field, conversion wave field and reflected wave field form the reflected wave field of cross-well seismic data jointly; 4) according to imaging precision requirement, to step 2) the two-dimentional TTI medium skew model that obtains carries out stress and strain model, obtains the two-dimentional TTI medium skew model of gridding; 5) the two-dimentional TTI medium skew model of gridding is adopted primary wave ray-tracing scheme, calculate the primary wave time of each grid, the gained primary wave time is image-forming condition; 6) based on two-dimentional TTI medium skew model, the reflected wave field of seismic data is carried out the continuation of wave field inverse time and calculate, obtain seismic data not wave field value in the same time; 7) by seismic data not wave field value application image-forming condition in the same time carry out imaging at each grid, obtain inclined shaft crosshole seismic depth migration imaging section.
Described step 2) concrete steps be: 1. the inclined shaft cross-well seismic data collected is carried out first break time pickup, obtains the primary wave time of inclined shaft cross-well seismic data; 2. the first break time of inclined shaft cross-well seismic data adopted TTI medium tomographic inversion algorithm to carry out inverting, obtain stratum TTI medium parameter, be i.e. two-dimentional TTI medium skew model.
Described step 2. in, described TTI medium tomographic inversion algorithm adopts method of conjugate gradient to solve the damped least squares problem of belt restraining.
Described step 4) in, the size of described grid requires to determine according to actual observation system and imaging precision.
Described step 5) in, described primary wave ray-tracing scheme adopts subregion multistep modified Shortest path ray tracing method.
Described step 6) in, described wave field inverse time continuation adopts staggering mesh finite-difference algorithm.
The present invention is owing to taking above technical scheme, it has the following advantages: 1, the present invention adopts Time Migration of Elastic Wave Equation staggering mesh finite-difference algorithm to carry out reverse-time extrapolation because wave field extrapolation calculates, grid can subdivision arbitrary size, therefore the imaging precision obtained is high, maintains kinematics and the dynamic characteristic of wave field simultaneously; 2, the present invention is due to two-dimentional TTI medium skew mode input employing TTI medium primary wave tomographic inversion imaging results, the anisotropy spread (i.e. anisotropic parameters distribution) on stratum can be obtained, make the model inputted meet the imaging precision requirement of oil and gas development; 3, the present invention calculates image-forming condition owing to adopting the subregion multistep modified Shortest path ray tracing method being applicable to TTI medium, and therefore can adapt to isotropic medium and TTI medium, and the method computing velocity is fast, computational accuracy is high; 4, formation method of the present invention is owing to maintaining kinematics and the dynamic characteristic of wave field preferably, therefore with routine based on ray theory formation method compared with, this method can adapt to complex structure stratum and isotropy and TTI medium, and overall imaging precision is higher than conventional image forming process; 5, formation method of the present invention is owing to can realize full Seismic imaging, avoids the difficulty of crosshole seismic wave field separation, and also can realize single Seismic imaging, therefore adaptability is wider simultaneously; 6, formation method of the present invention owing to not being similar to wave equation in computation process, possesses natural guarantor's width compared with the reflection wave stacking image method of routine, and therefore the precision of imaging results and reliability are higher than conventional reflection wave stacking image method.Therefore the present invention can be widely used in energy exploration performance history.
Accompanying drawing explanation
Fig. 1 is the inventive method schematic flow sheet;
Fig. 2 is that shot point of the present invention is through the diffraction path schematic diagram of Diffraction Point to acceptance point;
Fig. 3 is the TTI medium primary wave tomographic inversion result schematic diagram being used as to set up TTI dielectric model in the present invention, wherein, figure (a) is the distribution plan of the elastic parameter a11 of the TTI medium adopting TTI medium tomographic inversion algorithm to utilize first break time inverting to obtain, figure (b) is the distribution plan of the elastic parameter a13 of the TTI medium adopting TTI medium tomographic inversion algorithm to utilize first break time inverting to obtain, figure (c) is the distribution plan of the elastic parameter a33 of the TTI medium adopting TTI medium tomographic inversion algorithm to utilize first break time inverting to obtain, figure (d) is the distribution plan of the elastic parameter a44 of the TTI medium adopting TTI medium tomographic inversion algorithm to utilize first break time inverting to obtain,
Fig. 4 is the primary wave time diagram that the TTI medium subregion multistep modified critical path method (CPM) being used as image-forming condition in the present invention calculates, wherein " ☆ " represents focus, black curve between color lump is the isoline of first break time, represent wavefront surface when waiting, the broken line of black represents the primary wave raypath of this focus.
Embodiment
Below in conjunction with drawings and Examples, the present invention is described in detail.
As shown in Figure 1, marine inclined shaft crosshole seismic prestack reverse time depth migration formation method of the present invention, by single big gun seismologic record that acceptance point receives, namely the single big gun seismologic record before stacking image, calculating Diffraction Point place starts waveform when there is diffraction, be divided into the foundation of two-dimentional TTI medium skew model, image-forming condition calculating and reverse time depth migration imaging three parts, specifically comprise the following steps:
1, collection or field construction gather inclined shaft cross-well seismic data;
As shown in Figure 2, the embodiment of the present invention gathers cross-well seismic data process and is: suppose have adjacent two inclined shafts, and what define the left side is left well, the right be right well.Focus S is positioned at left aboveground, and seismic event is sent by focus S, propagates into Diffraction Point D, and seismic event is T by the focus S time propagated into needed for Diffraction Point D
sD; To there is diffraction at Diffraction Point D in seismic event, seismic wave directly arrives right aboveground acceptance point G by Diffraction Point D partially, and another part seismic event is transmitted to right aboveground acceptance point G again after the reflection of stratum; The seismologic record that acceptance point G receives is the cross-well seismic data collected.The seismologic record that the present invention is received by acceptance point G, calculating Diffraction Point D place starts waveform when there is diffraction, and namely Diffraction Point D is at T
sDthe waveform in moment.
2, inclined shaft cross-well seismic data is carried out TTI medium tomographic inversion, obtain two-dimentional TTI medium skew model, concrete steps are:
2.1) the inclined shaft cross-well seismic data collected is carried out first break time pickup, obtain the primary wave time of inclined shaft cross-well seismic data;
2.2) TTI medium tomographic inversion algorithm the first break time of inclined shaft cross-well seismic data is adopted to carry out inverting, obtain stratum TTI medium parameter (as shown in Figure 3), i.e. two-dimentional TTI medium skew model, wherein, the damped least squares problem that TTI medium tomographic inversion algorithm can adopt method of conjugate gradient to solve belt restraining carries out non-linear inversion;
3, carry out wave field process to inclined shaft cross-well seismic data, obtain the conversion wave field for imaging and reflected wave field, conversion wave field and reflected wave field form the reflected wave field of cross-well seismic data jointly, and the detailed process of wave field process is:
3.1) adopt prior art to carry out wave field process inclined shaft cross-well seismic data, remove through wave field, obtain conversion wave field and the reflected wave field of seismic data;
3.2) adopt prior art to carry out denoising conversion wave field and reflected wave field, improve the signal to noise ratio (S/N ratio) of seismic data further;
4, according to imaging precision requirement, stress and strain model is carried out to the two-dimentional TTI medium skew model that step 2 obtains, obtains the two-dimentional TTI medium skew model of gridding, wherein, the size of grid can require to determine according to actual observation system and imaging precision, in this no limit;
5, the two-dimentional TTI medium skew model of gridding is adopted primary wave ray-tracing scheme, calculate the primary wave time (as shown in Figure 4) of each grid, the gained primary wave time is image-forming condition, wherein, primary wave ray-tracing scheme can adopt subregion multistep modified Shortest path ray tracing method;
6, based on two-dimentional TTI medium skew model, the reflected wave field of seismic data is carried out the continuation of wave field inverse time and calculate, obtain seismic data not wave field value in the same time, wherein, the continuation of wave field inverse time can adopt staggering mesh finite-difference algorithm;
7, by seismic data not wave field value application image-forming condition in the same time carry out imaging at each grid, obtain inclined shaft crosshole seismic depth migration imaging section, the depth migration imaging section obtained be used for oil reservoir Fine structural interpretation, instruct oil and gas development.
The various embodiments described above are only for illustration of the present invention, and wherein each optimum configurations etc. all can change to some extent, and every equivalents of carrying out on the basis of technical solution of the present invention and improvement, all should not get rid of outside protection scope of the present invention.
Claims (9)
1. a marine inclined shaft crosshole seismic prestack reverse time depth migration formation method, comprises the following steps:
1) collection or field construction gather inclined shaft cross-well seismic data;
2) inclined shaft cross-well seismic data is carried out TTI medium tomographic inversion, obtain two-dimentional TTI medium skew model;
3) carry out wave field process to inclined shaft cross-well seismic data, obtain the conversion wave field for imaging and reflected wave field, conversion wave field and reflected wave field form the reflected wave field of cross-well seismic data jointly;
4) according to imaging precision requirement, to step 2) the two-dimentional TTI medium skew model that obtains carries out stress and strain model, obtains the two-dimentional TTI medium skew model of gridding;
5) the two-dimentional TTI medium skew model of gridding is adopted primary wave ray-tracing scheme, calculate the primary wave time of each grid, the gained primary wave time is image-forming condition;
6) based on two-dimentional TTI medium skew model, the reflected wave field of seismic data is carried out the continuation of wave field inverse time and calculate, obtain seismic data not wave field value in the same time;
7) by seismic data not wave field value application image-forming condition in the same time carry out imaging at each grid, obtain inclined shaft crosshole seismic depth migration imaging section.
2. a kind of marine inclined shaft crosshole seismic prestack reverse time depth migration formation method as claimed in claim 1, is characterized in that: described step 2) concrete steps be:
1. the inclined shaft cross-well seismic data collected is carried out first break time pickup, obtain the primary wave time of inclined shaft cross-well seismic data;
2. the first break time of inclined shaft cross-well seismic data adopted TTI medium tomographic inversion algorithm to carry out inverting, obtain stratum TTI medium parameter, be i.e. two-dimentional TTI medium skew model.
3. a kind of marine inclined shaft crosshole seismic prestack reverse time depth migration formation method as claimed in claim 2, is characterized in that: described step 2. in, described TTI medium tomographic inversion algorithm adopts method of conjugate gradient to solve the damped least squares problem of belt restraining.
4. the marine inclined shaft crosshole seismic of the one as described in claim 1 or 2 or 3 prestack reverse time depth migration formation method, is characterized in that: described step 4) in, the size of described grid requires to determine according to actual observation system and imaging precision.
5. the marine inclined shaft crosshole seismic of the one as described in claim 1 or 2 or 3 prestack reverse time depth migration formation method, it is characterized in that: described step 5) in, described primary wave ray-tracing scheme adopts subregion multistep modified Shortest path ray tracing method.
6. a kind of marine inclined shaft crosshole seismic prestack reverse time depth migration formation method as claimed in claim 4, is characterized in that: described step 5) in, described primary wave ray-tracing scheme adopts subregion multistep modified Shortest path ray tracing method.
7. the marine inclined shaft crosshole seismic of the one as described in claim 1 or 2 or 3 or 6 prestack reverse time depth migration formation method, is characterized in that: described step 6) in, described wave field inverse time continuation adopts staggering mesh finite-difference algorithm.
8. a kind of marine inclined shaft crosshole seismic prestack reverse time depth migration formation method as claimed in claim 4, is characterized in that: described step 6) in, described wave field inverse time continuation adopts staggering mesh finite-difference algorithm.
9. a kind of marine inclined shaft crosshole seismic prestack reverse time depth migration formation method as claimed in claim 5, is characterized in that: described step 6) in, described wave field inverse time continuation adopts staggering mesh finite-difference algorithm.
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| CN105974470A (en) * | 2016-07-04 | 2016-09-28 | 中国石油大学(华东) | Multi-component seismic data least squares reverse time migration imaging method and system |
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| CN105974470A (en) * | 2016-07-04 | 2016-09-28 | 中国石油大学(华东) | Multi-component seismic data least squares reverse time migration imaging method and system |
| CN105974470B (en) * | 2016-07-04 | 2017-06-16 | 中国石油大学(华东) | A kind of multi-component seismic data least square reverse-time migration imaging method and system |
| US20190293813A1 (en) * | 2017-11-20 | 2019-09-26 | Conocophillips Company | Offshore application of non-uniform optimal sampling survey design |
| CN108303736A (en) * | 2017-12-07 | 2018-07-20 | 东华理工大学 | Anisotropy TI medium Shortest path ray tracing forward modeling methods |
| CN108303736B (en) * | 2017-12-07 | 2020-11-17 | 东华理工大学 | Ray tracing forward method for shortest path of anisotropic TI medium |
| CN108363101A (en) * | 2018-02-02 | 2018-08-03 | 西安石油大学 | A kind of inclined shaft crosshole seismic Gaussian beam pre-stack depth migration imaging method |
| CN108363101B (en) * | 2018-02-02 | 2019-07-02 | 西安石油大学 | A kind of inclined shaft crosshole seismic Gaussian beam pre-stack depth migration imaging method |
| CN109100784A (en) * | 2018-06-08 | 2018-12-28 | 恒泰艾普（北京）能源科技研究院有限公司 | All-wave field imaging method is exchanged in the inspection of three-dimensional VSP source |
| CN109100784B (en) * | 2018-06-08 | 2020-04-28 | 恒泰艾普（北京）能源科技研究院有限公司 | Three-dimensional VSP source detection interchange full-wave-field imaging method |
| CN113376629A (en) * | 2021-05-13 | 2021-09-10 | 电子科技大学 | In-well radar least square inversion method based on non-uniform input parameter grid |
| CN113376629B (en) * | 2021-05-13 | 2022-08-05 | 电子科技大学 | In-well radar least square inversion method based on non-uniform input parameter grid |
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Address after: 100010 Beijing, Chaoyangmen, North Street, No. 25, No. Co-patentee after: CNOOC research institute limited liability company Patentee after: China Offshore Oil Group Co., Ltd. Address before: 100010 Beijing, Chaoyangmen, North Street, No. 25, No. Co-patentee before: CNOOC Research Institute Patentee before: China National Offshore Oil Corporation |