CN110632663A - Longitudinal and transverse wave velocity ratio inversion method without well control - Google Patents
Longitudinal and transverse wave velocity ratio inversion method without well control Download PDFInfo
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Abstract
The invention discloses a well-control-free longitudinal and transverse wave velocity ratio inversion method, which comprises the following steps: acquiring the attribute of the region to be inverted, which is sensitive to reservoir lithology and physical properties, by using geological data, pre-stack time migration seismic data and logging data; optimizing the seismic prestack gather generated by prestack time migration; extracting three input wavelets of prestack synchronous inversion from the prestack time migration seismic data; carrying out prestack depth migration processing on the prestack time migration seismic data to obtain a longitudinal wave velocity model; calculating a density model and a transverse wave velocity model by taking the distribution range of the density and the longitudinal and transverse wave velocity ratio as constraint conditions; respectively calculating by using a longitudinal wave impedance model and a transverse wave impedance model by using a longitudinal wave impedance model calculation formula and a transverse wave impedance model calculation formula; and taking the longitudinal wave impedance model, the transverse wave impedance model and the density model as inversion input, and setting inversion iteration times for inversion to obtain an inversion result. The invention improves the precision of the inversion model of the low-frequency range of the well-free area and the accuracy of the inversion result.
Description
Technical Field
The invention relates to the technical field of petroleum geophysical exploration, in particular to a longitudinal and transverse wave velocity ratio inversion method without well control.
Background
The longitudinal wave velocity ratio information of the stratum has a good effect on identifying the reservoir and is generally obtained by pre-stack synchronous inversion. The seismic gather quality, the low-frequency model and the inversion parameter setting become three key factors influencing the inversion accuracy of the longitudinal-transverse wave velocity ratio. The low-frequency model is generally required to be influenced by the number of the drilled wells and the distribution of the drilled wells, and when the number of the drilled wells is large and the drilled wells are uniformly distributed on a work area plane, the low-frequency model is generally high in precision. When no well or few wells exist in a work area, the low-frequency model is low in precision and even difficult to establish, inversion cannot be directly conducted, and then a longitudinal-transverse wave velocity ratio inversion result cannot be obtained. When the seismic gather quality is poor, the requirement of prestack inversion cannot be met, and the precision of the velocity ratio of the longitudinal wave to the transverse wave is also influenced. From the current literature data, the inversion of the velocity ratio of longitudinal waves to transverse waves under the condition of no well is focused on the solution of a method for constructing a virtual well. However, this method has the disadvantage that when the selected control point is not enough to represent the work area, it will bring a large error to the inversion.
In addition, the frequency band of the seismic record is generally between 10 and 70hz, low-frequency and high-frequency information is lacked, the high-frequency information of the seismic is capable of reflecting the details of lithology change, and in recent years, a plurality of expert scholars propose a plurality of methods for compensating high frequency, and the importance of the methods is generally accepted. Due to the influence of a seismic acquisition instrument and an acquisition mode, low-frequency information is lacked in seismic data, particularly the seismic information lower than 8-10hz is seriously lacked, the lack of the information affects formation imaging and reservoir prediction, and when a large set of formations exist in the formations, the influence caused by the low-frequency lack is particularly obvious. In the current low-frequency modeling research aiming at a well-free area, the accuracy of a low-frequency model is low, so that an inversion result is influenced, and the prediction precision of a reservoir is directly reduced.
Disclosure of Invention
The invention provides a longitudinal and transverse wave velocity ratio inversion method without well control, aiming at overcoming the defects of poor accuracy of a low-frequency range inversion model and unsatisfactory inversion result in a well-free area in the prior art.
The primary objective of the present invention is to solve the above technical problems, and the technical solution of the present invention is as follows:
a longitudinal and transverse wave velocity ratio inversion method without well control comprises the following steps:
s1, acquiring elastic parameters sensitive to reservoir lithology and physical properties in the region to be inverted by using geological data, prestack time migration seismic data and logging data, wherein sensitive elastic parameter analysis is the theoretical basis of longitudinal and transverse wave velocity ratio inversion;
s2, performing gather leveling processing and residual multiple removal processing on the seismic prestack gather generated by prestack time migration;
s3: extracting three statistical wavelets from the prestack time migration seismic data according to a preset angle range to serve as three input wavelets of prestack synchronous inversion;
s4: pre-stack depth migration processing is carried out on the pre-stack time migration seismic data, and a high-precision grid chromatographic velocity field is obtained and is used as a longitudinal wave velocity model;
s5: calculating a density model and a transverse wave velocity model by using a Gardner formula and a preset value range of a longitudinal wave velocity ratio and a transverse wave velocity ratio;
s6: respectively calculating by using a longitudinal wave impedance model and a transverse wave impedance model by using a longitudinal wave impedance model calculation formula and a transverse wave impedance model calculation formula;
s7: and taking the longitudinal wave impedance model, the transverse wave impedance model and the density model as inversion input, and setting inversion iteration times for inversion to obtain an inversion result.
The preset angle ranges of step S3 include three, which are respectively recorded as a first preset angle range, a second preset angle range, and a third preset angle range, wherein the statistical wavelet within the first preset angle range is a near-channel wavelet, the statistical wavelet within the second preset angle range is a middle-channel wavelet, and the statistical wavelet within the third preset angle range is a far-channel wavelet.
Further, a density model is calculated by using a gardner formula, wherein the gardner formula specifically comprises:
den＝c1*vp**c2
wherein vp represents the longitudinal wave velocity, c1 and c2 are parameters, and the correction parameters are determined according to the elastic relation of well logging in the region to be inverted.
Further, the calculation formula of the longitudinal and transverse wave impedance model comprises: the method comprises a longitudinal wave impedance model calculation formula and a transverse wave impedance model calculation formula, wherein the longitudinal wave impedance model calculation formula specifically comprises the following steps:
zp＝vp*den
wherein vp represents the velocity of the longitudinal wave, den represents the density model, and zp represents the impedance of the longitudinal wave;
the transverse wave impedance model calculation formula specifically comprises:
zs＝vs*den
where vs represents the shear wave velocity, den represents the density model, and zs represents the shear wave impedance.
Further, the inversion method in step S7 includes pre-stack synchronous inversion and post-stack inversion.
Further, step S5 includes determining a density range of the log data in the region to be inverted.
Compared with the prior art, the technical scheme of the invention has the beneficial effects that:
according to the invention, the optimization is carried out through the seismic gather, the longitudinal wave velocity model is obtained through prestack depth migration processing, the density model and the impedance model of the low-frequency range are respectively obtained by combining the Gardner formula and the preset value range of the longitudinal wave velocity ratio and the transverse wave velocity ratio, the precision of the inversion model of the low-frequency range of the non-well area is improved, and the inversion is carried out by combining the optimized seismic gather, so that the inversion result is more accurate.
Drawings
FIG. 1 is a flow chart of the present invention.
FIG. 2 is a diagram of seismic prestack gather effect after gather flattening.
FIG. 3 is a diagram of the effect of seismic prestack gathers after residual multiples have been removed.
FIG. 4 is a schematic view of a density model.
FIG. 5 is a schematic diagram of a shear velocity model.
FIG. 6 is a schematic diagram of inversion results of the velocity ratio of the longitudinal and transverse waves.
Detailed Description
In order that the above objects, features and advantages of the present invention can be more clearly understood, a more particular description of the invention will be rendered by reference to the appended drawings. It should be noted that the embodiments and features of the embodiments of the present application may be combined with each other without conflict.
In the following description, numerous specific details are set forth in order to provide a thorough understanding of the present invention, however, the present invention may be practiced in other ways than those specifically described herein, and therefore the scope of the present invention is not limited by the specific embodiments disclosed below.
Example 1
A longitudinal and transverse wave velocity ratio inversion method without well control comprises the following steps:
s1, acquiring elastic parameters sensitive to reservoir lithology and physical properties of the area to be inverted by using geological data, prestack time migration seismic data and logging data;
it should be noted that lithology and physical properties of a reservoir are mainly analyzed by logging elastic property intersection, which mainly includes: the longitudinal wave impedance intersects with the transverse wave impedance, the longitudinal wave impedance intersects with the velocity ratio of the longitudinal wave to the transverse wave, the lamb darrho intersects with the MiuRho, the longitudinal wave impedance intersects with the density, and new attributes derived from coordinate rotation intersect. The invention utilizes the velocity ratio of longitudinal wave and transverse wave to identify lithology.
S2, performing gather leveling processing and residual multiple removal processing on the seismic prestack gather generated by prestack time migration; fig. 2 is a diagram showing an effect of a seismic prestack gather after the gather leveling process, and fig. 3 is a diagram showing an effect of a seismic prestack gather after the residual multiples are removed.
The seismic gather has high fidelity amplitude-preserving property by performing gather leveling processing and residual multiple removal processing on the seismic prestack gather, and the seismic gather can be used for inversion gather input.
S3: extracting three statistical wavelets from the prestack time migration seismic data according to a preset angle range to serve as three input wavelets of prestack synchronous inversion; according to the method, three statistical wavelets are extracted from an angle trace set of pre-stack time migration seismic data, an angle range corresponding to three different statistical wavelets is determined, and the statistical wavelets are extracted in the determined angle range and are endowed with corresponding angles.
More specifically, the preset angle ranges include three, which are respectively recorded as a first preset angle range, a second preset angle range, and a third preset angle range, wherein the statistical wavelet in the first preset angle range is a near-channel wavelet, the statistical wavelet in the second preset angle range is a medium-channel wavelet, and the statistical wavelet in the third preset angle range is a far-channel wavelet. The angle range of the extracted near channel wavelet is as follows: 3-13 degrees; the angle range of the extracted midchannel wavelets is 14-22 degrees, and the angle range of the extracted far channel wavelets is 23-33 degrees. Wavelets are extracted from three angle ranges respectively, wherein the angle of the extracted wavelet in the near-channel wavelet angle range is assigned to 8 degrees, the angle of the extracted wavelet in the middle-channel wavelet angle range is assigned to 18 degrees, and the angle of the extracted wavelet in the far-channel wavelet angle range is assigned to 28 degrees.
S4: and performing prestack depth migration processing on the prestack time migration seismic data to obtain a high-precision grid chromatographic velocity field, and taking the high-precision grid chromatographic velocity field as a longitudinal wave velocity model, and marking the high-precision grid chromatographic velocity field as vp, wherein the longitudinal wave velocity of the longitudinal wave velocity model can be used as the longitudinal wave velocity input in a longitudinal wave impedance model calculation formula.
S5: calculating a density model and a transverse wave velocity model by using a Gardner formula and a preset value range of a longitudinal wave velocity ratio and a transverse wave velocity ratio; specifically, the density (den) range of multi-well logging data in an adjacent area outside the region to be inverted and the longitudinal-transverse wave velocity ratio (vp/vs) data range are determined, in this embodiment, the density range of the logging data is (2.2,2.8), and the longitudinal-transverse wave velocity ratio range is [ 1.80-2.10 ]. The density range and the range of the longitudinal-transverse wave velocity ratio of the logging data are hard constraint conditions for subsequent density model and impedance model calculation.
In the embodiment, a stratum mainly including sand and mudstone is selected, the longitudinal and transverse wave velocity ratio vp/vs of the mudstone stratum is a constant between [2.00 and 2.10], no logging exists in the selected area in the embodiment, so that the vp/vs cannot be uniquely determined, namely, values between [2.00 and 2.10] are possible, and therefore the stratum is selected at regular intervals from the longitudinal and transverse wave velocity ratio of 2.0 until the vp/vs is 2.10. Thus, a series of values of vp/vs can be obtained. Wherein, the step length can be selected from 0.005, 0.01, 0.02 and the like, and the step length is selected according to the inversion result.
According to the longitudinal wave velocity model vp and the longitudinal and transverse wave velocity ratio, a density model den is obtained by using a Gardner formula
den＝c1*vp**c2
Wherein vp represents the longitudinal wave velocity, and c1 and c2 are parameters and are obtained according to the logging elastic relation in the region to be inverted.
Fig. 4 is a schematic diagram of a density model, and fig. 5 is a schematic diagram of a shear wave velocity model. From fig. 4-5, it can be seen that from these two models, the model transitions naturally, consistent with geological knowledge. And the requirements of subsequent inversion on a low-frequency model are met.
S6: respectively utilizing a longitudinal wave impedance model calculation formula and a transverse wave impedance model calculation formula to calculate corresponding impedance models, which specifically comprises the following steps:
the longitudinal wave impedance model calculation formula is specifically as follows:
zp＝vp*den
wherein vp represents the velocity of the longitudinal wave, den represents the density model, and zp represents the impedance of the longitudinal wave;
the transverse wave impedance model calculation formula specifically comprises:
zs＝vs*den
where vs represents the shear wave velocity, den represents the density model, and zs represents the shear wave impedance.
S7: and taking the longitudinal wave impedance model, the transverse wave impedance model and the density model as inversion input, setting inversion iteration times, and simultaneously combining the seismic prestack gather subjected to the gather leveling processing and the residual multiple removal processing to perform prestack synchronous inversion to obtain an inversion result.
Note that the number of inversion iterations in this embodiment is typically 20, 50, or 100. The more iterations, the longer the computation takes, preferably 50 iterations. The criterion for selecting the iteration times is to make the inversion result tend to the seismic information, so that the seismic inversion result is real and credible, and to make the inversion time economically feasible, so as not to consume too long time.
Fig. 6 is a schematic diagram of the result of the velocity ratio of the longitudinal and transverse waves, wherein the velocity ratio of the longitudinal and transverse waves vp/vs is less than or equal to 2.0, the reservoir is a reservoir, and it can be seen from the diagram that the sandstone reservoir is obviously distributed and the sandstone is obviously distinguished from the background mudstone. It accords with geological knowledge.
It should be understood that the above-described embodiments of the present invention are merely examples for clearly illustrating the present invention, and are not intended to limit the embodiments of the present invention. Other variations and modifications will be apparent to persons skilled in the art in light of the above description. And are neither required nor exhaustive of all embodiments. Any modification, equivalent replacement, and improvement made within the spirit and principle of the present invention should be included in the protection scope of the claims of the present invention.
Claims (6)
1. A longitudinal and transverse wave velocity ratio inversion method without well control is characterized by comprising the following steps:
s1, acquiring elastic parameters sensitive to reservoir lithology and physical properties of the area to be inverted by using geological data, prestack time migration seismic data and logging data;
s2, performing gather leveling processing and residual multiple removal processing on the seismic prestack gather generated by prestack time migration;
s3: extracting three statistical wavelets from the prestack time migration seismic data according to a preset angle range to serve as three input wavelets of prestack synchronous inversion;
s4: pre-stack depth migration processing is carried out on the pre-stack time migration seismic data, and a high-precision grid chromatographic velocity field is obtained and is used as a longitudinal wave velocity model;
s5: calculating a density model and a transverse wave velocity model by using a Gardner formula and a preset value range of a longitudinal wave velocity ratio and a transverse wave velocity ratio;
s6: respectively calculating by using a longitudinal wave impedance model and a transverse wave impedance model by using a longitudinal wave impedance model calculation formula and a transverse wave impedance model calculation formula;
s7: and taking the longitudinal wave impedance model, the transverse wave impedance model and the density model as inversion input, and setting inversion iteration times for inversion to obtain an inversion result.
2. The method of claim 1, wherein the predetermined angular ranges in step S3 include three predetermined angular ranges, which are respectively denoted as a first predetermined angular range, a second predetermined angular range, and a third predetermined angular range, wherein the statistical wavelet within the first predetermined angular range is a near-channel wavelet, wherein the statistical wavelet within the second predetermined angular range is a middle-channel wavelet, and wherein the statistical wavelet within the third predetermined angular range is a far-channel wavelet.
3. The well-control-free longitudinal and transverse wave velocity ratio inversion method according to claim 1, wherein a density model is calculated by using a gardner formula, wherein the gardner formula specifically comprises:
den＝c1*vp**c2
where vp represents the longitudinal wave velocity, and c1 and c2 are correction parameters.
4. The method for inverting the velocity ratio of a longitudinal wave and a transverse wave without well control according to claim 1, wherein the calculation formula of the longitudinal wave and the transverse wave impedance model comprises: the method comprises a longitudinal wave impedance model calculation formula and a transverse wave impedance model calculation formula, wherein the longitudinal wave impedance model calculation formula specifically comprises the following steps:
zp＝vp*den
wherein vp represents the velocity of the longitudinal wave, den represents the density model, and zp represents the impedance of the longitudinal wave;
the transverse wave impedance model calculation formula specifically comprises:
zs＝vs*den
where vs represents the shear wave velocity, den represents the density model, and zs represents the shear wave impedance.
5. The method of claim 1, wherein the inversion method in step S7 includes pre-stack synchronous inversion and post-stack inversion.
6. The method of claim 1, wherein the step S5 further comprises determining a density range of the log data in the region to be inverted.
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| CN101872024A (en) * | 2010-06-02 | 2010-10-27 | 中国海洋石油总公司 | Method for carrying out well design by using time-lapse seismic |
| US20160131781A1 (en) * | 2014-11-12 | 2016-05-12 | Chevron U.S.A. Inc. | Creating a high resolution velocity model using seismic tomography and impedance inversion |
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