CN106468782B - It is a kind of based on crack prediction method of the ceiling capacity than method - Google Patents
It is a kind of based on crack prediction method of the ceiling capacity than method Download PDFInfo
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Abstract
The present invention provides a kind of based on crack prediction method of the ceiling capacity than method.Shear Waves Splitting division " the orientation time difference orientation time difference " spectrum can be calculated in this method, and then conveniently obtains fracture orientation and density parameter.This method specifically includes：Rotation of horizontal component is carried out to vertical seismic profiling (VSP) data, postrotational component is obtained, carries out the down-going wave fields of the component of isolated rotation；To the geophone station at each target depth, window when selecting suitable is allowed to include the conversion wave field of one group of generation shear wave splitting on downlink R and T component, and is composed using the orientation time difference data scanning computer azimuth time difference in window during improved maximum capacity ratio method pair；Pickup crack relative bearing and the Concerning With Fast-slow Waves time difference in finally being composed from the orientation time difference orientation time difference, calculate crack nature azimuth and density.
Description
Technical Field
The invention relates to the technical field of seismic exploration, in particular to a crack prediction method based on a maximum energy ratio method.
Background
When the seismic transverse wave propagates in the anisotropic medium containing the crack, the transverse wave splitting phenomenon occurs, and a fast transverse wave polarized in parallel with the crack trend and a slow transverse wave polarized in perpendicular to the crack trend are formed. Because the fast and slow transverse waves have difference in speed, the crack attribute can be identified by using the difference between the fast and slow transverse waves. The polarization directions of the fast and slow transverse waves reflect the trend of the crack, the travel time difference of the fast and slow transverse waves reflects the density of the crack, and the larger the time difference is, the larger the density of the crack is. Therefore, the research on the phenomenon of the fast and slow shear wave splitting becomes one of the most direct and effective methods for researching the crack direction and the development degree thereof.
At present, there are many methods for determining fracture parameters by shear wave splitting in the prior art. From the viewpoint of data requirements, the method can be divided into a multi-source method and a single-source method:
1) the multi-source method is represented by Alford rotation and is suitable for four-component VSP data, nine-component data and the like excited by a shear wave seismic source, wherein the VSP refers to a vertical seismic section;
2) single source method (cross correlation method; a parametric inversion method, a maximum energy ratio method, an orthogonal basis rotation method and the like) is suitable for the VSP data excited by the P wave seismic source and received by three components. Because the cost of exciting the shear wave seismic source is high, VSP data which are contacted by people in reality are mostly excited by the P-wave seismic source, and therefore, the research of the conversion shear wave splitting method excited by the P-wave seismic source has higher practicability.
At present, the maximum energy ratio method excited by a P-wave seismic source is popular. However, the method can only calculate the azimuth angle of the crack, and cannot directly obtain the time difference of the fast and slow transverse waves, and the fast and slow transverse wave splitting time difference can be obtained only by further analyzing and calculating the split fast and slow waves through other methods.
Disclosure of Invention
Aiming at the problems, the invention provides a new and improved crack prediction method based on a maximum energy ratio method. The method comprises the following steps:
s10, rotating the horizontal components X and Y of the vertical seismic profile data to obtain a radial component R and a transverse component T after rotation;
s20, performing wave field separation on the rotated component to obtain a separated downlink component, and picking up a group of converted wave fields with shear wave splitting on the downlink component;
s30, selecting a demodulator probe at a target depth, and executing the following steps on each seismic source data received by the demodulator probe to obtain the fracture azimuth and density parameters of the target depth:
s30.1, taking a time window including the converted wave picked up in the step S20 on the downstream component, separating the fast and slow waves of the component data in the time window, calculating the azimuth-time difference spectrum based on the improved maximum energy ratio calculation formula scanning,
s30.2, picking up the azimuth and the fast-slow transverse wave time difference of the crack relative to the measuring line from the azimuth-time difference spectrum, and calculating the natural azimuth and the density of the crack;
and S40, repeating the step S30 for the wave detection points at other target depths until fracture azimuth and density parameters of all the target depths are obtained.
According to an embodiment of the present invention, the improved maximum energy ratio calculation formula is
In the formula, ER (α, t)n) Is the scanning energy, tnIs the difference between fast and slow transverse wave, S1(α, k) is fast transverse wave recording, S2(α, k) is slow transverse wave recording, wnIs the time window size, and k is the sampling point within the time window.
According to an embodiment of the invention, the above step S30.1 comprises the following small steps:
① selecting a same time window on the downlink component, wherein the time window size requirement can include the converted wave picked up in step S20;
② scans an azimuth angle α, and fast and slow transverse wave separation is carried out on downlink component data in a time window by the formula (1), and fast transverse wave records S1(α, t) and slow transverse wave records S2(α, t) are calculated;
in the formula, t is sampling time of a sample point in a time window; r (t) is radial component data, t (t) is transverse component data;
③ sweep a time difference tnCalculating and saving the scan energy ER (α, t) from the improved maximum energy ratio calculationn)
In the formula, ER (α, t)n) Is the scanning energy, tnIs the difference between fast and slow transverse wave, S1(α, k) is fast transverse wave recording, S2(α, k) is slow transverse wave recording, wnIs the size of the time window, k is the sampling point in the time window;
④ order tn＝tn+ Δ t, repeat step ③ until tn＝wnFinishing; wherein, delta t is the time difference scanning step length;
⑤, α is α + delta α, and the steps ② to ④ are repeated until α is pi/2, wherein delta α is the angle scanning step;
⑥ according to each ER calculated (α, t)n) And manufacturing an azimuth-time difference energy spectrogram.
According to the embodiment of the invention, the value of the azimuth α is-pi/2 ≦ α ≦ pi/2.
According to an embodiment of the invention, the time difference t isnHas a value range of 0 to tn＜wn。
According to an embodiment of the invention, the above step S30.2 comprises the following minor steps:
① picking the maximum energy value from the azimuth-time difference energy spectrogram, wherein the angle corresponding to the maximum energy value is the azimuth angle α of the crack relative to the measuring line, and the time difference tnNamely the time difference of the fast and slow transverse waves;
② calculating the natural azimuth angle β ═ theta + α, where β ∈ [0, pi), theta is the azimuth angle of the connecting line of the shot point and the demodulator probe, and theta ∈ [0, 2 pi);
③ the fracture density e is calculated according to the following equation (3):
e≈γ/1.1 (3)
wherein,ts1travel time of a fast transverse wave picked up by a crack bottom interface; t is tnThe time difference of the fast and slow transverse waves.
According to an embodiment of the present invention, it may be 0 ° in the eastern direction.
According to the embodiment of the invention, the counterclockwise rotation direction can be taken as the direction of increasing azimuth angle.
According to an embodiment of the present invention, the step S30 may further include a step S30.3 of counting the distribution of all fracture orientations and density parameters of the demodulator probe at the target depth by using a chart.
According to the embodiment of the invention, the rose diagram can be utilized to count all the crack azimuth distributions of the wave detection points at the target depth; and counting all density parameter distributions of the demodulator probe at the target depth by using the bar graph.
One or more embodiments of the present invention may have the following advantages over the prior art: the method is based on the shear wave splitting crack prediction principle, improves the conventional maximum energy ratio shear wave splitting crack prediction method, can simultaneously obtain the crack azimuth angle and the splitting time difference of the fast and slow shear waves, overcomes the defect that the crack density parameter cannot be directly obtained in the original method, and achieves the aim of conveniently and accurately predicting the crack parameter through one-time calculation.
Drawings
The accompanying drawings, which are included to provide a further understanding of the invention and are incorporated in and constitute a part of this specification, illustrate embodiments of the invention and together with the description serve to explain the principles of the invention and not to limit the invention. In the drawings:
FIG. 1 is a flow chart of the operation of a fracture prediction method employed in an embodiment of the present invention;
FIG. 2a is a schematic illustration of the relationship between the natural orientation of the fracture and the inline orientation;
FIG. 2b is a schematic illustration of the relationship between the natural orientation and the relative orientation of the fracture;
FIG. 3 is a schematic illustration of a fracture medium model analyzed in an embodiment of the present invention;
FIG. 4 is a schematic diagram of an azimuthal anisotropy forward modeling acquisition scheme in an embodiment of the present invention;
FIGS. 5 a-5 c are schematic illustrations of three component recordings X, Y, Z for a simulated 0 azimuth line angle in an embodiment of the invention;
FIGS. 6 a-6 b are separated downgoing R, T component wavefields in an embodiment of the present invention;
7 a-7 b are R, T component common detector gather records for a time window of converted waves at a target depth of 600 meters in an embodiment of the present invention;
FIG. 8 is a polarization plot of the original R, T component at a target depth of 600 meters in an embodiment of the present invention;
FIG. 9 is a calculated azimuth-time difference spectrum from the modified maximum energy ratio calculation at a target depth of 600 meters in an embodiment of the present invention;
FIG. 10 is a graph of S1, S2 polarization after shear wave splitting at a target depth of 600 meters in an embodiment of the invention;
11 a-11 b are pure fast and slow shear wave recordings after shear wave splitting at a target depth of 600 meters in an embodiment of the invention;
FIG. 12 is a table of computed fracture azimuth, fast and slow shear wave delay and density parameters at various azimuth records for a target depth of 600 meters in an embodiment of the invention;
FIG. 13 is a statistical rose of fracture orientations obtained in an example of the invention;
FIG. 14 is a statistical bar graph of fracture density obtained in an example of the invention.
Detailed Description
In order to make the objects, technical solutions and advantages of the present invention more apparent, the present invention is further described in detail below with reference to the accompanying drawings.
FIG. 1 is a flow chart of the operation of a fracture prediction method employed in an embodiment of the present invention. The figure includes the main steps of the crack prediction method, which may be increased or decreased according to the specific requirements at the time of implementation.
S110, the horizontal components X and Y of the VSP data are rotated to obtain a radial component R and a lateral component T (hereinafter, may be referred to as R component and T component).
And S120, performing wave field separation on the R component and the T component to obtain a separated downlink R component and a separated T component, and picking up a group of converted wave fields with shear wave splitting on the downlink R component or the T component.
S130, for a certain shot data received by a wave detection point at a target depth, a time window including the converted wave picked up in the step S120 is taken from the downlink R component and the downlink T component, and the azimuth-time difference spectrum is scanned and calculated by using the improved maximum energy ratio algorithm on the data in the time window.
S140, picking up the azimuth and the time difference of the fast and slow waves of the crack relative to the measuring line from the azimuth-time difference spectrum, and calculating the natural azimuth and the density of the crack.
S150, repeating steps S130 and S140 for data of other shots received by the demodulator probes at the target depth of step S130.
And S160, drawing a rose diagram according to all fracture azimuth angles at a certain target depth obtained in the step S150, and drawing a bar diagram for fracture density to complete the statistics of azimuth angles and density parameters.
S170, repeating the steps S130-160 for the wave detection points at other target depths until the fracture azimuth and the density parameters of all the target depths are obtained.
The steps are explained in detail below. Wherein:
steps 110 and 120 pertain to conventional processing of vertical seismic profile data in the seismic arts and are not described in detail herein.
Step S130 further includes:
① selecting a same time window on the downlink component, the time window size wnThe converted wave picked up in step S200 is to be fully included.
② scans an azimuth angle α, -pi/2 ≦ α < pi/2, typically scanning from-pi/2, then fast and slow shear wave separation is performed on the downstream component data within the time window by equation (1) below, and fast shear wave records S1(α, t) and slow shear wave records S2(α, t) are calculated.
T in the formula is sampling time of a sample point in a time window; r (t) is radial component data, and t (t) is transverse component data.
③ sweep a time difference tn，0≤tn＜wnThen, the scan energy ER (α, t) is calculated by the following improved maximum energy ratio calculation equation (2)n) And the results are saved.
In the formula, ER (α, t)n) Is the scanning energy, tnIs the difference between fast and slow transverse wave, S1(α, k) is fast transverse wave recording, S2(α, k) is slow transverse wave recording, wnIs the time window size, and k is the sampling point within the time window.
④ order tn＝tn+ Δ t (Δ t is the time difference scanning step), and step ③ is repeated until tn＝wnAnd (6) ending.
⑤, make α equal to α + Δ α (Δ α is the angular scanning step), repeat steps ② to ④ until α equal to pi/2.
⑥ comparing each ER (α, t) calculated in step ③n) And (3) endowing different color depths according to the energy intensity to manufacture an azimuth-time difference energy spectrogram (as shown in figure 9). Of course, the azimuth-moveout energy spectrum may also not be limited to this representation.
Step S140 further includes:
① picking the maximum energy value from the azimuth-time difference energy spectrogram, wherein the angle corresponding to the maximum energy value is the azimuth angle α of the crack relative to the measuring line, and the time difference tnNamely the fast and slow transverse wave time difference.
②, calculating the natural azimuth angle β ═ theta + α, wherein β ∈ [0, pi ], θ ∈ [0, 2 pi) are the azimuth angle of the connecting line (R component) of the shot point and the demodulator probe.
③ the fracture density was calculated according to equation (3) below:
e≈γ/1.1 (3)
wherein,ts1and ts2The travel time of fast and slow transverse waves picked up by a crack bottom interface; t is tnThe time difference of the fast and slow transverse waves.
First embodiment
Fig. 2 a-2 b show schematic diagrams of the relationship between the natural orientation, the relative orientation and the inline orientation of a crack. The relationship between radial component R, transverse component T and line orientation obtained by horizontal component rotation is shown in fig. 2 a; the relationship between the natural orientation and the relative orientation of the fracture is shown in fig. 2 b. In the figure, N, E denotes the north and east directions, respectively.
The fracture prediction method of the present invention will be described below by taking a fracture medium model shown in fig. 3 as an example. The model has four layers of medium, wherein the second layer and the fourth layer are HTI crack anisotropic layers, and the model and medium parameters are shown in FIG. 3. In the figure, Vp is the longitudinal wave velocity, Vs is the transverse wave velocity, ρ is the density, and ∈ γ, and δ are Thomsen parameters.
FIG. 4 is a schematic diagram of an azimuthal anisotropy forward simulation acquisition scheme. As can be seen from the figure, taking a wellhead as a center, taking an azimuth at intervals of 15 degrees, deploying shot points on 24 azimuths in total, wherein the offset distance between the shot points and the wellhead is 500 meters; the receiving points are distributed at the position with the depth of 100-2000 meters in the well and are placed every 10 meters.
Fig. 5 a-5 c are plots of three components X, Y, Z for a simulated 0 deg. inline azimuth (true east, counterclockwise). Wherein P-waves are observed for each layer at X, Z components; on the Y component, no P-wave is received in the isotropic layers (1, 3 layers) and P-waves are received in the anisotropic layers (2, 4). In summary, S-waves (hereinafter, referred to as converted waves) converted by P-waves excited by a seismic source at the formation boundary surfaces are observed in the X, Y, Z components, and splitting phenomena occur in the transverse waves in the anisotropic layers (2 and 4 layers), so that, for an up-traveling wave, reflected P-waves and converted wave projections are present in three components, wherein the Y-component is dominated by the up-traveling converted waves and the Z-component is dominated by the up-traveling P-waves.
FIGS. 6 a-6 b are the separated down-going R, T component wavefields. Included in this wavefield are the down-going P-wave, the second-tier HTI converted wave, the third-tier isotropic layer converted wave, and the fourth-tier HTI converted wave. The dashed line indicates the second HTI layer converted wave, which is the shear wave to be analyzed.
In order to verify the correctness of the crack prediction method proposed by the invention, crack parameters (azimuth and density parameters) of a 600-meter target depth detection point of a second-layer HTI medium are respectively analyzed.
7 a-7 b are R, T component coretective wave point gather records for a time window of converted waves at a target depth of 600 meters. The R component in FIG. 7a and the T component gather in FIG. 7b are both "sinusoidal" transformed, with the records in the gather going from 0 to 245. Wherein travel times are minimal at parallel fractures (50 ° and 230 °); the energy of the R component is maximum when parallel cracks are formed and is minimum when the cracks are vertical (140 degrees and 320 degrees); the T component undergoes a change in polarity both in parallel and perpendicular fractures.
Fig. 8 is a polarization plot of the original R, T component at a target depth of 600 meters (R component on the horizontal axis and T component on the vertical axis). As can be seen from the figure, each polarization diagram has two sets of two polarization directions that are nearly linearly polarized and approximately perpendicular. Wherein, the larger energy is the polarization direction of the fast transverse wave, and the smaller energy is the polarization direction of the slow transverse wave.
Fig. 9 is an azimuth-time difference spectrum (angle on the horizontal axis and time difference on the vertical axis) calculated by the improved maximum energy ratio calculation formula at a target depth of 600 meters. The maximum energy value on the azimuth-time difference spectrum corresponds to the included angle direction of the crack and the measuring line.
Fig. 10 is a graph of S1, S2 polarization after shear wave splitting at a target depth of 600 meters (S1 waves on the horizontal axis and S2 waves on the vertical axis). After the transverse wave splitting, the fast transverse wave S1 is decomposed to the X-axis direction, the slow transverse wave S2 is decomposed to the Y-axis direction, and the polarization directions of the fast transverse wave and the slow transverse wave are approximately orthogonal.
11 a-11 b are pure fast and slow shear wave recordings after shear wave splitting at a target depth of 600 meters. It can be seen that the fast and slow waves after splitting have basically consistent travel time forms and similar waveforms, and meanwhile, the fast and transverse waves have obvious arrival time differences.
FIG. 12 is a table of the calculated fracture azimuth, fast and slow shear wave delay and density parameters at various azimuth records for a 600 meter target depth. By counting the data in this table, a statistical rose plot of the fracture orientations shown in fig. 13 and a statistical bar plot of the fracture densities shown in fig. 14 are finally obtained. As can be seen from the orientation rose diagram of fig. 13, the crack orientations are all approximately 50 °, and the average value of the statistical crack orientations is 51.04 °. This indicates that the predicted crack orientation is correct and with high accuracy. From the density bar graph of fig. 14, it can be seen that the average value of the crack density is 0.16, which is substantially close to the theoretically calculated crack density of 0.17. This indicates that the predicted crack density is correct and with high accuracy.
The embodiment strongly verifies that the crack prediction method provided by the invention is effective, the method makes up the defects that the maximum energy ratio method in the prior art cannot directly obtain the splitting time difference and the azimuth of the fast and slow transverse waves and has multi-solution property, and the method has good guiding significance for practical engineering exploration.
The above description is only an embodiment of the present invention, and the protection scope of the present invention is not limited thereto, and any person skilled in the art should modify or replace the present invention within the technical specification of the present invention.
Claims (9)
1. A crack prediction method based on a maximum energy ratio method comprises the following steps:
s10, rotating the horizontal components X and Y of the vertical seismic profile data to obtain a radial component R and a transverse component T after rotation;
s20, performing wave field separation on the rotated component to obtain a separated downlink component, and picking up a group of converted wave fields with shear wave splitting on the downlink component;
s30, selecting a demodulator probe at a target depth, and executing the following steps on each seismic source data received by the demodulator probe to obtain the fracture azimuth and density parameters of the target depth:
s30.1, taking a time window including the converted wave picked up in the step S20 on the downstream component, separating the fast and slow waves of the component data in the time window, calculating the azimuth-time difference spectrum based on the improved maximum energy ratio calculation formula scanning,
s30.2, picking up the azimuth and the fast-slow transverse wave time difference of the crack relative to the measuring line from the azimuth-time difference spectrum, and calculating the natural azimuth and the density of the crack;
s40, repeating the step S30 for the wave detection points at other target depths until the fracture azimuth and density parameters of all the target depths are obtained;
wherein the improved maximum energy ratio is calculated as
In the formula, ER (α, t)n) Is the scanning energy, tnIs the difference between fast and slow transverse wave, S1(α, k) is fast transverse wave recording, S2(α, k) is slow transverse wave recording, wnIs the time window size, k is the sample point within the time window, α is the azimuth.
2. Crack prediction method according to claim 1, characterised in that the step S30.1 comprises the following sub-steps:
① selecting a same time window on the downlink component, wherein the time window size requirement can include the converted wave picked up in step S20;
② scans an azimuth angle α, and fast and slow transverse wave separation is carried out on downlink component data in a time window by the formula (1), and fast transverse wave records S1(α, t) and slow transverse wave records S2(α, t) are calculated;
in the formula, t is sampling time of a sample point in a time window; r (t) is radial component data, t (t) is transverse component data;
③ scan oneA time difference tnCalculating and saving the scan energy ER (α, t) from the improved maximum energy ratio calculationn)
In the formula, ER (α, t)n) Is the scanning energy, tnIs the difference between fast and slow transverse wave, S1(α, k) is fast transverse wave recording, S2(α, k) is slow transverse wave recording, wnIs the size of the time window, k is the sampling point in the time window;
④ order tn＝tn+ Δ t, repeat step ③ until tn＝wnFinishing; wherein, delta t is the time difference scanning step length;
⑤, α is α + delta α, and the steps ② to ④ are repeated until α is pi/2, wherein delta α is the angle scanning step;
⑥ according to each ER calculated (α, t)n) And manufacturing an azimuth-time difference energy spectrogram.
3. The crack prediction method according to claim 2, characterized in that:
the value range of the azimuth angle α is-pi/2 is not less than α and is less than pi/2.
4. The crack prediction method according to claim 2, characterized in that:
said time difference tnHas a value range of 0 to tn＜wn。
5. Crack prediction method according to claim 1, characterised in that the step S30.2 comprises the following sub-steps:
① picking the maximum energy value from the azimuth-time difference energy spectrogram, wherein the angle corresponding to the maximum energy value is the azimuth angle α of the crack relative to the measuring line, and the time difference tnNamely the time difference of the fast and slow transverse waves;
② calculating the natural azimuth angle β ═ theta + α, where β ∈ [0, pi), theta is the azimuth angle of the connecting line of the shot point and the demodulator probe, and theta ∈ [0, 2 pi);
③ the fracture density e is calculated according to the following equation (3):
e≈γ/1.1 (3)
wherein,ts1travel time of a fast transverse wave picked up by a crack bottom interface; t is tnThe time difference of the fast and slow transverse waves.
6. The crack prediction method of claim 5, wherein:
with the east direction being 0.
7. The crack prediction method of claim 5, wherein:
the counterclockwise rotation direction is taken as the direction of increasing azimuth angle.
8. The fracture prediction method of claim 1, wherein the step S30 further comprises a step S30.3 of using a graph to count the distribution of all fracture orientation and density parameters of the demodulator probe at the target depth.
9. The crack prediction method of claim 8, wherein:
counting all crack azimuth distributions of the wave detection points of the target depth by using a rose diagram; and counting all density parameter distributions of the demodulator probe at the target depth by using the bar graph.
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| CN108229028B (en) * | 2018-01-05 | 2021-03-02 | 东北大学 | Method for generating weighted seismic network based on maximum energy ratio |
| CN109799529A (en) * | 2019-01-31 | 2019-05-24 | 河海大学 | A kind of shear wave splitting VSP crack prediction method based on cross-correlation |
| CN109992910B (en) * | 2019-04-09 | 2023-01-13 | 山东交通学院 | Energy spectrum density calculation method and application for mass data |
| CN112444871B (en) * | 2019-08-30 | 2023-07-04 | 中国石油化工股份有限公司 | Quantitative analysis method and equipment for crack spacing based on scattered wave seismic response characteristics |
| CN112649851A (en) * | 2019-10-09 | 2021-04-13 | 中国石油化工股份有限公司 | Shear wave splitting vertical seismic profile crack prediction method and system |
| CN113009572B (en) * | 2021-02-23 | 2022-07-01 | 成都理工大学 | A method for predicting fracture azimuth based on shear wave polarization analysis |
| CN116908909B (en) * | 2023-07-07 | 2023-12-12 | 成都理工大学 | Fast and slow transverse wave separation method based on three-parameter scanning |
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