CN112255682B - Q body modeling technical method based on VSP data - Google Patents
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Abstract
The invention discloses a Q body modeling technical method based on VSP data, which belongs to the technical field of oilfield development, and comprises the steps of selecting VSP data of a target area, and calculating the Q value of stratum of the target area by utilizing the VSP data; selecting a final prestack migration velocity field and performing interpolation processing; converting the pre-stack migration velocity field after interpolation processing into an earthquake channel, taking the wellhead channel velocity as a standard value, taking the ratio of other channel velocities to wellhead channel velocity as a velocity model scale factor, and establishing a three-dimensional model of the velocity model scale factor of the stratum in the target area; and (3) utilizing the consistency of the change condition of the scale factor of the speed model of the stratum in the target area and the change condition of the Q value of the stratum in the target area to horizontally extrapolate the Q value of the stratum in the target area, thereby establishing a three-dimensional Q body model. The invention has the characteristics of high modeling speed and stable model, and has positive effect on pushing well-ground combined data processing.
Description
Technical Field
The invention relates to the technical field of oilfield development, in particular to a rapid Q body modeling technical method based on VSP data.
Background
Due to irreversible frictional losses and heat losses of the earth medium, the seismic waves undergo absorption decay during their propagation into the subsurface, the high frequency content of the waves decreasing as the propagation path increases. Therefore, the method compensates the absorption attenuation of the seismic waves, increases the high-frequency components of the seismic data, protects the low-frequency components, expands the absolute bandwidth and the relative bandwidth of the data, and is a key for improving the resolution of the seismic data.
In conventional ground seismic data processing, the main means for improving resolution is various deconvolution methods, which have been widely used in production. However, none of these methods take into account the effects of absorption and attenuation of the seismic signals in the frequency domain, thus limiting further resolution improvements.
VSP (VerticalSeismicProfiling), vertical seismic section, is a seismic observation method. VSP data only passes through the low-speed zone once, so that absorption and attenuation of the low-speed zone to high-frequency components of the seismic signals are reduced. The frequency of the received seismic signals is higher, the frequency band is wider, the signal-to-noise ratio of effective waves is improved, the change of the kinematic characteristics (time-distance relation, layer speed and the like) and the change of the dynamic characteristics (amplitude, frequency, phase, waveform and the like) of the waves are more obvious and more sensitive, and the method has obvious advantages in the aspect of researching the attenuation rule of the seismic waves.
And (3) performing frequency and energy compensation on the ground seismic data by utilizing the attribute and high-frequency information obtained by the VSP, and improving the longitudinal resolution of the three-dimensional seismic data. The work can not only effectively improve the precision of oil-gas seismic exploration, but also expand the application range of a large amount of VSP data. However, when the stratum is horizontal, the Q (seismic wave attenuation quality factor) value is not greatly changed transversely, and the horizontal extrapolation can be carried out by utilizing the Q value of single well VSP data; when the stratum changes greatly, a Q value curve is utilized to be inconsistent with the geological rule, and a three-dimensional Q body model needs to be established.
Disclosure of Invention
The invention aims to provide a Q body modeling technical method based on VSP data, which accords with the geological rule of a target area, aiming at the defects of the prior art.
The technical scheme adopted by the invention is as follows.
The Q body modeling technical method based on VSP data is characterized by comprising the following steps:
step 1: selecting VSP data of the target area, and calculating the Q value of the stratum beside the well by utilizing the VSP data;
step 2: selecting a prestack migration velocity field; the prestack migration velocity field can be a prestack time migration velocity field or a prestack depth migration velocity field;
step 3: interpolation processing is carried out on the selected prestack migration velocity field (time domain or depth domain);
step 4: converting the pre-stack migration velocity field (time domain or depth domain) after interpolation processing into an earthquake channel, taking the wellhead channel velocity as a standard, taking the ratio of other channel velocities to wellhead channel velocity as a velocity model scale factor, and establishing a three-dimensional model of the velocity model scale factor of the stratum in the target area;
step 5: and (3) utilizing the consistency of the change condition of the scale factor of the speed model of the stratum in the target area and the change condition of the Q value of the stratum in the target area to horizontally extrapolate the Q value of the stratum in the target area, thereby establishing a three-dimensional Q body model.
In the step 1, the Q value of the stratum beside the well of the target area is calculated by using the descending wavefield of the VSP data.
As a preferable technical scheme, the method for calculating the Q value of the stratum is as follows:
q is defined as the ratio of the original stored elastic wave energy to the energy consumed after the wave propagates a wavelength distance, i.e
Wherein: e (E) 0 Is to store elastic wave energy originally; Δe is the energy consumed; q is the seismic attenuation quality factor.
Setting a stratum model, wherein the thickness is delta H, the speed is V, the absorption coefficient of seismic waves is alpha, and the quality factor is Q; at t 1 And t 2 The waveforms of direct waves reaching the top and bottom ends at the moment are W respectively 1 And W is equal to 2 After eliminating the influence of spherical diffusion, let the spectrum of the initial wavelet be S0 (f), and the spectrums corresponding to W1 and W2 are respectively:
wherein: α (f) is an absorption coefficient expressed by the frequency f as an argument, and e is a natural constant.
A plurality of core tests prove that when the frequency is in the range of a few Hz to a few thousand Hz, the absorption coefficient alpha is a function proportional to the frequency and has a relation shown in a formula 4 with Q;
substituting formula 4 into formula 1-formula 3, taking the natural logarithm of the spectrum ratio to obtain:
and (3) differentiating to obtain:
order the
Finally obtain
Preferably, interpolation is performed on the selected prestack migration velocity field (time domain or depth domain) to match the spatial density of the prestack migration velocity field (time domain or depth domain) with the density of the seismic section.
According to the method, the wellhead speed is used as a standard, the ratio of other track speeds to wellhead speed is used as a speed model scaling factor, and a three-dimensional model of the speed model scaling factor of the stratum in the target area is built.
In step 4, the method for calculating the speed model scale factor is as follows:
assuming a velocity field of the formation in the target zone of V i,j (i=1, 2, …, m; j=1, 2, …, n) at a wellhead speed V o,o The method comprises the steps of carrying out a first treatment on the surface of the The velocity model scale factor formula is as follows:
Y i,j ＝V i,j /V o,o ；
wherein: i is the vertical line number; j is the transverse line number; m and n are positive integers.
In step 5, the Q value of each formation around the well is obtained by multiplying the Q value of the wellhead formation by the velocity model scale factors of the different positions of each formation around the well.
In step 5, as an optimal technical scheme, the formula adopted for the rapid Q-body model calculation is as follows:
Q i,j ＝Q o,o Y i,j (i＝1,2,…,m；j＝1,2,…,n)；
wherein: q (Q) i,j Is the Q value curve of the stratum of the target area; q (Q) o,o Is a well mouth channel Q value curve; y is Y i,j Is a velocity model scaling factor; i is the vertical line number; j is the transverse line number; n is a positive integer.
The conventional Q body model manually explains geological horizons through geological staff, fills Q values in different horizons, and compared with the method, the method occupies a large amount of manual workload and influences the working efficiency. The beneficial effects of the invention are as follows: the invention utilizes VSP data to extract accurate Q value as standard value, and based on three-dimensional velocity field of ground earthquake, the invention researches and establishes velocity model scale factor, and obtains three-dimensional Q body model through velocity model scale factor and Q value. The Q body modeling technology based on VSP data has the characteristics of high modeling speed and stable model, and has positive effects on pushing well-ground combined data processing.
Drawings
FIG. 1 is a VSP data downgoing wavefield.
FIG. 2 is a graph showing the calculated Q-factor from the downstream wavefield of the VSP data shown in FIG. 1.
Fig. 3 is a velocity vs. schematic diagram of extraction.
Fig. 4 is a velocity versus interpolated velocity field profile (longitudinal).
FIG. 5 is a calculated velocity model scale factor profile.
Fig. 6 is a longitudinal sectional view of the obtained Q-body model.
Fig. 7 is a transverse cross-sectional view of the resulting Q-body model.
Fig. 8 is a time slice cross section of the obtained Q-body model.
Detailed Description
The following description of the embodiments of the present invention will be made clearly and fully with reference to the accompanying drawings, in which it is evident that the embodiments described are only some, but not all embodiments of the invention. All other embodiments, which can be made by those skilled in the art based on the embodiments of the invention without making any inventive effort, are intended to be within the scope of the invention. Additionally, the scope of the invention should not be limited to the specific steps or parameters described below. The invention is not limited to model data, can process the actual data, and has wide adaptability.
The Q body modeling technical method based on VSP data is characterized by comprising the following steps:
step 1: selecting VSP data of the target area, and calculating the Q value of the stratum of the target area by utilizing the VSP data;
step 2: selecting a final prestack migration velocity field (time domain velocity vs. format);
step 3: interpolation processing is carried out on the selected prestack migration velocity field (time domain), and the prestack migration velocity field (time domain) after interpolation is obtained; the velocity field spatial sampling density is consistent with the ground seismic spatial sampling density.
Step 4: as shown in fig. 5, the pre-stack migration velocity field (time domain) after interpolation processing is converted into a seismic trace, the wellhead trace velocity is used as a standard, the ratio of other trace velocities to wellhead trace velocity is used as a velocity model scale factor, and a three-dimensional model of the velocity model scale factor of the stratum in the target area is established.
Step 5: and (3) utilizing the consistency of the change condition of the scale factor of the speed model of the stratum in the target area and the change condition of the Q value of the stratum in the target area to horizontally extrapolate the Q value of the stratum in the target area, thereby establishing a three-dimensional Q body model. As shown in fig. 6-8, the Q-body is sliced in different directions, fig. 6 is a longitudinal Q-body section, fig. 7 is a transverse Q-body section, and fig. 8 is a Q-body time slice section.
In step 1, the Q value of the stratum at different depths beside the well is calculated by using the descending wavefield of the VSP data. As shown in FIG. 1, the initial arrival wave of the VSP data is at a low speed and the signal to noise ratio of the down going wave field is high. The calculated Q value curve is shown in fig. 2. The Q-value curve calculated in fig. 2 represents a Q-value curve directly calculated using a downstream wavefield, and the logarithmic (calculated Q-value) curve represents a trend line of the Q-value curve fitted using logarithms, with the ordinate being depth and the abscissa being Q-value. The Q value is 49.5 when the depth is 500m, 176 when the depth is 2000m, the Q value is gradually increased from shallow to deep, and the change rule of the Q value is met.
The method for calculating the Q value of the stratum is as follows:
q is defined as the ratio of the originally stored elastic wave energy to the energy consumed after the wave propagates a wavelength distance (Aki and Richard, 1980), i.e.
Wherein: e (E) 0 Is to store elastic wave energy originally; Δe is the energy consumed.
Setting a stratum model, wherein the thickness is delta H, the speed is V, the absorption coefficient of seismic waves is alpha, and the quality factor is Q; at t 1 And t 2 The waveforms of direct waves reaching the top and bottom ends at the moment are W respectively 1 And W is equal to 2 After eliminating the influence of spherical diffusion, let the spectrum of the initial wavelet be S0 (f), then W 1 And W is equal to 2 The corresponding frequency spectrums are respectively:
wherein: α (f) is an absorption coefficient expressed by the frequency f as an argument, and e is a natural number.
A number of core tests have shown that when the frequency is in the range of a few Hz to a few thousand Hz, the absorption coefficient alpha is a function proportional to the frequency and has a value of Q
Is a relationship of (3).
Substituting formula 4 into formula 1-formula 3, taking the natural logarithm of the spectrum ratio to obtain:
and (3) differentiating to obtain:
order the
Finally obtain
When interpolation processing is performed on the selected prestack migration velocity field (time domain or depth domain), a plurality of prestack depth migration velocity pairs are first selected, and then the prestack migration velocity field (time domain or depth domain) established by the velocity pairs is interpolated, as shown in fig. 3.
As shown in fig. 4, the spatial density of the interpolated prestack migration velocity field (time domain or depth domain) is consistent with the density of the seismic profile. From the graph, the prestack migration velocity field (time domain) changes smoothly, the velocity increases with time, the left velocity is low, and the right velocity is high
And taking the wellhead track speed as a standard, taking the ratio of other track speeds to the wellhead track speed as a speed model scaling factor, and establishing a three-dimensional model of the speed model scaling factor of the stratum in the target area.
In step 4, the method for calculating the speed model scale factor is as follows:
assuming a velocity field of the formation in the target zone of V i,j (i=1, 2, …, m; j=1, 2, …, n) at a wellhead speed V o,o The method comprises the steps of carrying out a first treatment on the surface of the The velocity model scale factor formula is as follows: ,
Y i,j ＝V i,j /V o,o ；
wherein: i is the vertical line number; j is the transverse line number; m and n are positive integers.
As shown in fig. 5, it can be seen from the figure that the speed scale factor is small at the left side of the wellhead and the speed scale factor is large at the right side of the wellhead, which is consistent with the change rule of the speed model;
in step 5, the Q value of each stratum around the well logging is obtained by multiplying the Q value of the stratum at the wellhead by the speed model scale factors of different positions of each stratum around the well logging.
In step 5, the formula adopted in the calculation of the fast Q-body model is as follows:
Q i,j ＝Q o,o Y i,j (i＝1,2,…,m；j＝1,2,…,n)；
wherein: q (Q) i,j Is the Q value curve of the stratum of the target area; q (Q) o,o Is a well mouth channel Q value curve; i is the vertical line number; j is the transverse line number; n is a positive integer.
Fig. 6-8 show the Q body in different directions, and fig. 6 shows the Q body in longitudinal direction, the Q body has obvious change in transverse direction, the Q value on the left side is small, and the Q value on the right side is large. Fig. 7 shows a transverse Q-body cross-section with small Q-body variations, substantially in the form of horizontal layers. Fig. 8 shows a time slice section of the Q body, and it can be seen from the section that the Q value varies greatly in the longitudinal direction and slightly in the transverse direction, which is consistent with the reaction rules of fig. 6 and 7.
The invention utilizes VSP data to extract accurate Q value as standard value, and based on three-dimensional velocity field of ground earthquake, the invention researches and establishes velocity model scale factor, and obtains three-dimensional Q body model through velocity model scale factor and Q value. The Q body modeling technology based on VSP data has the characteristics of high modeling speed and stable model. The method is simple and practical, stable in algorithm and high in calculation efficiency, and the obtained three-dimensional Q body model is high in accuracy and has positive effects on pushing well-ground combined data processing. The above-mentioned embodiments are only for understanding the present invention, and are not intended to limit the technical solutions described in the present invention, and a person skilled in the relevant art may make various changes or modifications based on the technical solutions described in the claims, and all equivalent changes or modifications are intended to be included in the scope of the claims of the present invention. The present invention is not described in detail in the present application, and is well known to those skilled in the art.
Claims (7)
1. The Q body modeling technical method based on VSP data is characterized by comprising the following steps:
step 1: selecting VSP data of the target area, and calculating the Q value of the stratum beside the well by utilizing the VSP data;
step 2: selecting a final prestack migration velocity field; the prestack migration velocity field is a prestack time migration velocity field or a prestack depth migration velocity field;
step 3: interpolation processing is carried out on the selected prestack migration velocity field;
step 4: converting the pre-stack migration velocity field after interpolation processing into an earthquake channel, taking the wellhead channel velocity as a standard, taking the ratio of other channel velocities to wellhead channel velocity as a velocity model scale factor, and establishing a three-dimensional model of the velocity model scale factor of the stratum in the target area;
step 5: and (3) utilizing the consistency of the change condition of the scale factor of the speed model of the stratum in the target area and the change condition of the Q value of the stratum in the target area to horizontally extrapolate the Q value of the stratum in the target area, thereby establishing a three-dimensional Q body model.
2. The VSP profile-based Q-volume modeling technique of claim 1, wherein: in step 1, the Q value of the stratum beside the well in the target area is calculated by using the descending wavefield of the VSP data.
3. The VSP profile-based Q-volume modeling technique of claim 1, wherein the formation Q-value is calculated by:
q is defined as the ratio of the original stored elastic wave energy to the energy consumed after the wave propagates a wavelength distance, i.e
Wherein: e (E) 0 Is to store elastic wave energy originally; Δe is the energy consumed; q is the seismic wave attenuation quality factor;
setting a stratum model, wherein the thickness is delta H, the speed is V, the absorption coefficient of a seismic wave is alpha, and the attenuation quality factor of the seismic wave is Q; at t 1 And t 2 The waveforms of direct waves reaching the top and bottom ends at the moment are W respectively 1 And W is equal to 2 After eliminating the influence of spherical diffusion, the spectrum of the initial wavelet is S 0 (f) W is then 1 And W is equal to 2 The corresponding frequency spectrums are respectively:
wherein: α (f) is an absorption function expressed by the frequency f as an argument, and e is a natural constant;
a plurality of core tests prove that when the frequency is in the range of a few Hz to a few thousand Hz, the absorption coefficient alpha is a function proportional to the frequency and has a relation shown in a formula 4 with Q;
substituting formula 4 into formula 1-formula 3, taking the natural logarithm of the spectrum ratio to obtain:
and (3) differentiating to obtain:
order the
Finally obtain
Wherein: Δt is the time sampling interval.
4. The VSP profile-based Q-volume modeling technique of claim 1, wherein: interpolation processing is carried out on the selected prestack migration velocity field, so that the spatial density of the prestack migration velocity field is consistent with the density of the seismic section.
5. The VSP profile-based Q-volume modeling technique of claim 1, wherein in step 4, the velocity model scale factor calculation method is as follows:
assuming a velocity field of the formation in the target zone of V i,j
Wherein: i=1, 2, …, m; j=1, 2, …, n;
the wellhead track speed is V o,o The method comprises the steps of carrying out a first treatment on the surface of the The velocity model scale factor formula is as follows:
Y i,j ＝V i,j /V o,o ；
wherein: i is the vertical line number; j is the transverse line number; m is the maximum vertical line number, n is the maximum horizontal line number, and m and n are positive integers.
6. The VSP profile-based Q-volume modeling technique of claim 1, wherein: in step 5, the Q value of each stratum around the well logging is obtained by multiplying the Q value of the stratum at the wellhead by the speed model scale factors of different positions of each stratum around the well logging.
7. The VSP profile-based Q-volume modeling technique of claim 1, wherein: in step 5, the formula adopted in the calculation of the fast Q-body model is as follows:
Q i,j ＝Q o,o Yi,j i＝1,2,…,m；j＝1,2,…,n；
wherein: q (Q) i,j Is the Q value curve of the stratum of the target area; q (Q) o,o Is a well mouth channel Q value curve; yi, j is the velocity model scaling factor; i is the vertical line number; j is the transverse line number; m is the maximum vertical line number, n is the maximum horizontal line number, and m and n are positive integers.
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