CN114200519B - Inversion method for obtaining density of well-free zone narrow incidence angle gather - Google Patents
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Abstract
The invention discloses an inversion method for obtaining density of a well-free zone narrow incidence angle gather, which comprises the following steps: step 1: obtaining seismic data with wide and narrow incidence angles; step 2: carrying out pre-stack simultaneous inversion on the seismic data with the wide incidence angle to obtain longitudinal wave impedance and transverse wave density; step 3: extracting a virtual well from the result of the step 2, and calculating an expanded elastic impedance curve by the virtual well curve to obtain a χ angle which best corresponds to the density correlation; step 4: calculating intercept and gradient, and calculating seismic data R according to the χ angle best corresponding to the correlation; step 5: performing post-stack inversion on the seismic data R to obtain density; step 6: comparing the densities of the step 5 and the step 2, if the consistency is good, taking the density as the final density, otherwise, jumping back to the step 3 for execution; step 7: and (4) executing the steps 4-6 on the seismic data with the narrow incidence angle to obtain the density of the seismic data with the narrow incidence angle, and finishing inversion. The invention can carry out density inversion on narrower incidence angles to obtain accurate density.
Description
Technical Field
The invention relates to the technical field of seismic data processing, in particular to an inversion method for obtaining density of a well-free zone narrow incident angle gather.
Background
In oil gas development exploration, particularly marine oil gas development exploration, the density can well reflect the saturation of oil gas, so that the density of a target object has a good early-stage guiding effect on oil gas development. Commercial oil and gas reservoirs can be effectively predicted through the density parameters, and the water layer with low gas saturation can be avoided to cause the false image of strong earthquake amplitude, so that higher recovery ratio is obtained, the practice of yield increase and well completion is improved, and the uncertainty of yield prediction is reduced. At the same time, the density data is also related to porosity, fluid type and its saturation and mineral composition, and in some instances it has also been observed that the longitudinal wave velocity of the hydrocarbon reservoir is not significantly reduced as expected compared to non-reservoir rock, in contrast to which density has been demonstrated to be a hydrocarbon indicator. The intersection between different rock parameters and pore fluids also shows that density is the best distinction between hydrocarbon reservoirs and other rock/fluid types.
The existing method for obtaining the density has the defects that the density data is difficult to obtain. The conventional method for solving the density data mainly performs pre-stack simultaneous inversion on long offset and high-quality seismic data or performs joint inversion on multi-wave and multi-component seismic data. The existing inversion method is mainly used for obtaining the density through simultaneous inversion before stack. The density is obtained by inversion at the same time before stack, and certain requirements are provided for the range of the incident angle of the earthquake, so that the inversion algorithm has certain dependence on the condition of the incident angle. Taking the main commercial software Jason and HRS of the existing density inversion as an example, the algorithms of the two inversion software are obtained based on an approximate shorthand formula 1 of the Zeoppritz equation:
in the formula (3), R (θ) represents a reflection coefficient, θ represents an incident angle, when θ is small (for example, less than 30 °),
approximately 0, the density term therefore cannot play a role in the formula, resulting in a very difficult inversion of the density.
On the other hand, the commercial software Jason uses partial corner gather overlay data, and the inventor studies found that: according to statistics, the software needs to obtain stable density inversion results, 5 partial angle gather superposition data bodies are required to participate in calculation, so that higher requirements are put on the number of times of gather coverage, the smaller the number of times of coverage is, the lower the signal to noise ratio of partial superposition data is, the stability of inversion is difficult to ensure, and therefore, high-quality seismic data with long offset distance and multiple coverage is required to obtain stable density inversion results.
In the actual oil gas development and exploration process, taking the south basin of the south China as an example, the area has seismic data collected at different years. The latest acquired data are covered for 120 times, the offset distance is larger, the maximum distance can reach 6800 meters, the data are converted into angle gathers, the maximum angle can reach 60 degrees, and the quality is good. But the data collected in the early stage are covered by a few times, the offset distance is small and reaches 1800 meters at the maximum, the data are converted into an angle gather, and the maximum incidence angle of a target interval only reaches 21 degrees. The accurate and effective density data cannot be obtained by directly adopting the existing inversion method.
Therefore, how to obtain the density of the target area under the condition that the target area has no logging data (i.e. no well), but the range of the seismic incidence angle in the early-collected seismic data is narrow (i.e. the seismic incidence angle is small) is a technical problem to be solved. How to ensure the stability of pre-stack inversion, particularly the stability of density inversion, is a factor that has to be considered for reservoir prediction and oil and gas detection by southern basin pre-stack inversion.
It should be noted that, the narrow incident angle of the present application cannot be specifically quantified, and according to the experience of the inventor, the narrow incident angle can be generally considered as a narrow incident angle, but it is not meant to limit the application to the incident angle range of less than 30 °; similarly, long offsets do not require specific quantification, and a commonly accepted consensus is that newly acquired seismic data can be considered to have a long offset at least an order of magnitude greater than the offset of seismic data at narrow angles of incidence.
Disclosure of Invention
Aiming at the defects of the prior art, the invention aims to provide an inversion method for obtaining density of a non-well region narrow incidence angle gather, which can solve the problem of obtaining density under the condition of the non-well region narrow incidence angle gather.
The technical scheme for realizing the purpose of the invention is as follows: an inversion method for obtaining density of a well-free narrow-angle-of-incidence gather comprises the following steps:
step 1: new acquired seismic data, which is seismic data with a wide angle of incidence and acquired later in time than the narrow angle of incidence seismic data, and narrow angle of incidence seismic data, which is seismic data acquired earlier and at a narrow angle of incidence, are obtained, and no log data is obtained.
Converting the angle trace sets of the newly acquired seismic data and the seismic data with the narrow incidence angle to obtain the seismic data with the wide incidence angle trace set and the seismic data with the narrow incidence angle trace set respectively;
step 2: carrying out pre-stack simultaneous inversion on the seismic data of the wide-incidence-angle gather to obtain longitudinal wave impedance, transverse wave impedance and density;
step 3: setting virtual well points in the seismic data of the wide-angle-of-incidence gather, extracting inversion channels at the well points and forming a well logging curve according to the longitudinal wave impedance, the transverse wave impedance and the density obtained in the step 2, thereby establishing a virtual well,
calculating an extended elastic impedance curve EEI (χ) for each log of the virtual well according to formula (1):
wherein χ represents the angle of Chi, χ has a function of the incident angle θ, specifically tan (χ) =sin 2 (θ)，α 0 Mean value of longitudinal wave velocity, beta 0 Average value ρ representing transverse wave velocity 0 The average value of the density is represented by α, the longitudinal wave velocity by β, the transverse wave velocity by ρ, the density by p=cos χ+sin χ, q=8k sin χ, and r=cos χ -4k sin χ.
After the extended elastic impedance curve EEI (χ) is calculated, the Chi angle corresponding to the extended elastic impedance curve EEI (χ) with the best correlation of the virtual well density ρ is determined by the correlation coefficient, and the Chi angle χ with the best correlation is recorded as χ best ；
Step 4: calculating AVO attribute of seismic data with wide incidence angle to obtain intercept P and gradient G, and calculating seismic data according to formula (2)
Step 5: seismic data obtained according to step 4
Performing post-stack inversion to obtain seismic data +.>
Is a density of (3);
step 6: comparing the density obtained by inversion after the step 5 is overlapped with the density obtained by calculation in the step 2, if the consistency is good, taking the density obtained in the step 5 as the final density of newly acquired seismic data, otherwise, jumping back to the step 3 to execute again;
step 7: and (3) carrying out the same processing on the seismic data with the narrow incidence angle according to the steps 4-6 to obtain the final density of the seismic data with the narrow incidence angle, thereby completing inversion of the blind zone narrow incidence angle gather to obtain the density.
Further, in step 1, the method further comprises optimizing the seismic data before converting the newly acquired seismic data and the narrow-angle-of-incidence seismic data angle gathers.
Further, the optimization process includes increasing the signal-to-noise ratio and resolution.
Further, the ray tracing method is adopted to respectively complete the conversion of the angle gather.
The beneficial effects of the invention are as follows: the invention can effectively solve the problem of unstable density inversion caused by narrower incident angle of seismic data with earlier seismic acquisition time. In the invention, technologies such as pre-stack inversion, extended elastic impedance inversion and the like are effectively combined, the difficult problem that old data information is difficult to use due to insufficient information is solved, the utilization rate of the old data is improved, and the space distribution of the predicted abnormal body is ensured to be more reliable. The problems of unstable density inversion caused by short early acquisition earthquake offset, narrow incidence angle and small coverage times can be effectively solved, the combined application of new and old data is realized, and the density and prediction accuracy of the data network measurement are improved; the density data obtained by inversion plays an important role in fluid detection and avoids the artifact of non-commercial gas reservoirs with strong amplitude anomalies at low gas saturation.
Drawings
FIG. 1 is a flow chart of a preferred embodiment;
FIG. 2 is a schematic illustration of a new acquired seismic data;
FIG. 3 is a schematic illustration of narrow angle of incidence seismic data of the same target object as FIG. 2;
FIG. 4 is a schematic cross-sectional view of the longitudinal wave impedance (up), transverse wave impedance (in) and density (down) of FIG. 2 undergoing a pre-stack inversion;
FIG. 5 is a schematic drawing of a log formed by extracting pre-stack inversion channels;
fig. 6 is a graph of expanded elastic curve versus virtual well density (χ = 10 degrees);
FIG. 7 is a schematic cross-sectional view of the intercept (up) and gradient (down) of FIG. 2 for AVO attribute analysis;
FIG. 8 is a graph of intercept, gradient and optimal Chi angle χ best A comparison schematic diagram of the calculated seismic data (lower) and the original seismic data (upper);
FIG. 9 is a schematic diagram of a comparison section of pre-stack simultaneous inversion density (left) and extended elastic inversion density (right);
FIG. 10 is a cross-sectional contrast plot of narrow angle of incidence seismic data versus extended elastic inversion density (below).
Detailed Description
The invention will be further described with reference to the drawings and detailed description.
As shown in FIG. 1, an inversion method for obtaining density of a well-free narrow-angle-of-incidence gather comprises the following steps:
step 1: obtaining new acquired seismic data and narrow-angle-of-incidence seismic data, wherein the new acquired seismic data is seismic data which has a long offset distance and a wide angle of incidence and is acquired later in time than the narrow-angle-of-incidence seismic data, and the narrow-angle-of-incidence seismic data is seismic data which is acquired at an early stage and is free of logging and is of a narrow angle of incidence. For example, the newly acquired seismic data is the seismic data acquired at the latest or a certain time in the near future, the narrow-angle-of-incidence seismic data is the seismic data acquired in the very early stage, and the angle of incidence of the seismic data acquired in the early stage is the narrow angle of incidence.
Preprocessing the newly acquired seismic data and the narrow-angle-of-incidence seismic data respectively, wherein the preprocessing comprises the steps of improving the signal-to-noise ratio and the resolution, and performing angle gather conversion on the newly acquired seismic data and the narrow-angle-of-incidence seismic data after the preprocessing by utilizing a ray tracing method respectively so as to correspondingly obtain wide-angle-of-incidence gather seismic data and narrow-angle-of-incidence seismic data, namely performing angle gather conversion according to the newly acquired seismic data to obtain wide-angle-of-incidence gather seismic data, and performing angle gather conversion according to the narrow-angle-of-incidence-angle seismic data to obtain narrow-angle-of-incidence gather seismic data.
Step 2: because the incident angle of the newly acquired seismic data is a wide incident angle, the pre-stack simultaneous inversion can be performed on the wide incident angle gather seismic data. The longitudinal wave impedance and the transverse wave impedance and the density of the wide-angle-of-incidence gather seismic data can be obtained by performing pre-stack simultaneous inversion on the wide-angle-of-incidence gather seismic data using existing commercial software, such as HRS.
The HRS software is adopted to perform prestack simultaneous inversion on the seismic data with the wide incidence angle, namely, the method is completed by adopting a formula 1 mentioned in the background art. In practical application, other commercial software or self-programming can be adopted to complete pre-stack simultaneous inversion.
Step 3: setting a virtual well point from the wide-incidence-angle seismic data, and extracting inversion channels at the well point and forming a well logging curve according to the longitudinal wave impedance, the transverse wave impedance and the density obtained in the step 2, so as to establish a virtual well. Calculating an extended elastic impedance curve EEI (χ) for each log of the virtual well according to formula (1):
wherein χ represents the angle of Chi, χ has a function of the incident angle θ, specifically tan (χ) =sin 2 (θ)，α 0 Mean value of longitudinal wave velocity, beta 0 Average value ρ representing transverse wave velocity 0 The average value of the density is represented by α, the longitudinal wave velocity by β, the transverse wave velocity by ρ, the density by p=cos χ+sin χ, q=8k sin χ, and r=cos χ -4k sin χ.
The Patrick Connolly introduces the concept of wave impedance into seismic data with non-zero incidence angles when solving the problem described by the reservoir, thereby leading to elastic impedance. Through continuous development, due to sin 2 (θ) inversion at angle is unstable and sin may occur 2 (θ) < -1, but the large angle gathers are again a major contributor to the effects of the fluid. For this purpose, tan (χ) is used instead of sin 2 (θ) such that the range of the variable is increased to the incident angle is also increased to-90 degrees to +90 degrees. Thereby introducing an extended elastic impedance formula:
therefore, χ is an intermediate variable having a functional relationship with the incident angle θ.
In calculating the extended elastic impedance curve EEI (χ), the Chi (χ) angle corresponding to the extended elastic impedance curve EEI (χ) with the best correlation with the virtual well density (ρ) under different Chi (χ) angles is determined by the correlation coefficient, and the Chi angle χ with the best correlation is recorded as χ best 。
The correlation coefficient is a coefficient of cross correlation, and represents the similarity between the two curves, if the correlation coefficient is 1, the two curves are completely consistent, and the correlation is the best.
Step 4: calculating AVO attribute of newly acquired seismic data to obtain intercept P and gradient G, and calculating optimal Chi angle χ according to step 3 best Calculating the earthquake number according to the formula (2)According to
Step 5: seismic data obtained according to step 4
Performing post-stack inversion to obtain seismic data +.>
Is a density of (3).
Step 6: comparing the density obtained by inversion after the step 5 is overlapped with the density obtained by calculation in the step 2, if the consistency is good, taking the density obtained in the step 5 as the final density of the newly acquired seismic data, otherwise, jumping back to the step 3 to execute again.
Step 7: and (3) carrying out the same processing on the seismic data with the narrow incidence angle according to the steps 4-6 to obtain the final density of the seismic data with the narrow incidence angle, thereby completing inversion of the blind zone narrow incidence angle gather to obtain the density.
The invention can effectively solve the problem of unstable density inversion caused by narrower incident angle of seismic data with earlier seismic acquisition time. In the invention, technologies such as pre-stack inversion, extended elastic impedance inversion and the like are effectively combined, the difficult problem that old data information is difficult to use due to insufficient information is solved, the utilization rate of the old data is improved, and the space distribution of the predicted abnormal body is ensured to be more reliable. The problems of unstable density inversion caused by short early acquisition earthquake offset, narrow incidence angle and small coverage times can be effectively solved, the combined application of new and old data is realized, and the density and prediction accuracy of the data network measurement are improved; the density data obtained by inversion plays an important role in fluid detection and avoids the artifact of non-commercial gas reservoirs with strong amplitude anomalies at low gas saturation.
Referring to fig. 2 and 3, fig. 2 is a schematic illustration of a new acquired seismic data; FIG. 3 is a schematic illustration of narrow angle of incidence seismic data for the same target object as FIG. 2.
Referring to fig. 4, fig. 4 is a schematic cross-sectional view of the longitudinal wave velocity (up), transverse wave velocity (in) and density (down) obtained by performing the pre-stack inversion of fig. 2.
Referring to fig. 5, fig. 5 is a schematic diagram of a log from which pre-stack inversion channels are extracted.
Referring to fig. 6, fig. 6 is a graph showing the correlation between the expanded elastic curve and the density (χ=10 degrees, i.e., chi=10 degrees in the graph).
Referring to fig. 7, fig. 7 is a schematic cross-sectional view of the intercept (up) and gradient (down) obtained by AVO attribute analysis of fig. 2.
Referring to FIG. 8, FIG. 8 is a graph with intercept, gradient, and optimal Chi angle χ best A comparison of the calculated seismic data (lower) with the original seismic data (upper).
Referring to fig. 9, fig. 9 is a schematic diagram of a comparison section of the pre-stack simultaneous inversion density (left) and the expanded elastic inversion density (right).
Referring to FIG. 10, FIG. 10 is a cross-sectional contrast plot of narrow angle of incidence seismic data versus extended elastic inversion density (down).
From fig. 2 to fig. 10, it can also be seen that the density obtained by the method based on the extended elastic inversion has good accuracy, and can realize the inversion of seismic data with no well region and narrow incidence angle to obtain accurate density.
The embodiment disclosed in the present specification is merely an illustration of one-sided features of the present invention, and the protection scope of the present invention is not limited to this embodiment, and any other functionally equivalent embodiment falls within the protection scope of the present invention. Various other corresponding changes and modifications will occur to those skilled in the art from the foregoing description and the accompanying drawings, and all such changes and modifications are intended to be included within the scope of the present invention as defined in the appended claims.
Claims (4)
1. The inversion method for obtaining the density of the well-free narrow-angle-of-incidence gather is characterized by comprising the following steps of:
step 1: obtaining new acquired seismic data, which is seismic data with a wide angle of incidence and acquired later in time than the narrow angle of incidence seismic data, and narrow angle of incidence seismic data, which is seismic data with a short offset, narrow angle of incidence acquired earlier,
step 2: performing prestack simultaneous inversion on the wide-angle-of-incidence gather seismic data to obtain longitudinal wave impedance, transverse wave impedance and density of the wide-angle-of-incidence gather seismic data;
step 3: setting virtual well points in the seismic data with wide incidence angles, extracting inversion channels at the well points and forming a well logging curve according to the longitudinal wave impedance, the transverse wave impedance and the density obtained in the step 2, thereby establishing a virtual well,
calculating an extended elastic impedance curve EEI (χ) for each log of the virtual well according to formula (1):
wherein χ represents the angle of Chi, χ has a function of the incident angle θ, specifically tan (χ) =sin 2 (θ)，α 0 Mean value of longitudinal wave velocity, beta 0 Average value ρ representing transverse wave velocity 0 Mean value of density, α represents longitudinal wave velocity, β represents transverse wave velocity, ρ represents density, p=cos χ+sin χ, q=8ksin χ, r=cos χ -4ksin χ,
after the extended elastic impedance curve EEI (χ) is calculated, the Chi angle corresponding to the extended elastic impedance curve EEI (χ) with the best correlation of the virtual well density ρ is determined by the correlation coefficient, and the Chi angle with the best correlation is recorded as χ best ；
Step 4: calculating AVO attribute of seismic data with wide incidence angle to obtain intercept P and gradient G, and calculating seismic data according to formula (2)
Step 5: seismic data obtained according to step 4
Performing post-stack inversion to obtain seismic data
Is a density of (3);
step 6: comparing the density obtained by inversion after the step 5 is overlapped with the density obtained by calculation in the step 2, if the consistency is good, taking the density obtained in the step 5 as the final density of newly acquired seismic data, otherwise, jumping back to the step 3 to execute again;
step 7: and (3) carrying out the same processing on the seismic data with the narrow incidence angle according to the steps 4-6 to obtain the final density of the seismic data with the narrow incidence angle, thereby completing inversion of the blind zone narrow incidence angle gather to obtain the density.
2. The inversion method for obtaining densities for a well-free narrow angle of incidence gather according to claim 1, further comprising optimizing both wide-angle and narrow-angle seismic data prior to transforming them in step 1.
3. The inversion method for obtaining density for a well-free narrow angle of incidence gather according to claim 2, wherein the optimization process comprises increasing signal-to-noise ratio and resolution.
4. The inversion method for obtaining the density of the narrow-angle-of-incidence gather without well region according to claim 1, wherein the angle gather conversion is respectively completed by adopting a ray tracing method.
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| WO2020191155A1 (en) * | 2019-03-21 | 2020-09-24 | Saudi Arabian Oil Company | Generating a velocity model and a density model of a subsurface structure of a reservoir |
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| WO2020191155A1 (en) * | 2019-03-21 | 2020-09-24 | Saudi Arabian Oil Company | Generating a velocity model and a density model of a subsurface structure of a reservoir |
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