CN112649857A - Fluid factor direct inversion method and system based on pre-stack seismic data - Google Patents

Fluid factor direct inversion method and system based on pre-stack seismic data Download PDF

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CN112649857A
CN112649857A CN201910964867.1A CN201910964867A CN112649857A CN 112649857 A CN112649857 A CN 112649857A CN 201910964867 A CN201910964867 A CN 201910964867A CN 112649857 A CN112649857 A CN 112649857A
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李京南
胡华锋
马灵伟
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China Petroleum and Chemical Corp
Sinopec Geophysical Research Institute
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    • G01—MEASURING; TESTING
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    • G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
    • G01V1/28—Processing seismic data, e.g. for interpretation or for event detection
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    • G01V1/306—Analysis for determining physical properties of the subsurface, e.g. impedance, porosity or attenuation profiles
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Abstract

A method and a system for directly inverting fluid factors based on pre-stack seismic data are disclosed. The method can comprise the following steps: determining a reflection coefficient expression of the fluid factors f rho and mu rho; determining a matrix form of the time domain seismic channels and the frequency domain seismic channels according to the reflection coefficient expression; obtaining a target functional according to a matrix form of the time domain seismic channel and the frequency domain seismic channel and by combining a Bayesian theory; determining an objective function for inverting the f rho and the mu rho according to the objective functional; and determining an inversion equation according to the target function, solving the inversion equation, and calculating the fluid factors f rho and mu rho. According to the method, the fluid factor is stably and accurately directly inverted through the time domain seismic data and the frequency domain seismic data, the stability of time domain inversion and the resolution capability of frequency domain inversion are achieved, and the result can be used for subsequent seismic data interpretation.

Description

Fluid factor direct inversion method and system based on pre-stack seismic data
Technical Field
The invention relates to the technical field of seismic exploration, in particular to a method and a system for directly inverting a fluid factor based on pre-stack seismic data.
Background
Seismic reservoir fluid identification is a technique for obtaining from seismic data an abnormal response that can be discerned as to the nature of the fluid. Seismic inversion is an important method for fluid identification. The focus of exploration shifts to the middle-deep layer as the exploration degree goes deep, and the incidence angle range of the seismic data gradually decreases as the depth of the target layer increases. In the pre-stack inversion process, the smaller the range of the seismic data is, the poorer the inversion stability is, and the stronger the uncertainty of the inversion result is. Therefore, it is necessary to study the fluid factor inversion of small-angle seismic data according to the characteristics of the seismic data range.
At present, a great number of scholars propose different fluid factor definition and inversion methods, one mainstream method is to invert the fluid factor by the elastic impedance result after elastic impedance inversion, and the method is easy to generate transmission errors. In addition, the conventional method only utilizes time domain seismic data, but the time domain method utilizes all frequency information of the seismic data, the inversion stability is stronger due to the data completeness, and the inversion resolution capability is limited due to the low signal-to-noise ratio part in the seismic data; the frequency domain method can preferably select the dominant frequency component with high signal-to-noise ratio to perform inversion, can improve the resolution capability of the inversion, but the stability of the inversion is poor due to the incomplete data. Therefore, there is a need to develop a fluid factor direct inversion method and system based on pre-stack seismic data.
The information disclosed in this background section is only for enhancement of understanding of the general background of the invention and should not be taken as an acknowledgement or any form of suggestion that this information forms the prior art already known to a person skilled in the art.
Disclosure of Invention
The invention provides a method and a system for directly inverting fluid factors based on pre-stack seismic data, which can stably and accurately directly invert the fluid factors through time domain seismic data and frequency domain seismic data, have the stability of time domain inversion and the resolution capability of frequency domain inversion, and can be used for subsequent seismic data interpretation, such as reservoir description, fluid identification and the like.
According to one aspect of the invention, a method for fluid factor direct inversion based on pre-stack seismic data is provided. The method may include: determining a reflection coefficient expression of the fluid factors f rho and mu rho; determining a matrix form of the time domain seismic channels and the frequency domain seismic channels according to the reflection coefficient expression; obtaining a target functional according to the matrix form of the time domain seismic channels and the frequency domain seismic channels by combining a Bayesian theory; determining an objective function for inverting the f rho and the mu rho according to the objective functional; and determining an inversion equation and solving according to the objective function, and calculating the fluid factors f rho and mu rho.
Preferably, the reflection coefficient expression is:
RPP(θ)＝h(θ)Fr+j(θ)Ur (1)
wherein h (theta) and j (theta) are calculation parameters,
Figure BDA0002230151670000021
Figure BDA0002230151670000022
Vpis the velocity of longitudinal wave, VsIs the transverse wave velocity, theta is the incident angle, and b is satisfied
Figure BDA0002230151670000023
A is a constant, f is the Gassmann fluid term,
Figure BDA0002230151670000024
mu is a shear modulus,
Figure BDA0002230151670000025
Frthe reflection coefficient for the fluid factor f p,
Figure BDA0002230151670000026
Urthe reflection coefficient for the fluid factor p,
Figure BDA0002230151670000027
preferably, the matrix form of the time domain seismic traces is:
S＝WR＝WAm＝Gtm (2)
the matrix form of the frequency domain seismic traces is as follows:
S(f)＝W(f)R(f)＝Gfm (3)
wherein S is a time domain seismic channel, A is a coefficient matrix composed of h (theta) and j (theta), m is a vector composed of reflection coefficients of a fluid factor f rho and mu rho, W is a wavelet matrix, S (f) is a frequency domain seismic channel, W (f) is a frequency spectrum of seismic waves, and R (f) is a frequency spectrum of the reflection coefficients.
Preferably, the target functional is:
Figure BDA0002230151670000031
wherein F (m) is a target functional.
Preferably, the objective function is:
Figure BDA0002230151670000032
wherein J (m) is an objective function,
Figure BDA0002230151670000033
according to another aspect of the invention, a fluid factor direct inversion system based on pre-stack seismic data is provided, which is characterized by comprising: a memory storing computer-executable instructions; a processor executing computer executable instructions in the memory to perform the steps of: determining a reflection coefficient expression of the fluid factors f rho and mu rho; determining a matrix form of the time domain seismic channels and the frequency domain seismic channels according to the reflection coefficient expression; obtaining a target functional according to the matrix form of the time domain seismic channels and the frequency domain seismic channels by combining a Bayesian theory; determining an objective function for inverting the f rho and the mu rho according to the objective functional; and determining an inversion equation and solving according to the objective function, and calculating the fluid factors f rho and mu rho.
Preferably, the reflection coefficient expression is:
RPP(θ)＝h(θ)Fr+j(θ)Ur (1)
wherein h (theta) and j (theta) are calculation parameters,
Figure BDA0002230151670000041
Figure BDA0002230151670000042
Vpis the velocity of longitudinal wave, VsIs the transverse wave velocity, theta is the incident angle, and b is satisfied
Figure BDA0002230151670000043
A is a constant, f is the Gassmann fluid term,
Figure BDA0002230151670000044
mu is a shear modulus,
Figure BDA0002230151670000045
Frthe reflection coefficient for the fluid factor f p,
Figure BDA0002230151670000046
Urthe reflection coefficient for the fluid factor p,
Figure BDA0002230151670000047
preferably, the matrix form of the time domain seismic traces is:
S＝WR＝WAm＝Gtm (2)
the matrix form of the frequency domain seismic traces is as follows:
S(f)＝W(f)R(f)＝Gfm (3)
wherein S is a time domain seismic channel, A is a coefficient matrix composed of h (theta) and j (theta), m is a vector composed of reflection coefficients of a fluid factor f rho and mu rho, W is a wavelet matrix, S (f) is a frequency domain seismic channel, W (f) is a frequency spectrum of seismic waves, and R (f) is a frequency spectrum of the reflection coefficients.
Preferably, the target functional is:
Figure BDA0002230151670000048
wherein F (m) is a target functional.
Preferably, the objective function is:
Figure BDA0002230151670000049
wherein J (m) is an objective function,
Figure BDA0002230151670000051
the method and apparatus of the present invention have other features and advantages which will be apparent from or are set forth in detail in the accompanying drawings and the following detailed description, which are incorporated herein, and which together serve to explain certain principles of the invention.
Drawings
The above and other objects, features and advantages of the present invention will become more apparent by describing in more detail exemplary embodiments thereof with reference to the attached drawings, in which like reference numerals generally represent like parts.
FIG. 1 shows a flow chart of the steps of a method for fluid factor direct inversion based on prestack seismic data according to the invention.
FIG. 2 shows a schematic diagram of synthetic seismic data according to one embodiment of the invention.
FIG. 3 shows a schematic of an amplitude spectrum of a synthetic seismic recording with an angle of incidence of 6 degrees, according to one embodiment of the invention.
FIG. 4 shows a schematic of the initial, true, and inverted values of the fluid factor f ρ, according to one embodiment of the invention.
FIG. 5 shows a schematic of the initial, true, and inverted values of the fluid factor μ ρ, according to one embodiment of the invention.
Detailed Description
The invention will be described in more detail below with reference to the accompanying drawings. While the preferred embodiments of the present invention are shown in the drawings, it should be understood that the present invention may be embodied in various forms and should not be limited to the embodiments set forth herein. Rather, these embodiments are provided so that this disclosure will be thorough and complete, and will fully convey the scope of the invention to those skilled in the art.
FIG. 1 shows a flow chart of the steps of a method for fluid factor direct inversion based on prestack seismic data according to the invention.
In this embodiment, the method for fluid factor direct inversion based on prestack seismic data according to the present invention may include: step 101, determining a reflection coefficient expression of a fluid factor f rho and a fluid factor mu rho; step 102, determining a matrix form of time domain seismic channels and frequency domain seismic channels according to a reflection coefficient expression; 103, obtaining a target functional according to a matrix form of the time domain seismic channels and the frequency domain seismic channels by combining a Bayes theory; step 104, determining an objective function for inverting the f rho and the mu rho according to the objective functional; and 105, determining an inversion equation and solving according to the target function, and calculating the fluid factors f rho and mu rho.
In one example, the reflection coefficient expression is:
RPP(θ)＝h(θ)Fr+j(θ)Ur (1)
wherein h (theta) and j (theta) are calculation parameters,
Figure BDA0002230151670000061
Figure BDA0002230151670000062
Vpis the velocity of longitudinal wave, VsIs the transverse wave velocity, theta is the incident angle, and b is satisfied
Figure BDA0002230151670000063
A is a constant, f is the Gassmann fluid term,
Figure BDA0002230151670000064
mu is a shear modulus,
Figure BDA0002230151670000065
Frthe reflection coefficient for the fluid factor f p,
Figure BDA0002230151670000066
Urthe reflection coefficient for the fluid factor p,
Figure BDA0002230151670000067
in one example, the matrix form of the time domain seismic traces is:
S＝WR＝WAm＝Gtm (2)
the matrix form of the frequency domain seismic traces is:
S(f)＝W(f)R(f)＝Gfm (3)
wherein S is a time domain seismic channel, A is a coefficient matrix composed of h (theta) and j (theta), m is a vector composed of reflection coefficients of a fluid factor f rho and mu rho, W is a wavelet matrix, S (f) is a frequency domain seismic channel, W (f) is a frequency spectrum of seismic waves, and R (f) is a frequency spectrum of the reflection coefficients.
In one example, the target functional is:
Figure BDA0002230151670000071
wherein F (m) is a target functional.
In one example, the objective function is:
Figure BDA0002230151670000072
wherein J (m) is an objective function,
Figure BDA0002230151670000073
specifically, the method for fluid factor direct inversion based on prestack seismic data according to the invention can comprise the following steps:
determining the reflection coefficient expressions of the fluid factors f ρ and μ ρ as formula (1), formula (1) can be written in a matrix form:
R＝Am (6)
wherein A is a coefficient matrix composed of h (theta) and j (theta), and m is a vector composed of reflection coefficients of the fluid factors f rho and mu rho.
And (3) determining the matrix form of the time domain seismic traces as formula (2) and the matrix form of the frequency domain seismic traces as formula (3) according to the reflection coefficient expression.
According to Bayes theory, the relationship between the model parameter posterior probability distribution and the prior distribution and likelihood function is:
p(m|d)∝p(d|m)p(m) (7)
where d is the actual observed seismic data.
Assuming that the model parameters conform to the Cauchy distribution, there are:
Figure BDA0002230151670000081
wherein, N is the number of sampling points,
Figure BDA0002230151670000082
is the model parameter variance.
The likelihood function of the time-frequency domain joint inversion is:
p(d|m)＝p(dt|m)p(df|m) (9)
wherein d ist、dfTime domain and frequency domain seismic data, respectively.
Assuming that the time domain likelihood function and the frequency domain likelihood function respectively obey gaussian distributions, there are:
Figure BDA0002230151670000083
Figure BDA0002230151670000084
wherein σn1、σn2The noise standard deviation of the seismic data in the time domain and the frequency domain is respectively, and n1 and n2 are the sampling point number of the seismic data in the time domain and the frequency domain respectively.
The likelihood function of the time-frequency domain joint inversion is:
Figure BDA0002230151670000085
the posterior probability distribution function of the time-frequency domain joint inversion can be obtained as follows:
Figure BDA0002230151670000086
the target functional is obtained as formula (4) by maximizing the joint posterior probability distribution function of formula (11).
Determining an objective function of inverting the f rho and the mu rho as a formula (5) according to the objective functional; by deriving the objective function with respect to the model parameters and making the derivative value zero, a final inversion equation can be obtained, and then an iterative reweighting algorithm is adopted to solve, and fluid factors f rho and mu rho are calculated.
According to the method, the fluid factor is stably and accurately directly inverted through the time domain seismic data and the frequency domain seismic data, the time domain inversion stability and the frequency domain inversion resolution capability are achieved, and the result can be used for subsequent seismic data interpretation, such as reservoir description, fluid identification and the like.
Application example
To facilitate understanding of the solution of the embodiments of the present invention and the effects thereof, a specific application example is given below. It will be understood by those skilled in the art that this example is merely for the purpose of facilitating an understanding of the present invention and that any specific details thereof are not intended to limit the invention in any way.
Determining the reflection coefficient expressions of the fluid factors f rho and mu rho as formula (1), determining the matrix form of the time domain seismic channels as formula (2) and the matrix form of the frequency domain seismic channels as formula (3) according to the reflection coefficient expressions. And (4) obtaining a target functional as a formula (4) by combining Bayesian theory according to the matrix form of the time domain seismic channels and the frequency domain seismic channels. Determining an objective function of inverting the f rho and the mu rho as a formula (5) according to the objective functional; by deriving the objective function with respect to the model parameters and making the derivative value zero, a final inversion equation can be obtained, and then an iterative reweighting algorithm is adopted to solve, and fluid factors f rho and mu rho are calculated.
FIG. 2 shows a schematic diagram of synthetic seismic data according to one embodiment of the invention.
The method comprises the steps of synthesizing prestack angle seismic data by utilizing actual logging data and seismic wavelets in a certain area, wherein the three pre-stack angle seismic data correspond to three incident angles of 6 degrees, 13 degrees and 20 degrees respectively as shown in figure 2, further utilizing the synthesized data to carry out fluid factor inversion, and utilizing wavelets used when the seismic data are simulated to be Rake wavelets with the dominant frequency of 40 Hz.
FIG. 3 shows a schematic representation of the amplitude spectrum of a synthetic seismic record with an angle of incidence of 6 degrees, obtained by Fourier transforming the time domain record of FIG. 2, with favorable frequency components selected for inversion in the inversion process, according to one embodiment of the invention.
FIG. 4 shows a schematic of the initial, true, and inverted values of the fluid factor f ρ, according to one embodiment of the invention. FIG. 5 shows a schematic of the initial, true, and inverted values of the fluid factor μ ρ, according to one embodiment of the invention. Therefore, the method can better inversely estimate the two fluid factors, wherein the prediction precision of the f rho is higher than the mu rho.
In summary, the fluid factor is stably and accurately directly inverted through the time domain seismic data and the frequency domain seismic data, the time domain inversion stability and the frequency domain inversion resolution capability are achieved, and the result can be used for subsequent seismic data interpretation, such as reservoir description and fluid identification.
It will be appreciated by persons skilled in the art that the above description of embodiments of the invention is intended only to illustrate the benefits of embodiments of the invention and is not intended to limit embodiments of the invention to any examples given.
According to an embodiment of the invention, a fluid factor direct inversion system based on pre-stack seismic data is provided, which is characterized by comprising: a memory storing computer-executable instructions; a processor executing computer executable instructions in the memory to perform the steps of: determining a reflection coefficient expression of the fluid factors f rho and mu rho; determining a matrix form of the time domain seismic channels and the frequency domain seismic channels according to the reflection coefficient expression; obtaining a target functional according to a matrix form of the time domain seismic channel and the frequency domain seismic channel and by combining a Bayesian theory; determining an objective function for inverting the f rho and the mu rho according to the objective functional; and determining an inversion equation according to the target function, solving the inversion equation, and calculating the fluid factors f rho and mu rho.
In one example, the reflection coefficient expression is:
RPP(θ)＝h(θ)Fr+j(θ)Ur (1)
wherein h (theta) and j (theta) are calculation parameters,
Figure BDA0002230151670000101
Figure BDA0002230151670000102
Vpis the velocity of longitudinal wave, VsIs the transverse wave velocity, theta is the incident angle, and b is satisfied
Figure BDA0002230151670000103
A is a constant, f is the Gassmann fluid term,
Figure BDA0002230151670000111
mu is a shear modulus,
Figure BDA0002230151670000112
Frthe reflection coefficient for the fluid factor f p,
Figure BDA0002230151670000113
Urthe reflection coefficient for the fluid factor p,
Figure BDA0002230151670000114
in one example, the matrix form of the time domain seismic traces is:
S＝WR＝WAm＝Gtm (2)
the matrix form of the frequency domain seismic traces is:
S(f)＝W(f)R(f)＝Gfm (3)
wherein S is a time domain seismic channel, A is a coefficient matrix composed of h (theta) and j (theta), m is a vector composed of reflection coefficients of a fluid factor f rho and mu rho, W is a wavelet matrix, S (f) is a frequency domain seismic channel, W (f) is a frequency spectrum of seismic waves, and R (f) is a frequency spectrum of the reflection coefficients.
In one example, the target functional is:
Figure BDA0002230151670000115
wherein F (m) is a target functional.
In one example, the objective function is:
Figure BDA0002230151670000116
wherein J (m) is an objective function,
Figure BDA0002230151670000117
the system can stably and accurately directly invert the fluid factor through the time domain seismic data and the frequency domain seismic data, has the stability of time domain inversion and the resolution capability of frequency domain inversion, and can be used for subsequent seismic data interpretation, such as reservoir description, fluid identification and the like.
It will be appreciated by persons skilled in the art that the above description of embodiments of the invention is intended only to illustrate the benefits of embodiments of the invention and is not intended to limit embodiments of the invention to any examples given.
Having described embodiments of the present invention, the foregoing description is intended to be exemplary, not exhaustive, and not limited to the embodiments disclosed. Many modifications and variations will be apparent to those of ordinary skill in the art without departing from the scope and spirit of the described embodiments.

Claims (10)

1. A fluid factor direct inversion method based on pre-stack seismic data is characterized by comprising the following steps:
determining a reflection coefficient expression of the fluid factors f rho and mu rho;
determining a matrix form of the time domain seismic channels and the frequency domain seismic channels according to the reflection coefficient expression;
obtaining a target functional according to the matrix form of the time domain seismic channels and the frequency domain seismic channels by combining a Bayesian theory;
determining an objective function for inverting the f rho and the mu rho according to the objective functional;
and determining an inversion equation and solving according to the objective function, and calculating the fluid factors f rho and mu rho.
2. The pre-stack seismic data-based fluid factor direct inversion method of claim 1, wherein the reflection coefficient expression is:
RPP(θ)＝h(θ)Fr+j(θ)Ur (1)
wherein h (theta) and j (theta) are calculation parameters,
Figure FDA0002230151660000011
Figure FDA0002230151660000012
Vpis the velocity of longitudinal wave, VsIs the transverse wave velocity, theta is the incident angle, and b is satisfied
Figure FDA0002230151660000013
A is a constant, f is the Gassmann fluid term,
Figure FDA0002230151660000014
mu is a shear modulus,
Figure FDA0002230151660000015
Frthe reflection coefficient for the fluid factor f p,
Figure FDA0002230151660000016
Urthe reflection coefficient for the fluid factor p,
Figure FDA0002230151660000017
3. the pre-stack seismic data-based fluid factor direct inversion method of claim 1, wherein the matrix form of the time-domain seismic traces is:
S＝WR＝WAm＝Gtm (2)
the matrix form of the frequency domain seismic traces is as follows:
S(f)＝W(f)R(f)＝Gfm (3)
wherein S is a time domain seismic channel, A is a coefficient matrix composed of h (theta) and j (theta), m is a vector composed of reflection coefficients of a fluid factor f rho and mu rho, W is a wavelet matrix, S (f) is a frequency domain seismic channel, W (f) is a frequency spectrum of seismic waves, and R (f) is a frequency spectrum of the reflection coefficients.
4. The pre-stack seismic data-based fluid factor direct inversion method of claim 1, wherein the target functional is:
Figure FDA0002230151660000021
wherein F (m) is a target functional.
5. The pre-stack seismic data-based fluid factor direct inversion method of claim 1, wherein the objective function is:
Figure FDA0002230151660000022
wherein J (m) is an objective function,
Figure FDA0002230151660000023
6. a system for fluid factor direct inversion based on prestack seismic data, the system comprising:
a memory storing computer-executable instructions;
a processor executing computer executable instructions in the memory to perform the steps of:
determining a reflection coefficient expression of the fluid factors f rho and mu rho;
determining a matrix form of the time domain seismic channels and the frequency domain seismic channels according to the reflection coefficient expression;
obtaining a target functional according to the matrix form of the time domain seismic channels and the frequency domain seismic channels by combining a Bayesian theory;
determining an objective function for inverting the f rho and the mu rho according to the objective functional;
and determining an inversion equation and solving according to the objective function, and calculating the fluid factors f rho and mu rho.
7. The pre-stack seismic data-based fluid factor direct inversion system of claim 6, wherein the reflection coefficient expression is:
RPP(θ)＝h(θ)Fr+j(θ)Ur (1)
wherein h (theta) and j (theta) are calculation parameters,
Figure FDA0002230151660000031
Figure FDA0002230151660000032
Vpis the velocity of longitudinal wave, VsIs the transverse wave velocity, theta is the incident angle, and b is satisfied
Figure FDA0002230151660000033
A is a constant, f is the Gassmann fluid term,
Figure FDA0002230151660000034
mu is a shear modulus,
Figure FDA0002230151660000035
Frthe reflection coefficient for the fluid factor f p,
Figure FDA0002230151660000036
Urthe reflection coefficient for the fluid factor p,
Figure FDA0002230151660000037
8. the pre-stack seismic data-based fluid factor direct inversion system of claim 6, wherein the matrix form of the time-domain seismic traces is:
S＝WR＝WAm＝Gtm (2)
the matrix form of the frequency domain seismic traces is as follows:
S(f)＝W(f)R(f)＝Gfm (3)
wherein S is a time domain seismic channel, A is a coefficient matrix composed of h (theta) and j (theta), m is a vector composed of reflection coefficients of a fluid factor f rho and mu rho, W is a wavelet matrix, S (f) is a frequency domain seismic channel, W (f) is a frequency spectrum of seismic waves, and R (f) is a frequency spectrum of the reflection coefficients.
9. The pre-stack seismic data-based fluid factor direct inversion system of claim 6, wherein the target functional is:
Figure FDA0002230151660000041
wherein F (m) is a target functional.
10. The pre-stack seismic data-based fluid factor direct inversion system of claim 6, wherein the objective function is:
Figure FDA0002230151660000042
wherein J (m) is an objective function,
Figure FDA0002230151660000043
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* Cited by examiner, † Cited by third party
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CN116027406A (en) * 2023-02-10 2023-04-28 成都理工大学 Multi-channel simultaneous inversion identification method, device and medium for improving inversion resolution
CN116027406B (en) * 2023-02-10 2023-08-18 成都理工大学 Multi-channel simultaneous inversion identification method, device and medium for improving inversion resolution

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