CN112558153B

CN112558153B - Oil and gas reservoir prediction method and device for two-phase medium

Info

Publication number: CN112558153B
Application number: CN201910908826.0A
Authority: CN
Inventors: 桂金咏; 高建虎; 雍学善; 李胜军; 王洪求; 刘炳杨
Original assignee: Petrochina Co Ltd
Current assignee: Petrochina Co Ltd
Priority date: 2019-09-25
Filing date: 2019-09-25
Publication date: 2022-03-29
Anticipated expiration: 2039-09-25
Also published as: WO2021057773A1; CN112558153A; CA3158470A1

Abstract

The invention provides a method and a device for predicting an oil and gas reservoir with a two-phase medium, wherein the method comprises the following steps: obtaining a reservoir to be determined of a target area according to a parameter value of a first solid phase parameter and a parameter value of a second solid phase parameter of a two-phase medium of the target area; determining a fluid-containing reservoir of the target area according to the parameter values of the first liquid phase parameter and the second liquid phase parameter of the two-phase medium and the reservoir to be determined of the target area; and predicting the oil and gas reservoir of the target area according to the parameter value of the at least one physical property parameter of the two-phase medium and the fluid-containing reservoir of the target area. The device is used for executing the method. The method and the device for predicting the oil and gas reservoir of the two-phase medium improve the accuracy of oil and gas reservoir prediction.

Description

Oil and gas reservoir prediction method and device for two-phase medium

Technical Field

The invention relates to the technical field of geological exploration, in particular to a method and a device for predicting an oil and gas reservoir of a two-phase medium.

Background

In the field of seismic exploration, oil and gas exploration has been shifted from structural exploration to lithological exploration, and concealed reservoirs are new targets of oil and gas exploration, and the reservoirs are two-phase media consisting of rock solid skeletons and fluids in rock pores.

In the prior art, an oil-gas prediction method generally enables an oil-gas reservoir to be equivalent to a single solid, prestack AVO inversion is carried out by utilizing the characteristic that the reflection amplitude of seismic waves changes along with the offset, and the theoretical basis of the method is a Zoeppritz equation. The Zoeppritz equation is a fundamental equation describing the law of reflection and transmission of seismic amplitudes at the interface of two single-phase solid media. However, hydrocarbon-bearing reservoirs are not completely solid, elastic media. Generally, hydrocarbon-bearing reservoirs are of the pore, fracture type and are characterized by a solid framework and a fluid two-phase medium. The propagation of elastic waves in a biphasic medium is more complex than in a single-phase medium, since the presence of fluids and the interaction of solids with fluids weaken the mechanical properties of the rock. Therefore, in the prior art, the Zoeppritz equation based on the single-phase medium theory is difficult to accurately describe the propagation process and the law of the seismic waves in the two-phase medium.

Therefore, how to provide a method for predicting a hydrocarbon reservoir with a dual-phase medium can realize the prediction of the hydrocarbon reservoir in a target area so as to improve the accuracy of the hydrocarbon reservoir prediction becomes an important problem to be solved in the field.

Disclosure of Invention

Aiming at the problems in the prior art, the embodiment of the invention provides a method and a device for predicting an oil and gas reservoir with a two-phase medium.

On one hand, the invention provides a method for predicting a hydrocarbon reservoir of a two-phase medium, which comprises the following steps:

obtaining a reservoir to be determined of a target area according to a parameter value of a first solid phase parameter and a parameter value of a second solid phase parameter of a two-phase medium of the target area;

determining a fluid-containing reservoir of the target area according to the parameter value of the first liquid phase parameter and the parameter value of the second liquid phase parameter of the two-phase medium of the target area and the reservoir to be determined of the target area;

predicting a hydrocarbon reservoir of the target region according to the parameter value of at least one physical property parameter of the dual-phase medium of the target region and the fluid-containing reservoir of the target region;

wherein the parameter value of the first solid phase parameter, the parameter value of the second solid phase parameter, the parameter value of the first liquid phase parameter, and the parameter value of the second liquid phase parameter are obtained in advance, and the parameter value of the at least one physical property parameter is obtained according to the parameter value of the first solid phase parameter, the parameter value of the second solid phase parameter, the parameter value of the first liquid phase parameter, and the parameter value of the second liquid phase parameter.

In another aspect, the present invention provides a hydrocarbon reservoir prediction apparatus for a two-phase medium, comprising:

the reservoir to be determined obtaining unit is used for obtaining the reservoir to be determined of the target area according to the parameter value of the first solid phase parameter and the parameter value of the second solid phase parameter of the two-phase medium of the target area;

the fluid-containing reservoir determining unit is used for determining the fluid-containing reservoir of the target area according to the parameter value of the first liquid phase parameter and the parameter value of the second liquid phase parameter of the two-phase medium of the target area and the reservoir to be determined of the target area;

the hydrocarbon reservoir prediction unit is used for predicting the hydrocarbon reservoir of the target area according to the parameter value of at least one physical property parameter of the dual-phase medium of the target area and the fluid-containing reservoir of the target area;

In yet another aspect, the present invention provides an electronic device, including a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor implements the steps of the method for dual-phase medium hydrocarbon reservoir prediction according to any of the embodiments.

In yet another aspect, the present invention provides a computer readable storage medium having stored thereon a computer program which, when executed by a processor, performs the steps of the method for hydrocarbon reservoir prediction of a dual phase medium as described in any of the embodiments above.

According to the method and the device for predicting the oil and gas reservoir of the two-phase medium, the reservoir to be determined in the target area is obtained according to the parameter value of the first solid-phase parameter and the parameter value of the second solid-phase parameter of the two-phase medium in the target area, the fluid-containing reservoir in the target area is determined according to the parameter value of the first liquid-phase parameter and the parameter value of the second liquid-phase parameter of the two-phase medium and the reservoir to be determined in the target area, and finally the oil and gas reservoir in the target area is predicted according to the parameter value of at least one physical parameter of the two-phase medium and the fluid-containing reservoir in the target area, so that quantitative prediction of the oil and gas reservoir in the target area can be realized, and the accuracy of prediction of the oil and gas reservoir is improved.

Drawings

In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the drawings used in the description of the embodiments or the prior art will be briefly described below, it is obvious that the drawings in the following description are only some embodiments of the present invention, and for those skilled in the art, other drawings can be obtained according to the drawings without creative efforts. In the drawings:

fig. 1 is a schematic flow chart of a method for predicting a hydrocarbon reservoir with a dual-phase medium according to an embodiment of the present invention.

FIG. 2a is a schematic diagram of the inversion result of the first solid phase parameters according to an embodiment of the present invention.

FIG. 2b is a diagram illustrating the inversion result of the second solid phase parameters according to an embodiment of the present invention.

FIG. 3a is a schematic diagram of the inversion result of the first liquidus parameter according to an embodiment of the present invention.

FIG. 3b is a diagram illustrating the inversion result of the second liquid phase parameter according to an embodiment of the present invention.

FIG. 4a is a schematic diagram of the inversion results of porosity provided by an embodiment of the present invention.

FIG. 4b is a schematic diagram of the inversion results of hydrocarbon saturation provided by an embodiment of the present invention.

FIG. 5 is a schematic flow chart of a method for dual phase medium hydrocarbon reservoir prediction provided by another embodiment of the present invention.

FIG. 6 is a diagram illustrating elastic impedance curves of a two-phase medium at different incident angles according to an embodiment of the present invention.

Fig. 7 is a comparative illustration of the elastic parameters of a dual phase medium provided by an embodiment of the present invention.

FIG. 8 is a schematic flow chart of a method for dual phase medium hydrocarbon reservoir prediction provided by yet another embodiment of the present invention.

FIG. 9 is a schematic flow chart of a method for dual phase hydrocarbon reservoir prediction provided by yet another embodiment of the present invention.

FIG. 10 is a graph illustrating physical property parameters obtained by different methods according to an embodiment of the present invention.

Fig. 11 is a schematic structural diagram of a dual-phase medium hydrocarbon reservoir prediction device according to an embodiment of the present invention.

Fig. 12 is a schematic structural diagram of a dual-phase medium hydrocarbon reservoir prediction device according to another embodiment of the present invention.

Fig. 13 is a schematic structural diagram of a dual-phase medium hydrocarbon reservoir prediction apparatus according to yet another embodiment of the present invention.

Fig. 14 is a schematic structural diagram of a hydrocarbon reservoir prediction apparatus for dual-phase medium according to still another embodiment of the present invention.

Fig. 15 is a schematic physical structure diagram of an electronic device according to an embodiment of the present invention.

Detailed Description

In order to make the objects, technical solutions and advantages of the embodiments of the present invention more apparent, the embodiments of the present invention are further described in detail below with reference to the accompanying drawings. The exemplary embodiments and descriptions of the present invention are provided to explain the present invention, but not to limit the present invention. It should be noted that the embodiments and features of the embodiments in the present application may be arbitrarily combined with each other without conflict.

Fig. 1 is a schematic flow chart of a method for predicting a hydrocarbon reservoir with a dual-phase medium according to an embodiment of the present invention, and as shown in fig. 1, the method for predicting a hydrocarbon reservoir with a dual-phase medium according to an embodiment of the present invention includes:

s101, obtaining a reservoir stratum to be determined in a target area according to a parameter value of a first solid phase parameter and a parameter value of a second solid phase parameter of a two-phase medium in the target area;

specifically, inversion of the first solid phase parameters of the two-phase medium is performed on the prestack gather data of the target area, and the inversion result of the first solid phase parameters of the target area can be obtained. Similarly, inversion of the second solid phase parameters of the two-phase medium is performed on the prestack gather data of the target area, and the inversion result of the second solid phase parameters of the target area can be obtained. And if the parameter value of the first solid phase parameter is in the value range of the first solid phase parameter of the reservoir and the corresponding parameter value of the second solid phase parameter is in the value range of the second solid phase parameter of the reservoir, the position of the target area corresponding to the parameter value of the first solid phase parameter and the parameter value of the second solid phase parameter belongs to the reservoir to be determined in the target area. And performing the judgment process on the inversion result of the first solid phase parameter and the inversion result of the second solid phase parameter of the target area, so that the reservoir to be determined of the target area can be determined.

Wherein the first solid phase parameter may be a measure representing the tensile stress required to prevent lateral compression of the solid skeleton of the biphasic medium, and may be in newtons per square meter; the second solid phase parameter may be a measure of shear strain resistance of the solid framework of the biphasic medium, and may be in newtons per square meter; and the parameter value of the first solid phase parameter and the parameter value of the second solid phase parameter which correspond to the same gather data and time data in the inversion result of the first solid phase parameter and the inversion result of the second solid phase parameter correspond to each other. The inversion result of the first solid phase parameter comprises the corresponding relation of time, a gather and the first solid phase parameter, and the inversion result of the second solid phase parameter comprises the corresponding relation of time, a gather and the second solid phase parameter. The inversion result of the first solid phase parameter and the inversion result of the second solid phase parameter are obtained in advance. The prestack gather data of the target area can be obtained through prestack seismic data acquired by the target area; the value range of the first solid phase parameter of the reservoir is set according to actual experience, and the embodiment of the invention is not limited; the value range of the second solid phase parameter corresponding to the reservoir is set according to practical experience, and the embodiment of the invention is not limited. The execution subject of the method for predicting the oil and gas reservoir of the two-phase medium provided by the embodiment of the invention comprises but is not limited to a computer.

For example, fig. 2a is a schematic diagram of the inversion result of the first solid phase parameter according to an embodiment of the present invention, as shown in fig. 2a, the abscissa represents a gather in units of traces, and the ordinate represents time in units of milliseconds, and the gray scale in the graph represents the parameter value of the first solid phase parameter in units of n/m, and the lighter the gray scale represents the larger the parameter value of the first solid phase parameter. The correspondence between the gather data, the time data and the parameter values of the first solid phase parameter can be shown by fig. 2 a. In the embodiment of the invention, the reservoir has weaker solid property and smaller solid parameter value compared with a non-reservoir. The distribution position of the reservoir can be observed by the value of the first solid phase parameter in fig. 2a, as shown by the ellipse in fig. 2 a.

Fig. 2b is a schematic diagram of the inversion result of the second solid phase parameter according to an embodiment of the present invention, as shown in fig. 2b, the abscissa represents a gather in units of traces, and the ordinate represents time in units of milliseconds, and the shade of gray in the graph represents a parameter value of the second solid phase parameter in units of newtons per square meter, and the lighter the gray level represents the larger the parameter value of the second solid phase parameter. The correspondence between the gather data, the time data and the parameter values of the second solid phase parameter can be shown by fig. 2 b. In the embodiment of the invention, the reservoir has weaker solid property and smaller solid parameter value compared with a non-reservoir. The distribution position of the reservoir can be observed by the magnitude of the second solid phase parameter in fig. 2b, as shown by the ellipse in fig. 2 b.

S102, determining a fluid-containing reservoir of the target area according to the parameter value of the first liquid phase parameter and the parameter value of the second liquid phase parameter of the two-phase medium of the target area and the reservoir to be determined of the target area;

specifically, inversion of the first liquid phase parameters of the two-phase medium is performed on prestack gather data of the target area, and the inversion result of the first liquid phase parameters of the target area can be obtained. And similarly, performing inversion of second liquid phase parameters of a two-phase medium on prestack gather data of the target area to obtain an inversion result of the second liquid phase parameters of the target area, wherein the distribution position of the fluid-containing reservoir can be determined according to the parameter value of each second liquid phase parameter in the inversion result of the second liquid phase parameters of the target area and the value range of the second liquid phase parameters of the oil and gas reservoir because the value ranges of the second liquid phase parameters of the fluid-containing reservoir and the non-fluid-containing reservoir are different. If the parameter value of the first liquid phase parameter is in the value range of the first liquid phase parameter of the fluid-containing reservoir, the parameter value of the second liquid phase parameter corresponding to the parameter value of the first liquid phase parameter is in the value range of the second liquid phase parameter corresponding to the fluid-containing reservoir, and the position of the target area corresponding to the parameter value of the first liquid phase parameter and the parameter value of the second liquid phase parameter belongs to the reservoir to be determined in the target area, the position of the target area corresponding to the parameter value of the first liquid phase parameter and the parameter value of the second liquid phase parameter belongs to the fluid-containing reservoir in the target area. And performing the judgment process on the inversion result of the first liquid phase parameter and the inversion result of the second liquid phase parameter of the target area, so that the fluid reservoir of the target area can be determined.

Wherein the first liquid phase parameter may be a metric reflecting a coupling relationship between a solid volume and a fluid volume change, and may be in newton per square meter; the second liquid phase parameter may be a measure of the force required to flow a predetermined volume of fluid into the biphasic medium while maintaining the total volume of the biphasic medium constant, and may be in newton per square meter; and the parameter value of the first liquid phase parameter and the parameter value of the second liquid phase parameter which correspond to the same gather data and time data in the inversion result of the first liquid phase parameter and the inversion result of the second liquid phase parameter correspond to each other. The inversion result of the first liquid phase parameter comprises the corresponding relation of time, a gather and the first liquid phase parameter, and the inversion result of the second liquid phase parameter comprises the corresponding relation of time, the gather and the second liquid phase parameter. The inversion result of the first liquid phase parameter and the inversion result of the second liquid phase parameter are obtained in advance. The value range of the first liquid phase parameter of the fluid-containing reservoir is set according to practical experience, and the embodiment of the invention is not limited; the value range of the second liquid-phase parameter of the fluid-containing reservoir is set according to practical experience, and the embodiment of the invention is not limited. The first solid phase parameter, the second solid phase parameter, the first liquid phase parameter, and the second liquid phase parameter are referred to as a biphasic medium elasticity parameter.

For example, fig. 3a is a schematic diagram of an inversion result of the first liquidus parameter according to an embodiment of the present invention, where in fig. 3a, the abscissa represents a gather in units of traces, and the ordinate represents time in units of milliseconds, and the gray scale in the graph represents the parameter value of the first liquidus parameter in units of newtons per square meter, and the lighter the gray scale represents the larger the parameter value of the first liquidus parameter. The correspondence between the gather data, the time data, and the parameter values of the first liquidus parameter may be shown in fig. 3 a. In the embodiment of the invention, the fluid-containing reservoir has a higher liquid phase parameter value than a non-fluid-containing reservoir. The distribution of the fluid-bearing reservoir can be observed by the magnitude of the first liquidus parameter in fig. 3a, as shown by the ellipse in fig. 3 a.

Fig. 3b is a schematic diagram of an inversion result of the second liquid-phase parameter according to an embodiment of the present invention, where in fig. 3b, the abscissa represents a gather in units of traces, and the ordinate represents time in units of milliseconds, and the shade of gray in the diagram represents a parameter value of the second liquid-phase parameter in units of newtons per square meter, and the lighter the gray level represents the larger the parameter value of the second liquid-phase parameter. Fig. 3b shows the corresponding relationship between the trace gather data, the time data and the parameter values of the second liquid-phase parameter. In the embodiment of the invention, the fluid-containing reservoir has a higher liquid phase parameter value than a non-fluid-containing reservoir. The distribution position of the fluid-containing reservoir can be observed by the value of the second liquid-phase parameter in fig. 3b, as shown by the ellipse in fig. 3 b.

S103, predicting a hydrocarbon reservoir of the target area according to the parameter value of the at least one physical parameter of the two-phase medium and the fluid-containing reservoir of the target area;

specifically, each physical property parameter in the at least one physical property parameter of the two-phase medium is inverted according to the first solid phase parameter, the second solid phase parameter, the first liquid phase parameter, and the second liquid phase parameter of the target region, so that an inversion result of each physical property parameter of the target region can be obtained. If the at least one physical property parameter is one physical property parameter, comparing the parameter value of each physical property parameter in the inversion result of the physical property parameter of the target area with the corresponding hydrocarbon threshold value, and if the parameter value of the physical property parameter existing in the inversion result of the physical property parameter is larger than the corresponding hydrocarbon threshold value and the position of the target area corresponding to the parameter value of the physical property parameter larger than the hydrocarbon threshold value belongs to the fluid-containing reservoir of the target area, the position of the target area corresponding to the parameter value of the physical property parameter larger than the hydrocarbon threshold value belongs to the hydrocarbon reservoir of the target area. And performing the judgment process on the parameter value of each physical property parameter in the inversion result of the physical property parameter of the target area, so that the oil and gas reservoir of the target area can be predicted.

And if the at least one physical property parameter comprises a plurality of physical property parameters, comparing the parameter value of each physical property parameter in the inversion result of each physical property parameter of the target area with the corresponding hydrocarbon threshold value, and if each physical property parameter of the plurality of physical property parameters has a parameter value of a physical property parameter larger than the respective hydrocarbon threshold value, the parameter values of the physical property parameters larger than the respective hydrocarbon threshold values correspond to the same position of the target area, and the same position of the target area belongs to the fluid-containing reservoir of the target area, the parameter values of the physical property parameters larger than the respective hydrocarbon threshold values correspond to the same position of the target area, and the hydrocarbon reservoir of the target area belongs to the hydrocarbon reservoir of the target area. And performing the judgment process on the parameter value of each physical property parameter in the inversion result of the plurality of physical property parameters of the target area, so that the oil and gas reservoir of the target area can be predicted. Wherein the at least one physical property parameter includes, but is not limited to, porosity and oil and gas saturation. The oil-gas threshold corresponding to each physical property parameter is set according to actual experience, and the embodiment of the invention is not limited.

For example, the at least one property parameter includes a property parameter that is porosity. Fig. 4a is a schematic diagram of an inversion result of porosity according to an embodiment of the present invention, as shown in fig. 4a, the abscissa represents a gather in units of traces, and the ordinate represents time in units of milliseconds, and the depth of gray in the diagram represents a parameter value of porosity, and the lighter the gray is, the larger the parameter value of porosity is. The correspondence between the gather data, the time data and the porosity parameter values can be shown by fig. 4 a. In the embodiment of the invention, the oil and gas reservoir has good physical properties and high porosity parameter value, and the distribution position of the oil and gas reservoir corresponding to high porosity can be observed through figure 4a, as shown by an ellipse in figure 4 a.

For example, the at least one property parameter includes a property parameter of oil and gas saturation. Fig. 4b is a schematic diagram of an inversion result of the hydrocarbon saturation according to an embodiment of the present invention, as shown in fig. 4b, the abscissa represents a gather in units of traces, the ordinate represents time in units of milliseconds, and the gray scale in the diagram indicates the parameter value of the hydrocarbon saturation, and the lighter the gray scale, the larger the parameter value of the hydrocarbon saturation. The correspondence between the trace gather data, the time data and the parameter values of the oil and gas saturation can be shown in fig. 4 b. In the embodiment of the invention, the oil and gas reservoir has better physical properties and higher oil and gas saturation value, and the distribution position of high oil and gas saturation can be observed through the graph 4b, as shown by an ellipse in the graph 4 b.

For example, the at least one physical property parameter includes two physical property parameters, porosity and oil and gas saturation. Is obtained by

After the retrieval result of the porosity shown in fig. 4a and the retrieval result of the oil and gas saturation shown in fig. 4b, obtaining the position where the parameter value of each porosity is greater than the oil and gas threshold value corresponding to the porosity in the retrieval result of the porosity, and recording as a first-class position, and obtaining the position where the parameter value of each oil and gas saturation is greater than the oil and gas threshold value corresponding to the oil and gas saturation in the retrieval result of the oil and gas saturation, and recording as a second-class position; then, acquiring the intersection of the first-type position and the second-type position, namely the positions corresponding to the same time data and trace set data, and acquiring a third-type position; and then obtaining the position in the hydrocarbon reservoir of the target area from the third type of position, so that the hydrocarbon reservoir of the target area can be obtained. And the hydrocarbon threshold corresponding to the porosity can be set to 0.045, and the hydrocarbon threshold corresponding to the hydrocarbon saturation can be set to 0.7.

According to the method for predicting the oil and gas reservoir of the two-phase medium, the reservoir to be determined in the target area is obtained according to the parameter value of the first solid-phase parameter and the parameter value of the second solid-phase parameter of the two-phase medium in the target area, the fluid-containing reservoir in the target area is determined according to the parameter value of the first liquid-phase parameter and the parameter value of the second liquid-phase parameter of the two-phase medium and the reservoir to be determined in the target area, and finally the oil and gas reservoir in the target area is predicted according to the parameter value of at least one physical parameter of the two-phase medium and the fluid-containing reservoir in the target area, so that quantitative prediction of the oil and gas reservoir in the target area can be achieved, and accuracy of prediction of the oil and gas reservoir is improved.

Fig. 5 is a schematic flow chart of a method for predicting a hydrocarbon reservoir with a two-phase medium according to another embodiment of the present invention, as shown in fig. 5, and based on the foregoing embodiments, the step of obtaining the parameter value of the first solid-phase parameter, the parameter value of the second solid-phase parameter, the parameter value of the first liquid-phase parameter, and the parameter value of the second liquid-phase parameter further includes:

s501, performing double-phase medium elastic impedance inversion on the pre-stack angle part superposed gathers of at least four different incident angles of the target area according to a double-phase medium elastic impedance equation to obtain a double-phase medium elastic impedance data volume corresponding to each incident angle; the elastic impedance equation of the two-phase medium is obtained based on a simplified equation of reflection coefficients of the two-phase medium and an impedance expression of the reflection coefficients of the two-phase medium, and the simplified equation of the reflection coefficients of the two-phase medium is preset and comprises the first solid phase parameter, the second solid phase parameter, the first liquid phase parameter and the second liquid phase parameter;

specifically, the elastic impedance equation of the two-phase medium can be expressed as follows:

where DEI (theta) represents a two-phase medium elastic impedance data volume at an incident angle theta, I₀Representing the average longitudinal wave impedance of the target area, A representing a first solid phase parameter of the biphasic medium, N representing a second solid phase parameter of the biphasic medium, P representing a first liquid phase parameter of the biphasic medium, Q representing a second liquid phase parameter of the biphasic medium, A₀Mean value of the first solid phase parameter, N, representing the target region₀Mean value of the second solid phase parameter, P, representing the target region₀Mean value of a parameter of the first liquid phase, Q, representing the target area₀An average value of a second liquid phase parameter representing the target area, a (theta) represents a coefficient corresponding to the first solid phase parameter, b (theta) represents a coefficient corresponding to the second solid phase parameter, c (theta) represents a coefficient corresponding to the first liquid phase parameter, d (theta) represents a coefficient corresponding to the second liquid phase parameter, and a (theta), b (theta), c (theta) and d (theta) incidence angles theta are related.

Because the two-phase medium elastic impedance equation comprises four parameters, namely a first solid phase parameter, a second solid phase parameter, a first liquid phase parameter and a second liquid phase parameter, at least four elastic impedance data volumes with different incidence angles need to be inverted. According to the biphase medium elastic impedance equation, performing biphase medium elastic impedance inversion on the prestack angle part superposed gathers of at least four different incident angles of the target area, and obtaining biphase medium elastic impedance data volumes of at least four different incident angles. Wherein the prestack angle partially superimposed gather of the angle of incidence of the target region is obtainable from prestack gather data of the target region. The specific process of the inversion of the elastic impedance of the two-phase medium at each incident angle is the same as the algorithm and the flow of the inversion of the elastic impedance of the equivalent medium in the prior art, and is not repeated here.

The elastic impedance equation of the two-phase medium is obtained based on a simplified equation of the reflection coefficient of the two-phase medium and an impedance expression of the reflection coefficient of the two-phase medium. The simplified equation for the reflection coefficient of the two-phase medium can be expressed as the sum of the solid phase portion and the liquid phase portion as follows:

wherein, R (theta) represents the longitudinal wave reflection coefficient corresponding to the incident angle theta, A represents the first solid phase parameter of the two-phase medium, N represents the second solid phase parameter of the two-phase medium, P represents the first liquid phase parameter of the two-phase medium, Q represents the second liquid phase parameter of the two-phase medium, a (theta) represents the coefficient corresponding to the first solid phase parameter, b (theta) represents the coefficient corresponding to the second solid phase parameter, c (theta) represents the coefficient corresponding to the first liquid phase parameter, d (theta) represents the coefficient corresponding to the second liquid phase parameter, Delta A represents the difference of the first solid phase parameter of the two-phase medium on both sides of the reflecting interface, Delta N represents the difference of the second solid phase parameter of the two-phase medium on both sides of the reflecting interface, Delta P represents the difference of the first liquid phase parameter of the two-phase medium on both sides of the reflecting interface, and Delta Q represents the difference of the second liquid phase parameter of the two-phase medium on both sides of the reflecting interface.

Represents the solid phase portion, representing the contribution of the solid skeleton of the biphasic medium to the reflection coefficient;

the liquid phase fraction is shown and represents the contribution of the pore fluid to the reflection coefficient.

The reflection coefficient of the longitudinal wave corresponding to the incident angle theta can be expressed by the logarithm of the impedance as the impedance expression of the reflection coefficient of the two-phase medium as follows:

wherein R (theta) represents the longitudinal wave reflection coefficient corresponding to the incident angle theta, DEI₁(theta) represents the elastic resistance value, DEI, of the upper two-phase medium of the reflecting interface₂And (theta) represents the elastic impedance value of the lower two-phase medium of the reflecting interface, and DEI (theta) represents the elastic impedance data volume of the two-phase medium of the incident angle theta.

From equations (2) and (3), the following expression can be obtained:

assuming that the difference in properties of the upper and lower two-phase media of the reflective interface is neglected, it is possible to obtain

And

the following expression can thus be obtained:

the following expression can be obtained by performing logarithm operation and merging the same terms for formula (5):

Δln(DEI(θ))＝lnA^2a(θ)+lnN^2b(θ)+lnP^2c(θ)+lnQ^2d(θ) (6)

by performing an integration operation on equation (6), the following expression can be obtained:

DEI(θ)＝A^2a(θ)N^2b(θ)P^2c(θ)Q^2d(θ) (7)

in order to facilitate comparison between the elastic impedances of the two-phase media at different incidence angles, the elastic impedance equation (1) of the two-phase media can be obtained by scaling the above equation (7).

Fig. 6 is a schematic diagram of elastic impedance curves of a two-phase medium at different incident angles according to an embodiment of the present invention, as shown in fig. 6, the incident angles are 10 degrees, 15 degrees, 20 degrees, and 25 degrees, respectively, and it can be seen that there is a certain difference between the elastic impedance curves of the two-phase medium at different angles, and the elastic parameters of the two-phase medium can be inverted by using the difference: a first solid phase parameter, a second solid phase parameter, a first liquid phase parameter, and a second liquid phase parameter. The elastic impedance curves of the two-phase medium at different incidence angles shown in fig. 6 are calculated by using the single-well data of the target area.

S502, obtaining the parameter value of the first solid phase parameter, the parameter value of the second solid phase parameter, the parameter value of the first liquid phase parameter and the parameter value of the second liquid phase parameter according to the two-phase medium elastic impedance data bodies corresponding to the at least four incidence angles and the two-phase medium elastic impedance equations corresponding to the two-phase medium elastic impedance data bodies.

Specifically, the exponential terms at each sampling point are the same due to the same bi-phase medium elastic impedance data volume. And carrying out logarithmic operation on the biphase medium elastic impedance equation, and substituting the biphase medium elastic impedance data bodies with at least four different incidence angles and the index terms of the corresponding angles to obtain a multivariate linear equation set. And solving the multivariate linear equation set to obtain the parameter value of the first solid phase parameter, the parameter value of the second solid phase parameter, the parameter value of the first liquid phase parameter and the parameter value of the second liquid phase parameter.

For example, the four different incident angles are each θ₁、θ₂、θ₃And theta₄，θ₁The elastic impedance data volume of the two-phase medium is DEI (theta)₁)，θ₂The elastic impedance data volume of the two-phase medium is DEI (theta)₂)，θ₃The elastic impedance data volume of the two-phase medium is DEI (theta)₃)，θ₄The elastic impedance data volume of the two-phase medium is DEI (theta)₄). To theta₁、θ₂、θ₃And theta₄The elastic impedance equation of the two-phase medium is subjected to logarithmic operation and is substituted into theta₁、θ₂、θ₃And theta₄And a two-phase medium elastic impedance data bodyAnd obtaining a quaternary linear equation set corresponding to the exponential term of the angle as follows:

and solving the quaternary linear equation set (8) to obtain the parameter value of the first solid phase parameter A, the parameter value of the second solid phase parameter N, the parameter value of the first liquid phase parameter P and the parameter value of the second liquid phase parameter Q. The specific obtaining process of a (θ), b (θ), c (θ) and d (θ) is described below, and is not described herein again.

For example, fig. 7 is a schematic diagram comparing elastic parameters of a two-phase medium according to an embodiment of the present invention, and as shown in fig. 7, an actual value of the first solid phase parameter a, an actual value of the second solid phase parameter N, an actual value of the first liquid phase parameter P, and an actual value of the second liquid phase parameter Q are shown by solid lines, and a solved value of the first solid phase parameter a, a solved value of the second solid phase parameter N, a solved value of the first liquid phase parameter P, and a solved value of the second liquid phase parameter Q obtained by solving the system of equations (8) of quaternary equations are shown by dashed lines. Comparing the curve of the actual value of the first solid phase parameter A with the curve of the solved value, the curve of the actual value of the second solid phase parameter N with the curve of the solved value, the curve of the actual value of the first liquid phase parameter P with the curve of the solved value, and the curve of the actual value of the second liquid phase parameter Q with the curve of the solved value respectively, it can be seen that the difference between the curve of the actual value of each two-phase medium elastic parameter and the curve of the solved value is not large, and the curve of the solved value of each two-phase medium elastic parameter can reflect the corresponding curve of the actual value.

On the basis of the above embodiments, further, the simplified equation of the reflection coefficient of the two-phase medium is the sum of a solid phase part and a liquid phase part, the solid phase part is obtained according to the first solid phase parameter and the second solid phase parameter and the respective corresponding coefficients, and the liquid phase part is obtained according to the first liquid phase parameter and the second liquid phase parameter and the respective corresponding coefficients; wherein the coefficient corresponding to the first solid phase parameter, the coefficient corresponding to the second solid phase parameter, the coefficient corresponding to the first liquid phase parameter, and the coefficient corresponding to the second liquid phase parameter are all related to the incident angle.

Specifically, the simplified equation for the reflection coefficient of the bi-phase medium is shown in equation (2). The solid phase part is

Representing the contribution of a solid skeleton of the dual-phase medium to a reflection coefficient, wherein A represents a first solid phase parameter of the dual-phase medium, N represents a second solid phase parameter of the dual-phase medium, a (theta) represents a coefficient corresponding to the first solid phase parameter, b (theta) represents a coefficient corresponding to the second solid phase parameter, c (theta) represents a coefficient corresponding to the first liquid phase parameter, Δ A represents the difference between the first solid phase parameters of the dual-phase medium on both sides of the reflection interface, and Δ N represents the difference between the second solid phase parameters of the dual-phase medium on both sides of the reflection interface; the liquid phase part

Representing the contribution of the pore fluid to the reflection coefficient, P represents a first liquid phase parameter of the dual-phase medium, Q represents a second liquid phase parameter of the dual-phase medium, c (theta) represents a coefficient corresponding to the first liquid phase parameter, d (theta) represents a coefficient corresponding to the second liquid phase parameter, Δ P represents the difference between the first liquid phase parameter of the dual-phase medium on both sides of the reflective interface, and Δ Q represents the difference between the second liquid phase parameter of the dual-phase medium on both sides of the reflective interface. Wherein the coefficient corresponding to the first solid phase parameter, the coefficient corresponding to the second solid phase parameter, the coefficient corresponding to the first liquid phase parameter, and the coefficient corresponding to the second liquid phase parameter are all related to the incident angle.

On the basis of the foregoing embodiments, further, the first solid phase parameter is a measure of a tensile stress required to prevent the solid skeleton of the two-phase medium from being compressed laterally, the second solid phase parameter is a measure of a shear strain resistance of the solid skeleton of the two-phase medium, a coefficient corresponding to the first solid phase parameter is determined according to a coefficient of a lamel parameter of an equivalent medium reflection coefficient equation, and a coefficient corresponding to the second solid phase parameter is determined according to a coefficient of a shear modulus of the equivalent medium reflection coefficient equation.

In particular, the first solid phase parameter is a measure of the tensile stress required to prevent transverse compression of the solid skeleton of the biphasic medium and may be in newtons per square meter. The second solid phase parameter is a measure of the shear strain resistance of the solid framework of the biphasic medium and may be in newtons per square meter. The reflection coefficient of the solid phase part in the two-phase medium is similar to the reflection coefficient of the equivalent medium, the first solid phase parameter is similar to a Lame parameter in an equivalent medium reflection coefficient equation, and the second solid phase parameter is similar to a shear modulus in the equivalent medium reflection coefficient equation, so that the coefficient corresponding to the first solid phase parameter can be determined according to the coefficient of the Lame parameter of the equivalent medium reflection coefficient equation, and the coefficient corresponding to the second solid phase parameter can be determined according to the coefficient of the shear modulus of the equivalent medium reflection coefficient equation.

The coefficient a (θ) corresponding to the first solid phase parameter can be expressed as:

the coefficient b (θ) corresponding to the second solid phase parameter can be expressed as:

wherein K is a constant and can be the square of the ratio of the average transverse wave velocity and the average longitudinal wave velocity of the solid medium; r is a constant, and the average ratio of the change rate of the transverse wave speed of the solid medium to the change rate of the density can be taken. K and r can be obtained by well log data analysis of the target area.

Fig. 8 is a schematic flow chart of a method for predicting a hydrocarbon reservoir of a two-phase medium according to another embodiment of the present invention, as shown in fig. 8, and based on the foregoing embodiments, the step of obtaining the coefficients corresponding to the first liquid phase parameter and the coefficients corresponding to the second liquid phase parameter further includes:

s801, constructing an I multiplied by J order matrix equation set according to I incident angles in the angle range of the prestack gather, J sets of elastic parameters of the two-phase medium and a simplified equation of the reflection coefficient of the two-phase medium; the longitudinal wave reflection coefficient corresponding to each incident angle and each group of the elastic parameters of the two-phase medium is obtained by solving a general equation of the reflection coefficient of the two-phase medium; each set of biphasic medium elasticity parameters comprises the first solid phase parameter, the second solid phase parameter, the first liquid phase parameter and the second liquid phase parameter;

specifically, J groups of elasticity parameters of the two-phase medium are randomly constructed according to the petrophysical model of the target area, and each group of elasticity parameters of the two-phase medium comprises the first solid phase parameter, the second solid phase parameter, the first liquid phase parameter and the second liquid phase parameter. And setting I incident angles, wherein the I incident angles belong to the angle range of the prestack gather. I incident angles and J sets of elastic parameters of the two-phase medium are freely combined and input into the simplified equation of the reflection coefficient of the two-phase medium, I multiplied by J simplified equations of the reflection coefficient of the two-phase medium can be obtained, and the I multiplied by J order matrix equation set is formed by the simplified equation of the reflection coefficient of the I multiplied by J two-phase medium. The petrophysical model of the target region is set according to practical experience, and the embodiment of the invention is not limited. The pre-stack gather angle range is set according to practical experience, and the embodiment of the invention is not limited. The specific values of I and J are set according to actual needs, and the embodiment of the present invention is not limited.

The system of I × J order matrix equations may be expressed as follows:

D＝S_sW_s+S_FW_F (11)

wherein D is a longitudinal wave reflection coefficient vector of I multiplied by J dimension,

the element of the jth row and ith column in the D is the elasticity parameter of the jth group of the dual-phase medium and the longitudinal wave reflection coefficient corresponding to the ith incident angle, S_sRepresents a matrix of solid phase coefficients,

W_srepresents a matrix of elastic parameters of the solid phase,

S_Frepresents a liquid phase coefficient matrix and a liquid phase coefficient matrix,

W_Frepresents a matrix of elastic parameters of the liquid phase,

i is a positive integer and I is not more than I, J is a positive integer and J is not more than J, I and J are positive integers.

The elasticity parameter of the j-th group of the two-phase medium and the longitudinal wave reflection coefficient corresponding to the i-th incident angle can be obtained by solving a general equation of the reflection coefficient of the two-phase medium, and the specific solving process is the prior art and is not described herein any more. Wherein the general equation for the reflection coefficient of the bi-phase medium can be expressed as follows:

wherein,

in order to obtain a fast longitudinal wave reflection coefficient,

is the reflection coefficient of the slow longitudinal wave,

is a reflection coefficient of a transverse wave,

in order to obtain a fast longitudinal wave transmission coefficient,

is the transmission coefficient of the slow longitudinal wave,

is the transverse wave transmission coefficient, A₁、N₁、Q₁、R₁As the elastic parameter of the upper medium,

is the density of the upper medium, A₂、N₂、Q₂、R₂Is the elastic parameter of the lower-layer medium,

is the density of the lower layer medium, phi₁Is the porosity of the upper medium, phi₂Is the porosity of the underlying medium, /)₁₁、l₁₂、l₁、l₂₁、l₂₂、l₂、l_iAre respectively P₁₁、P₁₂、S₁、P₂₁、P₂₂、S₂、P_iNumber of circles, m₁₁、m₁₂、m₂₁、m₂₂Are respectively P₁₁、P₁₂、P₂₁、P₂₂Corresponding ratio of fluid amplitude to solid amplitude, alpha₁₁、α₁₂、β₁Are respectively P₁₁、P₁₂、S₁Angle of reflection of alpha₂₁、α₂₂、β₂Are respectively P₂₁、P₂₂、S₂The transmission angle of (d); alpha is alpha_iIs P_iAngle of incidence.

S802, solving the I × J order matrix equation set to obtain the coefficient values corresponding to the first liquid phase parameters corresponding to the I incident angles and the coefficient values corresponding to the second liquid phase parameters corresponding to the I incident angles;

specifically, in the I × J order matrix equation set (11), the I incident angles and the J set of elastic parameters of the two-phase medium are known numbers, D is obtained, and the solid phase coefficient matrix S_sThe solid phase elastic parameter matrix W can be obtained from the equations (9) and (10)_sCan be obtained according to the parameter value of the first solid phase parameter and the parameter value of the second solid phase parameter in the elastic parameters of the J groups of two-phase medium, and the liquid phase elastic parameter matrix W_FThe parameter value of the first liquid phase parameter and the second liquid phase parameter in the elastic parameters of the two-phase medium in the J groupThe value of the parameter (c) is obtained. The system of I × J order matrix equations (11) can be converted into the following expression:

S_F＝((D-S_sW_s)^T(D-S_sW_s))^-1(D-S_sW_s)^TW_F (12)

solving the equation set (12) by least square method to obtain the liquid phase coefficient matrix S_FThereby obtaining the values of the coefficients corresponding to the first liquid phase parameters corresponding to the respective I incident angles and the values of the coefficients corresponding to the second liquid phase parameters corresponding to the respective I incident angles.

S803, obtaining a relationship between the incident angle and a coefficient corresponding to the first liquid phase parameter according to the value of the coefficient corresponding to the first liquid phase parameter corresponding to each of the I incident angles, and obtaining a relationship between the incident angle and a coefficient corresponding to the second liquid phase parameter according to the value of the coefficient corresponding to the second liquid phase parameter corresponding to each of the I incident angles.

Specifically, after obtaining the values of the coefficients corresponding to the first liquidus parameters corresponding to the I incident angles, the relationship between the incident angle and the coefficient corresponding to the first liquidus parameter may be established in a data fitting manner, and the coefficient corresponding to the first liquidus parameter corresponding to the incident angle may be obtained under the condition that the incident angle is known. After obtaining the values of the coefficients corresponding to the second liquid-phase parameters corresponding to the respective I incident angles, the relationship between the incident angle and the coefficient corresponding to the second liquid-phase parameter may be established by means of data fitting, and the coefficient corresponding to the second liquid-phase parameter corresponding to the incident angle may be found in the case of a known incident angle.

Fig. 9 is a schematic flow chart of a method for predicting a hydrocarbon reservoir with a dual-phase medium according to still another embodiment of the present invention, as shown in fig. 9, and further, obtaining the parameter value of the at least one physical parameter according to the parameter value of the first solid-phase parameter, the parameter value of the second solid-phase parameter, the parameter value of the first liquid-phase parameter, and the parameter value of the second liquid-phase parameter includes:

s901, inputting the parameter value of the first solid-phase parameter, the parameter value of the second solid-phase parameter, the parameter value of the first liquid-phase parameter and the parameter value of the second liquid-phase parameter into a physical property parameter target inversion function to obtain an equation to be solved; wherein the physical property parameter target inversion function is obtained after training based on the at least one physical property parameter and a sample training data set of a corresponding first solid phase parameter, a corresponding second solid phase parameter, a corresponding first liquid phase parameter and a corresponding second liquid phase parameter;

specifically, after obtaining the parameter value of the first solid phase parameter, the parameter value of the second solid phase parameter, the parameter value of the first liquid phase parameter, and the parameter value of the second liquid phase parameter, the parameter value of the first solid phase parameter, the parameter value of the second solid phase parameter, the parameter value of the first liquid phase parameter, and the parameter value of the second liquid phase parameter are input into a physical property parameter target inversion function as known quantities, and an equation to be solved is obtained, where an unknown quantity of the equation to be solved includes the at least one physical property parameter.

Based on the bayesian theory, the physical parameters of the target area are values of a set of physical parameters corresponding to the maximum value of the posterior probability density under the premise of knowing the elastic parameters of the two-phase medium, and the target inversion function of the physical parameters can be expressed as:

wherein the vector X represents the at least one physical property parameter, X_iA parameter value of the i-th group representing said at least one physical property parameter, X if said at least one physical property parameter is oil and gas saturation Sg and porosity Por_iCan be represented as X_i＝[Sg_i Por_i]^T，Sg_iValue of ith parameter, Por, representing oil and gas saturation_iAn ith parameter value representing porosity; the vector E represents the elastic parameter of the two-phase medium, the first solid phase parameter is A, the second solid phase parameter is N, andwhere the first liquid phase parameter is P and the second liquid phase parameter is Q, then E may be expressed as E ═ an _ pq]^T(ii) a Posterior probability density function P (X)_i| E) represents the probability of obtaining the ith set of parameter values of the at least one physical property parameter under the condition that the elastic parameters of the dual-phase medium are known, and the prior distribution function P (X)_i) A likelihood function P (E | X) representing a probability of obtaining the i-th set of parameter values of the at least one property parameter_i) The probability distribution of the values of the elastic parameters of the two-phase medium under the condition that the at least one physical parameter is known to take the ith group of parameter values is shown. Vector quantity

And (3) representing the solving result of the physical parameter target inversion function, namely the value of a group of corresponding physical parameters when the posterior probability density is maximum.

The target inversion function comprises a prior distribution function and a likelihood function, wherein the prior distribution function P (X)_i) Statistically derived from the well-logging samples of the study area, and the likelihood function P (E | X)_i) It needs to be obtained by means of rock physical model and stochastic simulation technology. The relation of the elasticity parameter of the two-phase medium and the petrophysical model of the at least one physical property parameter can be expressed as follows:

E＝f(X)+σ (14)

wherein the vector E represents the elastic parameter of the two-phase medium, E ═ A N P Q]^TThe vector X represents the at least one physical property parameter, σ represents an error between the petrophysical model and the measured value of the well logging, and the function f () represents a petrophysical model relationship, which is set according to practical experience, for example, according to a bi-phase medium petrophysical experiment or an empirical relationship of a research area, which is not limited in the embodiments of the present invention.

And randomly generating the at least one physical property parameter according to the prior distribution probability of the at least one physical property parameter by means of a Markov chain Monte Carlo random simulation technology, and obtaining a randomly generated elasticity parameter of the dual-phase medium corresponding to the at least one physical property parameter according to the at least one randomly generated physical property parameter and a formula (14). Based on the at least one physical property parameter randomly generated and the pair thereofConstructing a sample training data set of the at least one physical property parameter and the corresponding first solid phase parameter, second solid phase parameter, first liquid phase parameter and second liquid phase parameter, and performing conventional Bayesian classification training based on the sample training data set to obtain the likelihood function P (E | X |)_i)。

S902, solving the equation to be solved to obtain a parameter value of the at least one physical property parameter.

In particular, the prior distribution function P (X) is obtained_i) Likelihood function P (E | X)_i) And then, determining the target inversion function, and solving the equation to be solved. Since the range of each of the at least one physical property parameter is limited, the posterior probability density value of the target inversion function can be obtained by enumerating each of the at least one physical property parameter, and a plurality of posterior probability density values can be obtained. And taking the enumerated value of the at least one physical property parameter corresponding to the maximum value of the posterior probability density as the parameter value of the at least one physical property parameter. Namely, the parameter value of at least one physical property parameter corresponding to the maximum value of the posterior probability density of the target inversion function is obtained as the inversion value of the final physical property parameter

The value range of each physical property parameter is set according to actual experience, and the embodiment of the invention is not limited.

For example, fig. 10 is a schematic diagram of physical property parameters obtained by different methods according to an embodiment of the present invention, as shown in fig. 10, dotted lines in the diagram are a curve of oil and gas saturation Sg and a curve of porosity Por obtained by using the oil and gas reservoir prediction method for a two-phase medium according to the embodiment of the present invention, dotted lines in the diagram are a curve of oil and gas saturation Sg and a curve of porosity Por obtained by using a single-phase medium physical property inversion method in a conventional technique, and solid lines in the diagram are a curve of actual oil and gas saturation Sg and a curve of porosity Por. By comparing the three curves of the oil and gas saturation Sg and the three curves of the porosity Por, the fact that the fitting degree of a dotted line in the graph relative to a dotted line and a solid line is higher can be found, namely the physical property parameters obtained by the inversion of the oil and gas reservoir prediction method of the two-phase medium provided by the embodiment of the invention are more accurate relative to the physical property parameters obtained by a single-phase medium physical property inversion method of the conventional technology.

Based on the above embodiments, further, the at least one physical property parameter includes porosity and/or oil and gas saturation.

Fig. 11 is a schematic structural diagram of a hydrocarbon reservoir prediction apparatus using a two-phase medium according to an embodiment of the present invention, and as shown in fig. 11, the hydrocarbon reservoir prediction apparatus using a two-phase medium according to an embodiment of the present invention includes a reservoir to be determined obtaining unit 1101, a fluid-containing reservoir determining unit 1102, and a hydrocarbon reservoir prediction unit 1103, where:

the reservoir to be determined obtaining unit 1101 is configured to obtain a reservoir to be determined of a target region according to a parameter value of a first solid phase parameter and a parameter value of a second solid phase parameter of a two-phase medium of the target region; the fluid-containing reservoir determination unit 1102 is configured to obtain a fluid-containing reservoir of the target region according to the parameter value of the first liquid phase parameter and the parameter value of the second liquid phase parameter of the dual-phase medium of the target region and the reservoir to be determined of the target region; the hydrocarbon reservoir prediction unit 1103 is configured to obtain a hydrocarbon reservoir of the target region according to a parameter value of at least one physical property parameter of the two-phase medium of the target region and the fluid-containing reservoir of the target region; wherein the parameter value of the first solid phase parameter, the parameter value of the second solid phase parameter, the parameter value of the first liquid phase parameter, and the parameter value of the second liquid phase parameter are obtained in advance, and the parameter value of the at least one physical property parameter is obtained according to the parameter value of the first solid phase parameter, the parameter value of the second solid phase parameter, the parameter value of the first liquid phase parameter, and the parameter value of the second liquid phase parameter.

Specifically, inversion of the first solid phase parameters of the two-phase medium is performed on prestack gather data of the target region, so that an inversion result of the first solid phase parameters of the target region can be obtained, and the to-be-determined reservoir obtaining unit 1101 can determine whether the parameter values of the first solid phase parameters are within the value range of the first solid phase parameters of the oil and gas reservoir according to the parameter values of the first solid phase parameters in the inversion result of the first solid phase parameters of the target region and the value range of the first solid phase parameters of the reservoir, because the value ranges of the first solid phase parameters of the reservoir and the non-reservoir are different. Similarly, inversion of the second solid phase parameters of the two-phase medium is performed on the prestack gather data of the target area, and an inversion result of the second solid phase parameters of the target area can be obtained. And if the parameter value of the first solid phase parameter is in the value range of the first solid phase parameter of the reservoir and the corresponding parameter value of the second solid phase parameter is in the value range of the second solid phase parameter of the reservoir, the position of the target area corresponding to the parameter value of the first solid phase parameter and the parameter value of the second solid phase parameter belongs to the reservoir to be determined in the target area. And performing the judgment process on the inversion result of the first solid phase parameter and the inversion result of the second solid phase parameter of the target area, so that the reservoir to be determined of the target area can be determined.

Wherein the first solid phase parameter may be a measure representing the tensile stress required to prevent lateral compression of the solid skeleton of the biphasic medium, and may be in newtons per square meter; the second solid phase parameter may be a measure of shear strain resistance of the solid framework of the biphasic medium, and may be in newtons per square meter; and the parameter value of the first solid phase parameter and the parameter value of the second solid phase parameter which correspond to the same gather data and time data in the inversion result of the first solid phase parameter and the inversion result of the second solid phase parameter correspond to each other. The inversion result of the first solid phase parameter comprises the corresponding relation of time, a gather and the first solid phase parameter, and the inversion result of the second solid phase parameter comprises the corresponding relation of time, a gather and the second solid phase parameter. The inversion result of the first solid phase parameter and the inversion result of the second solid phase parameter are obtained in advance. The prestack gather data of the target area can be obtained through prestack seismic data acquired by the target area; the value range of the first solid phase parameter of the reservoir is set according to actual experience, and the embodiment of the invention is not limited; the value range of the second solid phase parameter corresponding to the reservoir is set according to practical experience, and the embodiment of the invention is not limited.

The inversion of the first liquidus parameters of the two-phase medium is performed on the prestack gather data of the target area, so that the inversion result of the first liquidus parameters of the target area can be obtained, and the fluid-bearing reservoir determination unit 1102 can determine whether the parameter values of the first liquidus parameters are within the value range of the first liquidus parameters of the oil and gas reservoir according to the parameter values of the first liquidus parameters in the inversion result of the first liquidus parameters of the target area and the value range of the first liquidus parameters of the oil and gas reservoir because the value ranges of the first liquidus parameters of the fluid-bearing reservoir and the fluid-bearing reservoir are different. Similarly, inversion of second liquid phase parameters of a two-phase medium is performed on prestack gather data of the target area, and an inversion result of the second liquid phase parameters of the target area can be obtained, and since the value ranges of the second liquid phase parameters of the fluid-bearing reservoir and the non-fluid-bearing reservoir are different, the fluid-bearing reservoir determination unit 1102 can determine whether each second liquid phase parameter is within the value range of the second liquid phase parameter of the fluid-bearing reservoir according to the parameter value of each second liquid phase parameter in the inversion result of the second liquid phase parameters of the target area and the value range of the second liquid phase parameter of the fluid-bearing reservoir. If the parameter value of the first liquid phase parameter is in the value range of the first liquid phase parameter of the fluid-containing reservoir, the parameter value of the second liquid phase parameter corresponding to the parameter value of the first liquid phase parameter is in the value range of the second liquid phase parameter corresponding to the fluid-containing reservoir, and the position of the target area corresponding to the parameter value of the first liquid phase parameter and the parameter value of the second liquid phase parameter belongs to the reservoir to be determined in the target area, the position of the target area corresponding to the parameter value of the first liquid phase parameter and the parameter value of the second liquid phase parameter belongs to the fluid-containing reservoir in the target area. And performing the judgment process on the inversion result of the first liquid phase parameter and the inversion result of the second liquid phase parameter of the target area, so that the fluid reservoir of the target area can be determined.

And according to the first solid phase parameter, the second solid phase parameter, the first liquid phase parameter and the second liquid phase parameter of the target area, inverting each physical property parameter in at least one physical property parameter of the two-phase medium, so as to obtain an inversion result of each physical property parameter of the target area. If the at least one physical property parameter is a physical property parameter, the hydrocarbon reservoir prediction unit 1103 compares a parameter value of each physical property parameter in the inversion result of the physical property parameter of the target region with a corresponding hydrocarbon threshold, and if the parameter value of the physical property parameter existing in the inversion result of the physical property parameter is greater than the corresponding hydrocarbon threshold and the position of the target region corresponding to the parameter value of the physical property parameter greater than the hydrocarbon threshold belongs to the fluid-containing reservoir of the target region, the position of the target region corresponding to the parameter value of the physical property parameter greater than the hydrocarbon threshold belongs to the hydrocarbon reservoir of the target region. The hydrocarbon reservoir prediction unit 1103 performs the above determination process on the parameter value of each physical property parameter in the inversion result of the physical property parameter of the target region, so as to predict the hydrocarbon reservoir of the target region.

If the at least one physical property parameter includes a plurality of physical property parameters, the hydrocarbon reservoir prediction unit 1103 compares the parameter value of each physical property parameter in the inversion result of each physical property parameter of the target region with the corresponding hydrocarbon threshold value, and if each physical property parameter of the plurality of physical property parameters has a parameter value of a physical property parameter greater than the respective hydrocarbon threshold value, and the parameter values of the physical property parameters greater than the respective hydrocarbon threshold values correspond to the same position of the target region, and the same position of the target region belongs to the fluid-containing reservoir of the target region, the parameter values of the physical property parameters greater than the respective hydrocarbon threshold values correspond to the same position of the target region belonging to the hydrocarbon reservoir of the target region. The hydrocarbon reservoir prediction unit 1103 performs the above determination process on the parameter value of each physical property parameter in the inversion result of the plurality of physical property parameters of the target region, so that the hydrocarbon reservoir of the target region can be predicted. Wherein the at least one physical property parameter includes, but is not limited to, porosity and oil and gas saturation. The oil-gas threshold corresponding to each physical property parameter is set according to actual experience, and the embodiment of the invention is not limited.

According to the oil and gas reservoir prediction device for the two-phase medium, the reservoir to be determined in the target area is obtained according to the parameter value of the first solid-phase parameter and the parameter value of the second solid-phase parameter of the two-phase medium in the target area, the fluid-containing reservoir in the target area is determined according to the parameter value of the first liquid-phase parameter and the parameter value of the second liquid-phase parameter of the two-phase medium and the reservoir to be determined in the target area, and finally the oil and gas reservoir in the target area is predicted according to the parameter value of at least one physical parameter of the two-phase medium and the fluid-containing reservoir in the target area, so that quantitative prediction of the oil and gas reservoir in the target area can be achieved, and accuracy of prediction of the oil and gas reservoir is improved.

Fig. 12 is a schematic structural diagram of a hydrocarbon reservoir prediction apparatus for a dual-phase medium according to another embodiment of the present invention, and as shown in fig. 12, the hydrocarbon reservoir prediction apparatus for a dual-phase medium according to an embodiment of the present invention further includes a first obtaining unit 1104 and a second obtaining unit 1105, where:

the first obtaining unit 1104 is configured to perform dual-phase medium elastic impedance inversion on the prestack angle partial superposed gathers at least at four different incident angles of the target area according to a dual-phase medium elastic impedance equation, and obtain a dual-phase medium elastic impedance data volume corresponding to each incident angle; the elastic impedance equation of the two-phase medium is obtained based on a simplified equation of reflection coefficients of the two-phase medium and an impedance expression of the reflection coefficients of the two-phase medium, and the simplified equation of the reflection coefficients of the two-phase medium is preset and comprises the first solid phase parameter, the second solid phase parameter, the first liquid phase parameter and the second liquid phase parameter; the second obtaining unit 1105 is configured to obtain a parameter value of the first solid-phase parameter, a parameter value of the second solid-phase parameter, a parameter value of the first liquid-phase parameter, and a parameter value of the second liquid-phase parameter according to the two-phase medium elastic impedance data volumes corresponding to the at least four incident angles and the respective two-phase medium elastic impedance equations.

where DEI (theta) represents a two-phase medium elastic impedance data volume at an incident angle theta, I₀Represents the average longitudinal wave impedance of the target area, A represents dualA first solid phase parameter of the phase medium, N a second solid phase parameter of the biphasic medium, P a first liquid phase parameter of the biphasic medium, Q a second liquid phase parameter of the biphasic medium, A₀Mean value of the first solid phase parameter, N, representing the target region₀Mean value of the second solid phase parameter, P, representing the target region₀Mean value of a parameter of the first liquid phase, Q, representing the target area₀An average value of a second liquid phase parameter representing the target area, a (theta) represents a coefficient corresponding to the first solid phase parameter, b (theta) represents a coefficient corresponding to the second solid phase parameter, c (theta) represents a coefficient corresponding to the first liquid phase parameter, d (theta) represents a coefficient corresponding to the second liquid phase parameter, and a (theta), b (theta), c (theta) and d (theta) incidence angles theta are related.

Because the two-phase medium elastic impedance equation comprises four parameters, namely a first solid phase parameter, a second solid phase parameter, a first liquid phase parameter and a second liquid phase parameter, at least four elastic impedance data volumes with different incidence angles need to be inverted. The first obtaining unit 1104 performs dual-phase medium elastic impedance inversion on the prestack angle partial superposed gathers of at least four different incident angles of the target area according to the dual-phase medium elastic impedance equation, so as to obtain dual-phase medium elastic impedance data volumes of at least four different incident angles. Wherein the prestack angle partially superimposed gather of the angle of incidence of the target region is obtainable from prestack gather data of the target region. The specific process of the inversion of the elastic impedance of the two-phase medium at each incident angle is the same as the algorithm and the flow of the inversion of the elastic impedance of the equivalent medium in the prior art, and is not repeated here.

Due to the same two-phase medium elastic impedance data body, the exponential terms at all sampling points are the same. The second obtaining unit 1105 performs logarithmic operation on the two-phase medium elastic impedance equation, and brings in the two-phase medium elastic impedance data volume of at least four different incident angles and the index terms of the corresponding angles to obtain a multivariate linear equation set. And solving the multivariate linear equation set to obtain the parameter value of the first solid phase parameter, the parameter value of the second solid phase parameter, the parameter value of the first liquid phase parameter and the parameter value of the second liquid phase parameter.

On the basis of the above embodiments, further, the simplified equation of the reflection coefficient of the two-phase medium is the sum of a solid phase part and a liquid phase part, the solid phase part is obtained according to the first solid phase parameter, the second solid phase parameter and the respective corresponding coefficients, and the liquid phase part is obtained according to the first liquid phase parameter, the second liquid phase parameter and the respective corresponding coefficients; wherein the coefficient corresponding to the first solid phase parameter, the coefficient corresponding to the second solid phase parameter, the coefficient corresponding to the first liquid phase parameter, and the coefficient corresponding to the second liquid phase parameter are all related to the incident angle.

On the basis of the foregoing embodiments, further, the first solid phase parameter is a measure of a tensile stress required to prevent the solid skeleton of the two-phase medium from being compressed laterally, the second solid phase parameter is a measure of a shear strain resistance of the solid skeleton of the two-phase medium, and a coefficient corresponding to the first solid phase parameter is determined according to a coefficient of a lame parameter of an equivalent medium reflectance equation, and a coefficient corresponding to the second solid phase parameter is determined according to a coefficient of a shear modulus of the equivalent medium reflectance equation.

Fig. 13 is a schematic structural diagram of a hydrocarbon reservoir prediction apparatus for a dual-phase medium according to yet another embodiment of the present invention, as shown in fig. 13, on the basis of the foregoing embodiments, further, the hydrocarbon reservoir prediction apparatus for a dual-phase medium according to an embodiment of the present invention further includes a construction unit 1106, a solving unit 1107, and a third obtaining unit 1108, where:

the constructing unit 1106 is configured to construct an I × J order matrix equation set according to the I incident angles and J sets of elastic parameters of the two-phase medium in the pre-stack gather angle range and the simplified equation of the reflection coefficient of the two-phase medium; the longitudinal wave reflection coefficient corresponding to each incident angle and each group of the elastic parameters of the two-phase medium is obtained by solving a general equation of the reflection coefficient of the two-phase medium; each set of biphasic medium elasticity parameters comprises the first solid phase parameter, the second solid phase parameter, the first liquid phase parameter and the second liquid phase parameter; the solving unit 1107 is configured to solve the I × J order matrix equation set to obtain a value of a coefficient corresponding to a first liquid phase parameter corresponding to each of the I incident angles and a value of a coefficient corresponding to a second liquid phase parameter corresponding to each of the I incident angles; the third obtaining unit 1108 is configured to obtain a relationship between the incident angle and a coefficient corresponding to the first liquid phase parameter according to a value of the coefficient corresponding to the first liquid phase parameter corresponding to each of the I incident angles, and obtain a relationship between the incident angle and a coefficient corresponding to the second liquid phase parameter according to a value of the coefficient corresponding to the second liquid phase parameter corresponding to each of the I incident angles.

Specifically, J groups of elasticity parameters of the two-phase medium are randomly constructed according to the petrophysical model of the target area, and each group of elasticity parameters of the two-phase medium comprises the first solid phase parameter, the second solid phase parameter, the first liquid phase parameter and the second liquid phase parameter. And setting I incident angles, wherein the I incident angles belong to the angle range of the prestack gather. The construction unit 1106 inputs the I incident angles and the J sets of the two-phase medium elastic parameters into the simplified equation of the reflection coefficient of the two-phase medium in a free combination manner, so as to obtain I × J simplified equations of the reflection coefficient of the two-phase medium, and the I × J order matrix equation set is formed by the simplified equations of the reflection coefficient of the I × J two-phase medium. The petrophysical model of the target region is set according to practical experience, and the embodiment of the invention is not limited. The pre-stack gather angle range is set according to practical experience, and the embodiment of the invention is not limited. The specific values of I and J are set according to actual needs, and the embodiment of the present invention is not limited.

In the I multiplied by J order matrix equation set (11), I incident angles and J sets of two-phase medium elastic parameters are known numbers, D is obtained, and a solid phase coefficient matrix S_sThe solid phase elastic parameter matrix W can be obtained from the equations (9) and (10)_sCan be obtained according to the parameter value of the first solid phase parameter and the parameter value of the second solid phase parameter in the elastic parameters of the J groups of two-phase medium, and the liquid phase elastic parameter matrix W_FThe parameter value of the first liquid phase parameter and the second liquid in the elastic parameter of the two-phase medium in the J groupAnd (5) solving parameter values of the phase parameters. The system of I × J order matrix equations (11) can be converted into the following expression:

S_F＝((D-S_sW_s)^T(D-S_sW_s))^-1(D-S_sW_s)^TW_F (12)

the solving unit 1107 solves the above equation set (12) by using the least square method, and then the liquid phase coefficient matrix S can be obtained_FThereby obtaining the values of the coefficients corresponding to the first liquid phase parameters corresponding to the respective I incident angles and the values of the coefficients corresponding to the second liquid phase parameters corresponding to the respective I incident angles.

After obtaining the values of the coefficients corresponding to the first liquidus parameters corresponding to the I incident angles, the third obtaining unit 1108 may establish the relationship between the incident angle and the coefficient corresponding to the first liquidus parameter through data fitting, and may find the coefficient corresponding to the first liquidus parameter corresponding to the incident angle under the condition that the incident angle is known. After obtaining the values of the coefficients corresponding to the second liquid-phase parameters corresponding to the I incident angles, the third obtaining unit 1108 may establish the relationship between the incident angle and the coefficient corresponding to the second liquid-phase parameter by means of data fitting, and may obtain the coefficient corresponding to the second liquid-phase parameter corresponding to the incident angle when the incident angle is known.

Fig. 14 is a schematic structural diagram of a hydrocarbon reservoir prediction apparatus for a dual-phase medium according to still another embodiment of the present invention, and as shown in fig. 14, on the basis of the foregoing embodiments, further, the hydrocarbon reservoir prediction apparatus for a dual-phase medium according to an embodiment of the present invention further includes a fourth obtaining unit 1109 and a fifth obtaining unit 1110, where:

a fourth obtaining unit 1109 is configured to input the parameter value of the first solid-phase parameter, the parameter value of the second solid-phase parameter, the parameter value of the first liquid-phase parameter, and the parameter value of the second liquid-phase parameter to a physical property parameter target inversion function, so as to obtain an equation to be solved; wherein the physical property parameter target inversion function is obtained after training based on the at least one physical property parameter and a sample training data set of a corresponding first solid phase parameter, a corresponding second solid phase parameter, a corresponding first liquid phase parameter and a corresponding second liquid phase parameter; the fifth obtaining unit 1110 is configured to solve the equation to be solved, and obtain a parameter value of the at least one physical property parameter.

Specifically, after obtaining the parameter value of the first solid-phase parameter, the parameter value of the second solid-phase parameter, the parameter value of the first liquid-phase parameter, and the parameter value of the second liquid-phase parameter, the fourth obtaining unit 1109 inputs the parameter value of the first solid-phase parameter, the parameter value of the second solid-phase parameter, the parameter value of the first liquid-phase parameter, and the parameter value of the second liquid-phase parameter as known quantities into the objective inversion function of the physical property parameters, so as to obtain an equation to be solved, where the unknown quantity of the equation to be solved includes the at least one physical property parameter.

After obtaining the equation to be solved, the fifth obtaining unit 1110 solves the equation to be solved. Since the range of each of the at least one physical property parameter is limited, the posterior probability density value of the target inversion function can be obtained by enumerating each of the at least one physical property parameter, and a plurality of posterior probability density values can be obtained. And taking the enumerated value of the at least one physical property parameter corresponding to the maximum value of the posterior probability density as the parameter value of the at least one physical property parameter. Namely, the parameter value of at least one physical property parameter corresponding to the maximum value of the posterior probability density of the target inversion function is obtained as the inversion value of the final physical property parameter. The value range of each physical property parameter is set according to actual experience, and the embodiment of the invention is not limited.

The embodiment of the apparatus provided in the embodiment of the present invention may be specifically configured to execute the processing flows of the above method embodiments, and the functions of the apparatus are not described herein again, and refer to the detailed description of the above method embodiments.

Fig. 15 is a schematic physical structure diagram of an electronic device according to an embodiment of the present invention, and as shown in fig. 15, the electronic device may include: a processor (processor)1501, a communication Interface (Communications Interface)1502, a memory (memory)1503 and a communication bus 1504, wherein the processor 1501, the communication Interface 1502 and the memory 1503 communicate with each other via the communication bus 1504. The processor 1501 may call the logic instructions in the memory 1503 to perform the following method: obtaining a reservoir to be determined of a target area according to a parameter value of a first solid phase parameter and a parameter value of a second solid phase parameter of a two-phase medium of the target area; determining a fluid-containing reservoir of the target area according to the parameter value of the first liquid phase parameter and the parameter value of the second liquid phase parameter of the two-phase medium of the target area and the reservoir to be determined of the target area; predicting a hydrocarbon reservoir of the target region according to the parameter value of at least one physical property parameter of the dual-phase medium of the target region and the fluid-containing reservoir of the target region; wherein the parameter value of the first solid phase parameter, the parameter value of the second solid phase parameter, the parameter value of the first liquid phase parameter, and the parameter value of the second liquid phase parameter are obtained in advance, and the parameter value of the at least one physical property parameter is obtained according to the parameter value of the first solid phase parameter, the parameter value of the second solid phase parameter, the parameter value of the first liquid phase parameter, and the parameter value of the second liquid phase parameter.

In addition, the logic instructions in the memory 1503 can be implemented in the form of software functional units and stored in a computer readable storage medium when the software functional units are sold or used as independent products. Based on such understanding, the technical solution of the present invention may be embodied in the form of a software product, which is stored in a storage medium and includes instructions for causing a computer device (which may be a personal computer, a server, or a network device) to execute all or part of the steps of the method according to the embodiments of the present invention. And the aforementioned storage medium includes: a U-disk, a removable hard disk, a Read-Only Memory (ROM), a Random Access Memory (RAM), a magnetic disk or an optical disk, and other various media capable of storing program codes.

The present embodiment discloses a computer program product comprising a computer program stored on a non-transitory computer readable storage medium, the computer program comprising program instructions which, when executed by a computer, enable the computer to perform the method provided by the above-mentioned method embodiments, for example, comprising: obtaining a reservoir to be determined of a target area according to a parameter value of a first solid phase parameter and a parameter value of a second solid phase parameter of a two-phase medium of the target area; determining a fluid-containing reservoir of the target area according to the parameter value of the first liquid phase parameter and the parameter value of the second liquid phase parameter of the two-phase medium of the target area and the reservoir to be determined of the target area; predicting a hydrocarbon reservoir of the target region according to the parameter value of at least one physical property parameter of the dual-phase medium of the target region and the fluid-containing reservoir of the target region; wherein the parameter value of the first solid phase parameter, the parameter value of the second solid phase parameter, the parameter value of the first liquid phase parameter, and the parameter value of the second liquid phase parameter are obtained in advance, and the parameter value of the at least one physical property parameter is obtained according to the parameter value of the first solid phase parameter, the parameter value of the second solid phase parameter, the parameter value of the first liquid phase parameter, and the parameter value of the second liquid phase parameter.

The present embodiment provides a computer-readable storage medium, which stores a computer program, where the computer program causes the computer to execute the method provided by the above method embodiments, for example, the method includes: obtaining a reservoir to be determined of a target area according to a parameter value of a first solid phase parameter and a parameter value of a second solid phase parameter of a two-phase medium of the target area; determining a fluid-containing reservoir of the target area according to the parameter value of the first liquid phase parameter and the parameter value of the second liquid phase parameter of the two-phase medium of the target area and the reservoir to be determined of the target area; predicting a hydrocarbon reservoir of the target region according to the parameter value of at least one physical property parameter of the dual-phase medium of the target region and the fluid-containing reservoir of the target region; wherein the parameter value of the first solid phase parameter, the parameter value of the second solid phase parameter, the parameter value of the first liquid phase parameter, and the parameter value of the second liquid phase parameter are obtained in advance, and the parameter value of the at least one physical property parameter is obtained according to the parameter value of the first solid phase parameter, the parameter value of the second solid phase parameter, the parameter value of the first liquid phase parameter, and the parameter value of the second liquid phase parameter.

As will be appreciated by one skilled in the art, embodiments of the present invention may be provided as a method, system, or computer program product. Accordingly, the present invention may take the form of an entirely hardware embodiment, an entirely software embodiment or an embodiment combining software and hardware aspects. Furthermore, the present invention may take the form of a computer program product embodied on one or more computer-usable storage media (including, but not limited to, disk storage, CD-ROM, optical storage, and the like) having computer-usable program code embodied therein.

The present invention is described with reference to flowchart illustrations and/or block diagrams of methods, apparatus (systems), and computer program products according to embodiments of the invention. It will be understood that each flow and/or block of the flow diagrams and/or block diagrams, and combinations of flows and/or blocks in the flow diagrams and/or block diagrams, can be implemented by computer program instructions. These computer program instructions may be provided to a processor of a general purpose computer, special purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, create means for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.

These computer program instructions may also be stored in a computer-readable memory that can direct a computer or other programmable data processing apparatus to function in a particular manner, such that the instructions stored in the computer-readable memory produce an article of manufacture including instruction means which implement the function specified in the flowchart flow or flows and/or block diagram block or blocks.

These computer program instructions may also be loaded onto a computer or other programmable data processing apparatus to cause a series of operational steps to be performed on the computer or other programmable apparatus to produce a computer implemented process such that the instructions which execute on the computer or other programmable apparatus provide steps for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.

In the description herein, reference to the description of the terms "one embodiment," "a particular embodiment," "some embodiments," "for example," "an example," "a particular example," or "some examples," etc., means that a particular feature, structure, material, or characteristic described in connection with the embodiment or example is included in at least one embodiment or example of the invention. In this specification, the schematic representations of the terms used above do not necessarily refer to the same embodiment or example. Furthermore, the particular features, structures, materials, or characteristics described may be combined in any suitable manner in any one or more embodiments or examples.

The above-mentioned embodiments are intended to illustrate the objects, technical solutions and advantages of the present invention in further detail, and it should be understood that the above-mentioned embodiments are only exemplary embodiments of the present invention, and are not intended to limit the scope of the present invention, and any modifications, equivalent substitutions, improvements and the like made within the spirit and principle of the present invention should be included in the scope of the present invention.

Claims

1. A method for predicting a hydrocarbon reservoir with a two-phase medium is characterized by comprising the following steps:

wherein the parameter value of the first solid phase parameter, the parameter value of the second solid phase parameter, the parameter value of the first liquid phase parameter, and the parameter value of the second liquid phase parameter are obtained in advance, and the parameter value of the at least one physical property parameter is obtained according to the parameter value of the first solid phase parameter, the parameter value of the second solid phase parameter, the parameter value of the first liquid phase parameter, and the parameter value of the second liquid phase parameter;

wherein the step of obtaining the parameter value of the first solid phase parameter, the parameter value of the second solid phase parameter, the parameter value of the first liquid phase parameter, and the parameter value of the second liquid phase parameter comprises:

according to a two-phase medium elastic impedance equation, performing two-phase medium elastic impedance inversion on the prestack angle part superposed gathers of at least four different incident angles of the target area to obtain a two-phase medium elastic impedance data volume corresponding to each incident angle; the elastic impedance equation of the two-phase medium is obtained based on a simplified equation of reflection coefficients of the two-phase medium and an impedance expression of the reflection coefficients of the two-phase medium, and the simplified equation of the reflection coefficients of the two-phase medium is preset and comprises the first solid phase parameter, the second solid phase parameter, the first liquid phase parameter and the second liquid phase parameter;

and obtaining the parameter value of the first solid phase parameter, the parameter value of the second solid phase parameter, the parameter value of the first liquid phase parameter and the parameter value of the second liquid phase parameter according to the two-phase medium elastic impedance data bodies corresponding to the at least four incidence angles and the two-phase medium elastic impedance equations corresponding to the two-phase medium elastic impedance data bodies.

2. The method of claim 1, wherein the simplified equation for the reflectance of the bi-phase medium is the sum of a solid phase fraction obtained from the first and second solid phase parameters and respective coefficients and a liquid phase fraction obtained from the first and second liquid phase parameters and respective coefficients; wherein the coefficient corresponding to the first solid phase parameter, the coefficient corresponding to the second solid phase parameter, the coefficient corresponding to the first liquid phase parameter, and the coefficient corresponding to the second liquid phase parameter are all related to the incident angle.

3. The method of claim 2, wherein the first solid phase parameter is a measure of the tensile stress required to prevent lateral compression of the solid framework of the dual phase medium, the second solid phase parameter is a measure of the shear strain resistance of the solid framework of the dual phase medium, and the coefficients for the first solid phase parameter are determined from the coefficients for the lame parameter of the equivalent medium reflectance equation, and the coefficients for the second solid phase parameter are determined from the coefficients for the shear modulus of the equivalent medium reflectance equation.

4. The method of claim 2, wherein obtaining the coefficients corresponding to the first liquid phase parameter and the second liquid phase parameter comprises:

constructing an I multiplied by J order matrix equation set according to I incident angles in the angle range of the prestack gather, J sets of elastic parameters of the two-phase medium and a simplified equation of the reflection coefficient of the two-phase medium; the longitudinal wave reflection coefficient corresponding to each incident angle and each group of the elastic parameters of the two-phase medium is obtained by solving a general equation of the reflection coefficient of the two-phase medium; each set of biphasic medium elasticity parameters comprises the first solid phase parameter, the second solid phase parameter, the first liquid phase parameter and the second liquid phase parameter;

solving the I multiplied by J order matrix equation set to obtain the coefficient values corresponding to the first liquid phase parameters corresponding to the I incident angles and the coefficient values corresponding to the second liquid phase parameters corresponding to the I incident angles;

and obtaining the relation between the incident angle and the coefficient corresponding to the first liquid phase parameter according to the value of the coefficient corresponding to the first liquid phase parameter corresponding to each of the I incident angles, and obtaining the relation between the incident angle and the coefficient corresponding to the second liquid phase parameter according to the value of the coefficient corresponding to the second liquid phase parameter corresponding to each of the I incident angles.

5. The method of claim 1, wherein obtaining the parameter value for the at least one physical parameter from the parameter value for the first solid phase parameter, the parameter value for the second solid phase parameter, the parameter value for the first liquid phase parameter, and the parameter value for the second liquid phase parameter comprises:

inputting the parameter value of the first solid phase parameter, the parameter value of the second solid phase parameter, the parameter value of the first liquid phase parameter and the parameter value of the second liquid phase parameter into a physical property parameter target inversion function to obtain an equation to be solved; wherein the physical property parameter target inversion function is obtained after training based on the at least one physical property parameter and a sample training data set of a corresponding first solid phase parameter, a corresponding second solid phase parameter, a corresponding first liquid phase parameter and a corresponding second liquid phase parameter;

and solving the equation to be solved to obtain the parameter value of the at least one physical property parameter.

6. The method of any one of claims 1 to 5, wherein the at least one physical property parameter comprises porosity and/or oil and gas saturation.

7. A hydrocarbon reservoir prediction device for a two-phase medium, comprising:

the device further comprises:

the first obtaining unit is used for performing two-phase medium elastic impedance inversion on the prestack angle part superposed gathers of at least four different incident angles of the target area according to a two-phase medium elastic impedance equation to obtain a two-phase medium elastic impedance data volume corresponding to each incident angle; the elastic impedance equation of the two-phase medium is obtained based on a simplified equation of reflection coefficients of the two-phase medium and an impedance expression of the reflection coefficients of the two-phase medium, and the simplified equation of the reflection coefficients of the two-phase medium is preset and comprises the first solid phase parameter, the second solid phase parameter, the first liquid phase parameter and the second liquid phase parameter;

and the second obtaining unit is used for obtaining the parameter value of the first solid-phase parameter, the parameter value of the second solid-phase parameter, the parameter value of the first liquid-phase parameter and the parameter value of the second liquid-phase parameter according to the two-phase medium elastic impedance data bodies corresponding to the at least four incidence angles and the two-phase medium elastic impedance equations corresponding to the two-phase medium elastic impedance data bodies.

8. The apparatus of claim 7, wherein the simplified equation for the reflectance of the bi-phase medium is the sum of a solid phase fraction obtained from the first and second solid phase parameters and respective coefficients and a liquid phase fraction obtained from the first and second liquid phase parameters and respective coefficients; wherein the coefficient corresponding to the first solid phase parameter, the coefficient corresponding to the second solid phase parameter, the coefficient corresponding to the first liquid phase parameter, and the coefficient corresponding to the second liquid phase parameter are all related to the incident angle.

9. The apparatus of claim 8, wherein the first solid phase parameter is a measure of the tensile stress required to prevent lateral compression of the solid framework of the dual phase medium, the second solid phase parameter is a measure of the shear strain resistance of the solid framework of the dual phase medium, and the coefficients for the first solid phase parameter are determined from the coefficients for the lame parameter of the equivalent medium reflectance equation, and the coefficients for the second solid phase parameter are determined from the coefficients for the shear modulus of the equivalent medium reflectance equation.

10. The apparatus of claim 8, further comprising:

the construction unit is used for constructing an I multiplied by J order matrix equation set according to I incident angles in the angle range of the prestack gather, J sets of elastic parameters of the two-phase medium and a simplified equation of the reflection coefficient of the two-phase medium; the longitudinal wave reflection coefficient corresponding to each incident angle and each group of the elastic parameters of the two-phase medium is obtained by solving a general equation of the reflection coefficient of the two-phase medium; each set of biphasic medium elasticity parameters comprises the first solid phase parameter, the second solid phase parameter, the first liquid phase parameter and the second liquid phase parameter;

the solving unit is used for solving the I multiplied by J order matrix equation set to obtain the coefficient values corresponding to the first liquid phase parameters corresponding to the I incident angles and the coefficient values corresponding to the second liquid phase parameters corresponding to the I incident angles;

a third obtaining unit, configured to obtain, according to values of coefficients corresponding to first liquid phase parameters corresponding to the I incident angles, a relationship between the incident angle and the coefficient corresponding to the first liquid phase parameter, and obtain, according to values of coefficients corresponding to second liquid phase parameters corresponding to the I incident angles, a relationship between the incident angle and the coefficient corresponding to the second liquid phase parameter.

11. The apparatus of claim 7, further comprising:

a fourth obtaining unit, configured to input the parameter value of the first solid-phase parameter, the parameter value of the second solid-phase parameter, the parameter value of the first liquid-phase parameter, and the parameter value of the second liquid-phase parameter to a physical property parameter target inversion function, so as to obtain an equation to be solved; wherein the physical property parameter target inversion function is obtained after training based on the at least one physical property parameter and a sample training data set of a corresponding first solid phase parameter, a corresponding second solid phase parameter, a corresponding first liquid phase parameter and a corresponding second liquid phase parameter;

and the fifth obtaining unit is used for solving the equation to be solved to obtain the parameter value of the at least one physical property parameter.

12. The apparatus of any one of claims 7 to 11, wherein the at least one physical property parameter comprises porosity and/or oil gas saturation.

13. An electronic device comprising a memory, a processor and a computer program stored on the memory and executable on the processor, characterized in that the steps of the method of any of claims 1 to 6 are implemented when the computer program is executed by the processor.

14. A computer-readable storage medium, on which a computer program is stored, which, when being executed by a processor, carries out the steps of the method of any one of claims 1 to 6.