Reservoir physical property parameter simultaneous calculation method, device, equipment and storage medium

Abstract

The application provides a reservoir physical property parameter simultaneous calculation method, device, equipment and storage medium, including: calculating well-ground seismic correlation coefficients of current sought point seismic data and seismic data at each well point; normalizing the well-ground seismic correlation coefficients to obtain normalized seismic correlation coefficients; calculating physical property correlation coefficients between all physical property data in each well and P-wave velocity, S-wave velocity, density and original seismic data; the all physical property data include: porosity por, shale content vsh, sandy mineral content sand, dolomite content dolo and limestone content lime; repeating step S3 until the physical property correlation coefficients of all m wells are completely calculated, applying the normalized seismic correlation coefficients and the physical property correlation coefficients to obtain a final multi-well physical property data expression; normalizing the physical property data expression to obtain physical property parameter data under the whole work area.

Description

Technical Field

[0001] This application relates to the field of geophysical exploration, and in particular to a method, apparatus, equipment and storage medium for simultaneous calculation of reservoir physical parameters. Background Technology

[0002] Reservoir physical properties mainly include porosity, clay content, and sandy mineral content. Currently, the main methods for determining reservoir physical properties both domestically and internationally are:

[0003] 1. Obtain the linear correlation by using the intersection diagram of wave impedance and physical property parameters, and then directly convert them;

[0004] 2. By using statistical stochastic simulation methods, the nonlinear correlation is determined and then simulated.

[0005] 3. By using deep learning methods, establish the intrinsic relationship between known samples and the desired physical property data, and then learn it.

[0006] 4. Combining methods 1 and 2, we comprehensively consider multiple types of data and use correlation coefficients and linear transformations to obtain the final result. The first method has low accuracy but can quickly obtain data and provide a general understanding. The second method significantly improves accuracy and precision compared to the first, but it requires more known data and a certain correlation between the desired data and the known data; however, it also requires a longer computation time. The third method has higher requirements for sample points, including the quantity and accuracy of the samples; higher quality sample points result in more accurate calculations, but also require a longer computation time. The fourth method is currently only applicable to single-well scenarios. Each method has its own applicable situations, and different methods can be selected according to the specific needs of the work.

[0007] Each method has its own drawbacks. In order to solve the problems mentioned above, there is an urgent need for a method that can solve all the problems and be applicable to various scenarios. Summary of the Invention

[0008] To address the aforementioned issues, this application provides a method, apparatus, device, and storage medium for simultaneous calculation of reservoir physical parameters.

[0009] This application provides a method for simultaneous calculation of reservoir physical property parameters, including:

[0010] S1: Calculate the well-to-ground seismic correlation coefficient between the seismic data at the current point and the seismic data at each well point;

[0011] S2: Normalize the well-to-ground seismic correlation coefficient to obtain the normalized seismic correlation coefficient;

[0012] S3: Calculate the correlation coefficients between all physical property data within each well and the P-wave velocity, S-wave velocity, density, and raw seismic data; the physical property data include: porosity (por), clay content (vsh), sandy mineral content (sand), dolomite content (dolo), and limestone content (lime).

[0013] S4: Repeat step S3 until the physical property correlation coefficients of all m wells have been calculated. Apply the normalized seismic correlation coefficient and physical property correlation coefficient to obtain the final physical property data expression for the multi-well.

[0014] S5: Normalize the physical property data expression to obtain the physical property parameter data for the entire work area.

[0015] In some embodiments, the specific method for calculating the well-to-ground seismic correlation coefficient between the seismic data at the current point and the seismic data at each well point includes:

[0016] Let the seismic data of the point being sought be seis. * The seismic data at each well point is seis l If the number of wells is m, then the range of l is [1, m]. A single-channel seismic dataset is a one-dimensional dataset, dependent only on time t, which ranges from [0, n]. It is the average value of single-channel seismic data at the l-th well point. If is the average value of the single-track seismic data of the desired point, then the correlation between the seismic data of the desired point and the seismic data at that well point is called the well-to-ground seismic correlation coefficient, and its mathematical expression is:

[0017]

[0018] In some embodiments, the specific method for normalizing the well-to-surface seismic correlation coefficient is as follows:

[0019]

[0020] in,

[0021] ω l :coefficient

[0022] :ω l Normalized value of coefficients.

[0023] In some embodiments, the specific method for calculating the physical property correlation coefficients between all physical property data within each well and the P-wave velocity, S-wave velocity, density, and raw seismic data includes:

[0024] If the minimum value of porosity data for the target layer is a and the maximum value is b, then the range of porosity por is set as [a, b].

[0025] (1) The horizontal axis represents the line number, the vertical axis represents the trace number, and the vertical axis represents the time. Let the line number be i, the trace number be j, and the time be t. Normalize the P-wave velocity vp, S-wave velocity vs, density den, and the squared values ​​of seismic data after stack to the porosity range [a, b]. Extract the minimum value x and the maximum value y from the P-wave velocity of the target segment. Let the range of P-wave velocity vp be [x, y]. Then, according to the normalization formula, calculate the value for the l-th well:

[0026]

[0027] but

[0028] in For the P-wave velocity in the range [a, b], the S-wave velocity in the range [a, b] can be calculated similarly. density Square of stacked data

[0029] (2) Porosity using well logging data With the well point Perform correlation analysis separately, targeting and Calculate the correlation coefficient:

[0030]

[0031] in For the lth well and The correlation coefficient, for The average value from 1 to n for The average value from 1 to n; similarly, find the average value from 1 to n. respectively with Correlation coefficient:

[0032] (3) Normalize,

[0033]

[0034]

[0035]

[0036]

[0037] (4) The porosity of the intermediate process is determined by linear calculation:

[0038]

[0039] In some embodiments, the methods for determining the correlation coefficients of the mud content (vsh), sandy mineral content (sand), dolomite content (dolo), and limestone content (lime) are the same as the methods for determining the correlation coefficient of porosity.

[0040] get,

[0041] clay content in the intermediate process

[0042] Sandy mineral content in the intermediate process (vsh) ijt ;

[0043] Dolomite content in the intermediate process (dolo) ijt ;

[0044] limestone content in the intermediate process ijt .

[0045] In some embodiments, the specific method for obtaining the final multi-well physical property data expression includes:

[0046]

[0047]

[0048]

[0049]

[0050]

[0051] por ijt ′ represents the final porosity;

[0052] vsh ijt ′ represents the final mud content;

[0053] sand ijt ′ represents the final sandy mineral content;

[0054] dolo ijt ′ represents the final dolomite content;

[0055] lime ijt ′ represents the final limestone content.

[0056] In some embodiments, the specific formula for normalizing the physical property data expression is as follows:

[0057]

[0058]

[0059]

[0060]

[0061]

[0062] This represents the final porosity after normalization.

[0063] This represents the final mud content after normalization.

[0064] This represents the final normalized content of sandy minerals;

[0065] This represents the final dolomite content after normalization.

[0066] This represents the final limestone content after normalization.

[0067] This application provides a device for simultaneously calculating reservoir physical property parameters, including:

[0068] The module includes a well-to-surface seismic correlation coefficient calculation module, a seismic correlation coefficient normalization module, a physical property correlation coefficient calculation module, a physical property data expression calculation module, and a physical property parameter data calculation module.

[0069] The well-to-ground seismic correlation coefficient calculation module calculates the well-to-ground seismic correlation coefficient between the seismic data of the current point and the seismic data at each well point.

[0070] The earthquake correlation coefficient normalization module: normalizes the well-to-surface earthquake correlation coefficient to obtain the normalized earthquake correlation coefficient;

[0071] The physical property correlation coefficient calculation module calculates the physical property correlation coefficient between all physical property data within each well and the P-wave velocity, S-wave velocity, density, and original seismic data. The physical property data includes: porosity (por), clay content (vsh), sandy mineral content (sand), dolomite content (dolo), and limestone content (lime).

[0072] The physical property data expression calculation module completes the calculation of all physical property correlation coefficients for all m wells, and applies the normalized seismic correlation coefficient and physical property correlation coefficient to obtain the final physical property data expression for the multi-well.

[0073] The physical property parameter data calculation module normalizes the physical property data expression to obtain the physical property parameter data for the entire work area.

[0074] This application provides a device for simultaneously calculating reservoir physical parameters, including a memory and a processor. The memory stores a computer program, which, when executed by the processor, performs any of the above-described methods for simultaneously calculating reservoir physical parameters.

[0075] This application provides a storage medium storing a computer program that can be executed by one or more processors and can be used to implement the method for simultaneous calculation of reservoir physical parameters described in any of the above claims.

[0076] This application provides a method, apparatus, equipment, and storage medium for simultaneous calculation of reservoir physical property parameters.

[0077] Based on the elastic parameter results of pre-stack inversion, including P-wave velocity, S-wave velocity, density, and the squares of post-stack seismic data, and considering the presence of multiple wells in the work area, the entire process first determines the correlation between the calculated point and each well point, then calculates the physical property parameters within a single well, and finally uses a correlation coefficient weighting method. This method is fast and comprehensively considers the multi-well situation, employing the correlation between three elastic parameters and one original seismic data set, thus ensuring accuracy and precision. Finally, the calculation method of this invention can output all physical property data simultaneously, eliminating the need to solve them one by one. Therefore, when calculating all physical property data, only one calculation is required. Attached Figure Description

[0078] The present application will be described in more detail below based on embodiments and with reference to the accompanying drawings.

[0079] Figure 1 A schematic diagram illustrating the implementation process of a method for simultaneously calculating reservoir physical parameters provided in this application embodiment;

[0080] Figure 2 Well point location diagram provided for embodiments of this application;

[0081] Figure 3 The longitudinal wave velocity diagram provided for the embodiments of this application;

[0082] Figure 4 Shear wave velocity diagrams provided for embodiments of this application;

[0083] Figure 5Density maps provided for embodiments of this application;

[0084] Figure 6 The original seismic data provided for the embodiments of this application;

[0085] Figure 7 Porosity diagrams provided for embodiments of this application;

[0086] Figure 8 This is a schematic diagram illustrating the implementation process of a method for simultaneously calculating reservoir physical parameters provided in an embodiment of this application.

[0087] In the accompanying drawings, the same parts are referred to by the same reference numerals, and the drawings are not drawn to scale. Detailed Implementation

[0088] To make the objectives, technical solutions, and advantages of this application clearer, the application will be further described in detail below with reference to the accompanying drawings. The described embodiments should not be regarded as limitations on this application. All other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of this application.

[0089] In the following description, references are made to “some embodiments,” which describe a subset of all possible embodiments. However, it is understood that “some embodiments” may be the same subset or different subsets of all possible embodiments and may be combined with each other without conflict.

[0090] If the application documents contain similar descriptions such as "first, second, third", the following explanation shall be added: In the following description, the terms "first, second, third" are used only to distinguish similar objects and do not represent a specific order of objects. It is understood that "first, second, third" may be interchanged in a specific order or sequence where permitted, so that the embodiments of this application described herein can be implemented in an order other than that illustrated or described herein.

[0091] Unless otherwise defined, all technical and scientific terms used herein have the same meaning as commonly understood by one of ordinary skill in the art to which this application belongs. The terminology used herein is for the purpose of describing embodiments of this application only and is not intended to limit this application.

[0092] Before introducing the method for simultaneous calculation of reservoir physical parameters provided in the embodiments of this application, a brief introduction is given to the problems existing in the related technologies:

[0093] Reservoir physical properties mainly include porosity, clay content, and sandy mineral content. Currently, the main methods for determining reservoir physical properties both domestically and internationally are:

[0094] 1. Obtain the linear correlation by using the intersection diagram of wave impedance and physical property parameters, and then directly convert them;

[0095] 2. By using statistical stochastic simulation methods, the nonlinear correlation is determined and then simulated.

[0096] 3. By using deep learning methods, establish the intrinsic relationship between known samples and the desired physical property data, and then learn it.

[0097] 4. Combining methods 1 and 2, we comprehensively consider multiple types of data and use correlation coefficients and linear transformations to obtain the final result. The first method has low accuracy but can quickly obtain data and provide a general understanding. The second method significantly improves accuracy and precision compared to the first, but it requires more known data and a certain correlation between the desired data and the known data; however, it also requires a longer computation time. The third method has higher requirements for sample points, including the quantity and accuracy of the samples; higher quality sample points result in more accurate calculations, but also require a longer computation time. The fourth method is currently only applicable to single-well scenarios. Each method has its own applicable situations, and different methods can be selected according to the specific needs of the work.

[0098] To address the problems existing in related technologies, this application provides a method for simultaneously calculating reservoir physical parameters. The method is applied to a device for simultaneously calculating reservoir physical parameters, which can be an electronic device, such as a computer or mobile terminal. The functionality achieved by the method provided in this application can be implemented by the processor of the electronic device calling program code, wherein the program code can be stored in a computer storage medium.

[0099] Example 1

[0100] This application provides a method for simultaneously calculating reservoir physical property parameters. Figure 8 A schematic diagram illustrating the implementation process of a method for simultaneously calculating reservoir physical parameters provided in this application embodiment is shown below. Figure 8 As shown, it includes:

[0101] Based on the foregoing embodiments, this application further provides a method for simultaneous calculation of reservoir physical property parameters, including:

[0102] S1: Calculate the well-to-ground seismic correlation coefficient between the seismic data at the current point and the seismic data at each well point;

[0103] S2: Normalize the well-to-ground seismic correlation coefficient to obtain the normalized seismic correlation coefficient;

[0104] S3: Calculate the correlation coefficients between all physical property data within each well and the P-wave velocity, S-wave velocity, density, and raw seismic data; the physical property data include: porosity (por), clay content (vsh), sandy mineral content (sand), dolomite content (dolo), and limestone content (lime).

[0105] S4: Repeat step S3 until the physical property correlation coefficients of all m wells have been calculated. Apply the normalized seismic correlation coefficient and physical property correlation coefficient to obtain the final physical property data expression for the multi-well.

[0106] S5: Normalize the physical property data expression to obtain the physical property parameter data for the entire work area.

[0107] This application provides a method for simultaneously calculating reservoir physical parameters. Based on the elastic parameter results of pre-stack inversion, including P-wave velocity, S-wave velocity, and density, as well as the squares of post-stack seismic data, the method is suitable for situations with multiple wells in the work area. The process first determines the correlation between the calculation point and each well point, then calculates the physical parameters within a single well, and finally uses a correlation coefficient weighting method. This method is fast and comprehensively considers the multi-well situation, employing the correlation between three elastic parameters and one original seismic data set, thus ensuring accuracy and precision. Finally, the calculation method of this invention can output all physical property data simultaneously, eliminating the need to solve them one by one. Therefore, when calculating all physical property data, only one calculation is required.

[0108] Example 2

[0109] Based on the foregoing embodiments, this application further provides a method for simultaneous calculation of reservoir physical property parameters, including:

[0110] S21: Calculate the well-to-ground seismic correlation coefficient between the current seismic data at the desired point and the seismic data at each well point;

[0111] In some embodiments, the specific method for calculating the well-to-ground seismic correlation coefficient between the seismic data at the current point and the seismic data at each well point includes:

[0112] Let the seismic data of the point being sought be seis. * The seismic data at each well point is seis l If the number of wells is m, then the range of l is [1, m]. A single-channel seismic dataset is a one-dimensional dataset, dependent only on time t, which ranges from [0, n]. It is the average value of single-channel seismic data at the l-th well point. If is the average value of the single-track seismic data of the desired point, then the correlation between the seismic data of the desired point and the seismic data at that well point is called the well-to-ground seismic correlation coefficient, and its mathematical expression is:

[0113]

[0114] S22: Normalize the well-to-ground seismic correlation coefficient to obtain the normalized seismic correlation coefficient;

[0115] S23: Calculate the physical property correlation coefficients between all physical property data within each well and the P-wave velocity, S-wave velocity, density, and raw seismic data; the physical property data include: porosity (por), clay content (vsh), sandy mineral content (sand), dolomite content (dolo), and limestone content (lime).

[0116] S24: Repeat step S3 until the physical property correlation coefficients of all m wells have been calculated. Apply the normalized seismic correlation coefficient and physical property correlation coefficient to obtain the final physical property data expression for the multi-well.

[0117] S25: Normalize the physical property data expression to obtain the physical property parameter data for the entire work area.

[0118] This application provides a method for simultaneously calculating reservoir physical parameters. Based on the elastic parameter results of pre-stack inversion, including P-wave velocity, S-wave velocity, and density, as well as the squares of post-stack seismic data, the method is suitable for situations with multiple wells in the work area. The process first determines the correlation between the calculation point and each well point, then calculates the physical parameters within a single well, and finally uses a correlation coefficient weighting method. This method is fast and comprehensively considers the multi-well situation, employing the correlation between three elastic parameters and one original seismic data set, thus ensuring accuracy and precision. Finally, the calculation method of this invention can output all physical property data simultaneously, eliminating the need to solve them one by one. Therefore, when calculating all physical property data, only one calculation is required.

[0119] Example 3

[0120] Based on the foregoing embodiments, this application further provides a method for simultaneous calculation of reservoir physical property parameters, including:

[0121] S31: Calculate the well-to-ground seismic correlation coefficient between the seismic data at the current point and the seismic data at each well point;

[0122] In some embodiments, the specific method for calculating the well-to-ground seismic correlation coefficient between the seismic data at the current point and the seismic data at each well point includes:

[0123] Let the seismic data of the point being sought be seis. *The seismic data at each well point is seis l If the number of wells is m, then the range of l is [1, m]. A single-channel seismic dataset is a one-dimensional dataset, dependent only on time t, which ranges from [0, n]. It is the average value of single-channel seismic data at the l-th well point. If is the average value of the single-track seismic data of the desired point, then the correlation between the seismic data of the desired point and the seismic data at that well point is called the well-to-ground seismic correlation coefficient, and its mathematical expression is:

[0124]

[0125] S32: Normalize the well-to-ground seismic correlation coefficient to obtain the normalized seismic correlation coefficient;

[0126] In some embodiments, the specific method for normalizing the well-to-surface seismic correlation coefficient is as follows:

[0127]

[0128] in,

[0129] ω l :coefficient

[0130] :ω l Normalized value of coefficients.

[0131] S33: Calculate the correlation coefficients between all physical property data within each well and the P-wave velocity, S-wave velocity, density, and raw seismic data; the physical property data include: porosity (por), clay content (vsh), sandy mineral content (sand), dolomite content (dolo), and limestone content (lime).

[0132] S34: Repeat step S3 until the physical property correlation coefficients of all m wells have been calculated. Apply the normalized seismic correlation coefficient and physical property correlation coefficient to obtain the final physical property data expression for the multi-well.

[0133] S35: Normalize the physical property data expression to obtain the physical property parameter data for the entire work area.

[0134] This application provides a method for simultaneously calculating reservoir physical parameters. Based on the elastic parameter results of pre-stack inversion, including P-wave velocity, S-wave velocity, and density, as well as the squares of post-stack seismic data, the method is suitable for situations with multiple wells in the work area. The process first determines the correlation between the calculation point and each well point, then calculates the physical parameters within a single well, and finally uses a correlation coefficient weighting method. This method is fast and comprehensively considers the multi-well situation, employing the correlation between three elastic parameters and one original seismic data set, thus ensuring accuracy and precision. Finally, the calculation method of this invention can output all physical property data simultaneously, eliminating the need to solve them one by one. Therefore, when calculating all physical property data, only one calculation is required.

[0135] Example 4

[0136] Based on the foregoing embodiments, this application further provides a method for simultaneous calculation of reservoir physical property parameters, including:

[0137] S41: Calculate the well-to-ground seismic correlation coefficient between the seismic data at the current point and the seismic data at each well point;

[0138] In some embodiments, the specific method for calculating the well-to-ground seismic correlation coefficient between the seismic data at the current point and the seismic data at each well point includes:

[0139] Let the seismic data of the point being sought be seis. * The seismic data at each well point is seis l If the number of wells is m, then the range of l is [1, m]. A single-channel seismic dataset is a one-dimensional dataset, dependent only on time t, which ranges from [0, n]. It is the average value of single-channel seismic data at the l-th well point. If is the average value of the single-track seismic data of the desired point, then the correlation between the seismic data of the desired point and the seismic data at that well point is called the well-to-ground seismic correlation coefficient, and its mathematical expression is:

[0140]

[0141] S42: Normalize the well-to-ground seismic correlation coefficient to obtain the normalized seismic correlation coefficient;

[0142] In some embodiments, the specific method for normalizing the well-to-surface seismic correlation coefficient is as follows:

[0143]

[0144] in,

[0145] ω l :coefficient

[0146] :ω l Normalized values ​​of coefficients;

[0147] S43: Calculate the physical property correlation coefficients between all physical property data within each well and the P-wave velocity, S-wave velocity, density, and raw seismic data; the physical property data include: porosity (por), clay content (vsh), sandy mineral content (sand), dolomite content (dolo), and limestone content (lime).

[0148] In some embodiments, the specific method for calculating the physical property correlation coefficients between all physical property data within each well and the P-wave velocity, S-wave velocity, density, and raw seismic data includes:

[0149] If the minimum value of porosity data for the target formation is a and the maximum value is b, then the range of porosity per is set as [a, b].

[0150] (1) The horizontal axis represents the line number, the vertical axis represents the trace number, and the vertical axis represents the time. Let the line number be i, the trace number be j, and the time be t. Normalize the P-wave velocity vp, S-wave velocity vs, density den, and the squared values ​​of seismic data after stack to the porosity range [a, b]. Extract the minimum value x and the maximum value y from the P-wave velocity of the target segment. Let the range of P-wave velocity vp be [x, y]. Then, according to the normalization formula, calculate the value for the l-th well:

[0151]

[0152] but

[0153] in The P-wave velocity in the range [a, b] can be calculated similarly for the S-wave velocity in the range [a, b]. density Square of stacked data

[0154] (2) Porosity using well logging data With the well point Perform correlation analysis separately, targeting and Calculate the correlation coefficient:

[0155]

[0156] in For the lth well and The correlation coefficient, for The average value from 1 to n for The average value from 1 to n; similarly, the average value can be calculated. respectively with Correlation coefficient:

[0157] (3) Normalize,

[0158]

[0159]

[0160]

[0161]

[0162] (4) The porosity of the intermediate process is determined by linear calculation:

[0163]

[0164] S44: Repeat step S3 until the physical property correlation coefficients of all m wells have been calculated. Apply the normalized seismic correlation coefficient and physical property correlation coefficient to obtain the final physical property data expression for the multi-well. S45: Normalize the physical property data expression to obtain the physical property parameter data for the entire work area.

[0165] This application provides a method for simultaneously calculating reservoir physical parameters. Based on the elastic parameter results of pre-stack inversion, including P-wave velocity, S-wave velocity, and density, as well as the squares of post-stack seismic data, the method is suitable for situations with multiple wells in the work area. The process first determines the correlation between the calculation point and each well point, then calculates the physical parameters within a single well, and finally uses a correlation coefficient weighting method. This method is fast and comprehensively considers the multi-well situation, employing the correlation between three elastic parameters and one original seismic data set, thus ensuring accuracy and precision. Finally, the calculation method of this invention can output all physical property data simultaneously, eliminating the need to solve them one by one. Therefore, when calculating all physical property data, only one calculation is required.

[0166] Example 5

[0167] Based on the foregoing embodiments, this application further provides a method for simultaneous calculation of reservoir physical property parameters, including:

[0168] S51: Calculate the well-to-ground seismic correlation coefficient between the current seismic data at the desired point and the seismic data at each well point;

[0169] In some embodiments, the specific method for calculating the well-to-ground seismic correlation coefficient between the seismic data at the current point and the seismic data at each well point includes:

[0170] Let the seismic data of the point being sought be seis. * The seismic data at each well point is seis l If the number of wells is m, then the range of l is [1, m]. A single-channel seismic dataset is a one-dimensional dataset, dependent only on time t, which ranges from [0, n]. It is the average value of single-channel seismic data at the l-th well point. If is the average value of the single-track seismic data of the desired point, then the correlation between the seismic data of the desired point and the seismic data at that well point is called the well-to-ground seismic correlation coefficient, and its mathematical expression is:

[0171]

[0172] S52: Normalize the well-to-ground seismic correlation coefficient to obtain the normalized seismic correlation coefficient;

[0173] In some embodiments, the specific method for normalizing the well-to-surface seismic correlation coefficient is as follows:

[0174]

[0175] S53: Calculate the correlation coefficients between all physical property data within each well and the P-wave velocity, S-wave velocity, density, and raw seismic data; the physical property data include: porosity (por), clay content (vsh), sand mineral content (sand), dolomite content (dolo), and limestone content (lime).

[0176] In some embodiments, the specific method for calculating the physical property correlation coefficients between all physical property data within each well and the P-wave velocity, S-wave velocity, density, and raw seismic data includes:

[0177] If the minimum value of porosity data for the target layer is a and the maximum value is b, then the range of porosity por is set as [a, b].

[0178] (1) The horizontal axis represents the line number, the vertical axis represents the trace number, and the vertical axis represents the time. Let the line number be i, the trace number be j, and the time be t. Normalize the P-wave velocity vp, S-wave velocity vs, density den, and the squared values ​​of seismic seismic data after stack to the porosity range [a, b]. Extract the minimum value x and the maximum value y from the P-wave velocity of the target segment. Let the range of P-wave velocity vp be [x, y]. Then, according to the normalization formula, take the l-th well as an example:

[0179]

[0180] but

[0181] in The P-wave velocity in the range [a, b] can be calculated similarly for the S-wave velocity in the range [a, b]. density Square of stacked data

[0182] (2) Porosity using well logging data With the well point Perform correlation analysis separately, to and For example, let's calculate the correlation coefficient:

[0183]

[0184] in For the lth well and The correlation coefficient, for The average value from 1 to n for The average value from 1 to n; similarly, the average value can be calculated. respectively with Correlation coefficient:

[0185] (3) Normalize,

[0186]

[0187]

[0188]

[0189]

[0190] (4) The porosity of the intermediate process is determined by linear calculation:

[0191]

[0192] In some embodiments, the method for determining the correlation coefficients of the physical properties of mud content (vsh), sandy mineral content (sand), dolomite content (dolo), and limestone content (lime) is the same as the method for determining the correlation coefficient of porosity.

[0193] get,

[0194] clay content in the intermediate process

[0195] Sandy mineral content in the intermediate process (vsh) ijt ;

[0196] Dolomite content in the intermediate process (dolo) ijt ;

[0197] limestone content in the intermediate process ijt .

[0198] S54: Repeat step S3 until the physical property correlation coefficients of all m wells have been calculated. Apply the normalized seismic correlation coefficient and physical property correlation coefficient to obtain the final physical property data expression for the multi-well.

[0199] S55: Normalize the physical property data expression to obtain the physical property parameter data for the entire work area.

[0200] This application provides a method for simultaneously calculating reservoir physical parameters. Based on the elastic parameter results of pre-stack inversion, including P-wave velocity, S-wave velocity, and density, as well as the squares of post-stack seismic data, the method is suitable for situations with multiple wells in the work area. The process first determines the correlation between the calculation point and each well point, then calculates the physical parameters within a single well, and finally uses a correlation coefficient weighting method. This method is fast and comprehensively considers the multi-well situation, employing the correlation between three elastic parameters and one original seismic data set, thus ensuring accuracy and precision. Finally, the calculation method of this invention can output all physical property data simultaneously, eliminating the need to solve them one by one. Therefore, when calculating all physical property data, only one calculation is required.

[0201] Example 6

[0202] Based on the foregoing embodiments, this application further provides a method for simultaneous calculation of reservoir physical property parameters, including:

[0203] S61: Calculate the well-to-ground seismic correlation coefficient between the seismic data at the current point and the seismic data at each well point;

[0204] In some embodiments, the specific method for calculating the well-to-ground seismic correlation coefficient between the seismic data at the current point and the seismic data at each well point includes:

[0205] Let the seismic data of the point being sought be seis. * The seismic data at each well point is seis lIf the number of wells is m, then the range of l is [1, m]. A single-channel seismic dataset is a one-dimensional dataset, dependent only on time t, which ranges from [0, n]. It is the average value of single-channel seismic data at the l-th well point. If is the average value of the single-track seismic data of the desired point, then the correlation between the seismic data of the desired point and the seismic data at that well point is called the well-to-ground seismic correlation coefficient, and its mathematical expression is:

[0206]

[0207] S62: Normalize the well-to-ground seismic correlation coefficient to obtain the normalized seismic correlation coefficient;

[0208] In some embodiments, the specific method for normalizing the well-to-surface seismic correlation coefficient is as follows:

[0209]

[0210] S63: Calculate the correlation coefficients between all physical property data within each well and the P-wave velocity, S-wave velocity, density, and raw seismic data; the physical property data include: porosity (por), clay content (vsh), sandy mineral content (sand), dolomite content (dolo), and limestone content (lime).

[0211] In some embodiments, the specific method for calculating the physical property correlation coefficients between all physical property data within each well and the P-wave velocity, S-wave velocity, density, and raw seismic data includes:

[0212] If the minimum value of porosity data for the target layer is a and the maximum value is b, then the range of porosity por is set as [a, b].

[0213] (1) The horizontal axis represents the line number, the vertical axis represents the trace number, and the vertical axis represents the time. Let the line number be i, the trace number be j, and the time be t. Normalize the P-wave velocity vp, S-wave velocity vs, density den, and the squared values ​​of seismic seismic data after stack to the porosity range [a, b]. Extract the minimum value x and the maximum value y from the P-wave velocity of the target segment. Let the range of P-wave velocity vp be [x, y]. Then, according to the normalization formula, take the l-th well as an example:

[0214]

[0215] but

[0216] in The P-wave velocity in the range [a, b] can be calculated similarly for the S-wave velocity in the range [a, b]. density Square of stacked data

[0217] (2) Porosity using well logging data With the well point Perform correlation analysis separately, to and For example, let's calculate the correlation coefficient:

[0218]

[0219] in For the lth well and The correlation coefficient, for The average value from 1 to n for The average value from 1 to n; similarly, the average value can be calculated. respectively with Related systems:

[0220] (3) Normalize,

[0221]

[0222]

[0223]

[0224]

[0225] (4) The porosity of the intermediate process is determined by linear calculation:

[0226]

[0227] In some embodiments, the method for determining the correlation coefficients of the physical properties of mud content (vsh), sandy mineral content (sand), dolomite content (dolo), and limestone content (lime) is the same as the method for determining the correlation coefficient of porosity.

[0228] get,

[0229] clay content in the intermediate process

[0230] Sandy mineral content in the intermediate process (vsh) ijt ;

[0231] Dolomite content in the intermediate process (dolo) ijt ;

[0232] limestone content in the intermediate process ijt .

[0233] S64: Repeat step S3 until the physical property correlation coefficients of all m wells have been calculated. Apply the normalized seismic correlation coefficient and physical property correlation coefficient to obtain the final physical property data expression for the multi-well.

[0234] In some embodiments, the specific method for obtaining the final multi-well physical property data expression includes:

[0235]

[0236]

[0237]

[0238]

[0239]

[0240] por ijt ′ represents the final porosity;

[0241] vsh ijt ′ represents the final mud content;

[0242] sand ijt ′ represents the final sandy mineral content;

[0243] dolo ijt ′ represents the final dolomite content;

[0244] lime ijt ′ represents the final limestone content;

[0245] S65: Normalize the physical property data expression to obtain the physical property parameter data for the entire work area.

[0246] This application provides a method for simultaneously calculating reservoir physical parameters. Based on the elastic parameter results of pre-stack inversion, including P-wave velocity, S-wave velocity, and density, as well as the squares of post-stack seismic data, the method is suitable for situations with multiple wells in the work area. The process first determines the correlation between the calculation point and each well point, then calculates the physical parameters within a single well, and finally uses a correlation coefficient weighting method. This method is fast and comprehensively considers the multi-well situation, employing the correlation between three elastic parameters and one original seismic data set, thus ensuring accuracy and precision. Finally, the calculation method of this invention can output all physical property data simultaneously, eliminating the need to solve them one by one. Therefore, when calculating all physical property data, only one calculation is required.

[0247] Example 7

[0248] Based on the foregoing embodiments, this application further provides a method for simultaneous calculation of reservoir physical property parameters, including:

[0249] S71: Calculate the well-to-ground seismic correlation coefficient between the current seismic data at the desired point and the seismic data at each well point;

[0250] In some embodiments, the specific method for calculating the well-to-ground seismic correlation coefficient between the seismic data at the current point and the seismic data at each well point includes:

[0251] Let the seismic data of the point being sought be seis. * The seismic data at each well point is seis l If the number of wells is m, then the range of l is [1, m]. A single-channel seismic dataset is a one-dimensional dataset, dependent only on time t, which ranges from [0, n]. It is the average value of single-channel seismic data at the l-th well point. If is the average value of the single-track seismic data of the desired point, then the correlation between the seismic data of the desired point and the seismic data at that well point is called the well-to-ground seismic correlation coefficient, and its mathematical expression is:

[0252]

[0253] S72: Normalize the well-to-ground seismic correlation coefficient to obtain the normalized seismic correlation coefficient;

[0254] In some embodiments, the specific method for normalizing the well-to-surface seismic correlation coefficient is as follows:

[0255]

[0256] S73: Calculate the correlation coefficients between all physical property data within each well and the P-wave velocity, S-wave velocity, density, and raw seismic data; the physical property data include: porosity (por), clay content (vsh), sandy mineral content (sand), dolomite content (dolo), and limestone content (lime).

[0257] In some embodiments, the specific method for calculating the physical property correlation coefficients between all physical property data within each well and the P-wave velocity, S-wave velocity, density, and raw seismic data includes:

[0258] If the minimum value of porosity data for the target layer is a and the maximum value is b, then the range of porosity por is set as [a, b].

[0259] (1) The horizontal axis represents the line number, the vertical axis represents the trace number, and the vertical axis represents the time. Let the line number be i, the trace number be j, and the time be t. Normalize the P-wave velocity vp, S-wave velocity vs, density den, and the squared values ​​of seismic seismic data after stack to the porosity range [a, b]. Extract the minimum value x and the maximum value y from the P-wave velocity of the target segment. Let the range of P-wave velocity vp be [x, y]. Then, according to the normalization formula, take the l-th well as an example:

[0260]

[0261] but

[0262] in The P-wave velocity in the range [a, b] can be calculated similarly for the S-wave velocity in the range [a, b]. density Square of stacked data

[0263] (2) Porosity using well logging data With the well point Perform correlation analysis separately, to and For example, let's calculate the correlation coefficient:

[0264]

[0265] in For the lth well and The correlation coefficient, for The average value from 1 to n for The average value from 1 to n; similarly, the average value can be calculated. respectively with Correlation coefficient:

[0266] (3) Normalize,

[0267]

[0268]

[0269]

[0270]

[0271] (4) The porosity of the intermediate process is determined by linear calculation:

[0272]

[0273] In some embodiments, the method for determining the correlation coefficients of the physical properties of mud content (vsh), sandy mineral content (sand), dolomite content (dolo), and limestone content (lime) is the same as the method for determining the correlation coefficient of porosity.

[0274] S74: Repeat step S3 until the physical property correlation coefficients of all m wells have been calculated. Apply the normalized seismic correlation coefficient and physical property correlation coefficient to obtain the final physical property data expression for the multi-well.

[0275] In some embodiments, the specific method for obtaining the final multi-well physical property data expression includes:

[0276]

[0277]

[0278]

[0279]

[0280]

[0281] por ijt ′ represents the final porosity;

[0282] vsh ijt ′ represents the final mud content;

[0283] sand ijt ′ represents the final sandy mineral content;

[0284] dolo ijt′ represents the final dolomite content;

[0285] lime ijt ′ represents the final limestone content;

[0286] S75: Normalize the physical property data expression to obtain the physical property parameter data for the entire work area; in some embodiments, the specific formula for normalizing the physical property data expression is as follows:

[0287]

[0288]

[0289]

[0290]

[0291]

[0292] This represents the final porosity after normalization.

[0293] This represents the final mud content after normalization.

[0294] This represents the final normalized content of sandy minerals;

[0295] This represents the final dolomite content after normalization.

[0296] This represents the final limestone content after normalization.

[0297] This application provides a method for simultaneously calculating reservoir physical parameters. Based on the elastic parameter results of pre-stack inversion, including P-wave velocity, S-wave velocity, and density, as well as the squares of post-stack seismic data, the method is suitable for situations with multiple wells in the work area. The process first determines the correlation between the calculation point and each well point, then calculates the physical parameters within a single well, and finally uses a correlation coefficient weighting method. This method is fast and comprehensively considers the multi-well situation, employing the correlation between three elastic parameters and one original seismic data set, thus ensuring accuracy and precision. Finally, the calculation method of this invention can output all physical property data simultaneously, eliminating the need to solve them one by one. Therefore, when calculating all physical property data, only one calculation is required.

[0298] Example 8

[0299] Based on the method of Embodiment Seven, such as Figure 1 and Figure 8The embodiments shown in this application are based on real data:

[0300] S81: Calculate the well-to-ground seismic correlation coefficient between the seismic data at the current point and the seismic data at each well point;

[0301] In some embodiments, the specific method for calculating the well-to-ground seismic correlation coefficient between the seismic data at the current point and the seismic data at each well point includes:

[0302] Let the seismic data of the point being sought be seis. * The seismic data at each well point is seis l If the number of wells is m, then the range of l is [1, m]. A single-channel seismic dataset is a one-dimensional dataset, dependent only on time t, which ranges from [0, n]. It is the average value of single-channel seismic data at the l-th well point. If is the average value of the single-track seismic data of the desired point, then the correlation between the seismic data of the desired point and the seismic data at that well point is called the well-to-ground seismic correlation coefficient, and its mathematical expression is:

[0303]

[0304] S82: Normalize the well-to-ground seismic correlation coefficient to obtain the normalized seismic correlation coefficient;

[0305] In some embodiments, the specific method for normalizing the well-to-surface seismic correlation coefficient is as follows:

[0306]

[0307] S83: Calculate the correlation coefficients between all physical property data within each well and the P-wave velocity, S-wave velocity, density, and raw seismic data; the physical property data include: porosity (por), clay content (vsh), sandy mineral content (sand), dolomite content (dolo), and limestone content (lime).

[0308] In some embodiments, the specific method for calculating the physical property correlation coefficients between all physical property data within each well and the P-wave velocity, S-wave velocity, density, and raw seismic data includes:

[0309] If the minimum value of porosity data for the target layer is a and the maximum value is b, then the range of porosity por is set as [a, b].

[0310] (1) The horizontal axis represents the line number, the vertical axis represents the trace number, and the vertical axis represents the time. Let the line number be i, the trace number be j, and the time be t. Normalize the P-wave velocity vp, S-wave velocity vs, density den, and the squared values ​​of seismic seismic data after stack to the porosity range [a, b]. Extract the minimum value x and the maximum value y from the P-wave velocity of the target segment. Let the range of P-wave velocity vp be [x, y]. Then, according to the normalization formula, take the l-th well as an example:

[0311]

[0312] but

[0313] in The P-wave velocity in the range [a, b] can be calculated similarly for the S-wave velocity in the range [a, b]. density Square of stacked data

[0314] (2) Porosity using well logging data With the well point Perform correlation analysis separately, to and For example, let's calculate the correlation coefficient:

[0315]

[0316] in For the lth well and The correlation coefficient, for The average value from 1 to n for The average value from 1 to n; similarly, the average value can be calculated. respectively with Correlation coefficient:

[0317] (3) Normalize,

[0318]

[0319]

[0320]

[0321]

[0322] (4) The porosity of the intermediate process is determined by linear calculation:

[0323]

[0324] In some embodiments, the method for determining the correlation coefficients of the physical properties of mud content (vsh), sandy mineral content (sand), dolomite content (dolo), and limestone content (lime) is the same as the method for determining the correlation coefficient of porosity.

[0325] get,

[0326] clay content in the intermediate process

[0327] Sandy mineral content in the intermediate process (vsh) ijt ;

[0328] Dolomite content in the intermediate process (dolo) ijt ;

[0329] limestone content in the intermediate process ijt .

[0330] S84: Repeat step S3 until the physical property correlation coefficients of all m wells have been calculated. Apply the normalized seismic correlation coefficient and physical property correlation coefficient to obtain the final physical property data expression for the multi-well.

[0331] In some embodiments, the specific method for obtaining the final multi-well physical property data expression includes:

[0332]

[0333]

[0334]

[0335]

[0336]

[0337] por ijt ′ represents the final porosity;

[0338] vsh ijt ′ represents the final mud content;

[0339] sand ijt ′ represents the final sandy mineral content;

[0340] dolo ijt ′ represents the final dolomite content;

[0341] limeijt ′ represents the final limestone content;

[0342] S85: Normalize the physical property data expression to obtain the physical property parameter data for the entire work area; in some embodiments, the specific formula for normalizing the physical property data expression is:

[0343]

[0344]

[0345]

[0346]

[0347]

[0348] This represents the final porosity after normalization.

[0349] This represents the final mud content after normalization.

[0350] This represents the final normalized content of sandy minerals;

[0351] This represents the final dolomite content after normalization.

[0352] This represents the final limestone content after normalization.

[0353] Figure 2 It is a multi-well location map. Figure 3 , Figure 4 , Figure 5 , Figure 6 A planar graph is provided as the input data. Figure 7 This is the result of porosity calculation.

[0354] This application provides a method for simultaneously calculating reservoir physical parameters. Based on the elastic parameter results of pre-stack inversion, including P-wave velocity, S-wave velocity, and density, as well as the squares of post-stack seismic data, the method is suitable for situations with multiple wells in the work area. The process first determines the correlation between the calculation point and each well point, then calculates the physical parameters within a single well, and finally uses a correlation coefficient weighting method. This method is fast and comprehensively considers the multi-well situation, employing the correlation between three elastic parameters and one original seismic data set, thus ensuring accuracy and precision. Finally, the calculation method of this invention can output all physical property data simultaneously, eliminating the need to solve them one by one. Therefore, when calculating all physical property data, only one calculation is required.

[0355] Example 9

[0356] Based on the foregoing embodiments, this application provides a device for simultaneously calculating reservoir physical property parameters, including:

[0357] The module includes a well-to-surface seismic correlation coefficient calculation module, a seismic correlation coefficient normalization module, a physical property correlation coefficient calculation module, a physical property data expression calculation module, and a physical property parameter data calculation module.

[0358] The well-to-ground seismic correlation coefficient calculation module calculates the well-to-ground seismic correlation coefficient between the seismic data of the current point and the seismic data at each well point.

[0359] The earthquake correlation coefficient normalization module: normalizes the well-to-surface earthquake correlation coefficient to obtain the normalized earthquake correlation coefficient;

[0360] The physical property correlation coefficient calculation module calculates the physical property correlation coefficient between all physical property data within each well and the P-wave velocity, S-wave velocity, density, and original seismic data. The physical property data includes: porosity (por), clay content (vsh), sandy mineral content (sand), dolomite content (dolo), and limestone content (lime).

[0361] The physical property data expression calculation module completes the calculation of all physical property correlation coefficients for all m wells, and applies the normalized seismic correlation coefficient and physical property correlation coefficient to obtain the final physical property data expression for the multi-well.

[0362] The physical property parameter data calculation module normalizes the physical property data expression to obtain the physical property parameter data for the entire work area.

[0363] This application provides a device for simultaneously calculating reservoir physical parameters, including a memory and a processor. The memory stores a computer program, which, when executed by the processor, performs any of the above-described methods for simultaneously calculating reservoir physical parameters.

[0364] It should be noted that, in the embodiments of this application, if the above-mentioned method for simultaneously calculating reservoir physical parameters is implemented as a software functional module and sold or used as an independent product, it can also be stored in a computer-readable storage medium. Based on this understanding, the technical solution of the embodiments of this application, or the part that contributes to the prior art, can be embodied in the form of a software product. This computer software product is stored in a storage medium and includes several instructions to cause a computer device (which may be a personal computer, server, or network device, etc.) to execute all or part of the methods described in the various embodiments of this application. The aforementioned storage medium includes various media capable of storing program code, such as USB flash drives, portable hard drives, read-only memory (ROM), magnetic disks, or optical disks. Thus, the embodiments of this application are not limited to any specific hardware and software combination.

[0365] Accordingly, this application provides a storage medium storing a computer program, characterized in that the computer program, when executed by a processor, implements the steps in the method for simultaneously calculating reservoir physical property parameters provided in the above embodiments.

[0366] Example 10

[0367] This application provides a device for simultaneously calculating reservoir physical parameters, including a memory and a processor. The memory stores a computer program. When the processor executes the computer program, the processor is configured to execute a program for simultaneously calculating reservoir physical parameters stored in the memory, so as to implement the steps in the method for simultaneously calculating reservoir physical parameters provided in the above embodiment.

[0368] The descriptions of the display device and storage medium embodiments above are similar to those of the method embodiments above, and have similar beneficial effects. For technical details not disclosed in the computer device and storage medium embodiments of this application, please refer to the descriptions of the method embodiments of this application for understanding.

[0369] It should be noted that the descriptions of the storage medium and device embodiments above are similar to the descriptions of the method embodiments above, and have similar beneficial effects. For technical details not disclosed in the storage medium and device embodiments of this application, please refer to the descriptions of the method embodiments of this application for understanding.

[0370] It should be understood that the phrase "one embodiment" or "an embodiment" throughout the specification means that a specific feature, structure, or characteristic related to the embodiment is included in at least one embodiment of this application. Therefore, "in one embodiment" or "in an embodiment" appearing throughout the specification does not necessarily refer to the same embodiment. Furthermore, these specific features, structures, or characteristics can be combined in any suitable manner in one or more embodiments. It should be understood that in the various embodiments of this application, the sequence numbers of the above-described processes do not imply a sequential order of execution; the execution order of each process should be determined by its function and internal logic, and should not constitute any limitation on the implementation process of the embodiments of this application. The sequence numbers of the above-described embodiments are merely descriptive and do not represent the superiority or inferiority of the embodiments.

[0371] It should be noted that, in this document, the terms "comprising," "including," or any other variations thereof are intended to cover non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements includes not only those elements but also other elements not expressly listed, or elements inherent to such a process, method, article, or apparatus. Unless otherwise specified, an element defined by the phrase "comprising one..." does not exclude the presence of other identical elements in the process, method, article, or apparatus that includes that element.

[0372] In the several embodiments provided in this application, it should be understood that the disclosed devices and methods can be implemented in other ways. The device embodiments described above are merely illustrative. For example, the division of units is only a logical functional division, and in actual implementation, there may be other division methods, such as: multiple units or components can be combined, or integrated into another system, or some features can be ignored or not executed. In addition, the coupling, direct coupling, or communication connection between the various components shown or discussed can be through some interfaces, and the indirect coupling or communication connection between devices or units can be electrical, mechanical, or other forms.

[0373] The units described above as separate components may or may not be physically separate. The components shown as units may or may not be physical units. They may be located in one place or distributed across multiple network units. Some or all of the units may be selected to achieve the purpose of this embodiment according to actual needs.

[0374] In addition, each functional unit in the various embodiments of this application can be integrated into one processing unit, or each unit can be a separate unit, or two or more units can be integrated into one unit; the integrated unit can be implemented in hardware or in the form of hardware plus software functional units.

[0375] Those skilled in the art will understand that all or part of the steps of the above method embodiments can be implemented by hardware related to program instructions. The aforementioned program can be stored in a computer-readable storage medium. When the program is executed, it performs the steps of the above method embodiments. The aforementioned storage medium includes various media that can store program code, such as mobile storage devices, read-only memory (ROM), magnetic disks, or optical disks.

[0376] Alternatively, if the integrated units described above are implemented as software functional modules and sold or used as independent products, they can also be stored in a computer-readable storage medium. Based on this understanding, the technical solutions of the embodiments of this application, or the parts that contribute to the prior art, can be embodied in the form of a software product. This computer software product is stored in a storage medium and includes several instructions to cause a controller to execute all or part of the methods described in the various embodiments of this application. The aforementioned storage medium includes various media capable of storing program code, such as mobile storage devices, ROMs, magnetic disks, or optical disks.

[0377] The above description is merely an embodiment of this application, but the scope of protection of this application is not limited thereto. Any variations or substitutions that can be easily conceived by those skilled in the art within the scope of the technology disclosed in this application should be included within the scope of protection of this application. Therefore, the scope of protection of this application should be determined by the scope of the claims.

Claims

1. A method for simultaneously calculating reservoir physical property parameters, characterized in that, include: S1: Calculate the well-to-ground seismic correlation coefficient between the seismic data of the current point and the seismic data of each well point. The correlation between the seismic data of the current point and the seismic data of that well point is called the well-to-ground seismic correlation coefficient. S2: Normalize the well-to-ground seismic correlation coefficient to obtain the normalized seismic correlation coefficient; S3: Calculate the correlation coefficients between all physical property data within each well and the P-wave velocity, S-wave velocity, density, and raw seismic data; the physical property data include: porosity (por), clay content (vsh), sandy mineral content (sand), dolomite content (dolo), and limestone content (lime). S4: Repeat step S3 until all The physical property correlation coefficients of all wells have been calculated. By applying the normalized seismic correlation coefficient and the physical property correlation coefficient, the final physical property data expression for multiple wells is obtained. S5: Normalize the physical property data expression to obtain the physical property parameter data for the entire work area; The specific method for calculating the correlation coefficients between all physical property data within each well and the P-wave velocity, S-wave velocity, density, and raw seismic data includes: If the minimum value of porosity data for the target layer is a and the maximum value is b, then the range of porosity por is set as [a, b]. (1) The horizontal axis represents the line number, the vertical axis represents the track number, and the vertical axis represents time. The line number is set as follows: The Taoist name is The time is ; P-wave velocity transverse wave velocity ,density and post-stack seismic data The squared values ​​are uniformly normalized to the range of porosity values. , The minimum value of the target segment extracted from the P-wave velocity is […]. The maximum value is Let the longitudinal wave velocity be... The range of values ​​for is [ , According to the normalization formula, for the first... Requesting information from a well: （3） but (4) in for[ , The longitudinal wave velocity within the range is similarly calculated. , transverse wave velocity under [condition] ,density Square of the stacked data ; (2) Porosity using well logging data At the well point , , , Perform correlation coefficient analysis separately, targeting and Calculate the correlation coefficient: （5） in For the first Koujing and The correlation coefficient, for From 1 to The average value, for From 1 to The average value; similarly, find the average value. respectively with , , Correlation coefficient: , , ; (3) To , , , Normalize, = （6） = （7） = （8） = （9）； (4) The porosity of the intermediate process is determined using linear calculation: + + （10）； The method for determining the correlation coefficients of the physical properties of clay content (vsh), sandy mineral content (sand), dolomite content (dolo), and limestone content (lime) is the same as the method for determining the correlation coefficient of porosity. clay content in the intermediate process ; Sandy mineral content in the intermediate process ; Dolomite content in the intermediate process ; Limestone content in the intermediate process ; The specific methods for obtaining the final multi-well physical property data expressions include: （11） （12） （13） （14） （15） This represents the final porosity. This represents the final mud content; This represents the final content of sandy minerals; This represents the final dolomite content; This represents the final limestone content; This is the normalized value of the well-to-surface seismic correlation coefficient.

2. The method according to claim 1, characterized in that, The specific method for calculating the well-to-ground seismic correlation coefficient between the current seismic data at the desired point and the seismic data at each well point includes: Let the seismic data of the point being sought be... The seismic data at each well point are The number of wells is ,but The range of values ​​for is [1, ...]. Single-channel seismic data is a one-dimensional data set, only related to time. Related, The range of values ​​for is [1, ... ], It is the first The average value of single-channel seismic data at the well point. It is the average value of the single-channel seismic data for the desired point. The mathematical expression for the well-to-ground seismic correlation coefficient is: （1）。 3. The method according to claim 2, characterized in that, The specific method for normalizing the well-to-ground seismic correlation coefficient is as follows: = （2） in, : Well-to-ground seismic correlation coefficient.

4. The method according to claim 1, characterized in that, The specific formula for normalizing the physical property data expression is as follows: （16） （17） （18） （19） （20） This represents the final porosity after normalization. This represents the final mud content after normalization. This represents the final normalized content of sandy minerals; This represents the final dolomite content after normalization. This represents the final limestone content after normalization.

5. An apparatus for simultaneously calculating reservoir physical parameters to implement the method of claim 1, characterized in that, include: The module includes a well-to-surface seismic correlation coefficient calculation module, a seismic correlation coefficient normalization module, a physical property correlation coefficient calculation module, a physical property data expression calculation module, and a physical property parameter data calculation module. The well-to-ground seismic correlation coefficient calculation module calculates the well-to-ground seismic correlation coefficient between the seismic data of the current point and the seismic data at each well point. The earthquake correlation coefficient normalization module: normalizes the well-to-surface earthquake correlation coefficient to obtain the normalized earthquake correlation coefficient; The physical property correlation coefficient calculation module calculates the physical property correlation coefficient between all physical property data within each well and the P-wave velocity, S-wave velocity, density, and original seismic data. The physical property data includes: porosity (por), clay content (vsh), sandy mineral content (sand), dolomite content (dolo), and limestone content (lime). The physical property data expression calculation module: completes all The correlation coefficients of physical properties of all wells were calculated, and the normalized seismic correlation coefficient and physical property correlation coefficient were applied to obtain the final physical property data expression for multiple wells. The physical property parameter data calculation module normalizes the physical property data expression to obtain the physical property parameter data for the entire work area.

6. A device for simultaneously calculating reservoir physical property parameters, characterized in that, It includes a memory and a processor, wherein the memory stores a computer program that, when executed by the processor, performs the method for simultaneous calculation of reservoir physical parameters as described in any one of claims 1 to 4.

7. A storage medium, characterized in that, The computer program stored in the storage medium can be executed by one or more processors and can be used to implement the method for simultaneous calculation of reservoir physical property parameters as described in any one of claims 1 to 4.

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