Quantitative characterization method, system, equipment and medium for physical properties of tight sandstone reservoir

Abstract

The invention belongs to the technical field of natural gas exploration and development, and relates to a tight sandstone reservoir physical property quantitative characterization method, system, equipment and medium. The method comprises the following steps: acquiring the porosity and permeability of a gas-bearing layer of each well of a destination layer of a research block; respectively obtaining variation systems according to the porosity and the permeability; acquiring a porosity weight value and a permeability weight value according to the variation coefficient of the porosity and permeability data; according to the porosity, the porosity weight value, the permeability and the permeability weight value, the reservoir physical property characterization index is obtained. According to the method, the reservoir physical property characterization index is jointly obtained by combining the porosity and the permeability, the physical property of the compact sandstone reservoir at the exploration point can be accurately and quantitatively characterized, the characterization of the reservoir physical property is more reasonable and accurate, and the accuracy of the reservoir physical property characterization index when the compact sandstone reservoir porosity and permeability correlation is relatively poor is improved. The reservoir physical property characterization index is applied to reservoir classification evaluation and favorable target area prediction, and reliable geological data is provided for accelerating oil-gas exploration and development.

Description

Technical Field

[0001] This invention belongs to the field of natural gas exploration and development technology, and relates to a method, system, equipment and medium for quantitative characterization of the physical properties of tight sandstone reservoirs. Background Technology

[0002] With the arrival of the exploration and development stage that emphasizes both conventional and unconventional oil and gas resources, the proportion of unconventional oil and gas reservoirs such as tight sandstone in oil and gas resources is gradually increasing during the exploration and development process, indicating huge exploration and development potential.

[0003] In the exploration and development of oil and gas in tight sandstone, detailed description and quantitative characterization of reservoir properties are core components of modern oil and gas reservoir research. This is particularly important for conducting gas testing and reservoir selection, evaluating reservoirs, and identifying favorable target areas, and also provides theoretical guidance for oil and gas exploration. Therefore, it is urgent to conduct research on the characterization of tight sandstone reservoir properties to lay a scientific and reasonable theoretical foundation for exploration and development schemes, reduce the blind spots and risks in natural gas exploration and development, and provide geological basis for selecting optimal well locations and finding favorable natural gas enrichment areas in exploration and development blocks.

[0004] Currently, porosity and permeability are commonly used in scientific research and production to characterize the physical properties of tight sandstone reservoirs. By utilizing the porosity and permeability parameters of reservoirs at various exploration points in the study area, planar distribution maps and bar charts of reservoir porosity and permeability can be established. Alternatively, by leveraging the strong correlation between porosity and permeability, relationship curves can be constructed. [Ma Shangwei 2024, Li Mingyang 2023, Zong Tingbo 2023, Ding Sheng 2022, Ye Chao 2019, China University of Petroleum (Beijing) "A Method for Determining Oil and Gas Production Capacity Based on Rock Physics Phase Control of Oil and Gas Interactions"], the invention patent application with application number CN201310589208.7, and the invention patent application with publication number CN103645516A, all these methods can intuitively reflect the physical properties of reservoirs to a certain extent, thereby enabling refined classification of reservoirs and prediction of favorable target areas. However, when the correlation between porosity and permeability is poor in tight sandstone reservoirs, it is unreasonable and has certain limitations to select only one data point, such as permeability or porosity, as the main sequence to characterize the quality of reservoir properties.

[0005] In summary, existing technologies are not accurate enough in characterizing reservoir properties when the porosity-permeability correlation is poor in tight sandstone reservoirs. Summary of the Invention

[0006] The purpose of this invention is to provide a method, system, equipment, and medium for quantitative characterization of the physical properties of tight sandstone reservoirs, in order to solve the problem that the existing technology is not accurate enough in characterizing reservoir physical properties when the porosity-permeability correlation of tight sandstone reservoirs is poor. This invention can achieve accurate characterization of reservoir physical properties and improve the accuracy of reservoir physical property characterization indices when the porosity-permeability correlation of tight sandstone reservoirs is poor.

[0007] To achieve the above objectives, the present invention employs the following technical solution:

[0008] In a first aspect, the present invention provides a method for quantitative characterization of the physical properties of tight sandstone reservoirs, comprising the following steps:

[0009] Obtain the porosity and permeability of the gas-bearing layers in each well of the target formation in the study block;

[0010] The porosity variation coefficient is obtained from porosity, and the permeability data variation coefficient is obtained from permeability.

[0011] The porosity weight value and the permeability weight value are obtained based on the coefficient of variation of porosity and the coefficient of variation of permeability data.

[0012] The reservoir physical property characterization index is obtained based on porosity, porosity weight value, permeability, and permeability weight value.

[0013] Secondly, the present invention provides a quantitative characterization system for the physical properties of tight sandstone reservoirs, comprising a data acquisition module, a coefficient of variation acquisition module, a weight acquisition module, and a characterization index acquisition module connected in sequence, wherein:

[0014] Data acquisition module: used to acquire the porosity and permeability of the gas-bearing layer in each well of the target formation in the study block;

[0015] Coefficient of variation acquisition module: used to obtain the coefficient of variation of porosity based on porosity, and the coefficient of variation of permeability data based on permeability;

[0016] Weight acquisition module: used to obtain porosity weight value and permeability weight value based on the coefficient of variation of porosity and the coefficient of variation of permeability data;

[0017] Characterization index acquisition module: used to obtain reservoir property characterization indices based on porosity, porosity weight value, permeability, and permeability weight value.

[0018] Thirdly, the present invention provides an electronic device, comprising: a processor; a memory for storing computer program instructions; and steps for implementing a quantitative characterization method for the physical properties of tight sandstone reservoirs when executing the computer program.

[0019] Fourthly, the present invention provides a storage medium storing computer program instructions, which are loaded and executed by a processor, wherein the processor performs a method for quantitative characterization of the physical properties of tight sandstone reservoirs.

[0020] Fifthly, the present invention provides a computer program product, the computer program product including computer instructions, the computer instructions instructing a computer to execute a method for quantitative characterization of the physical properties of tight sandstone reservoirs.

[0021] Compared with the prior art, the present invention has the following beneficial effects:

[0022] 1. This invention obtains the porosity and permeability of the gas-bearing layer in each well of the target formation in the study block; it obtains the coefficient of variation of porosity data based on porosity, and the coefficient of variation of permeability data based on permeability data; it obtains porosity weight values ​​and permeability weight values ​​based on the coefficients of variation of porosity and permeability data; and it obtains a reservoir property characterization index based on porosity, porosity weight values, permeability, and permeability weight values. This invention combines porosity and permeability to obtain the reservoir property characterization index, enabling precise quantitative characterization of the properties of tight sandstone reservoirs at exploration points. This results in a more reasonable and accurate characterization of reservoir properties, improving the accuracy of the reservoir property characterization index when the correlation between porosity and permeability in tight sandstone reservoirs is poor. The reservoir property characterization index is applied to reservoir classification evaluation and prediction of favorable target areas, providing reliable geological data for accelerating oil and gas exploration and development.

[0023] 2. The system of this invention comprises a data acquisition module, a coefficient of variation acquisition module, a weight acquisition module, and a characterization index acquisition module connected in sequence. Specifically: the data acquisition module acquires the porosity and permeability of the gas-bearing layer in each well of the target formation in the study block; the coefficient of variation acquisition module acquires the porosity coefficient of variation based on porosity and the permeability coefficient of variation based on permeability; the weight acquisition module acquires porosity weight values ​​and permeability weight values ​​based on the porosity and permeability coefficients of variation; and the characterization index acquisition module acquires the reservoir property characterization index based on porosity, porosity weight values, permeability, and permeability weight values. The various modules of this system cooperate to achieve accurate characterization of reservoir properties, improving the accuracy of reservoir property characterization indices when the correlation between porosity and permeability in tight sandstone reservoirs is poor, and providing reliable geological data for accelerating oil and gas exploration and development.

[0024] 3. The equipment, media, and computer program products of this invention can also achieve accurate characterization of reservoir properties, improve the accuracy of reservoir property characterization index when the porosity-permeability correlation of tight sandstone reservoirs is poor, and provide reliable geological data for accelerating oil and gas exploration and development. Attached Figure Description

[0025] Figure 1 This is a flowchart of the method of the present invention;

[0026] Figure 2 This is a system module diagram of the present invention;

[0027] Figure 3This is a detailed module structure diagram of the coefficient of variation acquisition module of the system of the present invention;

[0028] Figure 4 This is a schematic diagram of the porosity acquisition module of the system of the present invention. Detailed Implementation

[0029] To enable those skilled in the art to better understand the present invention, the technical solutions of the present invention will be clearly and completely described below with reference to the accompanying drawings of the embodiments of the present invention. Obviously, the described embodiments are only some embodiments of the present invention, and not all embodiments. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative effort should fall within the scope of protection of the present invention.

[0030] It should be noted that the terms "first," "second," etc., in the specification, claims, and accompanying drawings of this invention are used to distinguish similar objects and are not necessarily used to describe a specific order or sequence. It should be understood that such data can be interchanged where appropriate so that the embodiments of the invention described herein can be implemented in orders other than those illustrated or described herein. Furthermore, the terms "comprising" and "having," and any variations thereof, are intended to cover a non-exclusive inclusion; for example, a process, method, system, product, or apparatus that comprises a series of steps or units is not necessarily limited to those steps or units explicitly listed, but may include other steps or units not explicitly listed or inherent to such processes, methods, products, or apparatus.

[0031] The present invention will now be described in further detail with reference to the accompanying drawings:

[0032] See Figure 1 This invention discloses a method for quantitative characterization of the physical properties of tight sandstone reservoirs, comprising the following steps:

[0033] S1. Obtain the porosity and permeability of the gas-bearing layers in each well of the target formation in the study block;

[0034] Preferably, the porosity and permeability of the gas-bearing strata in each well of the target stratum in the study block are obtained. The target stratum in the study block is an independent tight sandstone gas reservoir without fractures connecting it, and is a gas reservoir that migrates upward from the same gas source.

[0035] S2. Obtain the porosity variation coefficient based on porosity, and obtain the permeability data variation coefficient based on permeability, as detailed below:

[0036] The method for obtaining the coefficient of variation of porosity data is the same as that for obtaining the coefficient of variation of permeability data.

[0037] The method for obtaining the porosity variation coefficient is as follows:

[0038] The mean and standard deviation of porosity are obtained based on porosity.

[0039] The porosity variation coefficient is obtained from the mean porosity and the standard deviation of porosity.

[0040] S3. Obtain the porosity weight value and permeability weight value based on the coefficient of variation of porosity and the coefficient of variation of permeability data;

[0041] Preferably, the formula for calculating the porosity weight value is as follows:

[0042]

[0043] Where W1 is the porosity weight value, v j K is the porosity variation coefficient. j is the coefficient of variation of permeability.

[0044] Preferably, the formula for calculating the penetration rate weight value is as follows:

[0045]

[0046] Where W2 is the penetration rate weight value, v j K is the porosity variation coefficient. j is the coefficient of variation of permeability.

[0047] S4. Obtain the reservoir physical property characterization index based on porosity, porosity weight value, permeability, and permeability weight value. The calculation formula is as follows:

[0048] WX = x j W1+PjW2

[0049] Where WX is the reservoir property characterization index, x j P is the porosity value. j This represents the permeability value.

[0050] See Figure 1In another feasible embodiment of the present invention, the following modifications are made as appropriate. The process includes the following steps: obtaining the porosity and permeability of the gas-bearing layer in each well of the target formation in the study block; obtaining the porosity coefficient of variation based on porosity, and obtaining the coefficient of variation of permeability data based on permeability; obtaining porosity weight values ​​and permeability weight values ​​based on the coefficients of variation of porosity and permeability data; and obtaining the reservoir property characterization index based on porosity, porosity weight values, permeability, and permeability weight values. This invention combines porosity and permeability to obtain the reservoir property characterization index, enabling precise quantitative characterization of the properties of tight sandstone reservoirs at exploration points. This results in a more reasonable and accurate characterization of reservoir properties, improving the accuracy of the reservoir property characterization index when the correlation between porosity and permeability in tight sandstone reservoirs is poor. The reservoir property characterization index is applied to reservoir classification evaluation and prediction of favorable target areas, providing reliable geological data for accelerating oil and gas exploration and development. A larger reservoir property characterization index indicates better reservoir properties, while a smaller index indicates worse reservoir properties.

[0051] Example 1:

[0052] This embodiment discloses a method for quantitative characterization of the physical properties of tight sandstone reservoirs, including the following steps:

[0053] Step 1: Select a relatively independent tight sandstone gas reservoir without fractures connecting it to the gas reservoir that has migrated upward from the same gas source, and collect data on the porosity and permeability of the gas-bearing layer of each well in the target formation of the study block.

[0054] Step 2: Using the porosity data of the gas-bearing reservoir in each well of the target formation in the study block collected in Step 1, calculate the average porosity. and standard deviation S j Calculate the average and standard deviation S j The specific formula is as follows:

[0055]

[0056] in, Average porosity value, n: number of porosity data points, x j Porosity value, S j Porosity standard deviation.

[0057] Step 3: Based on the average porosity obtained in Step 2 and standard deviation S j Using the average porosity Except for its standard deviation S j The quotient is the porosity variation coefficient v. j Calculate the coefficient of variation v j The specific formula is as follows:

[0058]

[0059] Among them, v j Porosity variation coefficient, S j Porosity standard deviation. Average porosity.

[0060] Step 4: Repeat steps 2 and 3 to obtain the coefficient of variation K of the permeability data of the gas-bearing layer in the target formation of the study block. j The details are as follows:

[0061] Using the permeability data of the gas-bearing reservoir in each well of the target formation in the study block collected in step 1, the average permeability is calculated. and standard deviation S j ;

[0062] Using the average porosity Except for its standard deviation S j The coefficient of variation of permeability is obtained.

[0063] Step 5: Based on the calculation results of steps 3 and 4, divide the coefficients of variation of porosity and permeability by the sum of their respective coefficients of variation to obtain the weight values ​​W1 and W2 for porosity and permeability. Calculate the weights W1 and W2 for porosity and permeability using the following formulas:

[0064]

[0065] Where W1: porosity weight value, W2: permeability weight value, v j Porosity variation coefficient, K j : Permeability variation coefficient.

[0066] Step 6: Combining the porosity and permeability weight values ​​obtained in Step 5, calculate the reservoir property characterization index WX of the target gas-bearing reservoir in the study block using the following formula:

[0067] WX = x j W1+PjW2

[0068] Wherein, WX: reservoir property characterization index, x j Porosity value, P j : Permeability value.

[0069] Based on the above formula, the reservoir physical property characterization index of all wells in the gas-bearing layer of the target layer in the study block is calculated. The larger the reservoir physical property characterization index, the better the reservoir physical properties, and the smaller the reservoir physical property characterization index, the worse the reservoir physical properties.

[0070] Example 2:

[0071] This embodiment further illustrates the process using a specific example of the Box 8 section, a tight sandstone gas reservoir in a certain region of a basin, and includes the following steps:

[0072] Step 1: Based on the fact that the He8 section in a certain area of ​​a basin is a relatively independent tight sandstone lithological gas reservoir without fracture communication and the same gas source migrating upwards, we collected 334 data points on the porosity and permeability of the gas-bearing strata from 334 wells in the He8 section of the study area.

[0073] Step 2: Using the porosity data of 334 gas-bearing reservoirs from 334 wells in Section 8 of the study area collected in Step 1, calculate the average porosity. and standard deviation S j Calculate the average and standard deviation S j The specific formula is as follows:

[0074]

[0075] in, Average porosity value, n: number of porosity data points, x j Porosity value, S j Porosity standard deviation.

[0076] Step 3: Based on the average porosity of the 8 segments in the study area obtained in Step 2... and standard deviation S j Using the average porosity Except for its standard deviation S j The quotient was obtained, and the coefficient of variation v of the porosity data of 334 porosity data in 8 segments of the study area was calculated. j Calculate the coefficient of variation v j The specific formula is as follows:

[0077]

[0078] Among them, v j Porosity variation coefficient, S j Porosity standard deviation Average porosity.

[0079] Step 4: Repeat steps 2 and 3 to obtain the coefficient of variation K of 334 permeability data points for the gas-bearing strata in segment 8 of the study block. j .

[0080] Step 5: Based on the calculation results of Steps 3 and 4, divide the coefficients of variation of porosity and permeability by the sum of their respective coefficients of variation to obtain the weight values ​​W1 and W2 for porosity and permeability. W1 is 0.37 and W2 is 0.63. Calculate the weights W1 and W2 for porosity and permeability using the following formulas:

[0081]

[0082]

[0083] Where W1: porosity weight value, W2: permeability weight value, v j Porosity variation coefficient, K j : Permeability variation coefficient.

[0084] Step 6: Combining the porosity and permeability weight values ​​of 0.37 and 0.63 obtained in Step 5, the reservoir property characterization index WX of the gas-bearing reservoir in Box 8 of the study block is calculated using the following formula:

[0085] WX = x j W1+P j W2

[0086] Wherein, WX: reservoir property characterization index, x j Porosity value, P j : Permeability value.

[0087] The reservoir physical property characterization index was calculated based on the formula for the reservoir physical property characterization index of 334 wells in section 8 of the study block. The larger the reservoir physical property characterization index, the better the reservoir physical properties, and the smaller the reservoir physical property characterization index, the worse the reservoir physical properties.

[0088] In the reservoir evaluation criteria of the He8 section in the study area, the physical property parameters porosity and permeability can be replaced by physical property characterization indices, as shown in Tables 1 and 2. That is, the data in Table 2 is used instead of the data in Table 1, overcoming the problem that the poor correlation between porosity and permeability parameters makes it impossible to classify tight sandstone reservoirs. The calculated physical property characterization indices are used to conduct a detailed classification and evaluation of the tight sandstone reservoirs in the He8 section of the study area, thus providing a reliable basis for the efficient and high-quality exploration and development of natural gas.

[0089] Table 1. Evaluation criteria for the He 8 section reservoir in a certain area of ​​a basin:

[0090]

[0091]

[0092] Table 2. New Evaluation Standards for the He 8 Formation Reservoir in a Certain Region of a Basin

[0093]

[0094] The purpose of this invention is to provide a quantitative characterization method for the physical properties of tight sandstone reservoirs, accurately characterizing these properties and providing reliable geological data to accelerate oil and gas exploration and development. Based on a comprehensive analysis of previous methods for analyzing porosity and permeability data in tight sandstone reservoirs, this invention innovatively establishes a quantitative characterization method for tight sandstone reservoir properties. This overcomes the limitations of existing methods due to poor correlation between reservoir porosity and permeability, and possesses strong operability, practicality, and inventiveness.

[0095] The reservoir property characterization index of this invention can be effectively applied to reservoir evaluation and site selection, and also lays a scientific and reasonable theoretical basis for exploration and development schemes of tight sandstone reservoirs, reducing the blindness and risk of natural gas exploration and development, and providing geological basis for the optimal well site deployment and the search for favorable natural gas enrichment areas in exploration and development blocks.

[0096] This invention comprehensively utilizes data on the permeability and porosity of tight sandstone reservoirs to calculate reservoir property characterization indices, accurately and quantitatively characterizing the properties of tight sandstone reservoirs at exploration sites. It is applied to reservoir classification and evaluation and prediction of favorable target areas, demonstrating strong practicality, reliability, and operability, and providing reliable geological data for further accelerating oil and gas exploration and development.

[0097] Based on the above method, this invention also discloses a quantitative characterization system for the physical properties of tight sandstone reservoirs, see [link to relevant documentation]. Figure 2 It includes a data acquisition module, a coefficient of variation acquisition module, a weight acquisition module, and a characterization index acquisition module connected in sequence, wherein:

[0098] Data acquisition module: used to acquire the porosity and permeability of the gas-bearing layer in each well of the target formation in the study block;

[0099] Coefficient of variation acquisition module: used to obtain the coefficient of variation of porosity based on porosity, and the coefficient of variation of permeability data based on permeability;

[0100] Weight acquisition module: used to obtain porosity weight value and permeability weight value based on the coefficient of variation of porosity and the coefficient of variation of permeability data;

[0101] Characterization index acquisition module: used to obtain reservoir property characterization indices based on porosity, porosity weight value, permeability, and permeability weight value.

[0102] The various modules of the system of this invention work together to achieve accurate characterization of reservoir properties, improve the accuracy of reservoir property characterization index when the porosity-permeability correlation of tight sandstone reservoirs is poor, and provide reliable geological data for accelerating oil and gas exploration and development.

[0103] Example 3:

[0104] This embodiment also discloses a quantitative characterization system for the physical properties of tight sandstone reservoirs. See [link to documentation]. Figure 2 It includes a data acquisition module, a coefficient of variation acquisition module, a weight acquisition module, and a characterization index acquisition module connected in sequence, wherein:

[0105] Data acquisition module: used to acquire the porosity and permeability of the gas-bearing layer in each well of the target formation in the study block;

[0106] Coefficient of variation acquisition module: used to obtain the coefficient of variation of porosity based on porosity, and the coefficient of variation of permeability data based on permeability;

[0107] Preferred, see Figure 3 The coefficient of variation acquisition module includes a porosity acquisition module and a porosity data processing module:

[0108] Porosity acquisition module: used to obtain the porosity variation coefficient based on porosity;

[0109] Permeability variation coefficient acquisition module: Used to obtain the variation coefficient of permeability data based on the porosity variation coefficient.

[0110] Preferred, see Figure 4 The porosity acquisition module includes

[0111] Porosity processing module: used to obtain the mean porosity and standard deviation based on porosity;

[0112] Porosity reprocessing module: used to obtain the porosity variation coefficient based on the porosity mean and standard deviation.

[0113] Weight acquisition module: used to obtain porosity weight value and permeability weight value based on the coefficient of variation of porosity and the coefficient of variation of permeability data;

[0114] Characterization index acquisition module: used to obtain reservoir property characterization indices based on porosity, porosity weight value, permeability, and permeability weight value.

[0115] An electronic device includes: a processor; a memory for storing computer program instructions; and steps for implementing a quantitative characterization method for the physical properties of tight sandstone reservoirs when executing the computer program.

[0116] A storage medium storing computer program instructions, which are loaded and executed by a processor, wherein the processor performs a method for quantitative characterization of the physical properties of tight sandstone reservoirs.

[0117] Those skilled in the art will understand that embodiments of the present invention can be provided as methods, systems, or computer program products. Therefore, the present invention can take the form of a completely hardware embodiment, a completely software embodiment, or an embodiment combining software and hardware aspects. Furthermore, the present invention can 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, etc.) containing computer-usable program code.

[0118] This 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 block of the flowchart illustrations and / or block diagrams, and combinations of blocks in the flowchart illustrations and / or block diagrams, can be implemented by computer program instructions. These computer program instructions can 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, generate instructions for implementing the flowchart illustrations and / or block diagrams. Figure 1 One or more processes and / or boxes Figure 1 A device that provides the functions specified in one or more boxes.

[0119] These computer program instructions may also be stored in a computer-readable storage medium that can direct a computer or other programmable data processing device to function in a particular manner, such that the instructions stored in the computer-readable storage medium produce an article of manufacture including instruction means, which are implemented in a process Figure 1 One or more processes and / or boxes Figure 1 The function specified in one or more boxes.

[0120] These computer program instructions may also be loaded onto a computer or other programmable data processing equipment to cause a series of operational steps to be performed on the computer or other programmable equipment to produce a computer-implemented process, thereby providing instructions that execute on the computer or other programmable equipment for implementing the process. Figure 1 One or more processes and / or boxes Figure 1 The steps of the function specified in one or more boxes.

[0121] The above content is only for illustrating the technical concept of the present invention and should not be construed as limiting the scope of protection of the present invention. Any modifications made to the technical solution based on the technical concept proposed in this invention shall fall within the scope of protection of the claims of this invention.

Claims

1. A method for quantitative characterization of the physical properties of tight sandstone reservoirs, characterized in that, Includes the following steps: Obtain the porosity and permeability of the gas-bearing layers in each well of the target formation in the study block; The porosity variation coefficient is obtained from porosity, and the permeability data variation coefficient is obtained from permeability. The porosity weight value and the permeability weight value are obtained based on the coefficient of variation of porosity and the coefficient of variation of permeability data. The reservoir physical property characterization index is obtained based on porosity, porosity weight value, permeability, and permeability weight value.

2. The method for quantitative characterization of the physical properties of tight sandstone reservoirs according to claim 1, characterized in that, In the step of obtaining the porosity and permeability of the gas-bearing layer of each well in the target layer of the study block, the target layer of the study block is an independent tight sandstone lithological gas reservoir without fractures connecting it, and is a gas reservoir that migrates upward from the same gas source.

3. The method for quantitative characterization of the physical properties of tight sandstone reservoirs according to claim 1, characterized in that, The method for obtaining the porosity variation coefficient is the same as that for obtaining the permeability data variation coefficient.

4. The method for quantitative characterization of the physical properties of tight sandstone reservoirs according to claim 3, characterized in that, The method for obtaining the porosity variation coefficient is as follows: The mean and standard deviation of porosity are obtained based on porosity. The porosity variation coefficient is obtained from the mean porosity and the standard deviation of porosity.

5. The method for quantitative characterization of the physical properties of tight sandstone reservoirs according to claim 1, characterized in that, In the step of obtaining the porosity weight value and the permeability weight value based on the coefficient of variation of porosity and the coefficient of variation of permeability data, the calculation formula for the porosity weight value is as follows: Where W1 is the porosity weight value, v j K is the porosity variation coefficient. j is the coefficient of variation of permeability.

6. The method for quantitative characterization of the physical properties of tight sandstone reservoirs according to claim 1, characterized in that, In the step of obtaining the porosity weight value and the permeability weight value based on the coefficient of variation of porosity and the coefficient of variation of permeability data, the calculation formula for the permeability weight value is as follows: Where W2 is the penetration rate weight value, v j K is the porosity variation coefficient. j is the coefficient of variation of permeability.

7. The method for quantitative characterization of the physical properties of tight sandstone reservoirs according to claim 1, characterized in that, The calculation formula for obtaining the reservoir physical property characterization index based on porosity, porosity weight value, permeability, and permeability weight value is as follows: WX=x j W1+P j W2 Where WX is the reservoir property characterization index, x j P is the porosity value. j This represents the permeability value.

8. A quantitative characterization system for the physical properties of tight sandstone reservoirs, characterized in that, It includes a data acquisition module, a coefficient of variation acquisition module, a weight acquisition module, and a characterization index acquisition module connected in sequence, wherein: Data acquisition module: used to acquire the porosity and permeability of the gas-bearing layer in each well of the target formation in the study block; Coefficient of variation acquisition module: used to obtain the coefficient of variation of porosity based on porosity, and the coefficient of variation of permeability data based on permeability; Weight acquisition module: used to obtain porosity weight value and permeability weight value based on the coefficient of variation of porosity and the coefficient of variation of permeability data; Characterization index acquisition module: used to obtain reservoir property characterization indices based on porosity, porosity weight value, permeability, and permeability weight value.

9. An electronic device, comprising: A processor; a memory; an electronic device for storing computer program instructions; characterized in that, when executing the computer program, it implements the steps of the quantitative characterization method for the physical properties of tight sandstone reservoirs as described in any one of claims 1-7.

10. A storage medium storing computer program instructions, characterized in that, When the computer program instructions are loaded and run by the processor, the processor executes the quantitative characterization method for the physical properties of tight sandstone reservoirs according to any one of claims 1-7.

11. A computer program product, said computer program product comprising computer instructions, characterized in that, The computer instructions instruct the computer to execute the quantitative characterization method for the physical properties of tight sandstone reservoirs as described in any one of claims 1-7.

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