Method and device for determining open flow potential of gas well in fractured tight gas reservoir

Abstract

This application provides a method and apparatus for determining the unobstructed flow rate of a gas well in a fractured tight gas reservoir. The method includes: acquiring basic parameter information of the gas well in the fractured tight gas reservoir; wherein the basic parameter information includes a first dataset, a second dataset, and a third dataset, the first dataset including different formation pressures and the corresponding natural gas compressibility factors, the second dataset including different formation pressures and the corresponding natural gas viscosities, and the third dataset including different permeabilities and the corresponding non-Darcy flow coefficients; determining the production information of the gas well in the fractured tight gas reservoir based on the first dataset, the second dataset, and the third dataset; wherein the production information characterizes the correlation between formation pressure and gas well flow rate; and determining the unobstructed flow rate of the gas well in the fractured tight gas reservoir based on the production information. The method of this application improves the accuracy and efficiency of determining the unobstructed flow rate of a gas well in a fractured tight gas reservoir.

Description

Technical Field

[0001] This application relates to the field of oil and gas reservoir development technology, and in particular to a method and apparatus for determining the unobstructed flow rate of a gas well in a fractured tight gas reservoir. Background Technology

[0002] Unobstructed flow rate is a key parameter for evaluating gas well production. For fractured tight gas reservoirs, fractured tight gas reservoirs have a dual attribute of "fracture-matrix", that is, fractures are the main seepage channels of the gas reservoir, and the matrix is ​​the main storage space of the gas reservoir.

[0003] Current methods for determining the unobstructed flow rate of gas wells in fractured tight gas reservoirs require the establishment of geological models and the use of a large number of complex parameters, resulting in high work costs, high operating costs, and low execution efficiency. Consequently, it is difficult to accurately and conveniently determine the unobstructed flow rate of gas wells in fractured tight gas reservoirs.

[0004] Therefore, determining the unobstructed flow rate of gas wells in fractured tight gas reservoirs faces technical problems of low accuracy and low efficiency. Summary of the Invention

[0005] This application provides a method and apparatus for determining the unobstructed flow rate of a gas well in a fractured tight gas reservoir, in order to solve the technical problems of low accuracy and low efficiency in determining the unobstructed flow rate of a gas well in a fractured tight gas reservoir.

[0006] In a first aspect, this application provides a method for determining the unobstructed flow rate of a gas well in a fractured tight gas reservoir, comprising:

[0007] The basic parameter information of gas wells in fractured tight gas reservoirs is obtained. The basic parameter information includes a first dataset, a second dataset, and a third dataset. The first dataset includes different formation pressures and the natural gas compressibility factor corresponding to the formation pressure. The second dataset includes different formation pressures and the natural gas viscosity corresponding to the formation pressure. The third dataset includes different permeabilities and the non-Darcy permeability coefficient corresponding to the permeability.

[0008] Based on the first, second, and third datasets, the production information of gas wells in fractured tight gas reservoirs is determined; whereby the production information characterizes the correlation between formation pressure and gas well flow rate.

[0009] Based on production information, the unobstructed flow rate of a gas well in a fractured tight gas reservoir is determined; where the unobstructed flow rate characterizes the natural gas production of a gas well in a fractured tight gas reservoir when the formation pressure at the bottom of the gas well is zero.

[0010] Optionally, as described above, based on the first dataset, the second dataset, and the third dataset, the production information of gas wells in fractured tight gas reservoirs is determined, including:

[0011] Based on the first dataset, first relationship information is determined; based on the second dataset, second relationship information is determined; and based on the third dataset, third relationship information is determined. Among these, the first relationship information represents the correlation between formation pressure and natural gas compressibility factor, the second relationship information represents the correlation between formation pressure and natural gas viscosity, and the third relationship information represents the correlation between permeability and non-Darcy flow coefficient.

[0012] Based on the first, second, and third relational information, the production information of gas wells in fractured tight gas reservoirs is determined.

[0013] Alternatively, as described above, the first relation information is:

[0014] ;

[0015] in, Characterizing the compressibility factor of natural gas, Characterizing formation pressure, The constant term coefficients that characterize the information of the first relation. The coefficient of the first-order term representing the first relation information. The coefficient of the quadratic term representing the information of the first relation.

[0016] Alternatively, as described above, the second relation information is:

[0017] ;

[0018] in, Characterizing the viscosity of natural gas, Characterizing formation pressure, The constant term coefficients that characterize the information of the second relation. The coefficient of the first-order term representing the information of the second relation. The coefficients of the quadratic term that represent the second relation information.

[0019] Alternatively, as described above, the third relation information is:

[0020] ;

[0021] in, Characterizing the non-Darcy permeability coefficient, Characterizing penetration rate, The constant term coefficients that characterize information about the third relationship. The coefficient of the exponential term representing information about the third relationship.

[0022] Optionally, as described above, the production information of gas wells in fractured tight gas reservoirs is determined based on the first relational information, the second relational information, and the third relational information, including:

[0023] To obtain well test interpretation information of gas wells in fractured tight gas reservoirs; wherein, well test interpretation information characterizes the results obtained by performing well test interpretation technology;

[0024] Based on well test interpretation information, first relationship information, second relationship information, and third relationship information, the production information of gas wells in fractured tight gas reservoirs is determined.

[0025] Optionally, as described above, the well test interpretation information includes the permeability, well control radius, wellbore radius, matrix volume within the well control area, and channeling coefficient interpreted from the well test. The basic parameter information also includes the temperature and thickness of the fractured tight gas reservoir. Production information is characterized as follows:

[0026] ;

[0027] ;

[0028] ;

[0029] in, The original formation pressure of a gas well in a fractured tight gas reservoir. Formation pressure at the bottom of a gas well in a fractured tight gas reservoir. Characterizing natural gas production, Characterizing the viscosity of natural gas, Characterizing the compressibility factor of natural gas, Temperature characterizing fractured tight gas reservoirs Atmospheric pressure under standard conditions Characterizing temperature under standard conditions, Characterizing the permeability interpreted from well tests, The thickness characterizing fractured tight gas reservoirs, Characterizing the crossflow coefficient, Characterizing the well control radius, Characterizing the wellbore radius, Characterizing the matrix volume within the well control area, The non-Darcy flow coefficient characterizing the permeability interpreted from well tests. Characterizing the density of natural gas under standard conditions, , All represent constants.

[0030] Optionally, as described above, the unobstructed flow rate of a gas well in a fractured tight gas reservoir is determined based on production capacity information, including:

[0031] Based on production information, the natural gas production corresponding to the formation pressure at the bottom of the gas well in a fractured tight gas reservoir being zero is determined as the unobstructed flow rate of the gas well in the fractured tight gas reservoir.

[0032] Secondly, this application provides an apparatus for determining the unobstructed flow rate of a gas well in a fractured tight gas reservoir, comprising:

[0033] The acquisition unit is used to acquire basic parameter information of gas wells in fractured tight gas reservoirs. The basic parameter information includes a first dataset, a second dataset, and a third dataset. The first dataset includes different formation pressures and the natural gas compressibility factor corresponding to the formation pressure. The second dataset includes different formation pressures and the natural gas viscosity corresponding to the formation pressure. The third dataset includes different permeabilities and the non-Darcy permeability coefficient corresponding to the permeability.

[0034] The first determining unit is used to determine the production information of gas wells in fractured tight gas reservoirs based on the first dataset, the second dataset, and the third dataset; wherein, the production information represents the correlation between formation pressure and gas well flow rate;

[0035] The second determining unit is used to determine the unobstructed flow rate of a gas well in a fractured tight gas reservoir based on production information; wherein, the unobstructed flow rate characterizes the natural gas production of the gas well in the fractured tight gas reservoir when the formation pressure at the bottom of the gas well is zero.

[0036] Thirdly, this application provides an electronic device, including: a memory and a processor;

[0037] The memory stores the instructions that the computer executes;

[0038] The processor executes computer execution instructions stored in memory, causing the processor to perform the first aspect and / or various possible implementations of the first aspect as described above.

[0039] Fourthly, this application provides a computer-readable storage medium storing computer-executable instructions, which, when executed by a processor, are used to implement the first aspect and / or various possible embodiments of the first aspect.

[0040] Fifthly, this application provides a computer program product, comprising: a computer program that, when executed by a processor, implements the first aspect and / or various possible implementations of the first aspect.

[0041] The method and apparatus for determining the unobstructed flow rate of a gas well in a fractured tight gas reservoir provided in this application acquire basic parameter information of the gas well in the fractured tight gas reservoir. This basic parameter information includes a first dataset, a second dataset, and a third dataset. The first dataset includes different formation pressures and the corresponding natural gas compressibility factors. The second dataset includes different formation pressures and the corresponding natural gas viscosities. The third dataset includes different permeabilities and the corresponding non-Darcy flow coefficients. Further, based on the first, second, and third datasets, the production information of the gas well in the fractured tight gas reservoir is determined. This production information represents the correlation between formation pressure and gas well flow rate. Further, based on the production information, the unobstructed flow rate of the gas well in the fractured tight gas reservoir is determined. This unobstructed flow rate represents the natural gas production of the gas well in the fractured tight gas reservoir when the formation pressure at the bottom of the gas well is zero. The method for determining the unobstructed flow rate of a gas well in a fractured tight gas reservoir provided in this application does not require the introduction of a large amount of parameter information. It only needs to use a first dataset, a second dataset, and a third dataset to determine the production information of the gas well in the fractured tight gas reservoir. The production information characterizes the correlation between formation pressure and gas well flow rate. Therefore, the natural gas production of the gas well in the fractured tight gas reservoir, i.e., the unobstructed flow rate, can be determined when the formation pressure at the bottom of the gas well is zero. The method of this application improves the accuracy and efficiency of determining the unobstructed flow rate of a gas well in a fractured tight gas reservoir. Attached Figure Description

[0042] The accompanying drawings, which are incorporated in and form part of this specification, illustrate embodiments consistent with this application and, together with the description, serve to explain the principles of this application.

[0043] Figure 1 A flowchart illustrating a method for determining the unobstructed flow rate of a gas well in a fractured tight gas reservoir, as provided in this application. Figure 1 ;

[0044] Figure 2 A schematic diagram of the first relationship information provided in this application;

[0045] Figure 3 A schematic diagram of the second relationship information provided in this application;

[0046] Figure 4 A schematic diagram of the third-party relationship information provided in this application;

[0047] Figure 5 A schematic diagram illustrating the production information provided in this application;

[0048] Figure 6 A flowchart illustrating a method for determining the unobstructed flow rate of a gas well in a fractured tight gas reservoir, as provided in this application. Figure 2 ;

[0049] Figure 7 A schematic diagram of the structure of a device for determining the unobstructed flow rate of a gas well in a fractured tight gas reservoir provided in this application. Figure 1 ;

[0050] Figure 8 A schematic diagram of the structure of a device for determining the unobstructed flow rate of a gas well in a fractured tight gas reservoir provided in this application. Figure 2 ;

[0051] Figure 9 A schematic diagram of the structure of the electronic device provided in this application.

[0052] The accompanying drawings illustrate specific embodiments of this application, which will be described in more detail below. These drawings and descriptions are not intended to limit the scope of the concept in any way, but rather to illustrate the concept of this application to those skilled in the art through reference to particular embodiments. Detailed Implementation

[0053] Exemplary embodiments will now be described in detail, examples of which are illustrated in the accompanying drawings. When the following description relates to the drawings, unless otherwise indicated, the same numbers in different drawings denote the same or similar elements. The embodiments described in the following exemplary embodiments do not represent all embodiments consistent with this application. Rather, they are merely examples of apparatuses and methods consistent with some aspects of this application as detailed in the appended claims.

[0054] It should be noted that the user information (including but not limited to user device information, user personal information, etc.) and data (including but not limited to data used for analysis, data stored, data displayed, etc.) involved in this application are all information and data authorized by the user or fully authorized by all parties. Furthermore, the collection, use and processing of the relevant data must comply with relevant laws, regulations and standards, and corresponding operation entry points are provided for users to choose to authorize or refuse.

[0055] Unobstructed flow rate is a key parameter for evaluating gas well production. For fractured tight gas reservoirs, fractured tight gas reservoirs have a dual attribute of "fracture-matrix", that is, fractures are the main seepage channels of the gas reservoir, and the matrix is ​​the main storage space of the gas reservoir.

[0056] Currently, the main methods for determining the unobstructed flow rate of gas wells in fractured tight gas reservoirs are the homogeneous gas reservoir productivity formula method and the numerical simulation method.

[0057] In the homogeneous gas reservoir productivity formula method (also known as the equivalent homogeneous method), fractured tight gas reservoirs are treated as equivalent to homogeneous gas reservoirs, and the fracture permeability is taken as the equivalent homogeneous gas reservoir permeability. Then, the unobstructed flow rate of the gas wells in the fractured tight gas reservoir is calculated according to the homogeneous gas reservoir productivity formula. However, practice has shown that the homogeneous gas reservoir productivity formula method obtains the unobstructed flow rate of the fractures, that is, the unobstructed flow rate of the gas well in the short term, not the unobstructed flow rate of the gas wells in the fractured tight gas reservoir. Therefore, it is impossible to accurately determine the unobstructed flow rate of the gas wells in the fractured tight gas reservoir.

[0058] In numerical simulation methods (such as [1] Wang Rujun, Tang Yongliang, Zhu Songbai, et al. Multi-scale coupled flow numerical simulation of ultra-deep fractured tight sandstone gas reservoirs [J]. Natural Gas Industry, 2024, 44(03): 143-151), the open flow rate of gas wells in fractured tight gas reservoirs is obtained by numerically solving based on the geological model and the seepage coupling model of the fractured tight gas reservoir. However, this method requires the establishment of a geological model and the use of a large number of complex parameters, resulting in high working costs, high operating costs, and low execution efficiency, making it difficult to accurately and conveniently determine the open flow rate of gas wells in fractured tight gas reservoirs.

[0059] Therefore, determining the unobstructed flow rate of gas wells in fractured tight gas reservoirs faces technical problems of low accuracy and low efficiency.

[0060] The method and apparatus for determining the unobstructed flow rate of a gas well in a fractured tight gas reservoir provided in this application acquire basic parameter information of the gas well in the fractured tight gas reservoir. This basic parameter information includes a first dataset, a second dataset, and a third dataset. The first dataset includes different formation pressures and the corresponding natural gas compressibility factors. The second dataset includes different formation pressures and the corresponding natural gas viscosities. The third dataset includes different permeabilities and the corresponding non-Darcy flow coefficients. Further, based on the first, second, and third datasets, the production information of the gas well in the fractured tight gas reservoir is determined. This production information represents the correlation between formation pressure and gas well flow rate. Further, based on the production information, the unobstructed flow rate of the gas well in the fractured tight gas reservoir is determined. This unobstructed flow rate represents the natural gas production of the gas well in the fractured tight gas reservoir when the formation pressure at the bottom of the gas well is zero. The method for determining the unobstructed flow rate of a gas well in a fractured tight gas reservoir provided in this application does not require the introduction of a large amount of parameter information. It only needs to use a first dataset, a second dataset, and a third dataset to determine the production information of the gas well in the fractured tight gas reservoir. The production information characterizes the correlation between formation pressure and gas well flow rate. Therefore, the natural gas production of the gas well in the fractured tight gas reservoir, i.e., the unobstructed flow rate, can be determined when the formation pressure at the bottom of the gas well is zero. The method of this application improves the accuracy and efficiency of determining the unobstructed flow rate of a gas well in a fractured tight gas reservoir.

[0061] The technical solution of this application and how the technical solution of this application solves the above-mentioned technical problems are described in detail below with specific embodiments. These specific embodiments can be combined with each other, and the same or similar concepts or processes may not be described again in some embodiments. The embodiments of this application will now be described with reference to the accompanying drawings.

[0062] Figure 1 A flowchart illustrating a method for determining the unobstructed flow rate of a gas well in a fractured tight gas reservoir, as provided in this application. Figure 1 The execution subject of this method can be a server, host, or other device, such as... Figure 1 As shown, the method may include:

[0063] S101. Obtain basic parameter information of gas wells in fractured tight gas reservoirs; wherein, the basic parameter information includes a first dataset, a second dataset, and a third dataset. The first dataset includes different formation pressures and the natural gas compressibility factor corresponding to the formation pressure. The second dataset includes different formation pressures and the natural gas viscosity corresponding to the formation pressure. The third dataset includes different permeabilities and the non-Darcy permeability coefficient corresponding to the permeability.

[0064] Among them, fractured tight gas reservoirs can be a type of oil and gas reservoir with seepage characteristics. Specifically, fractured tight gas reservoirs have the dual attributes of "fracture-matrix", that is, fractures are the main seepage channels of the gas reservoir, and the matrix is ​​the main storage space of the gas reservoir.

[0065] Gas wells in fractured tight gas reservoirs can refer to wells used to extract natural gas from fractured tight gas reservoirs.

[0066] The basic parameter information of gas wells in fractured tight gas reservoirs can refer to the relevant parameters used to determine the production (also known as flow rate) of gas wells. Specifically, the basic parameter information of gas wells in fractured tight gas reservoirs includes, but is not limited to, formation pressure, natural gas compressibility factor, natural gas viscosity, permeability, and non-Darcy flow coefficient.

[0067] Specifically, the basic parameter information may include a first dataset, a second dataset, and a third dataset. The first dataset may include different formation pressures and the natural gas compressibility factor corresponding to the formation pressure. The second dataset may include different formation pressures and the natural gas viscosity corresponding to the formation pressure. The third dataset may include different permeabilities and the non-Darcy permeability coefficient corresponding to the permeability.

[0068] Formation pressure can refer to the pressure of fluids in a gas reservoir, and the unit can be megapascals (MPa).

[0069] The compressibility factor of natural gas can be used to describe the degree to which the behavior of a real gas deviates from an ideal state. It can be understood that the compressibility factor of natural gas is a dimensionless parameter used to reflect the deviation between the actual volume of natural gas and the ideal volume of natural gas.

[0070] Natural gas viscosity can be an indicator that reflects the viscosity of natural gas, and the unit can be millipascal-second (mPa·s).

[0071] Permeability can refer to the permeability of the rock in a natural gas reservoir. Specifically, permeability characterizes the ability of the rock to allow fluids to pass through, that is, the ability of natural gas to conduct in the reservoir. The unit of permeability can be millidarcy (mD).

[0072] The non-Darcy flow coefficient, also known as the nonlinear flow coefficient, describes the nonlinear flow behavior of fluids in porous media when the flow does not satisfy Darcy's law. Essentially, the non-Darcy flow coefficient reflects the fluid exchange capacity between the fracture and the matrix, i.e., the natural gas exchange capacity between them. The unit of the non-Darcy flow coefficient is the reciprocal of the value per meter (1 / m).

[0073] For example, formation pressure, natural gas compressibility factor, natural gas viscosity, permeability, and non-Darcy flow coefficient can all be obtained by existing sensor equipment or historical experimental measurements or empirical formulas. No limitation is made here on the measurement methods for formation pressure, natural gas compressibility factor, natural gas viscosity, permeability, and non-Darcy flow coefficient.

[0074] It is understandable that by obtaining the basic parameter information of gas wells in fractured tight gas reservoirs, the unobstructed flow rate of gas wells in fractured tight gas reservoirs can be used to determine the unobstructed flow rate of gas wells in fractured tight gas reservoirs.

[0075] S102. Based on the first dataset, the second dataset, and the third dataset, determine the production information of gas wells in fractured tight gas reservoirs; wherein, the production information represents the correlation between formation pressure and gas well flow rate.

[0076] Among them, the production information of gas wells in fractured tight gas reservoirs can characterize the correlation between formation pressure and gas well flow rate.

[0077] For example, formation pressure can refer to the formation pressure at the bottom of a gas well in a fractured tight gas reservoir, and gas well flow rate can refer to the flow rate of natural gas that a gas well in a fractured tight gas reservoir can produce (also known as natural gas production).

[0078] The relationship between formation pressure and gas well flow rate can be represented by digital models or charts, and there are no restrictions on the form in which production information is presented here.

[0079] In one alternative implementation, step S102 may include:

[0080] Based on the first dataset, first relationship information is determined; based on the second dataset, second relationship information is determined; and based on the third dataset, third relationship information is determined. The first relationship information represents the correlation between formation pressure and natural gas compressibility factor; the second relationship information represents the correlation between formation pressure and natural gas viscosity; and the third relationship information represents the correlation between permeability and non-Darcy flow coefficient. Based on the first, second, and third relationship information, the production information of gas wells in fractured tight gas reservoirs is determined.

[0081] It can be understood that the first relationship information describes the correlation between formation pressure and natural gas compressibility factor, the second relationship information describes the correlation between formation pressure and natural gas viscosity, and the third relationship information describes the correlation between permeability and non-Darcy flow coefficient. By combining the first, second, and third relationship information, the production information of gas wells in fractured tight gas reservoirs can be determined.

[0082] For example, the first relation information, the second relation information, and the third relation information can be combined to establish a quadratic equation for the gas well production capacity, thereby determining the production information of gas wells in fractured tight gas reservoirs.

[0083] The first relationship information can be obtained by fitting a first dataset. This first relationship information can characterize the correlation between formation pressure and natural gas compressibility factor. The fitting process can include, but is not limited to, polynomial fitting. For example, the expression form of the first relationship information can include, but is not limited to, binomial.

[0084] It is understandable that the first relational information can be expressed in the form of a polynomial mathematical expression, or in other forms such as a graph.

[0085] For example, the different formation pressures and their corresponding natural gas compressibility factors in the first dataset are distributed as data points in a plane coordinate system. Based on the distribution of the data points, a suitable function is selected so that the data points fall as close as possible to the points corresponding to the function. These points can be linear or non-linear. It can be understood that the suitable function here can represent the first relational information.

[0086] In one optional implementation, the first relationship information is:

[0087] ;

[0088] in, Characterizing the compressibility factor of natural gas, Characterizing formation pressure, The constant term coefficients that characterize the information of the first relation. The coefficient of the first-order term representing the first relation information. The coefficient of the quadratic term representing the information of the first relation.

[0089] To better describe the first relation information, Figure 2 A schematic diagram of the first relationship information provided in this application, such as Figure 2 As shown, in the plane coordinate system, the horizontal axis represents the formation pressure P, with the unit being megapascals (MPa), and the vertical axis represents the natural gas compressibility factor Z.

[0090] Different formation pressures and their corresponding natural gas compressibility factors are distributed as data points in this plane coordinate system. By using a suitable function, the data points corresponding to the first dataset are made to fall as close as possible to the points corresponding to the function. In this case, the function corresponding to the first dataset can be a quadratic function.

[0091] The formation pressure P can be represented by the letter x as the independent variable of the quadratic function, and the natural gas compressibility factor Z can be represented by the letter y as the dependent variable of the quadratic function.

[0092] For example, the expression for the quadratic function corresponding to the first dataset can be:

[0093] ;

[0094] Correspondingly, the constant term coefficients in the first relational information It can be 0.904098, the coefficient of the first-order term in the first relation information. It can be 0.004532, the coefficient of the quadratic term in the first relation. It can be 0.000027.

[0095] In one possible implementation, if the correlation coefficient of the function obtained by fitting the first dataset is greater than or equal to a preset first correlation coefficient threshold, then the function corresponding to the first dataset is determined to be the first relational information.

[0096] For example, the preset first correlation coefficient threshold can be 0.95.

[0097] The correlation coefficient of the function obtained by fitting the first dataset satisfies the following:

[0098] ;

[0099] in, This represents the correlation coefficient of the function obtained by fitting the first dataset. This indicates the number of data points in the first dataset. This represents the actual value of the natural gas compressibility factor in the first dataset. This represents the predicted value of the natural gas compressibility factor obtained from the formation pressure in the first dataset using the function.

[0100] For example, the correlation coefficient of the function obtained by fitting the first dataset can be 0.997545. It can be understood that since the correlation coefficient of the function obtained by fitting the first dataset is greater than the preset first correlation coefficient threshold of 0.95, the function corresponding to the first dataset can be determined. This is the first relational information, where, P represents the formation pressure. Z represents the compressibility factor of natural gas.

[0101] It is understandable that by representing the first relationship information as a quadratic function, and by obtaining a high correlation coefficient for the fitted quadratic function, the accuracy of determining the unobstructed flow rate of gas wells in fractured tight gas reservoirs is improved.

[0102] The second relationship information can also be obtained by fitting a second dataset. This second relationship information can characterize the correlation between formation pressure and natural gas viscosity. The fitting process can include, but is not limited to, polynomial fitting. For example, the expression form of the second relationship information can include, but is not limited to, binomial.

[0103] It is understandable that the second relation information can be expressed in the form of a polynomial mathematical expression, or in other forms such as a graph.

[0104] For example, the different formation pressures and corresponding natural gas viscosities in the second dataset are distributed as data points in a planar coordinate system. Based on the distribution of the data points, a suitable function is selected so that the data points fall as close as possible to the points corresponding to the function. The points corresponding to the function can be linear or non-linear. It can be understood that the suitable function here can be a representation of the second relational information.

[0105] In one optional implementation, the second relationship information is:

[0106] ;

[0107] in, Characterizing the viscosity of natural gas, Characterizing formation pressure, The constant term coefficients that characterize the information of the second relation. The coefficient of the first-order term representing the information of the second relation. The coefficients of the quadratic term that represent the second relation information.

[0108] To better describe the second relation information, Figure 3 A schematic diagram of the second relationship information provided in this application, such as Figure 3 As shown, in the plane coordinate system, the horizontal axis represents the formation pressure P, with the unit being megapascals (MPa), and the vertical axis represents the viscosity of natural gas. The unit is millipascal-second (mPa·s).

[0109] Different formation pressures and the corresponding natural gas viscosities are distributed as data points in this plane coordinate system. By using a suitable function, the data points corresponding to the second dataset are made to fall as close as possible to the points corresponding to the function. At this time, the function corresponding to the second dataset can be a quadratic function.

[0110] Taking formation pressure P as the independent variable of a quadratic function, which can be represented by the letter x, and considering the viscosity of natural gas... The dependent variable of a quadratic function can be represented by the letter y.

[0111] For example, the expression for the quadratic function corresponding to the second dataset can be:

[0112] ;

[0113] Correspondingly, the constant term coefficients in the second relational information It can be 0.013599, the coefficient of the first-order term in the second relation information. It can be The coefficient of the quadratic term in the second relation It can be 0.

[0114] Alternatively, the quadratic function corresponding to the second dataset at this point can be simplified to:

[0115] ;

[0116] At this point, the function corresponding to the second dataset can be a linear function.

[0117] In one possible implementation, if the correlation coefficient of the function obtained by fitting the second dataset is greater than or equal to a preset second correlation coefficient threshold, then the function corresponding to the second dataset is determined to be the second relation information.

[0118] For example, the preset second correlation coefficient threshold can be 0.95.

[0119] The correlation coefficient of the function obtained by fitting the second dataset satisfies the following:

[0120] ;

[0121] in, This represents the correlation coefficient of the function obtained by fitting the second dataset. This indicates the number of data points in the second dataset. This represents the actual value of natural gas viscosity in the second dataset. This represents the predicted value of natural gas viscosity obtained from the formation pressure in the function in the second dataset.

[0122] For example, the correlation coefficient of the function obtained by fitting the second dataset can be 0.999741. It can be understood that since the correlation coefficient of the function obtained by fitting the second dataset is greater than the preset second correlation coefficient threshold of 0.95, the function corresponding to the second dataset can be determined. This is the second relation information, where, P represents the formation pressure. Indicates the viscosity of natural gas .

[0123] It is understandable that by representing the second relationship information in the form of a quadratic or linear function, and by fitting the quadratic or linear function with a high correlation coefficient, the accuracy of determining the unobstructed flow rate of gas wells in fractured tight gas reservoirs is improved.

[0124] Third-party relationship information can also be obtained by fitting a third dataset. This third-party relationship information can characterize the correlation between permeability and the non-Darcy flow coefficient. The fitting process can include, but is not limited to, polynomial fitting and power function fitting. For example, the expression form of the third-party relationship information can include, but is not limited to, a power function.

[0125] It is understandable that the third relationship information can be expressed in the form of a power function of a mathematical expression, or in other forms such as a graph.

[0126] For example, the different permeabilities and their corresponding non-Darcy flow coefficients in the third dataset are distributed as data points in a planar coordinate system. Based on the distribution of the data points, a suitable function is selected so that the data points fall as close as possible to the points corresponding to the function. These points can be linear or non-linear. It can be understood that the suitable function here can represent the third-party relational information.

[0127] In one optional implementation, the third relationship information is:

[0128] ;

[0129] in, Characterizing the non-Darcy permeability coefficient, Characterizing penetration rate, The constant term coefficients that characterize information about the third relationship. The coefficient of the exponential term representing the information of the third relationship.

[0130] To better describe third-party relationship information, Figure 4 A schematic diagram of the third-party relationship information provided in this application, such as Figure 4 As shown, in the plane coordinate system, the horizontal axis represents the permeability K, with units of millidarcy (mD), and the vertical axis represents the non-Darcy permeability coefficient. The unit is the reciprocal of the unit per meter (1 / m).

[0131] Different permeabilities and their corresponding non-Darcy flow coefficients are distributed as data points in this planar coordinate system. By using a suitable function, the data points corresponding to the third dataset are made to fall as close as possible to the points corresponding to the function. In this case, the function corresponding to the third dataset can be a power function.

[0132] Using permeability K as the independent variable of a power function, which can be represented by the letter x, and the non-Darcy permeability coefficient... As the dependent variable of a power function, it can be represented by the letter y.

[0133] For example, the expression for the power function corresponding to the third dataset can be:

[0134] ;

[0135] in, equal , equal .

[0136] Correspondingly, the constant term coefficients of the third relation information It can be The coefficient of the exponential term of the third relation information It can be .

[0137] In one possible implementation, if the correlation coefficient of the function obtained by fitting the third dataset is greater than or equal to a preset third correlation coefficient threshold, then the function corresponding to the third dataset is determined to be the third relation information.

[0138] For example, the preset third correlation coefficient threshold can be 0.95.

[0139] The correlation coefficient of the function obtained by fitting the third dataset satisfies the following:

[0140] ;

[0141] in, This represents the correlation coefficient of the function obtained by fitting the third dataset. This indicates the number of data points in the third dataset. This represents the actual value of the non-Darcy seepage coefficient in the third dataset. This represents the predicted non-Darcy permeability coefficient obtained from the function for the permeability in the third dataset.

[0142] For example, the correlation coefficient of the function obtained by fitting the third dataset can be 0.968, which is equal to 9.68E-01. It can be understood that since the correlation coefficient of the function obtained by fitting the third dataset is greater than the preset second correlation coefficient threshold of 0.95, the function corresponding to the third dataset can be determined. This is third-party relation information, where, K represents the penetration rate. Indicates the non-Darcy permeability coefficient .

[0143] It is understandable that by representing the third relationship information in the form of a power function, and by fitting the power function with a high correlation coefficient, the accuracy of determining the unobstructed flow rate of gas wells in fractured tight gas reservoirs is improved.

[0144] It should be noted that while the steps for determining the functions corresponding to the first, second, and third relation information are largely the same, the meanings of the letters corresponding to different functions are not necessarily the same. Furthermore, the number of data points in the first, second, and third datasets may not be the same.

[0145] In one optional implementation, determining the production information of a gas well in a fractured tight gas reservoir based on first relationship information, second relationship information, and third relationship information may include:

[0146] Obtain well test interpretation information of gas wells in fractured tight gas reservoirs; wherein, well test interpretation information represents the results obtained by performing well test interpretation technology; and determine the production information of gas wells in fractured tight gas reservoirs based on well test interpretation information, first relation information, second relation information, and third relation information.

[0147] Well test interpretation can refer to a well test interpretation technique, which involves performing tests on oil and gas wells (such as pressure recovery tests, pressure drop tests, etc.). Well test interpretation information can refer to the results obtained from performing well test interpretation techniques. It can be understood that the results information may include, but is not limited to, the permeability of oil and gas wells.

[0148] It is understandable that well test interpretation information for gas wells in fractured tight gas reservoirs can include information such as the permeability of the gas wells.

[0149] By combining well test interpretation information from fractured tight gas reservoirs, the test information of the current fractured tight gas reservoir wells can be determined, providing reliable data support for the subsequent determination of the unobstructed flow rate of the gas wells in fractured tight gas reservoirs, thereby improving the accuracy of the subsequent determination of the unobstructed flow rate of the gas wells in fractured tight gas reservoirs.

[0150] In one optional implementation, the well test interpretation information includes the permeability, well control radius, wellbore radius, matrix volume within the well control area, and crossflow coefficient interpreted from the well test. The basic parameter information also includes the temperature of the fractured tight gas reservoir and the thickness of the fractured tight gas reservoir.

[0151] It is understandable that the sources or methods of obtaining data in well test interpretation information and basic parameter information are not necessarily the same. Specifically, well test interpretation information for gas wells in fractured tight gas reservoirs can be obtained through well test testing, numerical simulation, and field monitoring using well test interpretation technology. This information reflects the dynamic characteristics of the gas well and the reservoir. Basic parameter information, on the other hand, can be obtained through geological surveys, laboratory analysis, and historical experimental data. This information reflects the basic geological and fluid characteristics of the gas reservoir.

[0152] By combining well test interpretation information and basic parameter information of gas wells in fractured tight gas reservoirs, reliable data support is provided for the subsequent determination of the unobstructed flow rate of gas wells in fractured tight gas reservoirs, thereby improving the accuracy of the subsequent determination of the unobstructed flow rate of gas wells in fractured tight gas reservoirs.

[0153] Production information is represented as follows:

[0154] ;

[0155] ;

[0156] ;

[0157] in, The original formation pressure of a gas well in a fractured tight gas reservoir. Formation pressure at the bottom of a gas well in a fractured tight gas reservoir. Characterizing natural gas production, Characterizing the viscosity of natural gas, Characterizing the compressibility factor of natural gas, Temperature characterizing fractured tight gas reservoirs Atmospheric pressure under standard conditions Characterizing temperature under standard conditions, Characterizing the permeability interpreted from well tests, The thickness characterizing fractured tight gas reservoirs, Characterizing the crossflow coefficient, Characterizing the well control radius, Characterizing the wellbore radius, Characterizing the matrix volume within the well control area, The non-Darcy flow coefficient characterizing the permeability interpreted from well tests. Characterizing the density of natural gas under standard conditions, , All represent constants.

[0158] Specifically, the original formation pressure of gas wells in fractured tight gas reservoirs. This can refer to the formation pressure of a fractured tight gas reservoir in its initial state. The initial formation pressure can refer to the pressure of the reservoir before development or before it has been affected by extraction. For example, the initial formation pressure of a gas well in a fractured tight gas reservoir. It can be 116 MPa.

[0159] Formation pressure at the bottom of a gas well in a fractured tight gas reservoir This can refer to the bottomhole flowing pressure of a gas well in a fractured tight gas reservoir; it can be understood as the formation pressure at the bottom of the gas well in a fractured tight gas reservoir. The relationship between formation pressure and natural gas compressibility factor (as described in the first relationship information) and formation pressure and natural gas viscosity (as described in the second relationship information) must be satisfied, i.e., the formation pressure at the bottom of the well in a fractured tight gas reservoir. Information that satisfies the first relational requirement with the natural gas compressibility factor indicates the formation pressure at the bottom of the well in a fractured tight gas reservoir. The viscosity of natural gas satisfies the second relationship information.

[0160] Natural gas compressibility The first relation information can be satisfied: ;

[0161] Natural gas viscosity The second relation information can be satisfied: ;

[0162] Natural gas production It can refer to the amount of natural gas that a gas well in a fractured tight gas reservoir can produce per unit time. The unit of natural gas production can be cubic meters per day (m³ / d).

[0163] Temperature of fractured tight gas reservoirs It can reflect the thermal state of fractured tight gas reservoirs; for example, the temperature of a fractured tight gas reservoir. It can be 160 degrees Celsius (°C).

[0164] Atmospheric pressure under standard conditions Atmospheric pressure can be defined under standard conditions; for example, atmospheric pressure under standard conditions. It can be 101.325 kPa.

[0165] Temperature under standard conditions A temperature that can be defined under standard conditions, for example, the temperature under standard conditions It can be 15 degrees Celsius (°C).

[0166] Natural gas density under standard conditions The density of natural gas can be defined under standard conditions; for example, the density of natural gas under standard conditions. It can be 0.716 kg per cubic meter ( ).

[0167] Permeability interpreted from well tests This can refer to the permeability obtained from well test interpretation information of gas wells in fractured tight gas reservoirs. For example, the permeability interpreted from well tests... It can be 3.3 millidarcy (mD).

[0168] Thickness of fractured tight gas reservoirs This can refer to the vertical dimension of a fractured tight gas reservoir; for example, the thickness of a fractured tight gas reservoir. It can be 25 meters (m).

[0169] Crossflow coefficient The channeling coefficient can refer to the flow rate coefficient obtained from well test interpretation information of gas wells in fractured tight gas reservoirs. The channeling coefficient describes the fluid exchange capacity between fractures and the matrix. It is understood that the channeling coefficient is a dimensionless parameter. For example, the channeling coefficient... It can be .

[0170] Wellbore radius It can refer to the inner radius of the gas well casing, that is, the physical dimension of the well casing. For example, the well casing radius... It can be 0.1 meters (m).

[0171] Well control radius This can refer to the farthest distance from the center of the gas well to the area the well can influence. Within the well control radius, the gas well can effectively extract fluids (natural gas) from the reservoir. For example, the well control radius... It can be 200 meters (m). This means the well control radius is greater than or equal to the wellbore radius.

[0172] Matrix volume within well control range This can refer to the volume of the matrix within the well control radius. The matrix can refer to the rock skeleton portion of the reservoir, and its volume can be the storage space for natural gas. For example, the matrix volume within the well control radius... It can be 400,000 cubic meters ( ).

[0173] Non-Darcy flow coefficient corresponding to permeability interpreted from well tests This can refer to the non-Darcy flow coefficient obtained by determining the permeability interpreted from well tests using third-party relational information. For example, the permeability K interpreted from well tests can be 3.3 millidarcy (mD) as mentioned above. Substituting the permeability K of 3.3 millidarcy (mD) interpreted from well tests into the third-party relational information: ,in, equal , The non-Darcy permeability coefficient is equal to 1.18. It can be .

[0174] constant and constant It can refer to a parameter, or constant, used to improve the accuracy of determining the unobstructed flow rate of gas wells in fractured tight gas reservoirs based on production information. and constant It can be preset by staff based on experience; for example, a constant. It can be a constant with an approximate value of 2. It can also be a constant with an approximate value of 2.

[0175] For example, production information can be represented as:

[0176] ;

[0177] Among them, the original formation pressure of gas wells in fractured tight gas reservoirs It can be 116 MPa. Production information represents the relationship between formation pressure and gas well flow rate. Specifically, production information represents the relationship between formation pressure and gas well flow rate at the bottom of a gas well in a fractured tight gas reservoir.

[0178] It is understandable that the determination of production information takes into account the dual attributes of "fracture-matrix" of gas wells in fractured tight gas reservoirs. That is, fractures are the main seepage channels of the gas reservoir, and the matrix is ​​the main storage space of the gas reservoir, which improves the accuracy of determining the unobstructed flow rate of gas wells in fractured tight gas reservoirs.

[0179] S103. Based on production information, determine the unobstructed flow rate of the gas well in the fractured tight gas reservoir; wherein, the unobstructed flow rate characterizes the natural gas production of the gas well in the fractured tight gas reservoir when the formation pressure at the bottom of the gas well is zero.

[0180] Among them, the unobstructed flow rate of a gas well in a fractured tight gas reservoir can refer to the natural gas production of the gas well in the fractured tight gas reservoir when the formation pressure at the bottom of the gas well is zero.

[0181] It can be understood that production information represents the relationship between formation pressure and gas well flow rate, that is, production information represents the relationship between formation pressure and gas well flow rate at the bottom of a gas well in a fractured tight gas reservoir.

[0182] For example, production information can be: Among them, the original formation pressure of gas wells in fractured tight gas reservoirs The pressure can be 116 MPa. When the formation pressure at the bottom of the gas well in a fractured tight gas reservoir is zero, the corresponding natural gas production (also known as the gas well flow rate) can be calculated. That is, the unobstructed flow rate of the gas well in a fractured tight gas reservoir is... cubic meters / day ( ).

[0183] In one alternative implementation, step S103 may include:

[0184] Based on production information, the natural gas production corresponding to the formation pressure at the bottom of the gas well in a fractured tight gas reservoir being zero is determined as the unobstructed flow rate of the gas well in the fractured tight gas reservoir.

[0185] Specifically, based on production information, an inflow dynamic relationship curve (also known as an IPR curve) is plotted, and the gas well flow rate at the bottom of the gas well in the fractured tight gas reservoir when the formation pressure is zero is determined as the unobstructed flow rate of the gas well in the fractured tight gas reservoir.

[0186] Among them, the dynamic relationship curve characterizes the correlation between the formation pressure at the bottom of the gas well and the gas well flow rate in fractured tight gas reservoirs.

[0187] To better describe how to determine the unobstructed flow rate of a gas well in a fractured tight gas reservoir based on production information, Figure 5 A schematic diagram of the production information provided in this application, such as Figure 5 As shown, in the plane coordinate system, the horizontal axis represents natural gas production. (Also known as gas well flow rate or daily gas production), unit is... The vertical axis represents the formation pressure (also known as bottom hole pressure) at the bottom of the gas well in a fractured tight gas reservoir, and the unit is MPa.

[0188] Figure 5 One curve in the figure represents the dynamic relationship curve corresponding to the equivalent homogeneous method, and the other curve represents the dynamic relationship curve corresponding to the method for determining the unobstructed flow rate of gas wells in fractured tight gas reservoirs of this application (hereinafter referred to as: the method of this invention).

[0189] The dynamic relationship curve corresponding to the equivalent homogenization method does not take into account the dual "fracture-matrix" attributes of gas wells in fractured tight gas reservoirs. The production information obtained according to the equivalent homogenization method can be expressed as follows: The well flow rate when the formation pressure at the bottom of the gas well in a fractured tight gas reservoir is zero is: cubic meters / day ( ).

[0190] The invention method of this invention takes into account the dual "fracture-matrix" properties of gas wells in fractured tight gas reservoirs. The production information obtained by the invention method of this invention can be expressed as follows: The well flow rate when the formation pressure at the bottom of the gas well in a fractured tight gas reservoir is zero is: cubic meters / day ( ), that is, the unobstructed flow rate of a gas well in a fractured tight gas reservoir.

[0191] It can be seen that the unobstructed flow rate of the gas well obtained by the method of this invention has a better match with the actual production dynamics, and the calculation process is not complicated, which improves the accuracy and efficiency of determining the unobstructed flow rate of the gas well in fractured tight gas reservoirs.

[0192] The method for determining the unobstructed flow rate of a gas well in a fractured tight gas reservoir provided in this application does not require the introduction of a large amount of parameter information. It only needs to use a first dataset, a second dataset, and a third dataset to determine the production information of the gas well in the fractured tight gas reservoir. The production information characterizes the correlation between formation pressure and gas well flow rate. Therefore, the natural gas production of the gas well in the fractured tight gas reservoir, i.e., the unobstructed flow rate, can be determined when the formation pressure at the bottom of the gas well is zero. The method of this application improves the accuracy and efficiency of determining the unobstructed flow rate of a gas well in a fractured tight gas reservoir.

[0193] Figure 6 A flowchart illustrating a method for determining the unobstructed flow rate of a gas well in a fractured tight gas reservoir, as provided in this application. Figure 2 The execution subject of this method can be a server, host, or other device, such as... Figure 6 As shown, the method may include:

[0194] S601. Obtain basic parameter information of gas wells in fractured tight gas reservoirs; among which, basic parameter information includes different formation pressures and the natural gas compressibility factor corresponding to the formation pressure, different formation pressures and the natural gas viscosity corresponding to the formation pressure, different permeability and the non-Darcy flow coefficient corresponding to the permeability.

[0195] S602. Fit the first relationship information based on different formation pressures and the natural gas compressibility factor corresponding to the formation pressure, and fit the second relationship information based on different formation pressures and the natural gas viscosity corresponding to the formation pressure.

[0196] For example, the first relationship information is: Where P represents formation pressure, Characterizes the compressibility factor of natural gas.

[0197] The second relation information is: Where P represents formation pressure, Characterizes the viscosity of natural gas.

[0198] S603. Based on different permeabilities and the corresponding non-Darcy flow coefficients, fit the third relationship information, and based on the permeability interpreted in the well test information of the fractured tight gas reservoir, determine the non-Darcy flow coefficient corresponding to the permeability interpreted in the well test based on the third relationship information.

[0199] For example, the third-party relationship information is: ,in, Indicates osmotic pressure. This represents the non-Darcy permeability coefficient.

[0200] Substituting the permeability (e.g., 3.3 mD) from the well test interpretation information of a fractured tight gas reservoir into the third relational information, the non-Darcy flow coefficient corresponding to the permeability obtained from the well test interpretation can be: .

[0201] S604. Based on the well test interpretation information of the gas wells in the fractured tight gas reservoir, including the permeability, non-Darcy flow coefficient, crossflow coefficient, and basic parameter information of the gas wells in the well test interpretation information, determine the production information of the gas wells in the fractured tight gas reservoir. The production information of the gas wells represents the correlation between the formation pressure at the bottom of the gas well and the gas well flow rate in the fractured tight gas reservoir.

[0202] For example, the production information of a gas well can be: Among them, the original formation pressure of gas wells in fractured tight gas reservoirs It can be 116 MPa.

[0203] S605. Based on the production information of gas wells in fractured tight gas reservoirs, draw the inflow dynamic relationship curve, and determine the gas well flow rate when the formation pressure at the bottom of the gas well in the fractured tight gas reservoir is zero as the unobstructed flow rate of the gas well in the fractured tight gas reservoir.

[0204] For example, based on the gas well production information in S604, when the formation pressure at the bottom of the gas well in a fractured tight gas reservoir is zero, the corresponding natural gas production (also known as the gas well flow rate) can be calculated. That is, the unobstructed flow rate of the gas well in the fractured tight gas reservoir is... cubic meters / day ( ).

[0205] The method described in this application improves the accuracy and efficiency of determining the unobstructed flow rate of gas wells in fractured tight gas reservoirs.

[0206] Figure 7 A schematic diagram of the structure of a device for determining the unobstructed flow rate of a gas well in a fractured tight gas reservoir provided in this application. Figure 1 ,like Figure 7 As shown, the device 70 for determining the unobstructed flow rate of a gas well in a fractured tight gas reservoir includes: an acquisition unit 701, a first determination unit 702, and a second determination unit 703.

[0207] The acquisition unit 701 is used to acquire basic parameter information of gas wells in fractured tight gas reservoirs. The basic parameter information includes a first dataset, a second dataset, and a third dataset. The first dataset includes different formation pressures and the natural gas compressibility factor corresponding to the formation pressure. The second dataset includes different formation pressures and the natural gas viscosity corresponding to the formation pressure. The third dataset includes different permeabilities and the non-Darcy permeability coefficient corresponding to the permeability.

[0208] The first determining unit 702 is used to determine the production information of gas wells in fractured tight gas reservoirs based on the first dataset, the second dataset, and the third dataset; wherein, the production information represents the correlation between formation pressure and gas well flow rate;

[0209] The second determining unit 703 is used to determine the unobstructed flow rate of a gas well in a fractured tight gas reservoir based on production information; wherein, the unobstructed flow rate characterizes the natural gas production of the gas well in the fractured tight gas reservoir when the formation pressure at the bottom of the gas well is zero.

[0210] Figure 8 A schematic diagram of the structure of a device for determining the unobstructed flow rate of a gas well in a fractured tight gas reservoir provided in this application. Figure 2 ,like Figure 8 As shown, the device 80 for determining the unobstructed flow rate of a gas well in a fractured tight gas reservoir includes: an acquisition unit 801, a first determination unit 802, and a second determination unit 803. The first determination unit 802 further includes a first processing module 8021 and a second processing module 8022.

[0211] The first processing module 8021 is used to determine first relationship information based on a first dataset, second relationship information based on a second dataset, and third relationship information based on a third dataset; wherein, the first relationship information represents the correlation between formation pressure and natural gas compressibility factor, the second relationship information represents the correlation between formation pressure and natural gas viscosity, and the third relationship information represents the correlation between permeability and non-Darcy permeability coefficient.

[0212] The second processing module 8022 is used to determine the production information of gas wells in fractured tight gas reservoirs based on the first relationship information, the second relationship information, and the third relationship information.

[0213] In an optional example, the first relation information is:

[0214] ;

[0215] in, Characterizing the compressibility factor of natural gas, Characterizing formation pressure, The constant term coefficients that characterize the information of the first relation. The coefficient of the first-order term representing the information of the first relation. The coefficient of the quadratic term representing the first relation information.

[0216] In an optional example, the second relation information is:

[0217] ;

[0218] in, Characterizing the viscosity of natural gas, Characterizing formation pressure, The constant term coefficients that characterize the information of the second relation. The coefficient of the first-order term representing the information of the second relation. The coefficients of the quadratic term that represent the second relation information.

[0219] In an optional example, the third relation information is:

[0220] ;

[0221] in, Characterizing the non-Darcy permeability coefficient, Characterizing permeability, The constant term coefficients that characterize information about the third relationship. The coefficient of the exponential term representing the information of the third relationship.

[0222] In an optional example, the second processing module 8022 may also include a first submodule and a second submodule.

[0223] The first submodule is used to obtain well test interpretation information of gas wells in fractured tight gas reservoirs; wherein, well test interpretation information represents the results obtained by performing well test interpretation technology.

[0224] The second submodule is used to determine the production information of gas wells in fractured tight gas reservoirs based on well test interpretation information, first relationship information, second relationship information, and third relationship information.

[0225] In an optional example, well test interpretation information includes the interpreted permeability, well control radius, wellbore radius, matrix volume within the well control area, and channeling coefficient. Basic parameter information also includes the temperature and thickness of the fractured tight gas reservoir. Production information is characterized as follows:

[0226] ;

[0227] ;

[0228] ;

[0229] in, The original formation pressure of a gas well in a fractured tight gas reservoir. Formation pressure at the bottom of a gas well in a fractured tight gas reservoir. Characterizing natural gas production, Characterizing the viscosity of natural gas, Characterizing the compressibility factor of natural gas, Temperature characterizing fractured tight gas reservoirs Atmospheric pressure under standard conditions. Characterizing temperature under standard conditions, Characterizing the permeability interpreted from well tests, The thickness characterizing fractured tight gas reservoirs, Characterizing the crossflow coefficient, Characterizing the well control radius, Characterizing the wellbore radius, Characterizing the matrix volume within the well control area, The non-Darcy flow coefficient characterizing the permeability interpreted from well tests. Characterizing the density of natural gas under standard conditions, , All represent constants.

[0230] In an optional example, the second determining unit 803 is further specifically used to determine the natural gas production corresponding to the formation pressure at the bottom of the gas well in the fractured tight gas reservoir being zero, based on the production information, as the unobstructed flow rate of the gas well in the fractured tight gas reservoir.

[0231] Figure 9 A schematic diagram of the structure of the electronic device provided in this application, such as... Figure 9 As shown, the electronic device 90 provided in this embodiment includes at least one processor 901 and a memory 902. Optionally, the device 90 further includes a communication component 903. The processor 901, memory 902, and communication component 903 are connected via a bus 904.

[0232] In a specific implementation, at least one processor 901 executes computer execution instructions stored in memory 902, causing at least one processor 901 to perform the above-described method.

[0233] The specific implementation process of processor 901 can be found in the above method embodiments, and its implementation principle and technical effect are similar. It will not be repeated here.

[0234] In the above embodiments, it should be understood that the processor can be a Central Processing Unit (CPU), or other general-purpose processors, digital signal processors (DSPs), application-specific integrated circuits (ASICs), etc. The general-purpose processor can be a microprocessor or any conventional processor. The steps of the method disclosed in this invention can be directly implemented by a hardware processor, or implemented by a combination of hardware and software modules within the processor.

[0235] The memory may include random access memory (RAM) and may also include non-volatile memory (NVM), such as at least one disk storage device.

[0236] The bus can be an Industry Standard Architecture (ISA) bus, a Peripheral Component Interconnect (PCI) bus, or an Extended Industry Standard Architecture (EISA) bus, etc. Buses can be categorized as address buses, data buses, control buses, etc. For ease of illustration, the buses shown in the accompanying drawings are not limited to a single bus or a single type of bus.

[0237] This application also provides a computer program product, including a computer program that, when executed by a processor, implements the above-described method.

[0238] This application also provides a computer-readable storage medium storing computer-executable instructions, which, when executed by a processor, implement the above-described method.

[0239] It should be noted that, for the sake of simplicity, the foregoing method embodiments are all described as a series of actions. However, those skilled in the art should understand that this application is not limited to the described order of actions, as some steps may be performed in other orders or simultaneously according to this application. Furthermore, those skilled in the art should also understand that the embodiments described in the specification are all optional embodiments, and the actions and modules involved are not necessarily essential to this application.

[0240] It should be further noted that although the steps in the flowchart are shown sequentially according to the arrows, these steps are not necessarily executed in the order indicated by the arrows. Unless explicitly stated herein, there is no strict order restriction on the execution of these steps, and they can be executed in other orders. Moreover, at least some steps in the flowchart may include multiple sub-steps or multiple stages. These sub-steps or stages are not necessarily completed at the same time, but can be executed at different times. The execution order of these sub-steps or stages is not necessarily sequential, but can be performed alternately or in turn with other steps or at least some of the sub-steps or stages of other steps.

[0241] It should be understood that the above-described device embodiments are merely illustrative, and the device of this application can also be implemented in other ways. For example, the division of units / modules in the above embodiments is only a logical functional division, and there may be other division methods in actual implementation. For example, multiple units, modules, or components may be combined, or integrated into another system, or some features may be ignored or not executed.

[0242] Furthermore, unless otherwise specified, the functional units / modules in the various embodiments of this application can be integrated into one unit / module, or each unit / module can exist physically separately, or two or more units / modules can be integrated together. The integrated units / modules described above can be implemented in hardware or as software program modules.

[0243] When integrated units / modules are implemented in hardware, the hardware can be digital circuits, analog circuits, etc. The physical implementation of the hardware structure includes, but is not limited to, transistors, memristors, etc. Unless otherwise specified, the processor can be any suitable hardware processor, such as a CPU, GPU, FPGA, DSP, and ASIC, etc. Unless otherwise specified, the storage unit can be any suitable magnetic or magneto-optical storage medium, such as Resistive Random Access Memory (RRAM), Dynamic Random Access Memory (DRAM), Static Random Access Memory (SRAM), Enhanced Dynamic Random Access Memory (EDRAM), High-Bandwidth Memory (HBM), Hybrid Memory Cube (HMC), etc.

[0244] If the integrated unit / module is implemented as a software program module and sold or used as an independent product, it can be stored in a computer-readable storage device (CMD). Based on this understanding, the technical solution of this application, in essence, or the part that contributes to the prior art, or all or part of the technical solution, can be embodied in the form of a software product. This computer software product is stored in a memory 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 steps of the methods of the various embodiments of this application. The aforementioned memory includes various media capable of storing program code, such as a USB flash drive, read-only memory (ROM), random access memory (RAM), portable hard drive, magnetic disk, or optical disk.

[0245] In the above embodiments, the descriptions of each embodiment have their own emphasis. For parts not described in detail in a certain embodiment, please refer to the relevant descriptions of other embodiments. The technical features of the above embodiments can be combined arbitrarily. For the sake of brevity, not all possible combinations of the technical features in the above embodiments are described. However, as long as the combination of these technical features does not contradict each other, it should be considered within the scope of this specification.

[0246] Other embodiments of this application will readily occur to those skilled in the art upon consideration of the specification and practice of the invention disclosed herein. This application is intended to cover any variations, uses, or adaptations of this application that follow the general principles of this application and include common knowledge or customary techniques in the art not disclosed herein. The specification and examples are to be considered exemplary only, and the true scope and spirit of this application are indicated by the following claims.

[0247] It should be understood that this application is not limited to the precise structure described above and shown in the accompanying drawings, and various modifications and changes can be made without departing from its scope. The scope of this application is limited only by the appended claims.

Claims

1. A method for determining the unobstructed flow rate of a gas well in a fractured tight gas reservoir, characterized in that, include: Acquire basic parameter information of gas wells in fractured tight gas reservoirs; wherein, the basic parameter information includes a first dataset, a second dataset, and a third dataset, the first dataset includes different formation pressures and the natural gas compressibility factor corresponding to the formation pressure, the second dataset includes different formation pressures and the natural gas viscosity corresponding to the formation pressure, and the third dataset includes different permeabilities and the non-Darcy permeability coefficient corresponding to the permeability. Based on the first dataset, the second dataset, and the third dataset, the production information of the gas wells in the fractured tight gas reservoir is determined; wherein, the production information represents the correlation between formation pressure and gas well flow rate; Based on the production information, the unobstructed flow rate of the gas well in the fractured tight gas reservoir is determined; wherein, the unobstructed flow rate characterizes the natural gas production of the gas well in the fractured tight gas reservoir when the formation pressure at the bottom of the gas well is zero.

2. The method according to claim 1, characterized in that, Based on the first dataset, the second dataset, and the third dataset, the production information of the gas wells in the fractured tight gas reservoir is determined, including: Based on the first dataset, first relationship information is determined; based on the second dataset, second relationship information is determined; and based on the third dataset, third relationship information is determined. The first relationship information represents the correlation between formation pressure and natural gas compressibility factor; the second relationship information represents the correlation between formation pressure and natural gas viscosity; and the third relationship information represents the correlation between permeability and non-Darcy flow coefficient. Based on the first relationship information, the second relationship information, and the third relationship information, the production information of the gas wells in the fractured tight gas reservoir is determined.

3. The method according to claim 2, characterized in that, The first relationship information is: ； Among them, the Characterizing the compressibility factor of natural gas, the Characterizing formation pressure, the The constant term coefficients characterizing the first relation information, the The coefficients of the first-order terms representing the first relation information, the The coefficients of the quadratic term representing the first relational information.

4. The method according to claim 2, characterized in that, The second relationship information is: ； Among them, the Characterizing the viscosity of natural gas, the Characterizing formation pressure, the The constant term coefficients characterizing the second relation information, the The coefficients of the first-order terms characterizing the second relation information, the The coefficients of the quadratic term that characterize the second relation information.

5. The method according to claim 2, characterized in that, The third relationship information is: ； Among them, the Characterizing the non-Darcy seepage coefficient, the Characterizing permeability, the The constant term coefficients characterizing the third relation information, the The coefficients of the exponential term representing the third relation information.

6. The method according to claim 2, characterized in that, Based on the first relationship information, the second relationship information, and the third relationship information, the production information of the gas wells in the fractured tight gas reservoir is determined, including: Obtain well test interpretation information of the gas wells in the fractured tight gas reservoir; wherein, the well test interpretation information represents the results obtained by performing well test interpretation technology; Based on the well test interpretation information, the first relationship information, the second relationship information, and the third relationship information, the production information of the gas wells in the fractured tight gas reservoir is determined.

7. The method according to claim 6, characterized in that, The well test interpretation information includes the permeability, well control radius, wellbore radius, matrix volume within the well control area, and channeling coefficient. The basic parameter information also includes the temperature and thickness of the fractured tight gas reservoir. The production information is characterized as follows: ； ； ； Among them, the The original formation pressure of the gas well in the fractured tight gas reservoir is characterized by the The formation pressure at the bottom of the well in the fractured tight gas reservoir is characterized by the formation pressure at the bottom of the well. Characterizing natural gas production, the Characterizing the viscosity of natural gas, the Characterizing the compressibility factor of natural gas, the The temperature characterizing the fractured tight gas reservoir, the The atmospheric pressure under standard conditions, the The temperature under standard conditions, the Characterizing the permeability interpreted by the well test, the Characterizing the thickness of the fractured tight gas reservoir, the Characterizing the crossflow coefficient, the Characterizing the well control radius, the Characterizing the wellbore radius, the Characterizing the matrix volume within the well control area, the The non-Darcy flow coefficient characterizing the permeability interpreted by the well test, the Characterizing the density of natural gas under standard conditions, the , All represent constants.

8. The method according to any one of claims 1-7, characterized in that, Based on the aforementioned production capacity information, the unobstructed flow rate of the gas wells in the fractured tight gas reservoir is determined, including: Based on the production information, the natural gas production corresponding to the formation pressure at the bottom of the gas well in the fractured tight gas reservoir being zero is determined as the unobstructed flow rate of the gas well in the fractured tight gas reservoir.

9. A device for determining the unobstructed flow rate of a gas well in a fractured tight gas reservoir, characterized in that, include: The acquisition unit is used to acquire basic parameter information of gas wells in fractured tight gas reservoirs; wherein, the basic parameter information includes a first dataset, a second dataset, and a third dataset, the first dataset includes different formation pressures and the natural gas compressibility factor corresponding to the formation pressure, the second dataset includes different formation pressures and the natural gas viscosity corresponding to the formation pressure, and the third dataset includes different permeabilities and the non-Darcy permeability coefficient corresponding to the permeability. The first determining unit is configured to determine the production information of the gas wells in the fractured tight gas reservoir based on the first dataset, the second dataset, and the third dataset; wherein the production information represents the correlation between formation pressure and gas well flow rate; The second determining unit is used to determine the unobstructed flow rate of the gas well in the fractured tight gas reservoir based on the production information; wherein the unobstructed flow rate characterizes the natural gas production of the gas well in the fractured tight gas reservoir when the formation pressure at the bottom of the gas well is zero.

10. An electronic device, characterized in that, include: Memory, processor; The memory stores computer-executed instructions; The processor executes computer execution instructions stored in the memory, causing the processor to perform the method as described in any one of claims 1-8.

11. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores computer-executable instructions, which, when executed by a processor, are used to implement the method as described in any one of claims 1-8.

12. A computer program product, characterized in that, Includes a computer program that, when executed by a processor, implements the method described in any one of claims 1-8.

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