A method, system, device and medium for determining water body multiple of gas reservoir development

Abstract

The application provides a method, system, device and medium for determining water body multiple of gas reservoir development, comprising the following steps: determining the dynamic relationship between dynamic reserves and static geological reserves of a completely developed gas reservoir based on statistical induction; obtaining dynamic reserves of a complex gas reservoir with uncertain gas-water interface based on regression analysis method; evaluating the static geological reserves of the complex gas reservoir based on the dynamic relationship and the dynamic reserves of the complex gas reservoir; evaluating the gas-bearing area and the gas-water interface of the gas reservoir based on the static geological reserves and the volumetric method; evaluating the water body volume based on the gas-bearing area and the gas-water interface by using the volumetric method; and obtaining the water body multiple based on the relationship between the water body volume and the water body multiple. The application reversely obtains and evaluates the unknown gas-water interface and the water body multiple by using the dynamic method, thereby providing guidance for water prevention and treatment of the gas reservoir.

Description

TECHNICAL FIELD

[0001] The application belongs to the technical field of oilfield development, and particularly relates to a method, system, device and medium for determining water body multiple of gas reservoir development. BACKGROUND

[0002] Most conventional gas reservoirs in the prior art belong to water drive gas reservoirs to different degrees, and 40% to 50% of the gas reservoirs are active in edge and bottom water. In the development process of the water drive gas reservoir, with the output of gas and the reduction of formation pressure, the water body gradually invades the gas reservoir. On the one hand, the invasion of the water body can effectively supplement the formation energy, and on the other hand, the invasion of the water body can increase the abandoned pressure of the gas reservoir and reduce the recovery ratio of the gas reservoir. Therefore, the edge and bottom water problem has always been concerned by oil and gas reservoir engineers. The water invasion amount, water body volume, water body multiple and gas reservoir geological reserves of the water drive gas reservoir are the basis for the reasonable and efficient development of the gas reservoir, and are of great significance for the adjustment of the late development technical policy of the water drive gas reservoir.

[0003] In recent years, scholars have begun to pay attention to the size of the water body. The driving of the oil and gas by the edge and bottom water and the influence on the water cut are related to the size of the water body. Therefore, it is necessary to obtain the size of the edge and bottom water volume. The size of the edge and bottom water volume is commonly represented by the water body multiple. The water body multiple is the ratio of the volume of the edge and bottom water to the volume of the oil and gas. The method for obtaining the water body multiple in the prior art is relatively complex, has great calculation difficulty, and has poor calculation accuracy. Therefore, the size of the edge and bottom water volume cannot be accurately represented. SUMMARY

[0004] In view of the problems in the prior art, the application provides a method, system, device and medium for determining the water body multiple of gas reservoir development. The application can simultaneously calculate the static geological reserves, gas-water interface and water body volume of the gas reservoir, and provides guidance for water prevention and treatment of the gas reservoir.

[0005] The application is achieved by the following technical solutions.

[0006] A method for determining the water body multiple of gas reservoir development comprises the following steps.

[0007] The dynamic relationship between the dynamic reserves and the static geological reserves of the completely developed gas reservoir is determined based on a statistical induction method.

[0008] The dynamic reserves of the complex gas reservoir with a closed and uncertain gas-water interface are obtained based on a regression analysis method.

[0009] The static geological reserves of the complex gas reservoir are evaluated based on the dynamic relationship and the dynamic reserves of the complex gas reservoir.

[0010] The gas-bearing area and the gas-water interface of the gas reservoir are inversely evaluated based on the static geological reserves and the volumetric method.

[0011] The water volume is evaluated based on the gas-bearing area and the gas-water interface of the gas reservoir by using the volumetric method.

[0012] The water multiple is obtained based on the relationship between the water volume and the water multiple.

[0013] Further, the process of determining the dynamic relationship between the dynamic reserves and the static geological reserves of the completely developed gas reservoir based on the statistical induction method comprises the following steps:

[0014] The gas reservoirs of the same type are classified, and the corresponding dynamic reserves and static geological reserves are established in the same coordinate system, and all data points are regressed into a straight line, and the conversion coefficient of the static geological reserves and the dynamic reserves of the gas reservoir is obtained.

[0015] Further, in the process of obtaining the dynamic reserves of the complex gas reservoir with closed and uncertain gas-water interface based on the regression analysis method, linear regression analysis method and nonlinear regression analysis method are used according to the linear relationship and the nonlinear relationship, and the linear regression analysis method comprises the following steps:

[0016] For a gas reservoir with natural water drive, when the cumulative production Gp of gas is produced, the formation pressure decreases by:

[0017] (ΔP=Pi-P);

[0018] At this time, the expansion of gas in the gas reservoir, the expansion of rock and bound water, and the water invasion of natural water area will cause the cumulative effect of the three underground, which is equal to the cumulative gas production of the gas reservoir, and the (P / Z)(1-CeΔP-ω) and Gp are in linear relationship, and the slope of the straight line segment is The intercept of the straight line segment is

[0019] Based on the deformation of the material balance equation of the closed gas reservoir, ((P i / Z i ) / (P / Z)-1) / (Δp) and ((P i / Z i )G p / ΔP(P / Z)) are in linear relationship, and the slope of the straight line segment is The intercept of the straight line segment is C e , the derivative of the slope of the straight line segment is the dynamic reserves G, and the ratio of the intercept to the slope is the dynamic reserves G.

[0020] Wherein, Δp is the formation pressure drop, MPa; p i is the original formation pressure of the gas reservoir, MPa; p is the formation pressure of the gas reservoir at a certain production time, MPa; P / Z is the apparent formation pressure of the gas reservoir under the pressure p, MPa; p i is the original formation pressure of the gas reservoir, MPa; G is the dynamic reserves of the gas reservoir, 108m3 ; p / Z is apparent formation pressure under p i pressure, MPa; ω is water influx related parameter, C e is effective compressibility, MPa-1; Z is gas deviation factor under p and gas reservoir temperature conditions.

[0021] Further, the nonlinear regression analysis method comprises the following steps:

[0022] Approximate linear relationship of closed gas reservoir balance equation based on compressibility as variable:

[0023] C e (p) P i - P ≈ λGp,

[0024] Get

[0025] According to pressure, cumulative production data and natural gas deviation factor, binomial regression method is used to determine parameters,

[0026] Nonlinear regression method is used to determine parameters: Get G;

[0027] Based on closed gas reservoir material balance equation: Get If the original pressure, temperature and natural gas properties of the gas reservoir are known, ZD can be calculated, and then the typical curve can be established. Based on the actual production data, P D - G p A series of data points (G p , P D ) are plotted on the semi-logarithmic curve graph, which are superimposed on the P D - G pD semi-logarithmic typical curve graph;

[0028] Move the data points up and down to align the ordinate axis, and move the data points left and right to fit the curve in the P D - G pD semi-logarithmic typical curve graph corresponding to C D , so as to determine C D , read the fitting points, and then calculate G and C e ;

[0029] Where Δp is the formation pressure drop, MPa; p i is the original formation pressure of the gas reservoir, MPa; p is the formation pressure of the gas reservoir to a certain production time, MPa; P / Z is the apparent formation pressure under p pressure, MPa; pi is the original formation pressure of the gas reservoir, MPa; G is the dynamic reserves of the gas reservoir, 108m 3 ; pi / Zi is the apparent formation pressure under the gas reservoir pressure, MPa; ω is the water invasion related parameter, i Ce is the effective compressibility coefficient, MPa-1; Z is the gas deviation factor under the conditions of p and the gas reservoir temperature; C D is dimensionless, C D = C e p i ; Z D is dimensionless, G pD is the ratio of the cumulative gas production to the true geological reserves,

[0030] Further, the process for evaluating the static geological reserves of the complex gas reservoir based on the dynamic relationship and the dynamic reserves of the complex gas reservoir is:

[0031] According to the evaluated dynamic reserves G of the complex gas reservoir and the reserves conversion coefficient Gz, the static geological reserves Gc of the complex gas reservoir is calculated:

[0032] G c = G×G z = 1.0394G.

[0033] Further, the process for inversely evaluating the gas-bearing area and the gas-water interface of the gas reservoir based on the static geological reserves and the volumetric method is:

[0034] The volumetric method is used to calculate the geological reserves of the gas reservoir for the static reserves:

[0035] G c = 0.01A g hФS gi / B gi ;

[0036] The effective thickness h of the gas reservoir is obtained by using the well point area weighting method; the effective porosity Ф of the gas reservoir is obtained by using the well point area weighting method; the gas saturation S gi is obtained by using the well point area weighting method;

[0037] The original natural gas volume coefficient B gi is obtained by using the formula B gi = (P sc × T × Z i ) / (T sC × P i );

[0038] ​Wherein, the ground standard temperature Tsc is 293.15K (20℃), and the pressure Psc is 0.101MPa; the original gas reservoir formation pressure P and temperature T are converted by using the measured or borrowed pressure gradient and temperature gradient of the adjacent area i , the gas deviation factor Z i The single well PVT experimental analysis result is used;

[0039] The gas-bearing area Ag is:

[0040]

[0041] Wherein, h is the effective thickness, m; Ф is the effective porosity; S gi is the original gas saturation of the gas reservoir; B gi is the volume coefficient of the gas under the pressure p i ; G c is the geological reserves of the gas reservoir, 108m 3 ; G is the dynamic reserves of the gas reservoir, 108m 3 ;

[0042] According to the gas-bearing area Ag and the gas reservoir structure contour map, the gas-bearing outer boundary elevation, i.e. the gas-water interface elevation hw is inferred.

[0043] Further, the process of evaluating the water volume based on the gas-bearing area and the gas-water interface of the gas reservoir by using the volume method is:

[0044] The water volume is evaluated by using the volume method:

[0045] V w =100A w hФS wi ;

[0046] V w =100(S-A g )hФ;

[0047] Wherein: the water area A w =S-A g (km 2 ); the effective thickness h is obtained by using the effective thickness contour area weighting method; the effective porosity Ф is obtained by using the porosity calculated by logging and the corresponding effective thickness for thickness weighting; the water saturation S wi is 100%;

[0048] The process of obtaining the water multiple based on the relationship between the water volume and the water multiple is:

[0049]

[0050] Wherein, n is the water multiple; V w is the water volume, 104 m 3 ;B gi is the volume factor of gas under p i ressure; G c is the geological reserves of gas reservoir, 108m 3 .

[0051] A system for determining the water volume multiple of a gas reservoir development, comprising:

[0052] A dynamic relationship module for determining the dynamic relationship between the dynamic reserves and the static geological reserves of a completely developed gas reservoir based on statistical induction;

[0053] A dynamic reserves module for obtaining the dynamic reserves of a complex gas reservoir with uncertain gas-water interface based on regression analysis method;

[0054] A static geological reserves module for evaluating the static geological reserves of a complex gas reservoir based on the dynamic relationship and the dynamic reserves of the complex gas reservoir;

[0055] An evaluation module for evaluating the gas-bearing area and the gas-water interface of a gas reservoir based on the static geological reserves and the volumetric method;

[0056] A water volume module for evaluating the water volume based on the gas-bearing area and the gas-water interface of a gas reservoir using the volumetric method;

[0057] A water volume multiple module for obtaining the water volume multiple based on the relationship between the water volume and the water volume multiple.

[0058] A computer device comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor implements the steps of a method for determining the water volume multiple of a gas reservoir development when executing the computer program.

[0059] A computer readable storage medium storing a computer program, wherein the computer program implements the steps of a method for determining the water volume multiple of a gas reservoir development when executed by a processor.

[0060] Compared with the prior art, the present application has the following beneficial technical effects:

[0061] The present invention provides a method, system, equipment and medium for determining the water body multiple of gas reservoir development, comprising the following steps: determining the dynamic relationship between the dynamic reserves and the static geological reserves of a fully developed gas reservoir based on a statistical induction method; obtaining the dynamic reserves of a closed complex gas reservoir with an uncertain gas-water interface based on a regression analysis method; evaluating the static geological reserves of the complex gas reservoir based on the dynamic relationship and the dynamic reserves of the complex gas reservoir; inversely evaluating the gas-bearing area and the gas-water interface of the gas reservoir based on the static geological reserves and the volumetric method; and evaluating the water body based on the gas-bearing area and the gas-water interface of the gas reservoir using the volumetric method. Volume; the water body multiple is obtained based on the relationship between the water body volume and the water body multiple; the present invention is based on the dynamic relationship between the dynamic reserves and static geological reserves of a fully developed gas reservoir, and obtains the conversion coefficient between the static geological reserves and the dynamic reserves of the gas reservoir. According to the dynamic reserves and conversion coefficient of the evaluated complex gas reservoir, the static geological reserves of the complex gas reservoir are calculated, and then the volumetric method is used to reversely evaluate the gas-water interface and the water body volume, and finally the water body multiple of the gas reservoir is evaluated; the present application uses the dynamic method to reversely evaluate the unknown gas-water interface and water body multiple, and provide guidance for water prevention and control of gas reservoirs. BRIEF DESCRIPTION OF THE DRAWINGS

[0062] Figure 1 This is a flow chart of a method for determining the water body multiple for gas reservoir development according to the present invention;

[0063] Figure 2 A graph showing the relationship between the static geological reserves and the dynamic reserves of a gas reservoir in an embodiment of the present invention;

[0064] Figure 3 Schematic diagram of the top surface structure of a complex gas reservoir in an embodiment of the present invention;

[0065] Figure 4 Schematic diagram of another complex gas reservoir top surface structure in an embodiment of the present invention;

[0066] Figure 5 This is a schematic diagram of the K plane of a closed gas reservoir in a basin in western China according to an embodiment of the present invention;

[0067] Figure 6 This is a dynamic reserve evaluation diagram of the K gas reservoir using the p / Z material balance method in an embodiment of the present invention;

[0068] Figure 7 This is a dynamic reserve evaluation diagram of the K gas reservoir using the semi-logarithmic nonlinear regression method according to an embodiment of the present invention;

[0069] Figure 8 Schematic diagram of the K plane of a closed gas reservoir in a basin in western China according to an embodiment of the present invention;

[0070] Figure 9 Schematic diagram of the cross section of the K gas reservoir in an embodiment of the present invention. DETAILED DESCRIPTION

[0071] The application will be described in further detail below with reference to the drawings and embodiments. The description is an explanation of the application and is not a limitation.

[0072] For those skilled in the technical field, the technical solutions in the embodiments of the application will be described clearly and completely below with reference to the drawings in the embodiments of the application. Obviously, the described embodiments are only a part of the embodiments of the application, rather than all the embodiments. Based on the embodiments in the application, all other embodiments obtained by those skilled in the art without creative labor should fall within the scope of protection of the application.

[0073] It should be noted that the terms "first", "second", and the like in the specification of the application and the above-described drawings are used to distinguish similar objects, and do not necessarily indicate a specific order or a chronological sequence. It should be understood that the data thus used can be interchanged under appropriate circumstances, so that the embodiments of the application described herein can be implemented in an order other than that illustrated or described herein. In addition, the terms "include" and "have" and any variations thereof are intended to cover non-exclusive inclusion, for example, a process, method, system, product, or device including a series of steps or units does not necessarily have to be limited to the clearly listed steps or units, but can include other steps or units not clearly listed or inherent to the process, method, product, or device.

[0074] The application provides a method for determining water body multiple of gas reservoir development, as shown in Figure 1 The method comprises the following steps:

[0075] Determine the dynamic relationship between dynamic reserves and static geological reserves of a completely developed gas reservoir based on statistical induction method;

[0076] Obtain dynamic reserves of a complex gas reservoir with uncertain gas-water interface based on regression analysis method;

[0077] Evaluate the static geological reserves of the complex gas reservoir based on the dynamic relationship and the dynamic reserves of the complex gas reservoir;

[0078] Reverse evaluate the gas-bearing area and the gas-water interface of the gas reservoir based on the static geological reserves and the volumetric method;

[0079] Evaluate the water body volume based on the gas-bearing area and the gas-water interface of the gas reservoir using the volumetric method;

[0080] Obtain the water body multiple based on the relationship between the water body volume and the water body multiple.

[0081] Preferably, the process of determining the dynamic relationship between dynamic reserves and static geological reserves of a completely developed gas reservoir based on statistical induction method comprises the following steps:

[0082] The gas reservoirs of the same type are classified, the dynamic reserves and the static geological reserves of the classified gas reservoirs are established in the same coordinate system, all data points are regressed into a straight line, and a conversion coefficient of the static geological reserves and the dynamic reserves of the gas reservoir is obtained.

[0083] Preferably, in the process of obtaining the dynamic reserves of the complex gas reservoir with closed and uncertain gas-water interface based on the regression analysis method, the linear regression analysis method and the nonlinear regression analysis method are used according to the linear relationship and the nonlinear relationship, and the linear regression analysis method comprises the following steps:

[0084] For a gas reservoir with natural water drive, when the cumulative production Gp of gas is produced, the formation pressure decreases by:

[0085] (ΔP=Pi-P);

[0086] At this time, the expansion of gas in the gas reservoir, the expansion of rock and bound water and the water invasion of natural water area will occur, and the cumulative effect of the three in the ground is equal to the cumulative gas production in the ground of the gas reservoir, so that (P / Z)(1-CeΔP-ω) and Gp are in linear relationship, the slope of the straight line segment is The intercept of the straight line segment is

[0087] Based on the deformation of the material balance equation of the closed gas reservoir, ((P i / Z i ) / (P / Z)-1) / (Δp) and ((P i / Z i )G p / ΔP(P / Z)) are in linear relationship, the slope of the straight line segment is The intercept of the straight line segment is C e , the derivative of the slope of the straight line segment is the dynamic reserve G, and the ratio of the intercept to the slope is the dynamic reserve G.

[0088] Wherein, Δp is the formation pressure drop, MPa; p i is the original formation pressure of the gas reservoir, MPa; p is the formation pressure of the gas reservoir at a certain production time, MPa; P / Z is the apparent formation pressure of the gas reservoir under the pressure p, MPa; p i is the original formation pressure of the gas reservoir, MPa; G is the dynamic reserve of the gas reservoir, 108m 3 ; pi / Zi is the apparent formation pressure of the gas reservoir under the pressure p i , MPa; ω is a water invasion related parameter, C e is the effective compression coefficient, MPa-1; Z is the gas deviation factor under the conditions of p and the temperature of the gas reservoir.

[0089] Preferably, the nonlinear regression analysis method comprises the following steps:

[0090] The approximate linear relationship of the closed gas reservoir balance equation based on the compressibility coefficient as a variable:

[0091] C e (p)P i -P≈λGP,

[0092] get

[0093] Based on the pressure, cumulative production data and natural gas deviation coefficient, the binomial regression method is used to determine the parameters.

[0094] The nonlinear regression method was used to determine the parameters: Get G;

[0095] Based on the material balance equation of closed gas reservoir: get If the original pressure, temperature and natural gas properties of the gas reservoir are known, ZD can be calculated and then a typical curve can be established. Based on actual production data, D —G p Plot a series of data points on a semi-logarithmic graph (G p , P D ), stack it on P D —G pD On the semi-logarithmic typical curve plate;

[0096] Move the data points up and down to align the vertical axis, and move the data points left and right to align them with P D —G pD A C in the semi-logarithmic typical curve D The corresponding curve is fitted to determine C D , read the fitting points, and then calculate G and C e ;

[0097] Where Δp is the formation pressure drop, MPa; p i is the original formation pressure of the gas reservoir, MPa; p is the formation pressure of the gas reservoir at a certain production time, MPa; P / Z is the apparent formation pressure under the gas reservoir p pressure, MPa; p i is the original formation pressure of the gas reservoir, MPa; G is the dynamic reserves of the gas reservoir, 108m 3 ; pi / Zi is gas reservoir p i Apparent formation pressure under pressure, MPa; ω is a water invasion related parameter, Ce is the effective compression coefficient, MPa-1; Z is the gas deviation coefficient under the conditions of p and gas reservoir temperature; CD dimensionless, C D = C e p i ; Z D dimensionless, G pD is the ratio of cumulative gas production to true geological reserves,

[0098] Preferably, the process of evaluating the static geological reserves of the complex gas reservoir based on the dynamic relationship and the dynamic reserves of the complex gas reservoir is as follows:

[0099] According to the evaluated dynamic reserves G of the complex gas reservoir and the reserves conversion coefficient Gz, the static geological reserves Gc of the complex gas reservoir is calculated:

[0100] G c = G x G z = 1.0394G.

[0101] Preferably, the process of inversely evaluating the gas-bearing area and the gas-water interface of the gas reservoir based on the static geological reserves and the volumetric method is as follows:

[0102] The volumetric method is used to calculate the geological reserves of the gas reservoir for the static reserves:

[0103] G c = 0.01A g hΦS gi / B gi ;

[0104] The effective thickness h of the gas reservoir is obtained by the well point area weighting method; the effective porosity Φ of the gas reservoir is obtained by the well point area weighting method; the gas saturation S gi is obtained by the well point area weighting method;

[0105] The original natural gas volume coefficient B gi is obtained by the formula B gi = (P sc x T x Z i ) / (T sc x P i );

[0106] Wherein, the ground standard temperature Tsc is 293.15K (20℃), and the pressure Psc is 0.101MPa; the measured or borrowed pressure gradient and temperature gradient of the adjacent area are used to convert the original gas reservoir formation pressure P i and the temperature T; the gas deviation coefficient Z i is obtained by the single well PVT experimental analysis result;

[0107] The gas-bearing area Ag is:

[0108]

[0109] wherein h is effective thickness, m; Φ is effective porosity; S gi is the original gas saturation of the gas reservoir; B gi is the volume coefficient of the gas under p i ressure; G c is the geological reserves of the gas reservoir, 108m 3 ; G is the dynamic reserves of the gas reservoir, 108m 3 .

[0110] According to the gas-bearing area Ag and the gas reservoir structure contour map, the gas-bearing outer boundary elevation, i.e. the gas-water interface elevation hw, is inferred.

[0111] Preferably, the process of evaluating the water body volume based on the gas-bearing area of the gas reservoir and the gas-water interface using the volumetric method is as follows:

[0112] Evaluating the water body volume using the volumetric method:

[0113] V w =100A w hΦS wi .

[0114] V w =100(S-A g )hΦ.

[0115] wherein: the water area A w =S-A g (km 2 ); the effective thickness h is obtained by using the effective thickness contour area weighting method; the effective porosity Φ is obtained by using the porosity calculated by logging and the corresponding effective thickness for thickness weighting; the water saturation S wi is 100%;

[0116] The process of obtaining the water body multiple based on the relationship between the water body volume and the water body multiple is as follows:

[0117]

[0118] wherein n is the water body multiple; V w is the water body volume, 10 4 m 3 ; B gi is the volume coefficient of the gas under p i ressure; G c is the geological reserves of the gas reservoir, 108m 3 .

[0119] An embodiment provided by the present application is as follows:

[0120] Step 1: Determine the dynamic relationship between the dynamic reserves and the static geological reserves of the fully developed gas reservoirs by statistical induction:

[0121] Statistically induce the dynamic reserves and the static geological reserves of the five same type gas reservoirs in the jurisdiction, as shown in Table 1:

[0122] Table 1 Reserve statistics table

[0123]

[0124] Draw the relationship curve between the static geological reserves and the dynamic reserves of the gas reservoirs in the rectangular coordinate system, as shown in Figure 2 The data points are regressed into a straight line, and the correlation is good.

[0125] According to the regression formula, the conversion coefficient Gz of the static geological reserves and the dynamic reserves of the gas reservoirs is 1.0394.

[0126] Step 2: Calculate the dynamic reserves of the complex gas reservoirs with closed and uncertain gas-water interface:

[0127] Calculation method 1: linear regression analysis

[0128] Pressure drop method: In addition to considering the elastic driving energy of the gas, the pressure drop method also needs to consider the expansion energy of the rock and the influence of water invasion. For a gas reservoir with natural water drive, when the cumulative production Gp of gas is produced after production, the formation pressure drops (ΔP=Pi-P). At this time, the expansion of the gas in the gas reservoir, the expansion of the rock and the bound water, and the water invasion of the natural water region will cause the cumulative effect of the three underground, which is equal to the cumulative gas production of the gas reservoir, that is, (P / Z)(1-CeΔP-ω) and Gp are linearly related, and the slope of the straight line segment is The intercept of the straight line segment is The ratio of the intercept to the slope is the dynamic reserves G;

[0129] Roach analysis method: Roach transformed the material balance equation of the closed gas reservoir in 1981, that is, ((Pi / Zi) / (P / Z)-1) / (ΔP) and ((Pi / Zi)Gp / ΔP(P / Z)) are linearly related, and the slope of the straight line segment is The intercept of the straight line segment is Ce, that is, the derivative of the slope of the straight line segment is the dynamic reserves G. This method is simple and convenient, and not only can calculate the dynamic reserves, but also can calculate the effective compressibility coefficient.

[0130] Calculation method 2: nonlinear regression analysis

[0131] Gonzales binomial method, Gonzales in 2008 to the compressibility factor as a variable closed gas reservoir balance equation (Fetkovich, 1998), proposed the approximate linear relationship Ce (p) Pi-P≈λGP, namely According to the pressure, cumulative production data and natural gas deviation coefficient, using binomial regression method to determine the parameters, Using nonlinear regression regression method to determine the parameters, namely Further calculation of G.

[0132] Semi-log nonlinear regression method, Ambastha in 1991 to the closed gas reservoir material balance equation (Bourgoyne, 1972) dimensionless, That is If the original pressure of gas reservoir, temperature and nature gas properties are known, ZD can be calculated, and then the typical curve can be established. Based on the actual production data, in P D —G p Semi-log curve chart of a series of data points (G p , P D ) is drawn, which is superimposed on P D —G pD Semi-log typical curve chart; up and down the data points, so that the ordinate axis is aligned, and then left and right move the data points, so that it is with P D —G pD Semi-log typical curve chart of a certain C D corresponding curve fitting, so as to determine C D , read the fitting point, and then calculate G and C e .

[0133] Step 3: evaluation of complex gas reservoir static reserves;

[0134] According to the evaluation of complex gas reservoir dynamic reserves G and reserves conversion coefficient for Gz, the static reserves Gc of complex gas reservoir is calculated, namely:

[0135] G c =G×G z =1.0394G;

[0136] Step 4: according to the volume method to evaluate the gas area and gas water interface of gas reservoir;

[0137] The top structure map of complex gas reservoir is shown in Figure 3 , the total area is Skm 2 , it is a closed gas reservoir, and the current gas water interface is not clear.

[0138] According to the "Calculation Specification of Oil and Gas Reserves" (DZ / T 0217-2020), the volumetric method is used to calculate the geological reserves of gas reservoirs for static reserves:

[0139] G c = 0.01A g hΦS gi ; gi ;

[0140] The effective thickness h of the gas reservoir is obtained by the well point area weighting method; the effective porosity Φ of the gas reservoir is obtained by the well point area weighting method; the gas saturation S gi is obtained by the well point area weighting method;

[0141] The original natural gas volume coefficient B gi is obtained by the formula B gi = (P sc × T × Z i ) / (T sc × P i );

[0142] Wherein, the ground standard temperature Tscis 293.15K (20℃), and the pressure Pscis 0.101MPa; the measured or borrowed pressure gradient and temperature gradient of the adjacent area are used to convert the original gas reservoir formation pressure P i and temperature T; the gas deviation coefficient Z i is obtained by single well PVT experimental analysis results;

[0143] The gas-bearing area Ag is:

[0144]

[0145] Wherein, h is the effective thickness, m; Φ is the effective porosity; S gi is the original gas saturation of the gas reservoir; B gi is the volume coefficient of the gas under the pressure p i ; G c is the geological reserves of the gas reservoir, 108m 3 ; G is the dynamic reserves of the gas reservoir, 108m 3 ;

[0146] According to the gas-bearing area Ag and the gas reservoir structure contour map, the gas-bearing outer boundary elevation, i.e. the gas-water interface elevation hw, is inferred, as shown in Figure 4 .

[0147] Step 5: Evaluate the volume of the water body using the volumetric method:

[0148] V w = 100A w hΦS wi ;

[0149] V w =100(SA g )hФ;

[0150] Including: water area A w =SA g (km 2 ); the effective thickness h is obtained by using the effective thickness contour area trade-off method; the effective porosity Φ is obtained by weighting the porosity calculated by well logging and the corresponding effective thickness; the water saturation S wi is 100%.

[0151] Step 6: Evaluate the water volume multiple of the gas reservoir:

[0152]

[0153] Where G is the dynamic reserves of the gas reservoir, 108m3; Gc is the geological reserves of the gas reservoir, 108m3; Gz is the reserve conversion coefficient; Gp is ​​the cumulative gas production, 104m3; pi is the original formation pressure of the gas reservoir, MPa; p is the formation pressure of the gas reservoir at a certain production time, MPa; Δp is the formation pressure drop, MPa; Ce is the effective compression coefficient, MPa-1; pi / Zi is the apparent formation pressure at the pi pressure of the gas reservoir, MPa; P / Z is the apparent formation pressure at the p pressure of the gas reservoir, MPa; ω is a water invasion related parameter, Zi is the gas deviation coefficient under the conditions of pi and gas reservoir temperature; Z is the gas deviation coefficient under the conditions of p and gas reservoir temperature; P D is the dimensionless apparent formation pressure, C D is dimensionless, C D =C e p i ZD is dimensionless, GpD is the ratio of cumulative gas production to actual geological reserves. S is the gas reservoir area, km 2 ; Ag is the gas-bearing area of ​​the gas reservoir, km 2 ; h is the effective thickness, m; Ф is the effective porosity; Sgi is the original gas saturation of the gas reservoir; Bgi is the volume coefficient of gas at pi pressure; Vw is the water volume, 10 4 m 3 ; Aw is the water area, km 2 ; n is the water volume multiple.

[0154] Example 1:

[0155] An ultra-deep and ultra-high pressure water-sealed gas reservoir K in a basin in western China, such as Figure 5 As shown, the total area is 40.88km 2The structure is an east-west short-axis anticline. Seven wells have been drilled along the long axis of the structure without encountering any water layer. All wells have been tested and put into production. The reservoir is the Cretaceous Bashikiqik Formation. The well point area trade-off method is used to calculate the effective reservoir thickness to be 84.67m, the effective porosity to be 6%, the gas saturation to be 65%, the original formation pressure to be 109.17MPa, the pressure coefficient to be 1.7, the original natural gas volume coefficient to be 0.00229, and the rock compressibility coefficient to be 0.001MPa. -1 , the formation water compressibility coefficient is 0.0004MPa -1 , the formation water volume coefficient is 1.0.

[0156] Table 2 Parameters related to dynamic reserve evaluation of K gas reservoir

[0157] Year Formation pressure / MPa Deviation coefficient Cumulative gas production / 10 8 m 3 ]]> Natural gas compressibility factor / MPa -1 ]] 2009 109.17 1.744 0.00 0.00184 2016 108.88 1.741 0.49 0.00192 2017 106.60 1.718 8.05 0.00255 2018 105.02 1.703 11.89 0.00301 2019 100.08 1.654 22.66 0.00448 2020 95.61 1.612 32.34 0.00581 2021 87.40 1.537 44.18 0.00813

[0158] Evaluate the dynamic reserves of K gas reservoir based on historical production data and formation pressure change trends

[0159] The dynamic reserves of the K gas reservoir were evaluated using the commonly used pressure drop method, Roach analysis, Gonzales binomial method, semi-logarithmic nonlinear regression, and multi-well RTA method. The curve drawn using the Roach analysis method lacked linearity, making it impossible to calculate dynamic reserves. The Gonzales binomial method also underestimated the value and did not align with the current production figures, which show a 21.77 MPa drop in formation pressure and a cumulative gas production of 4.4 billion cubic meters.

[0160] Table 3 K gas reservoir dynamic reserves calculation results

[0161]

[0162] Figure 6 The K gas reservoir dynamic reserve evaluation diagram is commonly used to evaluate the pressure drop method. According to the known rock and formation water compressibility coefficient and natural gas deviation coefficient, the K gas reservoir p / Z (1-CeΔp) and G p It is a linear relationship, and the ratio of the intercept of the straight line segment to the slope of the straight line segment is the dynamic reserves of the K gas reservoir, 34.8 billion cubic meters; Figure 7 It is a semi-logarithmic nonlinear regression. According to the known gas reservoir formation pressure and natural gas deviation coefficient, the K gas reservoir P is plotted. D —G p Semi-logarithmic curve and P D —G pD Two plates of semi-logarithmic typical curve are superimposed, and the fitting points are read to determine G p G under these conditions pD, and then the dynamic reserves of K gas reservoir are calculated as 378 billion cubic meters; in the multi-well RTA analysis method, the most typical Blasingame production decline analysis curve chart is used to fit and evaluate the dynamic reserves of K gas reservoir as 399 billion cubic meters, and finally the arithmetic average is used to determine the dynamic reserves of K gas reservoir as 375 billion cubic meters.

[0163] According to the dynamic reserves G of K gas reservoir and the reserves conversion coefficient Gz, the static geological reserves Gc of K gas reservoir are calculated, that is:

[0164] G c = G x G z = 1.0394G = 1.0394 x 375 = 389.8 x 10 8 m 3

[0165] According to the volume method, the gas-bearing area Ag and the gas-water interface hw of K gas reservoir are inversely evaluated

[0166] According to the calculated static geological reserves 389.8 billion cubic meters of K gas reservoir, the gas-bearing area Ag of K gas reservoir is inversely evaluated by using the volume method:

[0167]

[0168] According to the calculated gas-bearing area Ag and the gas reservoir structure contour map, it is inferred that the gas-bearing outer boundary elevation of K gas reservoir is-5036m, that is, the gas-water interface elevation hw is-4936m, as shown in Figure 8 .

[0169] The volume of water body of K gas reservoir is evaluated by using the volume method:

[0170] V w = 100A w hΦS wi

[0171] That is, V w = 100 (S-A g ) hΦ = 100 x (40.88-27.03) x 97.37 x 0.05 = 6742.87 x 10 4 m 3

[0172] The water body multiple of K gas reservoir is evaluated, as shown in Figure 9 .

[0173]

[0174] The present application provides a kind of gas reservoir development water body multiple determination system, comprising:

[0175] Dynamic relationship module, for determining the dynamic relationship between dynamic reserves and static geological reserves of completely developed gas reservoir based on statistical induction method;

[0176] A dynamic reserve module is configured to obtain the dynamic reserve of the complex gas reservoir with closed and uncertain gas-water interface based on a regression analysis method.

[0177] A static geological reserve module is configured to evaluate the static geological reserve of the complex gas reservoir based on the dynamic relationship and the dynamic reserve of the complex gas reservoir.

[0178] An evaluation module is configured to evaluate the gas-bearing area and the gas-water interface of the gas reservoir based on the static geological reserve and the volumetric method.

[0179] A water volume module is configured to evaluate the water volume based on the gas-bearing area and the gas-water interface of the gas reservoir by using the volumetric method.

[0180] A water multiple module is configured to obtain the water multiple based on the relationship between the water volume and the water multiple.

[0181] In another embodiment of the present application, a computer device is provided, which comprises a processor and a memory, the memory is configured to store a computer program, the computer program comprises program instructions, and the processor is configured to execute the program instructions stored in the computer storage medium. The processor can be a central processing unit (CPU), and can also be other general-purpose processors, digital signal processors (DSP), application specific integrated circuits (ASIC), field-programmable gate arrays (FPGA) or other programmable logic devices, discrete gate or transistor logic devices, discrete hardware components, etc. The processor is the computing core and control core of the terminal, and is suitable for implementing one or more instructions, and is specifically suitable for loading and executing one or more instructions in the computer storage medium to implement a corresponding method flow or a corresponding function. The processor in the embodiment of the present application can be used for the operation of the method for determining the water multiple of the gas reservoir development.

[0182] In still another embodiment of the present application, the present application also provides a storage medium, specifically a computer readable storage medium (Memory), which is a memory device in a computer device, used for storing programs and data. It can be understood that the computer readable storage medium here can include the built-in storage medium in the computer device, and of course can also include the extended storage medium supported by the computer device. The computer readable storage medium provides a storage space, which stores the operating system of the terminal. Moreover, one or more instructions suitable for being loaded and executed by the processor are also stored in the storage space, and these instructions can be one or more computer programs (including program codes). It should be noted that the computer readable storage medium here can be a high-speed RAM memory, or a non-volatile memory such as at least one disk memory. One or more instructions stored in the computer readable storage medium can be loaded and executed by the processor to realize the corresponding steps of the method for determining the water multiple of a gas reservoir in the above embodiment.

[0183] Those skilled in the art should understand that the embodiments of the present application can be provided as a method, a system, or a computer program product. Therefore, the present application can take the form of an entirely hardware embodiment, an entirely software embodiment, or an embodiment combining software and hardware aspects. Moreover, the present application can take the form of a computer program product implemented on one or more computer-usable storage media (including, but not limited to, disk storage, CD-ROMs, optical storage, etc.) containing computer-usable program code.

[0184] The present application is described with reference to the flowcharts and / or block diagrams of the method, device (system), and computer program product according to the embodiments of the present application. It should be understood that each flow and / or block in the flowcharts and / or block diagrams, and the combination of the flows and / or blocks in the flowcharts 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, a special-purpose computer, an embedded processor, or other programmable data processing device to produce a machine, so that the instructions executed by the processor of the computer or other programmable data processing device produce a device implemented in the flowcharts and / or block diagrams. Figure 1 one or more flows and / or blocks Figure 1 an apparatus with the function specified in one or more flows or blocks.

[0185] These computer program instructions can also be stored in a computer readable memory capable of directing the computer or other programmable data processing device to work in a specific manner, so that the instructions stored in the computer readable memory produce a manufactured product including instruction apparatus, which realizes the flowcharts and / or block diagrams. Figure 1 one or more flows and / or blocksFigure 1 the function specified in the one or more blocks.

[0186] These computer program instructions can also be loaded into computer or other programmable data processing devices, so that a series of operation steps are performed on the computer or other programmable data processing devices to generate computer-implemented processes, thus the instructions executed on the computer or other programmable data processing devices provide a process for implementing the flow Figure 1 the flow or flows and / or blocks Figure 1 the steps of the function specified in the one or more blocks.

[0187] Finally, it should be noted that: the above embodiments are only used to illustrate the technical solutions of the present application, and not to limit them; although the present application has been described in detail with reference to the foregoing embodiments, those skilled in the art should understand: it can still modify the technical solutions recorded in the foregoing embodiments, or make equivalent replacement for part or all of the technical features; and these modifications or replacements do not make the essence of the corresponding technical solutions deviate from the scope of the technical solutions of the embodiments of the present application.

Claims

1. A method for determining the water body multiple of gas reservoir development, characterized in that: The following steps are involved: Determine the dynamic relationship between dynamic reserves and static geological reserves of fully developed gas reservoirs based on statistical induction; The dynamic reserves of closed and complex gas reservoirs with uncertain gas-water interface are obtained based on regression analysis method; Evaluate the static geological reserves of complex gas reservoirs based on dynamic relationships and dynamic reserves of complex gas reservoirs; Inversely evaluate the gas-bearing area and gas-water interface of gas reservoirs based on static geological reserves and volumetric method; The volume of water body is evaluated by volumetric method based on gas-bearing area of ​​gas reservoir and gas-water interface; The water body multiple is obtained based on the relationship between the water body volume and the water body multiple; In the process of obtaining the dynamic reserves of a closed complex gas reservoir with uncertain gas-water interface based on the regression analysis method, a linear regression analysis method and a nonlinear regression analysis method are respectively adopted according to their linear relationship and nonlinear relationship. The linear regression analysis method includes the following steps: For a gas reservoir with natural water drive, when the cumulative production Gp gas volume is put into production, the formation pressure drops to: (ΔP=Pi-P); At this time, it will cause the expansion of gas in the gas reservoir, the expansion of rock and bound water, and the water invasion of natural water. The underground cumulative effect of the three is equal to the underground cumulative gas production of the gas reservoir. It is obtained that (P / Z)(1-CeΔP-ω) is linearly related to Gp, and the slope of the straight line is , the intercept of the straight line segment is , Based on the deformation of the material balance equation of closed gas reservoir, ((P i / Z i ) / (P / Z)-1) / (Δp) and ((P i / Z i )G p / ΔP(P / Z)) is a linear relationship, and the slope of the straight line is , the intercept of the straight line segment is C e , the derivative of the slope of the straight line segment is the dynamic reserve G, and the ratio of the intercept to the slope is the dynamic reserve G; Where Δp is the formation pressure drop, MPa; p i is the original formation pressure of the gas reservoir, MPa; p is the formation pressure of the gas reservoir at a certain production time, MPa; P / Z is the apparent formation pressure under the gas reservoir pressure p, MPa; p i is the original formation pressure of the gas reservoir, MPa; G is the dynamic reserves of the gas reservoir, 108m 3 ; pi / Zi is gas reservoir p i Apparent formation pressure under pressure, MPa; ω is a water invasion related parameter, ; C e is the effective compression coefficient, , MPa-1; Z is the gas deviation coefficient under the conditions of p and gas reservoir temperature; The nonlinear regression analysis method comprises the following steps: The approximate linear relationship of the closed gas reservoir balance equation based on the compressibility coefficient as a variable: C e (p) P i -P≈λGP, get ; Based on the pressure, cumulative production data and natural gas deviation coefficient, the binomial regression method is used to determine the parameters. ; The nonlinear regression method was used to determine the parameters: ; get G; Based on the material balance equation of closed gas reservoir: ,get If the original pressure, temperature and natural gas properties of the gas reservoir are known, ZD can be calculated and then a typical curve can be established. Based on actual production data, D —G p Plot a series of data points on a semi-logarithmic graph (G p , P D ), stack it on P D —G pD On the semi-logarithmic typical curve plate; Move the data points up and down to align the vertical axis, and move the data points left and right to align them with P D —G pD A C in the semi-logarithmic typical curve D The corresponding curve is fitted to determine C D , read the fitting points, and then calculate G and C e ; Where Δp is the formation pressure drop, MPa; p i is the original formation pressure of the gas reservoir, MPa; p is the formation pressure of the gas reservoir at a certain production time, MPa; P / Z is the apparent formation pressure under the gas reservoir pressure p, MPa; p i is the original formation pressure of the gas reservoir, MPa; G is the dynamic reserves of the gas reservoir, 108m 3 ; pi / Zi is gas reservoir p i Apparent formation pressure under pressure, MPa; ω is a water invasion related parameter, ; Ce is the effective compression coefficient, , MPa-1; Z is the gas deviation coefficient under the conditions of p and gas reservoir temperature; C D is dimensionless, ; Z D is dimensionless, ; G pD is the ratio of cumulative gas production to actual geological reserves, .

2. The method for determining the water body multiple of gas reservoir development according to claim 1, characterized in that: The process of determining the dynamic relationship between the dynamic reserves and static geological reserves of a fully developed gas reservoir based on the statistical induction method is as follows: Gas reservoirs of the same type are classified, and their corresponding dynamic reserves and static geological reserves are established in the same coordinate system. All data points are regressed into a straight line, and the conversion coefficient between static geological reserves and dynamic reserves of gas reservoirs is obtained.

3. The method for determining the water body multiple of gas reservoir development according to claim 1, characterized in that: The process of evaluating the static geological reserves of complex gas reservoirs based on the dynamic relationship and the dynamic reserves of complex gas reservoirs is as follows: According to the evaluated dynamic reserves G of the complex gas reservoir and the reserve conversion coefficient Gz, the static geological reserves Gc of the complex gas reservoir are calculated: 。 4. The method for determining the water body multiple of gas reservoir development according to claim 1, characterized in that: The process of inversely evaluating the gas-bearing area and gas-water interface of a gas reservoir based on static geological reserves and volumetric method is as follows: For static reserves, the volumetric method is used to calculate the geological reserves of gas reservoirs: ； The effective thickness h of the gas reservoir is calculated by the well point area trade-off method; the effective porosity Φ of the gas reservoir is calculated by the well point area trade-off method; the gas saturation S gi It is obtained by using the well point area trade-off method; Original natural gas volume coefficient B gi Using the formula ; The ground standard temperature Tsc is 293.15K (20℃), and the pressure Psc is 0.101MPa. The original gas reservoir formation pressure is converted by using the measured pressure gradient and temperature gradient or the adjacent area. , temperature T; gas deviation coefficient The results of single-well PVT experiments were used to analyze the results; The gas-containing area Ag is: ； Where h is the effective thickness, m; Ф is the effective porosity; S gi is the original gas saturation of the gas reservoir; B gi For p i Volume coefficient of gas under pressure; G c The geological reserves of the gas reservoir are 108m 3 ; G is the dynamic reserves of gas reservoir, 108m 3 ; Based on the gas-bearing area Ag and the contour map of the gas reservoir structure, the altitude of the gas-bearing outer boundary, that is, the altitude of the gas-water interface hw, is inferred.

5. The method for determining the water body multiple of gas reservoir development according to claim 1, characterized in that: The process of evaluating the water volume using the volumetric method based on the gas-bearing area of ​​the gas reservoir and the gas-water interface is as follows: Evaluate the volume of a water body using the volumetric method: ； ； Including: water area =S- (km 2 The effective thickness h is calculated by using the effective thickness contour area trade-off method; the effective porosity Φ is calculated by using the porosity calculated by well logging and the corresponding effective thickness for thickness weighting; the water saturation S wi is 100%; The process of obtaining the water body multiple based on the relationship between the water body volume and the water body multiple is as follows: ； Where n is the water volume multiple; V w is the volume of water, 10 4 m 3 ; B gi For p i Volume coefficient of gas under pressure; G c The geological reserves of the gas reservoir are 108m 3 .

6. A system for determining the water body multiple of gas reservoir development, characterized in that: A method for determining a water body multiple for gas reservoir development according to any one of claims 1 to 5, comprising: Dynamic relationship module, used to determine the dynamic relationship between dynamic reserves and static geological reserves of fully developed gas reservoirs based on statistical induction method; Dynamic reserves module, used to obtain dynamic reserves of complex gas reservoirs with closed and uncertain gas-water interface based on regression analysis method; Static geological reserves module, used to evaluate the static geological reserves of complex gas reservoirs based on dynamic relationships and dynamic reserves of complex gas reservoirs; Evaluation module, used to reversely evaluate the gas-bearing area and gas-water interface of gas reservoirs based on static geological reserves and volumetric method; Water volume module, used to evaluate water volume using volumetric method based on gas reservoir area and gas-water interface; Water body multiple module, used to obtain water body multiple based on the relationship between water body volume and water body multiple; In the process of obtaining the dynamic reserves of a closed complex gas reservoir with uncertain gas-water interface based on the regression analysis method, a linear regression analysis method and a nonlinear regression analysis method are respectively adopted according to their linear relationship and nonlinear relationship. The linear regression analysis method includes the following steps: For a gas reservoir with natural water drive, when the cumulative production Gp gas volume is put into production, the formation pressure drops to: (ΔP=Pi-P); At this time, it will cause the expansion of gas in the gas reservoir, the expansion of rock and bound water, and the water invasion of natural water. The underground cumulative effect of the three is equal to the underground cumulative gas production of the gas reservoir. It is obtained that (P / Z)(1-CeΔP-ω) is linearly related to Gp, and the slope of the straight line is , the intercept of the straight line segment is , Based on the deformation of the material balance equation of closed gas reservoir, ((P i / Z i ) / (P / Z)-1) / (Δp) and ((P i / Z i )G p / ΔP(P / Z)) is a linear relationship, and the slope of the straight line is , the intercept of the straight line segment is C e , the derivative of the slope of the straight line segment is the dynamic reserve G, and the ratio of the intercept to the slope is the dynamic reserve G; Where Δp is the formation pressure drop, MPa; p i is the original formation pressure of the gas reservoir, MPa; p is the formation pressure of the gas reservoir at a certain production time, MPa; P / Z is the apparent formation pressure under the gas reservoir pressure p, MPa; p i is the original formation pressure of the gas reservoir, MPa; G is the dynamic reserves of the gas reservoir, 108m 3 ; pi / Zi is gas reservoir p i Apparent formation pressure under pressure, MPa; ω is a water invasion related parameter, ; C e is the effective compression coefficient, , MPa-1; Z is the gas deviation coefficient under the conditions of p and gas reservoir temperature; The nonlinear regression analysis method comprises the following steps: The approximate linear relationship of the closed gas reservoir balance equation based on the compressibility coefficient as a variable: C e (p) P i -P≈λGP, get ; Based on the pressure, cumulative production data and natural gas deviation coefficient, the binomial regression method is used to determine the parameters. ; The nonlinear regression method was used to determine the parameters: ; get G; Based on the material balance equation of closed gas reservoir: ,get If the original pressure, temperature and natural gas properties of the gas reservoir are known, ZD can be calculated and then a typical curve can be established. Based on actual production data, D —G p Plot a series of data points on a semi-logarithmic graph (G p , P D ), stack it on P D —G pD On the semi-logarithmic typical curve plate; Move the data points up and down to align the vertical axis, and move the data points left and right to align them with P D —G pD A C in the semi-logarithmic typical curve D The corresponding curve is fitted to determine C D , read the fitting points, and then calculate G and C e ; Where Δp is the formation pressure drop, MPa; p i is the original formation pressure of the gas reservoir, MPa; p is the formation pressure of the gas reservoir at a certain production time, MPa; P / Z is the apparent formation pressure under the gas reservoir pressure p, MPa; p i is the original formation pressure of the gas reservoir, MPa; G is the dynamic reserves of the gas reservoir, 108m 3 ; pi / Zi is gas reservoir p i Apparent formation pressure under pressure, MPa; ω is a water invasion related parameter, ; Ce is the effective compression coefficient, , MPa-1; Z is the gas deviation coefficient under the conditions of p and gas reservoir temperature; C D is dimensionless, ; Z D is dimensionless, ; G pD is the ratio of cumulative gas production to actual geological reserves, .

7. A computer device comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein: When the processor executes the computer program, the steps of the method for determining the water body multiple for gas reservoir development as described in any one of claims 1 to 5 are implemented.

8. A computer-readable storage medium storing a computer program, characterized in that: When the computer program is executed by a processor, the steps of the method for determining the water body multiple for gas reservoir development as described in any one of claims 1 to 5 are implemented.

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