Method and device for determining gas injection capacity of a condensate gas reservoir and storage medium

Abstract

The application provides a kind of determination condensate gas reservoir injection capacity calculation method, equipment and its storage medium, belongs to natural gas injection production technical field, determination condensate gas reservoir injection capacity calculation method includes: solving condensate gas well productivity equation;Using condensate gas well productivity equation, the condensate gas production corresponding to each production pressure difference is calculated;Using gas state equation, condensate gas production is converted into condensate gas well bottom volume flow rate;Using well bottom volume flow rate equation, condensate gas well bottom volume flow rate is converted into injected gas well bottom volume flow rate;Using gas state equation, injected gas well bottom volume flow rate is converted into injected gas ground standard condition volume flow rate;According to the volume flow rate of injected gas under ground standard condition and corresponding pressure, binomial injection equation of injection gas well is regressed to solve, the injection equation of injection gas well is obtained, and injection capacity is calculated.The method provided by the application can accurately and quickly obtain the injection capacity, and provide help for the economic and efficient development of injection development condensate gas reservoir.

Description

Technical Field

[0001] This invention relates to the field of natural gas injection and production technology, specifically to a method, equipment, and storage medium for calculating the injection capacity of condensate gas reservoirs. Background Technology

[0002] Condensate oil is a very valuable petroleum resource, therefore, improving recoverable reserves and recovery rates is a priority for petroleum workers both domestically and internationally. For high-condensate-oil-gas reservoirs with relatively good reservoir properties, large reserve size, small surface pressure differential, high reverse condensate volume, and insufficient energy from natural water bodies, gas injection and pressure maintenance development are generally adopted to achieve higher condensate oil recovery rates and optimal development results.

[0003] Before condensate gas reservoirs are put into development, development plans need to be studied. Among them, the most important is the study of the reasonable ratio of injection and production wells. Only by accurately grasping the gas production capacity of production wells and the gas injection capacity of injection wells can a reasonable ratio of injection and production wells be scientifically configured to avoid resource waste caused by insufficient or excessive allocation of injection wells, and to more effectively improve the overall development effect of condensate gas reservoirs.

[0004] Currently, there are relatively mature methods for determining the production capacity of gas wells both domestically and internationally. However, there is no systematic calculation method for the injection capacity of gas injection wells. In mining operations, empirical analogy and numerical simulation methods are mainly used for calculation. Among them, the reliability of the calculation results of the analogy method is relatively poor, while the numerical simulation method requires more parameters, has a complex calculation process, and the calculation accuracy is heavily dependent on the reliability of the geological model and fluid parameter model. Summary of the Invention

[0005] To address the issues of large errors in commonly used empirical analogy methods and the reliance on accurate models and extensive simulation calculations in traditional numerical simulation methods, this invention provides a method, equipment, and storage medium for determining the gas injection capacity of condensate gas reservoirs. This method can accurately and quickly obtain the gas injection capacity.

[0006] To achieve the above objectives, the present invention provides a method for determining the injection capacity of a condensate gas reservoir, comprising: solving the condensate gas well production capacity equation, wherein the condensate gas well production capacity equation satisfies the linear relationship of Darcy flow; using the condensate gas well production capacity equation, calculating the condensate gas production corresponding to each production pressure differential; using the gas state equation, converting the condensate gas production corresponding to each production pressure differential into the condensate gas bottom-hole volumetric flow rate under bottom-hole temperature and pressure; using the bottom-hole volumetric flow rate equation, converting the condensate gas bottom-hole volumetric flow rate under the bottom-hole temperature and pressure into the injection gas bottom-hole volumetric flow rate under the same temperature, pressure, and pressure differential; using the gas state equation, converting the injection gas bottom-hole volumetric flow rate under the same temperature, pressure, and pressure differential into the injection gas volumetric flow rate under surface standard conditions; and based on the injection gas volumetric flow rate under surface standard conditions and the corresponding pressure, regressively solving the binomial injection equation of the injection well to obtain the injection equation of the injection well, and calculating the injection capacity.

[0007] In an exemplary embodiment of the present invention, the calculation formula (1) of the bottom hole volume flow rate equation can be as follows:

[0008]

[0009] In equation (1), q w The condensate gas volumetric flow rate under bottom-hole temperature and pressure conditions, 10 4 m 3 μ g ρ is the gas viscosity in the formation, mPa·s; h is the effective thickness of the gas layer, m; K is the effective permeability of the gas layer, μm. 2 ;p e The pressure at the outer boundary is MPa; p w The pressure at the wellbore wall, in MPa; r e r is the distance from the well axis to the outer boundary, in meters (m); w Let be the wellbore radius, in meters (m).

[0010] In an exemplary embodiment of the present invention, the calculation step of solving the condensate gas well productivity equation may include: calculating the condensate gas production corresponding to each operating condition based on the bottom hole pressure, condensate oil production, and natural gas production under different operating conditions, to obtain a condensate gas production set; based on the condensate gas production set and the corresponding bottom hole pressure, using pressure analysis or pressure square analysis, regressively solving the binomial productivity equation; when the production pressure difference of the condensate gas well is less than 0.5 MPa, the influence of non-Darcy flow is ignored in the binomial productivity equation, to obtain a condensate gas well productivity equation that satisfies the linear relationship of Darcy flow.

[0011] In an exemplary embodiment of the present invention, the condensate gas yield can be calculated according to formula (2);

[0012] q tsc =qsc +543.15×(1.03-γ o )q o / 10000 (2)

[0013] In equation (2), q tsc Condensate production under standard ground conditions, 10 4 m 3 ;q sc For natural gas production under standard surface conditions, 10 4 m 3 ;q o The condensate production under standard surface conditions, m 3 ;γ o The value represents the relative density of condensate oil under standard ground conditions.

[0014] In an exemplary embodiment of the present invention, the calculation formula (3) of the pressure square analysis method can be as follows:

[0015] p e 2 -p w 2 =Aq tsc +Bq tsc 2 (3)

[0016] In equation (3), p e The pressure at the outer boundary is MPa; p w Pressure at the wellbore, MPa; A is Darcy flow coefficient; B is non-Darcy flow coefficient.

[0017] In an exemplary embodiment of the present invention, the production pressure differential may be the difference between the pressure at the outer boundary and the pressure at the wellbore, used to determine the severity of non-Darcy flow of gas in the formation.

[0018] In an exemplary embodiment of the present invention, the calculation formula (4) for the gas state equation is as follows:

[0019]

[0020] In equation (4), p sc q represents the standard ground pressure, in MPa. tsc Condensate production under standard ground conditions, 10 4 m 3 T sc Ground standard temperature, K, p w q represents the bottom hole pressure, in MPa; w The condensate gas volumetric flow rate under bottom-hole temperature and pressure conditions, 10 4 m 3 ;Tw is the bottom hole temperature, K; Z is the deviation factor.

[0021] In an exemplary embodiment of the present invention, the method for determining the injection capacity of a condensate gas reservoir may further include: collecting formation temperature, formation pressure, high-pressure physical properties of condensate gas, composition of injected gas, and high-pressure physical properties of injected gas, for use in calculating the condensate gas well productivity equation and the bottom hole volumetric flow rate equation.

[0022] Another aspect of the present invention provides a computer device, comprising: at least one processor; and a memory storing program instructions, wherein the program instructions are configured to be executed by the at least one processor, the program instructions including instructions for performing the above-described method.

[0023] Another aspect of the present invention provides a computer-readable storage medium having computer program instructions stored thereon, characterized in that the computer program instructions, when executed by a processor, implement the above-described method.

[0024] The present invention has at least the following technical effects through the technical solution provided by the present invention:

[0025] 1) Only condensate gas well production capacity test data, high pressure physical parameters of original formation condensate gas and injected gas are needed. Based on the seepage principle of porous media, the gas state equation is used to convert the underground and surface production of different fluids under the same pressure difference. It is easy to obtain the gas injection capacity of gas injection wells for condensate gas reservoir development. This solves the problem of large error in the currently commonly used empirical analogy method, and also avoids the shortcomings of traditional numerical simulation methods that must rely on accurate models and a large amount of simulation calculation work.

[0026] 2) This invention provides a convenient and reliable way to determine the gas injection capacity of injection wells. In particular, it can accurately and quickly obtain the gas injection capacity in the preparation of gas injection development plans for condensate gas reservoirs. This has great practical significance for determining a scientific and reasonable ratio of injection to production wells and provides assistance for the economical and efficient development of condensate gas reservoirs through gas injection.

[0027] Other features and advantages of the present invention will be described in detail in the following detailed description section. Attached Figure Description

[0028] The accompanying drawings are provided to further illustrate embodiments of the present invention and form part of the specification. They are used together with the following detailed description to explain the embodiments of the present invention, but do not constitute a limitation thereof. In the drawings:

[0029] Figure 1 A flowchart of a method for calculating the gas injection capacity of a condensate gas reservoir, provided as a first exemplary embodiment of the present invention;

[0030] Figure 2This is a graph showing the viscosity and pressure changes of the original formation fluid and injected natural gas in a condensate gas reservoir, as described in Example 1 of this invention.

[0031] Figure 3 This is a graph showing the deviation factor and pressure variation of the original formation fluid and injected natural gas in a condensate gas reservoir, as described in Example 1 of this invention.

[0032] Figure 4 This is a graph illustrating the solution to the binomial productivity equation of a condensate gas well, as shown in Example 1 of this invention.

[0033] Figure 5 This is a graph of the binomial gas injection equation for a gas injection well in a condensate gas reservoir, as shown in Example 1 of this invention. Detailed Implementation

[0034] The specific embodiments of the present invention will be described in detail below with reference to the accompanying drawings. It should be understood that the specific embodiments described herein are for illustration and explanation only and are not intended to limit the scope of the present invention.

[0035] It should be noted that, unless otherwise specified, the embodiments and features described in the present invention can be combined with each other.

[0036] In this invention, unless otherwise stated, directional terms such as "upper," "lower," "top," and "bottom" are generally used in relation to the direction shown in the accompanying drawings, or to describe the relative positional relationships of components in the vertical, perpendicular, or gravitational direction.

[0037] The present invention will now be described in detail with reference to the accompanying drawings and embodiments.

[0038] First exemplary embodiment

[0039] Please refer to Figure 1 This invention provides a method for determining the gas injection capacity of a condensate gas reservoir, the method comprising the following steps:

[0040] S101. Solve the condensate gas well productivity equation, and the condensate gas well productivity equation satisfies the linear relationship of Darcy flow.

[0041] Optionally, the method for determining the gas injection capacity of a condensate gas reservoir may also include: collecting formation temperature, formation pressure, high-pressure physical properties of condensate gas, composition of injected gas, and high-pressure physical properties of injected gas, which are used to calculate the condensate gas well productivity equation and the bottom hole volumetric flow rate equation.

[0042] Specifically, the calculation steps for solving the condensate gas well productivity equation may include: calculating the condensate gas production corresponding to each operating condition (also known as the working system) based on the bottom hole pressure, condensate oil production, and natural gas production, thus obtaining the condensate gas production set; using the pressure analysis method or pressure square analysis method based on the condensate gas production set and the corresponding bottom hole pressure, regressively solving the binomial productivity equation; when the production pressure difference of the condensate gas well is less than 0.5 MPa, the influence of non-Darcy flow is ignored in the binomial productivity equation, thus obtaining the condensate gas well productivity equation that satisfies the linear relationship of Darcy flow.

[0043] Alternatively, the condensate gas production can be calculated according to the following formula;

[0044] q tsc =q sc +543.15×(1.03-γ o )q o / 10000

[0045] In the formula, q tsc Condensate production under standard ground conditions, 10 4 m 3 ;q sc For natural gas production under standard surface conditions, 10 4 m 3 ;q o The condensate production under standard surface conditions, m 3 ;γ o Let be the relative density of condensate oil under standard ground conditions. Where is the gas equivalent of condensate oil calculated in the formula.

[0046] Here, gas well productivity analysis generally uses the pseudo-pressure analysis method. However, the pseudo-pressure analysis method requires numerical integration, and the calculation process is relatively complex. In the field, pressure analysis or pressure square analysis methods are often used instead of the pseudo-pressure analysis method, depending on the actual situation. For example, the calculation formula of the pressure square analysis method is as follows:

[0047] p e 2 -p w 2 =Aq tsc +Bq tsc 2

[0048] In the formula, p e The pressure at the outer boundary is MPa; p w Pressure at the wellbore, MPa; A is Darcy flow coefficient; B is non-Darcy flow coefficient.

[0049] Here, the formula for calculating the Darcy flow coefficient is as follows:

[0050]

[0051] In the formula, μ g ρ is the formation gas viscosity, mPa·s; Z is the deviation factor; T is the formation temperature, K; p sc Ground standard pressure, MPa; T sc 1. Ground standard temperature, K; 2. Effective gas layer thickness, m; 3. Effective gas layer permeability, μm. 2 ;r e r is the distance from the well axis to the outer boundary, in meters (m); w Let be the wellbore radius, in meters. Here, the standard surface pressure is 0.101 MPa, and the standard surface temperature is 293.15 K.

[0052] Here, the formula for calculating the non-Darcy flow coefficient is as follows:

[0053]

[0054] In the formula, b is a coefficient describing the effect of turbulence in the porous medium, and m -1 ;ρ sc Density of formation gas, g / cm³ 3 ;p sc ρ is the standard surface pressure, MPa; Z is the deviation factor; T is the formation temperature, K; h is the effective gas layer thickness, m; T sc For ground standard temperature, K; r e r is the distance from the well axis to the outer boundary, in meters (m); w Let be the wellbore radius, in meters. Here, the standard surface pressure is 0.101 MPa, and the standard surface temperature is 293.15 K.

[0055] Here, based on the binomial production capacity equation of condensate gas wells, the unobstructed flow rate of the gas well can be further calculated.

[0056] Optionally, the production pressure differential can be the difference between the pressure at the outer boundary and the pressure at the wellbore, used to determine the severity of non-Darcy flow of gas in the formation. For example, the production pressure differential in a condensate gas well is less than 0.5 MPa. Here, due to the low viscosity of the gas, non-Darcy flow is relatively easy to occur in formation seepage. Only when the production pressure differential is small and the gas velocity is low can the influence of non-Darcy flow be ignored, and a linear relationship satisfying Darcy flow be obtained. Gas wells at production pressure differentials less than 0.5 MPa basically satisfy the linear seepage relationship of Darcy's law. The critical Darcy flow production rate of a specific gas well can be calculated with reference to the Reynolds number formula. Here, given each linear production rate satisfying Darcy flow, the corresponding production pressure differential can be obtained according to the condensate gas well production capacity equation.

[0057] S102. Using the condensate gas well production capacity equation, calculate the condensate gas production corresponding to each production pressure difference.

[0058] S103. Using the gas state equation, the condensate production corresponding to each production pressure difference is converted into the condensate bottom-hole volumetric flow rate under the bottom-hole temperature and pressure.

[0059] Specifically, the assumptions and continuity equations of stable flow in gas wells indicate that the gas mass flow rate through the wellbore is equal to the gas mass flow rate at any cross-section in the formation, and also equal to the gas mass flow rate at the bottom of the well. The industry commonly uses gas volumetric flow rate to describe gas well production. However, due to the large elastic compressibility of gas, the gas volumetric flow rate varies with pressure in the formation. For ease of study, a bottom-of-well condition (p) is selected. w T w The corresponding volumetric flow rate (q) w The condensate gas was studied as an object. Based on the gas state equation, the high-pressure physical properties of the condensate gas were substituted, and the condensate gas production under standard surface conditions was converted into the condensate gas volumetric flow rate under bottom hole conditions using the following formula;

[0060]

[0061] In the formula, p sc q represents the standard ground pressure, in MPa. tsc Condensate production under standard ground conditions, 10 4 m 3 T sc Ground standard temperature, K, p w q represents the bottom hole pressure, in MPa; w The condensate gas volumetric flow rate under bottom-hole temperature and pressure conditions, 10 4 m 3 ;T w is the bottom hole temperature, K; Z is the deviation factor.

[0062] S104. Using the bottom-hole volumetric flow rate equation, the bottom-hole volumetric flow rate of the condensate gas at the bottom-hole temperature and pressure is converted into the bottom-hole volumetric flow rate of the injected gas at the same temperature, pressure and pressure difference.

[0063] Specifically, when the gas flow rate is low, the non-Darcy flow term is negligible. The gas well productivity equation simplifies to a linear equation satisfying Darcy's law. Combining this with the gas state equation and converting it to the bottom-hole volumetric flow rate, the bottom-hole volumetric flow rate equation can be obtained after deformation. The calculation formula for the bottom-hole volumetric flow rate equation is as follows:

[0064]

[0065] In the formula, q w The condensate gas volumetric flow rate under bottom-hole temperature and pressure conditions, 10 4 m 3 μ gρ is the gas viscosity in the formation, mPa·s; h is the effective thickness of the gas layer, m; K is the effective permeability of the gas layer, μm. 2 ;p e The pressure at the outer boundary is MPa; p w The pressure at the wellbore wall, in MPa; r e r is the distance from the well axis to the outer boundary, in meters (m); w Let be the wellbore radius, in meters (m).

[0066] Alternatively, the bottom-hole volumetric flow rate equation shows that, under the same formation pressure and differential pressure conditions, the bottom-hole formation volumetric flow rate q w With πhK / ln(r e / r w ) and (p e 2 -p w 2 ) / p w The product is directly proportional to the viscosity μ of the formation fluid. g It is inversely proportional and independent of the direction of fluid flow. That is, the flow from the formation to the bottom of the well and the flow from the bottom of the well to the formation are completely reversible and also follow the seepage law of porous media.

[0067] For example, the πhK / ln(r) of a specific well e / r w The product of the formation volumetric flow rate and viscosity of different fluids is constant under the same pressure level and differential pressure. Therefore, based on this characteristic, the bottom-hole volumetric flow rate can be converted by combining the high-pressure physical properties of different fluids. Based on the high-pressure physical properties of condensate gas and injected gas, the conversion of the bottom-hole volumetric flow rate of condensate gas and injected gas under various pressure differentials is completed.

[0068] S105. Using the gas state equation, the bottom volumetric flow rate of the injected gas at the same temperature, pressure and pressure difference is converted into the volumetric flow rate of the injected gas under the standard surface conditions.

[0069] Specifically, based on the equation of state for gases and the properties of the injected gases, the equivalent formation production of injected gas can be converted one by one to the gas volume under standard surface conditions.

[0070] S106. Based on the volumetric flow rate and corresponding pressure of the injected gas under the surface standard conditions, the binomial gas injection equation of the gas injection well is solved by regression to obtain the gas injection equation of the gas injection well and the gas injection capacity is calculated.

[0071] Optionally, this invention has significant practical implications for determining a scientifically reasonable injection-production well ratio. For example, firstly, based on the condensate oil content and reservoir size, the urgent demand for natural gas in the condensate gas reservoir is used to determine the reservoir's production rate and annual gas production (e.g., condensate oil production); then, the number of development wells for the reservoir is determined based on the condensate gas well production capacity; the injection-production ratio of the reservoir is determined based on the condensate gas reservoir's phase characteristics and natural gas demand (e.g., volume ratio under formation conditions); finally, a reasonable injection-production well ratio is set based on the capacity of the injection and production wells.

[0072] Second exemplary embodiment

[0073] In a second exemplary embodiment of the present invention, a computer device is provided.

[0074] The computer device includes at least one processor; and a memory storing program instructions, wherein the program instructions are configured to be executed by the at least one processor, the program instructions including instructions for performing the method for calculating the gas injection capacity of a condensate gas reservoir based on the exemplary embodiment described above.

[0075] Third Exemplary Example

[0076] In a third exemplary embodiment of the present invention, a computer-readable storage medium is provided.

[0077] The computer-readable storage medium stores computer program instructions, which, when executed by a processor, implement the method for calculating the gas injection capacity of a condensate gas reservoir based on the exemplary embodiment 1 described above.

[0078] The computer-readable storage medium can be any data storage device that stores data that can be read by a computer system. Examples of computer-readable storage media include: read-only memory, random access memory, read-only optical disc, magnetic tape, floppy disk, optical data storage device, and carrier waves (such as data transmission via the Internet through wired or wireless transmission paths).

[0079] To better understand the exemplary embodiments of the present invention described above, a method, apparatus, and storage medium for determining the gas injection capacity of a condensate gas reservoir will be described below with reference to specific examples.

[0080] Example 1

[0081] A certain gas injection development project features high temperature (176℃), high pressure (49.03MPa), and high condensate oil content (709g / m³). 3 Condensate gas reservoirs, such as Figure 2 The figure shows the viscosity of the original condensate gas and the injected gas as a function of pressure at formation temperature. Here, the injected gas is natural gas. Although both condensate gas and injected gas are gaseous under formation temperature and pressure conditions, Figure 2This indicates that the viscosity difference between the two is very large and increases with increasing pressure. When the pressure is greater than 45 MPa, the viscosity difference between the two is more than double.

[0082] In addition, such as Figure 3 As shown, the deviation factors of condensate gas and injected gas also differ at formation temperature. Although the difference is not as large as the viscosity difference under high temperature and high pressure conditions, the deviation between the two gases will exceed 10% at medium pressure (e.g., 20 MPa). Therefore, in practical work, attention should be paid to the changes in the high-pressure physical properties of different gases. Ignoring this change may lead to major errors in the work.

[0083] Step 1: Process the gas well productivity test data using a binomial productivity equation, and obtain a linear relationship through regression analysis. The linear relationship is as follows: Figure 4 As shown, the unobstructed flow rate is then calculated to be 58 × 10⁻⁶. 4 m 3 Based on the condensate gas well production capacity equation, four sets of production pressure differentials (e.g., 0.1, 0.2, 0.3, and 0.4 MPa) with a value less than 0.5 MPa are set. The surface production of condensate gas corresponding to the well is calculated, and the corresponding bottom-hole volumetric flow rate is calculated one by one according to the gas state equation.

[0084] Step 2: Using the bottom-hole volumetric flow rate equation, based on the principle that the product of seepage volumetric flow rate and fluid viscosity is equal under the same conditions, convert it into the bottom-hole volumetric flow rate of the injected gas under the same pressure difference.

[0085] Step 3: Using the viscosity and deviation factor of the injected gas, the volumetric flow rate under standard ground conditions is calculated again using the gas state equation.

[0086] Step 4: Based on the volumetric flow rate and corresponding pressure under standard surface conditions, organize the data according to the requirements of the binomial equation of the pressure method, and obtain the gas injection equation for the gas injection well through regression analysis. The gas injection equation for the gas injection well is as follows: Figure 5 As shown, the ideal unobstructed gas injection flow rate is calculated to be 109 × 10⁻⁶. 4 m 3 .

[0087] Here, the seepage and filtration capabilities of the same well for different fluids under the same pressure level and pressure difference are drastically different. In this example, the gas injection capacity is 1.88 times the gas production capacity.

[0088] Practice has shown that the gas injection capacity calculated using the method of this invention is consistent with actual production, with a relative error of less than 5% in general, and the calculation accuracy meets engineering requirements.

[0089] The preferred embodiments of the present invention have been described in detail above with reference to the accompanying drawings. However, the present invention is not limited to the specific details of the above embodiments. Within the scope of the technical concept of the present invention, various simple modifications can be made to the technical solution of the present invention, and these simple modifications all fall within the protection scope of the present invention.

[0090] It should also be noted that the various specific technical features described in the above specific embodiments can be combined in any suitable manner without contradiction. In order to avoid unnecessary repetition, the present invention will not describe the various possible combinations separately.

[0091] Furthermore, various different embodiments of the present invention can be combined in any way, as long as they do not violate the spirit of the present invention, they should also be regarded as the content disclosed by the present invention.

Claims

1. A method for calculating the gas injection capacity of a condensate gas reservoir, characterized in that, The method for determining the gas injection capacity of a condensate gas reservoir includes: Solve the productivity equation for condensate gas wells, and the productivity equation for condensate gas wells satisfies the linear relationship of Darcy flow; Using the aforementioned condensate well production capacity equation, calculate the condensate production corresponding to each production pressure differential; Using the gas state equation, the condensate production corresponding to each production pressure difference is converted into the condensate bottom-hole volumetric flow rate under bottom-hole temperature and pressure. The bottom-hole volumetric flow rate equation is used to convert the bottom-hole volumetric flow rate of condensate gas at the bottom-hole temperature and pressure into the bottom-hole volumetric flow rate of injected gas at the same temperature, pressure and pressure difference. Using the gas state equation, the bottom volumetric flow rate of the injected gas at the same temperature, pressure and pressure difference is converted into the volumetric flow rate of the injected gas under the standard surface conditions. Based on the volumetric flow rate and corresponding pressure of the injected gas under the surface standard conditions, the binomial gas injection equation of the gas injection well is solved by regression to obtain the gas injection equation of the gas injection well and calculate the gas injection capacity.

2. The method for determining the gas injection capacity of a condensate gas reservoir according to claim 1, characterized in that, The calculation formula (1) for the bottom-hole volumetric flow rate equation is as follows: In equation (1), q w The condensate gas volumetric flow rate under bottom-hole temperature and pressure conditions, 10 4 m 3 μ g ρ is the gas viscosity in the formation, mPa·s; h is the effective thickness of the gas layer, m; K is the effective permeability of the gas layer, μm. 2 ;p e The pressure at the outer boundary is MPa; p w The pressure at the wellbore wall, in MPa; r e r is the distance from the well axis to the outer boundary, in meters (m); w Let be the wellbore radius, in meters (m).

3. The method for calculating the gas injection capacity of a condensate gas reservoir according to claim 1, characterized in that, The calculation steps for solving the condensate gas well productivity equation include: Based on the bottom hole pressure, condensate production and natural gas production under different operating conditions, calculate the condensate production for each operating condition to obtain the condensate production group. Based on the condensate gas production group and the corresponding bottom hole pressure, the binomial production capacity equation is solved by regression analysis or pressure square analysis. When the production pressure difference of condensate gas wells is less than 0.5 MPa, the influence of non-Darcy flow is ignored in the binomial production capacity equation, and a condensate gas well production capacity equation that satisfies the linear relationship of Darcy flow is obtained.

4. The method for determining the gas injection capacity of a condensate gas reservoir according to claim 3, characterized in that, Calculate the condensate gas production rate according to formula (2); q tsc =q sc +543.15×(1.03-γ o )q o / 10000 (2) In equation (2), q tsc Condensate production under standard ground conditions, 10 4 m 3 ;q sc For natural gas production under standard surface conditions, 10 4 m 3 ;q o The condensate production under standard surface conditions, m 3 ;γ o The value represents the relative density of condensate oil under standard ground conditions.

5. The method for calculating the gas injection capacity of a condensate gas reservoir according to claim 3, characterized in that, The calculation formula (3) of the pressure square analysis method is as follows: p e 2 -p w 2 =Aq tsc +Bq tsc 2 (3) In equation (3), p e The pressure at the outer boundary is MPa; p w Pressure at the wellbore, MPa; A is Darcy flow coefficient; B is non-Darcy flow coefficient.

6. The method for determining the gas injection capacity of a condensate gas reservoir according to claim 3, characterized in that, The production pressure differential is the difference between the pressure at the outer boundary and the pressure at the wellbore, used to determine the severity of non-Darcy flow of gas in the formation.

7. The method for calculating the gas injection capacity of a condensate gas reservoir according to claim 1, characterized in that, The calculation formula (4) for the gas state equation is as follows: In equation (4), p sc q represents the standard ground pressure, in MPa. tsc Condensate production under standard ground conditions, 10 4 m 3 T sc For ground standard temperature, K, p w q represents the bottom hole pressure, in MPa; w The condensate gas volumetric flow rate under bottom-hole temperature and pressure conditions, 10 4 m 3 ;T w is the bottom hole temperature, K; Z is the deviation factor.

8. The method for calculating the gas injection capacity of a condensate gas reservoir according to claim 1, characterized in that, The method for determining the injection capacity of condensate gas reservoirs further includes: collecting formation temperature, formation pressure, high-pressure physical properties of condensate gas, composition of injected gas, and high-pressure physical properties of injected gas, which are used to calculate the condensate gas well productivity equation and bottom hole volumetric flow rate equation.

9. A computer device, characterized in that, include: At least one processor; A memory storing program instructions configured to be executed by the at least one processor, the program instructions including instructions for performing the method according to any one of claims 1 to 8.

10. A computer-readable storage medium having computer program instructions stored thereon, characterized in that, When the computer program instructions are executed by the processor, they implement the method of any one of claims 1 to 8.

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