Method and System for Determining Productivity of Abnormally High-Pressure Gas Wells in Wellbores

Abstract

The present invention provides a method and system for determining the productivity of a wellbore with abnormally high pressure gas wells. The method for determining the productivity of the wellbore with abnormally high pressure gas wells includes: generating a plurality of productivity coordinate points based on historical gas well production, historical wellhead oil pressure, historical formation pressure, and historical open flow potential; fitting the plurality of productivity coordinate points to generate a productivity fitting curve; determining a gas well productivity model based on the productivity fitting curve; and inputting the current gas well production, current wellhead oil pressure, and current formation pressure into the gas well productivity model to obtain the gas well productivity. The present invention can accurately determine the dynamic productivity of a gas well when the gas well is abnormal, laying a foundation for the formulation of early development technical policies and later optimization and adjustment.

Description

Technical Field

[0001] The present invention relates to the technical field of oil and gas exploitation analysis, and in particular, to a method and system for determining the productivity of a wellbore abnormally high-pressure gas well. Background Art

[0002] The evaluation of gas well productivity is the core issue of gas reservoir dynamic description. From the 1920s to the 1950s, technical personnel successively established single-well productivity testing methods such as backpressure well testing, isochronal well testing, and modified isochronal well testing by measuring the relationship between bottom-hole flowing pressure and production. The above methods usually use the binomial method for productivity calculation. The binomial productivity equation can better describe the turbulent flow influence when gas flows in the formation, so as to more accurately calculate the open-flow potential of the gas well. For gas wells in high-pressure and ultra-high-pressure gas reservoirs, the pressure method should be used for evaluation. On the basis of single-well productivity evaluation, a one-point productivity equation for the entire gas reservoir based on bottom-hole pressure can be established, and then the dynamic productivity of the gas well can be evaluated according to the measured bottom-hole pressure.

[0003] However, for high-pressure and ultra-high-pressure gas reservoirs, after the gas well is put into production, the wellhead pressure is high, and wellbore abnormalities such as wax deposition and scale formation often occur in the wellbore. It is very difficult to test the bottom-hole pressure with a pressure gauge, and the test risk is high, making it difficult to accurately determine the dynamic productivity of the gas well. Summary of the Invention

[0004] The main purpose of the embodiments of the present invention is to provide a method and system for determining the productivity of a wellbore abnormally high-pressure gas well, so as to accurately determine the dynamic productivity of the gas well when the gas well is abnormal, and lay a foundation for the formulation of early development technical policies and later optimization and adjustment.

[0005] To achieve the above purpose, the embodiments of the present invention provide a method for determining the productivity of a wellbore abnormally high-pressure gas well, including:

[0006] Generating a plurality of productivity coordinate points according to historical gas well production, historical wellhead oil pressure, historical formation pressure, and historical open-flow potential;

[0007] Fitting the plurality of productivity coordinate points to generate a productivity fitting curve;

[0008] Determining a gas well productivity model according to the productivity fitting curve;

[0009] Inputting the current gas well production, current wellhead oil pressure, and current formation pressure into the gas well productivity model to obtain the gas well productivity.

[0010] In one of the embodiments, generating a plurality of productivity coordinate points according to historical gas well production, historical wellhead oil pressure, historical formation pressure, and historical open-flow potential includes:

[0011] Determining the abscissa of the productivity coordinate point according to the historical wellhead oil pressure and historical formation pressure;

[0012] Determine the ordinate of the productivity coordinate point according to the historical gas well production and the historical absolute open flow potential;

[0013] Generate a plurality of productivity coordinate points according to the abscissa and the corresponding ordinate of the productivity coordinate point.

[0014] In one embodiment, it further includes:

[0015] Determine the historical absolute open flow potential according to the historical bottom hole flowing pressure and the historical gas well production.

[0016] In one embodiment, it further includes:

[0017] Determine the current production time;

[0018] Determine the current formation pressure according to the current production time.

[0019] An embodiment of the present invention further provides a productivity determination system for a wellbore abnormally high-pressure gas well, including:

[0020] A productivity coordinate point unit, configured to generate a plurality of productivity coordinate points according to the historical gas well production, the historical wellhead oil pressure, the historical formation pressure, and the historical absolute open flow potential;

[0021] A curve fitting unit, configured to fit a plurality of productivity coordinate points to generate a productivity fitting curve;

[0022] A gas well productivity model determination unit, configured to determine the gas well productivity model according to the productivity fitting curve;

[0023] A gas well productivity unit, configured to input the current gas well production, the current wellhead oil pressure, and the current formation pressure into the gas well productivity model to obtain the gas well productivity.

[0024] In one embodiment, the productivity coordinate point unit is specifically configured to:

[0025] Determine the abscissa of the productivity coordinate point according to the historical wellhead oil pressure and the historical formation pressure;

[0026] Determine the ordinate of the productivity coordinate point according to the historical gas well production and the historical absolute open flow potential;

[0027] Generate a plurality of productivity coordinate points according to the abscissa and the corresponding ordinate of the productivity coordinate point.

[0028] In one embodiment, it further includes:

[0029] A historical absolute open flow potential determination unit, configured to determine the historical absolute open flow potential according to the historical bottom hole flowing pressure and the historical gas well production.

[0030] In one embodiment, it further includes:

[0031] Current production time unit, used to determine the current production time;

[0032] Current formation pressure unit, used to determine the current formation pressure according to the current production time.

[0033] An embodiment of the present invention also provides a computer device, including a memory, a processor, and a computer program stored on the memory and running on the processor. When the processor executes the computer program, the steps of the method for determining the productivity of a wellbore abnormally high-pressure gas well are implemented.

[0034] An embodiment of the present invention also provides a computer-readable storage medium, on which a computer program is stored. When the computer program is executed by a processor, the steps of the method for determining the productivity of a wellbore abnormally high-pressure gas well are implemented.

[0035] The method and system for determining the productivity of a wellbore abnormally high-pressure gas well according to the embodiments of the present invention first determine a gas well productivity model based on historical gas well parameters and historical formation pressure, and then obtain the gas well productivity according to the gas well productivity model, current gas well parameters, and current formation pressure. It can accurately determine the dynamic productivity of a gas well when the gas well is abnormal, laying a foundation for the formulation of early development technical policies and later optimization and adjustment. Description of the Drawings

[0036] In order to more clearly illustrate the technical solutions in the embodiments of the present invention or the prior art, the following will briefly introduce the drawings required for use in the description of the embodiments. Obviously, the drawings in the following description are only some embodiments of the present invention. For those of ordinary skill in the art, without creative efforts, other drawings can also be obtained based on these drawings.

[0037] Figure 1 It is a flowchart of the method for determining the productivity of a wellbore abnormally high-pressure gas well in an embodiment of the present invention;

[0038] Figure 2 It is a flowchart of S101 in an embodiment of the present invention;

[0039] Figure 3 It is a flowchart of the method for determining the productivity of a wellbore abnormally high-pressure gas well in another embodiment of the present invention;

[0040] Figure 4 It is a schematic diagram of the productivity fitting curve in an embodiment of the present invention;

[0041] Figure 5 It is a schematic diagram of the relationship curve between historical formation pressure and historical production time in an embodiment of the present invention;

[0042] Figure 6 It is a schematic diagram of the curves of current gas well production, current wellhead oil pressure, and current formation pressure in an embodiment of the present invention;

[0043] Figure 7 It is a schematic curve diagram of the current gas well output, current wellhead oil pressure, current formation pressure and gas well productivity in the embodiment of the present invention;

[0044] Figure 8 It is a schematic curve diagram of the current gas well output, gas well productivity and the ratio of the current gas well output to the gas well productivity in the embodiment of the present invention;

[0045] Figure 9 It is a structural block diagram of a system for determining the productivity of a wellbore abnormally high-pressure gas well in the embodiment of the present invention;

[0046] Figure 10 It is a structural block diagram of a computer device in the embodiment of the present invention. Detailed implementation manners

[0047] Next, the technical solutions in the embodiments of the present invention will be clearly and completely described in conjunction with the accompanying drawings in the embodiments of the present invention. Obviously, the described embodiments are only a part of the embodiments of the present invention, rather than all the embodiments. Based on the embodiments of the present invention, all other embodiments obtained by those of ordinary skill in the art without creative efforts shall fall within the protection scope of the present invention.

[0048] Those skilled in the art know that the implementation manners of the present invention can be realized as a system, device, equipment, method or computer program product. Therefore, the present disclosure can be specifically realized in the following forms, that is: complete hardware, complete software (including firmware, resident software, microcode, etc.), or a combination of hardware and software.

[0049] In view of the difficulty in accurately determining the dynamic productivity of a gas well after the gas well is abnormal, the embodiment of the present invention provides a method for determining the productivity of a wellbore abnormally high-pressure gas well to accurately determine the dynamic productivity of the gas well when the gas well is abnormal, laying a foundation for the formulation of early development technical policies and later optimization and adjustment. The present invention will be described in detail below with reference to the accompanying drawings.

[0050] Figure 1 It is a flowchart of a method for determining the productivity of a wellbore abnormally high-pressure gas well in the embodiment of the present invention. Figure 3 It is a flowchart of a method for determining the productivity of a wellbore abnormally high-pressure gas well in another embodiment of the present invention. As Figure 1 and Figure 3 shown, the method for determining the productivity of a wellbore abnormally high-pressure gas well includes:

[0051] S101: Generate a plurality of productivity coordinate points according to the historical gas well output, historical wellhead oil pressure, historical formation pressure and historical open flow potential.

[0052] Figure 2 It is a flowchart of S101 in the embodiment of the present invention. As Figure 2As shown, S101 includes:

[0053] S201: Determine the horizontal coordinate of the production capacity coordinate point based on the historical wellhead oil pressure and the historical formation pressure.

[0054] During specific implementation, the horizontal coordinate of the production capacity coordinate point is determined according to the following formula:

[0055]

[0056] Among them, x c is the horizontal coordinate of the production capacity coordinate point, p t is the historical wellhead oil pressure, in MPa; p R is the historical formation pressure (formation pressure of the entire gas reservoir), in MPa.

[0057] S202: Determine the vertical coordinate of the production capacity coordinate point based on the historical gas well production and the historical open flow rate.

[0058] Determine the vertical coordinate of the production capacity coordinate point according to the following formula;

[0059]

[0060] Among them, y c is the ordinate of the production capacity coordinate point, q g is the historical gas well production, unit is 10 4 m 3 / d;q AOF The historical unimpeded flow rate, the unit is 10 4 m 3 / d.

[0061] S203: Generate multiple production capacity coordinate points according to the horizontal coordinate and the corresponding vertical coordinate of the production capacity coordinate point.

[0062] S102: Fitting multiple capacity coordinate points to generate a capacity fitting curve.

[0063] Figure 4 Schematic diagram of the capacity fitting curve in the embodiment of the present invention. Figure 4 As shown, Figure 4 The horizontal axis is The vertical axis is The fitting degree of the regression curve (capacity fitting curve) is R=0.9, Figure 4 The 9 different coordinate points represent the coordinate points corresponding to the 9 gas wells.

[0064] S103: Determine the gas well productivity model (the full gas reservoir productivity formula based on the wellhead oil pressure) according to the productivity fitting curve.

[0065] S104: Input the current gas well production, the current wellhead oil pressure, and the current formation pressure into the gas well productivity model to obtain the gas well productivity.

[0066] In specific implementation, the gas well productivity can be determined through the following gas well productivity model:

[0067]

[0068] Among them, q' AOF is the gas well productivity, with the unit of 10 4 m 3 / d; p' t is the current wellhead oil pressure, with the unit of MPa; p' R is the current formation pressure, with the unit of MPa; q' g is the current gas well production, with the unit of 10 4 m 3 / d.

[0069] Figure 1 The execution subject of the method for determining the productivity of the wellbore abnormally high-pressure gas well shown can be a computer. From Figure 1 the process shown, it can be seen that the method for determining the productivity of the wellbore abnormally high-pressure gas well in the embodiment of the present invention first determines the gas well productivity model according to the historical gas well parameters and the historical formation pressure, and then obtains the gas well productivity according to the gas well productivity model, the current gas well parameters, and the current formation pressure, which can accurately determine the dynamic productivity of the gas well when the gas well is abnormal, laying a foundation for the formulation of early development technical policies and later optimization and adjustment.

[0070] In one embodiment, it further includes: determining the historical absolute open flow according to the historical bottom-hole flowing pressure and the historical gas well production.

[0071] In one embodiment, it further includes: determining the current production time; determining the current formation pressure according to the current production time.

[0072] In specific implementation, first generate multiple formation pressure coordinate points according to the historical production time and the historical formation pressure. Then fit the multiple formation pressure coordinate points to generate a relationship curve between the historical formation pressure and the historical production time. Figure 5 is a schematic diagram of the relationship curve between the historical formation pressure and the historical production time in the embodiment of the present invention. As Figure 5 shown, Figure 5 the abscissa of which is time, with the unit of day (d); the ordinate is the historical formation pressure p R , with the unit of MPa.

[0073] According to the decreasing trend of the wellhead static pressure with the production time and the relationship between the wellhead static pressure and the formation pressure (the relationship curve between the historical formation pressure and the historical production time), the change trend of the formation pressure of the whole gas reservoir with time can be determined, and a formation pressure fitting model can be obtained: AsFigure 5 As shown, p R =104.09-0.00301t; where p R is the historical formation pressure, and t is the historical production time.

[0074] The current formation pressure can be obtained by inputting the current production time into the formation pressure fitting model.

[0075] Among them, the current formation pressure can be obtained through the following formation pressure fitting model:

[0076] p' R =104.09-0.00301t';

[0077] Where t' is the current production time in days.

[0078] The specific process of the embodiment of the present invention is as follows:

[0079] 1. Determine the historical open flow rate (single well production capacity in the initial stage of production) based on the historical bottom hole pressure and historical gas well production.

[0080] 2. Determine the horizontal coordinate of the production capacity coordinate point based on the historical wellhead oil pressure and historical formation pressure, and determine the vertical coordinate of the production capacity coordinate point based on the historical gas well production and historical open flow.

[0081] 3. Generate multiple capacity coordinate points based on the horizontal coordinate and the corresponding vertical coordinate of the capacity coordinate point.

[0082] 4. Fit multiple capacity coordinate points to generate a capacity fitting curve.

[0083] 5. Determine the gas well productivity model based on the productivity fitting curve.

[0084] 6. Determine the current production time and determine the current formation pressure based on the current production time.

[0085] 7. Input the current gas well production, current wellhead oil pressure and current formation pressure into the gas well productivity model to obtain the gas well productivity.

[0086] Figure 6 Schematic diagram of the curves of the current gas well production, the current wellhead oil pressure and the current formation pressure in an embodiment of the present invention. Figure 7 Schematic diagram of the curve of the current gas well production, current wellhead oil pressure, current formation pressure and gas well productivity in the embodiment of the present invention. Figures 6 - 7 As shown, Figure 6 and Figure 7 The horizontal axis is time, the left vertical axis is pressure p (including the current wellhead oil pressure and the current formation pressure), the unit is MPa, and the right vertical axis is production q (production q in Figure 6 The middle is the current gas well production,Figure 7 including the current gas well production and gas well productivity), with the unit of 10 4 m 3 / d.

[0087] 8. After determining the gas well productivity of a single well, the gas well productivities of all gas wells can be superimposed to further determine the dynamic productivity of the entire gas reservoir.

[0088] Figure 8 It is a schematic curve diagram of the current gas well production, gas well productivity, and the ratio of the current gas well production to the gas well productivity in the embodiment of the present invention. As Figure 8 shown, Figure 8 the abscissa of [diagram name] is time, and the left ordinate is production, including the current gas well production q' g and the gas well productivity q' AOF , with the unit of 10 4 m 3 / d. The right ordinate is the ratio of the current gas well production to the gas well productivity, with the unit of %. Whether the current gas well production is appropriate can be determined by the ratio of the current gas well production to the gas well productivity. If the ratio of the current gas well production to the gas well productivity is not within the preset range, the gas well production is adjusted.

[0089] In summary, the method for determining the productivity of a wellbore abnormally high-pressure gas well in the embodiment of the present invention can accurately obtain the magnitude of the dynamic productivity of a single well at different stages of gas well development, lay a foundation for the formulation of early development technical policies and later optimization and adjustment, and solve the problem of dynamic productivity evaluation in the case of abnormal wellbore or unsuitable for downhole testing.

[0090] Based on the same inventive concept, the embodiment of the present invention also provides a system for determining the productivity of a wellbore abnormally high-pressure gas well. Since the principle of the system to solve problems is similar to that of the method for determining the productivity of a wellbore abnormally high-pressure gas well, the implementation of the system can refer to the implementation of the method, and the repeated parts will not be elaborated.

[0091] Figure 9 It is a structural block diagram of the system for determining the productivity of a wellbore abnormally high-pressure gas well in the embodiment of the present invention. As Figure 9 shown, the system for determining the productivity of a wellbore abnormally high-pressure gas well includes:

[0092] A productivity coordinate point unit, configured to generate a plurality of productivity coordinate points according to historical gas well production, historical wellhead oil pressure, historical formation pressure, and historical open flow rate;

[0093] A curve fitting unit, configured to fit a plurality of productivity coordinate points to generate a productivity fitting curve;

[0094] A gas well productivity model determination unit, configured to determine the gas well productivity model according to the productivity fitting curve;

[0095] A gas well productivity unit is used to input the current gas well output, the current wellhead oil pressure, and the current formation pressure into a gas well productivity model to obtain the gas well productivity.

[0096] In one of the embodiments, the productivity coordinate point unit is specifically configured to:

[0097] Determine the abscissa of the productivity coordinate point according to the historical wellhead oil pressure and the historical formation pressure;

[0098] Determine the ordinate of the productivity coordinate point according to the historical gas well output and the historical absolute open flow;

[0099] Generate multiple productivity coordinate points according to the abscissa and the corresponding ordinate of the productivity coordinate point.

[0100] In one of the embodiments, it further includes:

[0101] A historical absolute open flow determination unit is used to determine the historical absolute open flow according to the historical bottom-hole flowing pressure and the historical gas well output.

[0102] In one of the embodiments, it further includes:

[0103] A current production time unit is used to determine the current production time;

[0104] A current formation pressure unit is used to determine the current formation pressure according to the current production time.

[0105] In summary, the productivity determination system for a wellbore abnormally high-pressure gas well according to the embodiments of the present invention can accurately obtain the magnitude of the single-well dynamic productivity at different stages of gas well development, lay a foundation for the formulation of early development technical policies and later optimization and adjustment, and solve the problem of dynamic productivity evaluation in the case of abnormal wellbores or unsuitable downhole tests.

[0106] The embodiments of the present invention also provide a specific implementation manner of a computer device capable of implementing all the steps in the productivity determination method for a wellbore abnormally high-pressure gas well in the above embodiments. Figure 10 It is a structural block diagram of the computer device in the embodiments of the present invention. Refer to Figure 10 , and the computer device specifically includes the following contents:

[0107] A processor 1001 and a memory 1002.

[0108] The processor 1001 is used to call a computer program in the memory 1002. When the processor executes the computer program, it implements all the steps in the productivity determination method for a wellbore abnormally high-pressure gas well in the above embodiments. For example, when the processor executes the computer program, it implements the following steps:

[0109] Generate multiple production capacity coordinate points based on historical gas well production, historical wellhead oil pressure, historical formation pressure and historical open flow;

[0110] Fit multiple capacity coordinate points to generate a capacity fitting curve;

[0111] Determine the gas well productivity model based on the productivity fitting curve;

[0112] The current gas well production, current wellhead oil pressure, and current formation pressure are input into the gas well productivity model to obtain the gas well productivity.

[0113] In summary, the computer equipment in the embodiment of the present invention can accurately obtain the dynamic production capacity of a single well at different stages of gas well development, laying the foundation for the formulation of early development technology policies and later optimization and adjustment, and solving the problem of dynamic production capacity evaluation when there are abnormalities in the wellbore or when downhole testing is not suitable.

[0114] An embodiment of the present invention also provides a computer-readable storage medium capable of implementing all steps of the method for determining the productivity of a gas well with abnormally high wellbore pressure in the above embodiment. The computer-readable storage medium stores a computer program. When the computer program is executed by a processor, all steps of the method for determining the productivity of a gas well with abnormally high wellbore pressure in the above embodiment are implemented. For example, when the processor executes the computer program, the following steps are implemented:

[0115] Generate multiple production capacity coordinate points based on historical gas well production, historical wellhead oil pressure, historical formation pressure and historical open flow;

[0116] Fit multiple capacity coordinate points to generate a capacity fitting curve;

[0117] Determine the gas well productivity model based on the productivity fitting curve;

[0118] The current gas well production, current wellhead oil pressure, and current formation pressure are input into the gas well productivity model to obtain the gas well productivity.

[0119] In summary, the computer-readable storage medium of the embodiment of the present invention can accurately obtain the size of the dynamic production capacity of a single well at different stages of gas well development, laying the foundation for the formulation of early development technology policies and later optimization and adjustment, and solving the problem of dynamic production capacity evaluation when there are abnormalities in the wellbore or when downhole testing is not suitable.

[0120] The specific embodiments described above further illustrate the objectives, technical solutions and beneficial effects of the present invention in detail. It should be understood that the above description is only a specific embodiment of the present invention and is not intended to limit the scope of protection of the present invention. Any modifications, equivalent substitutions, improvements, etc. made within the spirit and principles of the present invention should be included in the scope of protection of the present invention.

[0121] Those skilled in the art can also understand that the various illustrative logical blocks, units, and steps listed in the embodiments of the present invention can be implemented by electronic hardware, computer software, or a combination of both. To clearly show the interchangeability of hardware and software, the above-mentioned various illustrative components, units, and steps have been generally described in terms of their functions. Whether such functions are implemented by hardware or software depends on the specific application and the design requirements of the entire system. Those skilled in the art can use various methods to implement the described functions for each specific application, but such implementation should not be construed as exceeding the scope of protection of the embodiments of the present invention.

[0122] In the embodiments of the present invention, the various illustrative logical blocks, or units, or devices can be implemented or operate the described functions through a general-purpose processor, a digital signal processor, an application-specific integrated circuit (ASIC), a field-programmable gate array or other programmable logic devices, discrete gate or transistor logic, discrete hardware components, or any combination of the above designs. The general-purpose processor can be a microprocessor. Optionally, the general-purpose processor can also be any conventional processor, controller, microcontroller, or state machine. The processor can also be implemented by a combination of computing devices, such as a digital signal processor and a microprocessor, multiple microprocessors, one or more microprocessors combined with a digital signal processor core, or any other similar configuration.

[0123] The steps of the methods or algorithms described in the embodiments of the present invention can be directly embedded in hardware, software modules executed by the processor, or a combination of both. The software modules can be stored in a RAM memory, a flash memory, a ROM memory, an EPROM memory, an EEPROM memory, a register, a hard disk, a removable disk, a CD-ROM, or any other form of storage medium in the art. Exemplarily, the storage medium can be connected to the processor so that the processor can read information from the storage medium and write information to the storage medium. Optionally, the storage medium can also be integrated into the processor. The processor and the storage medium can be disposed in an ASIC, and the ASIC can be disposed in a user terminal. Optionally, the processor and the storage medium can also be disposed in different components of the user terminal.

[0124] In one or more exemplary designs, the functions described in embodiments of the present invention may be implemented in hardware, software, firmware, or any combination of the three. If implemented in software, the functions may be stored on a computer-readable medium or transmitted as one or more instructions or code on a computer-readable medium. A computer-readable medium includes both computer storage media and communication media that facilitate transfer of a computer program from one place to another. Storage media may be any available media that can be accessed by a general or special purpose computer. By way of example, and not limitation, such computer-readable media may include RAM, ROM, EEPROM, CD-ROM or other optical disk storage, magnetic disk storage or other magnetic storage devices, or any other medium that can be used to carry or store program code in the form of instructions or data structures and that can be accessed by a general or special purpose computer, or a general or special purpose processor. In addition, any connection is properly termed a computer-readable medium, for example, if software is transmitted from a website, server, or other remote source using a coaxial cable, fiber optic cable, twisted pair, DSL, or wireless technologies such as infrared, radio, and microwave, it is included in the definition of computer-readable medium. Disk and disc include compact disk, laser disk, optical disk, DVD, floppy disk, and Blu-ray disk, disk usually magnetically replicates data, while disc usually optically replicates data with lasers. Combinations of the above should also be included within the scope of computer-readable media.

Claims

1. A method for determining the productivity of an abnormal high-pressure gas well in a wellbore, characterized in that, Including: Generating a plurality of productivity coordinate points based on historical gas well production, historical wellhead oil pressure, historical formation pressure, and historical absolute open flow; Wherein, the generating a plurality of productivity coordinate points based on the historical gas well production, the historical wellhead oil pressure, the historical formation pressure, and the historical absolute open flow includes: Determine the abscissa of the productivity coordinate point based on the historical wellhead oil pressure and the historical formation pressure. The abscissa of the productivity coordinate point is determined according to the following formula: where x c represents the abscissa of the productivity coordinate point, p t represents the historical wellhead oil pressure, and p R represents the historical formation pressure; Determine the ordinate of the productivity coordinate point based on the historical gas well production and the historical absolute open flow rate, and determine the ordinate of the productivity coordinate point according to the following formula: where y c represents the ordinate of the productivity coordinate point, q g represents the historical gas well production, and q AOF represents the historical absolute open flow rate; Generating a plurality of productivity coordinate points based on the abscissa and the corresponding ordinate of the productivity coordinate points; Fitting the plurality of productivity coordinate points to generate a productivity fitting curve; Determining a gas well productivity model according to the productivity fitting curve, the gas well productivity model including: Among them, q' AOF represents the gas well productivity, p' t is the current wellhead oil pressure, p' R represents the current formation pressure, q' g represents the current gas well production; Inputting the current gas well production, the current wellhead oil pressure, and the current formation pressure into the gas well productivity model to obtain the gas well productivity.

2. The method for determining the productivity of an abnormally high-pressure gas well in a wellbore according to claim 1, wherein, Also including: Determining the historical absolute open flow according to the historical bottom-hole flowing pressure and the historical gas well production.

3. The method for determining the productivity of an abnormal high-pressure gas well in a wellbore according to claim 1, wherein Also including: Determining the current production time; Determining the current formation pressure according to the current production time.

4. A system for determining the productivity of an abnormally high-pressure gas well in a wellbore, characterized in that, Including: A productivity coordinate point unit for generating a plurality of productivity coordinate points based on historical gas well production, historical wellhead oil pressure, historical formation pressure, and historical absolute open flow; Wherein, the productivity coordinate point unit is specifically used for: Determine the abscissa of the production capacity coordinate point based on the historical wellhead oil pressure and the historical formation pressure. The abscissa of the production capacity coordinate point is determined according to the following formula: where x c represents the abscissa of the production capacity coordinate point, p t represents the historical wellhead oil pressure, and p R represents the historical formation pressure; Determine the ordinate of the productivity coordinate point according to the historical gas well production and the historical absolute open flow rate, and determine the ordinate of the productivity coordinate point according to the following formula: where y c represents the ordinate of the productivity coordinate point, q g represents the historical gas well production, and q AOF represents the historical absolute open flow rate; Generating a plurality of productivity coordinate points based on the abscissa and the corresponding ordinate of the productivity coordinate points; A curve fitting unit for fitting the plurality of productivity coordinate points to generate a productivity fitting curve; A gas well productivity model determining unit for determining a gas well productivity model according to the productivity fitting curve, the gas well productivity model including: Among them, q' AOF represents the gas well productivity, p' t is the current wellhead oil pressure, p' R represents the current formation pressure, q' g represents the current gas well production; A gas well productivity unit for inputting the current gas well production, the current wellhead oil pressure, and the current formation pressure into the gas well productivity model to obtain the gas well productivity.

5. The wellbore abnormal high-pressure gas well productivity determination system according to claim 4, wherein, Also including: A historical absolute open flow determining unit for determining the historical absolute open flow according to the historical bottom-hole flowing pressure and the historical gas well production.

6. The wellbore abnormal high-pressure gas well productivity determination system according to claim 4, wherein Also including: A current production time unit for determining the current production time; A current formation pressure unit for determining the current formation pressure according to the current production time.

7. A computer device, comprising a memory, a processor, and a computer program stored on the memory and running on the processor, characterized in that, When the processor executes the computer program, the steps of the method for determining the productivity of a wellbore abnormally high-pressure gas well according to any one of claims 1 to 3 are implemented.

8. A computer-readable storage medium having a computer program stored thereon, characterized in that, When the computer program is executed by the processor, the steps of the method for determining the productivity of a wellbore abnormally high-pressure gas well according to any one of claims 1 to 3 are implemented.

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