Plunger gas lift control method and system

Abstract

A plunger gas lift control method, comprises: acquiring historical production data of a gas well; setting a load factor value, the maximum well shut-in duration, an afterflow production duration and an afterflow adjustment time step length on the basis of the historical production data of the gas well; acquiring, in real time, state parameters in the gas well production; calculating a load factor on the basis of the state parameters in the gas well production; when the load factor reaches the load factor value or a well shut-in duration reaches the maximum well shut-in duration, opening the well; determining the minimum oil pressure value and the maximum oil pressure value during liquid drainage oscillation, wherein the oil pressure is the pressure at an oil pipe at the wellhead of the gas well; determining a liquid drainage amount on the basis of the minimum oil pressure value and the maximum oil pressure value; and when the liquid drainage amount does not fall within a preset range, adjusting the afterflow production duration on the basis of the liquid drainage amount and the afterflow adjustment time step length. Also provided are a computer device and a computer-readable storage medium. The method, the computer and the computer readable storage medium can realize periodic cyclic on / off control and automatic optimization on a plunger gas lift well on the basis of the set load factor value and the liquid drainage amount, thereby achieving efficient liquid drainage and stable operation of the plunger gas lift well.

Description

Plunger gas lift control method and system Technical Field

[0001] The present invention relates to the technical field of plunger gas lift, and in particular to a plunger gas lift control method and system. Background Art

[0002] This section is intended to provide a background or context to the embodiments of the invention that are recited in the claims. No statement herein is admitted to be prior art by virtue of its inclusion in this section.

[0003] Plunger gas lift technology controls plunger liquid lifting operations by setting appropriate operating parameters. Currently, the commonly used control method is the timed, constant-pressure well switching method. This requires manual calculation and setting of operating parameters based on the energy recovery status and liquid volume of the gas well. The setting process is labor-intensive, and untimely or inaccurate analysis will affect the technical effectiveness.

[0004] As the number of wells using plunger gas lift increases, the existing control methods cannot meet the control needs due to the large workload of manual parameter adjustment and insufficient control refinement, resulting in liquid accumulation and water flooding in gas wells, affecting the gas well production capacity and reducing the gas well recovery rate. Therefore, plunger gas lift control is urgently needed to solve the above problems.

[0005] Summary of the Invention

[0006] An embodiment of the present invention provides a plunger gas lift control method for improving plunger liquid lift efficiency and operational normality. The method includes:

[0007] Obtain historical production data of gas wells;

[0008] Set the load factor threshold, maximum shut-in time, continuous production time, and continuous flow adjustment time step based on the historical production data of the gas well;

[0009] Real-time collection of state parameters during gas well production;

[0010] Calculate the load factor based on the state parameters during gas well production;

[0011] When the load factor reaches the load factor threshold or the well shut-in time reaches the maximum well shut-in time, the well is controlled to be opened;

[0012] Determine the minimum and maximum oil pressures during fluid discharge oscillation; the oil pressure is the pressure at the wellhead tubing of the gas well;

[0013] Determine the discharge volume based on the minimum and maximum oil pressures;

[0014] When the discharge volume is not within the preset range, the continuous flow production time is adjusted according to the discharge volume and the continuous flow adjustment time step.

[0015] An embodiment of the present invention further provides a computer device, comprising a memory, a processor, and a computer program stored in the memory and executable on the processor. When the processor executes the computer program, the following plunger gas lift control method is implemented:

[0016] Obtain historical production data of gas wells;

[0017] Set the load factor threshold, maximum shut-in time, continuous production time, and continuous flow adjustment time step based on the historical production data of the gas well;

[0018] Real-time collection of state parameters during gas well production;

[0019] Calculate the load factor based on the state parameters during gas well production;

[0020] When the load factor reaches the load factor threshold or the well shut-in time reaches the maximum well shut-in time, the well is controlled to be opened;

[0021] Determine the minimum and maximum oil pressures during fluid discharge oscillation; the oil pressure is the pressure at the wellhead tubing of the gas well;

[0022] Determine the discharge volume based on the minimum and maximum oil pressures;

[0023] When the discharge volume is not within the preset range, the continuous flow production time is adjusted according to the discharge volume and the continuous flow adjustment time step.

[0024] An embodiment of the present invention further provides a computer-readable storage medium storing a computer program. When the computer program is executed by a processor, the following plunger gas lift control method is implemented:

[0025] Obtain historical production data of gas wells;

[0026] Set the load factor threshold, maximum shut-in time, continuous production time, and continuous flow adjustment time step based on the historical production data of the gas well;

[0027] Real-time collection of state parameters during gas well production;

[0028] Calculate the load factor based on the state parameters during gas well production;

[0029] When the load factor reaches the load factor threshold or the well shut-in time reaches the maximum well shut-in time, the well is controlled to be opened;

[0030] Determine the minimum and maximum oil pressures during fluid discharge oscillation; the oil pressure is the pressure at the wellhead tubing of the gas well;

[0031] Determine the discharge volume based on the minimum and maximum oil pressures;

[0032] When the discharge volume is not within the preset range, the continuous flow production time is adjusted according to the discharge volume and the continuous flow adjustment time step.

[0033] In an embodiment of the present invention, historical production data of the gas well is obtained; a load factor threshold, a maximum shut-in time, a continuous flow production time and a continuous flow adjustment time step are set according to the historical production data of the gas well; state parameters in gas well production are collected in real time; a load factor is calculated according to the state parameters in gas well production; when the load factor reaches the load factor threshold or the shut-in time reaches the maximum shut-in time, well opening is performed; the minimum oil pressure and the maximum oil pressure during liquid discharge oscillation are determined; the oil pressure is the pressure at the wellhead oil pipe of the gas well; the liquid discharge volume is determined according to the minimum oil pressure and the maximum oil pressure; when the liquid discharge volume is not within a preset range, the continuous flow production time is adjusted according to the liquid discharge volume and the continuous flow adjustment time step. Compared with the prior art, the liquid discharge volume is determined according to the minimum oil pressure and the maximum oil pressure; the continuous flow production time is adjusted according to the liquid discharge volume and the continuous flow adjustment time step. Without adding equipment, invalid well shut-in and liquid discharge overload operation in plunger gas lift operation are avoided, thereby improving the plunger liquid discharge efficiency and the normal operation rate. The plunger gas lift well is periodically cycled on and off controlled and automatically optimized according to the set load factor threshold and discharge volume, achieving efficient discharge and stable operation of the plunger gas lift well. BRIEF DESCRIPTION OF THE DRAWINGS

[0034] In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the following briefly introduces the drawings required for the embodiments or the description of the prior art. Obviously, the drawings described below are only some embodiments of the present invention. For those skilled in the art, other drawings can be obtained based on these drawings without creative work. In the drawings:

[0035] FIG1 is a schematic flow chart of a plunger gas lift control method provided by the present invention;

[0036] FIG2 is a schematic flow chart of the plunger gas lift control method provided by the present invention;

[0037] FIG3 is a schematic diagram of a plunger gas lift operation curve of a gas well provided by the present invention;

[0038] FIG4 is a schematic diagram of the plunger gas lift operation curve after optimization of the gas well provided by the present invention;

[0039] FIG5 is a schematic diagram of the plunger gas lift control system provided by the present invention. DETAILED DESCRIPTION

[0040] To make the purpose, technical solutions and advantages of the embodiments of the present invention more clear, the embodiments of the present invention are further described in detail below with reference to the accompanying drawings. Here, the exemplary embodiments of the present invention and their descriptions are used to explain the present invention, but are not intended to limit the present invention.

[0041] FIG1 is a flow chart of a plunger gas lift control method according to an embodiment of the present invention. As shown in FIG1 , the method includes:

[0042] Step 101: Obtain historical production data of the gas well.

[0043] Step 102 : setting a load factor threshold, a maximum shut-in time, a continuous production time, and a continuous adjustment time step according to historical production data of the gas well.

[0044] Based on the historical production data of the gas well, the gas well operating parameters are analyzed, and the load factor threshold, maximum shut-in time, continuous flow production time and continuous flow adjustment time step are set.

[0045] In this embodiment of the present invention, the duration of continued production is determined based on changes in casing pressure during the continued production period. After the plunger lifts fluid to the wellhead, the gas well enters the continued production phase. The changes in casing pressure are monitored in real time. When the casing pressure increases, the time the well is opened is determined to be the continued production duration. This duration is determined based on the increase in casing pressure during continued production, i.e., an increase in the oil-casing pressure differential, indicating the onset of liquid accumulation in the gas well.

[0046] Step 103: Real-time collection of state parameters of the gas well during production.

[0047] Step 104: Calculate the load factor according to the state parameters during gas well production.

[0048] The state parameters in gas well production include casing pressure, oil pressure, and back pressure.

[0049] Calculate the load factor based on casing pressure, oil pressure and back pressure.

[0050] It should be noted that the casing pressure is the pressure in the wellhead casing annulus; the back pressure is the pipeline transmission pressure.

[0051] The load factor is calculated by the ratio of the difference between the shut-in casing pressure and the shut-in oil pressure to the difference between the shut-in casing pressure and the wellhead throttling pressure, i.e., the back pressure.

[0052] The difference between the shut-in casing pressure and the shut-in oil pressure reflects the liquid accumulation in the gas wellbore and is the resistance to the plunger gas lift operation. The difference between the shut-in casing pressure and the pressure after wellhead throttling reflects the pure power provided by the plunger lift. The ratio of the two is the comparison of resistance and power. The smaller the value, the more favorable it is to the plunger lift operation.

[0053] Step 105 : When the load factor reaches a load factor threshold or the well shut-in duration reaches a maximum well shut-in duration, the well is opened.

[0054] When the plunger gas lift well is in the shut-in state, the load coefficient is monitored and analyzed in real time. When the set load coefficient threshold is reached, the well is opened. If the load coefficient threshold cannot be reached, the well is opened when the shut-in time reaches the maximum shut-in time.

[0055] Step 106 , determining the minimum and maximum oil pressures during the discharge oscillation.

[0056] Oil pressure is the pressure at the oil pipe at the wellhead of the gas well.

[0057] Step 107 : determining the amount of fluid to be discharged based on the minimum and maximum oil pressures.

[0058] After the well is opened, the information of the plunger lifting liquid to the wellhead is monitored, and the changes in the oil pressure of the gas well are tracked and analyzed in real time. When the oil pressure reaches the minimum value and then increases, the discharge oscillation occurs, and the discharge volume is automatically calculated based on the pressure difference between the minimum and maximum oil pressures.

[0059] The specific calculation formula is as follows: ΔPt=Pt(max)-Pt(min)

[0060] Ql represents the amount of liquid discharged during the plunger gas lift cycle, K represents the correction coefficient, ΔPt represents the pressure difference between the maximum and minimum oil pressures during plunger gas lift discharge, ρ represents the density of the produced liquid, g represents the acceleration of gravity, Pt(max) represents the maximum oil pressure, and Pt(min) represents the minimum oil pressure.

[0061] Step 108 : When the discharge volume is not within the preset range, the continuous flow production time is adjusted according to the discharge volume and the continuous flow adjustment time step.

[0062] In the embodiment of the present invention, the minimum and maximum values ​​of the liquid discharge volume are set according to the historical production data of the gas well.

[0063] When the discharge volume is less than the minimum discharge volume, the plunger gas lift operates inefficiently and enters the continuous flow optimization process. The time step is adjusted according to the continuous flow to increase the continuous flow production time and improve the gas well opening rate. After the optimization is completed, the well shut-in pressure recovery stage is entered, and then the next cycle operation is carried out.

[0064] When the discharge volume is greater than the maximum discharge volume, the plunger lift volume is too large and the operation is overloaded. The continuous flow optimization process is also entered. The time step is adjusted according to the continuous flow to shorten the continuous flow production time and improve the stability of the plunger gas lift operation. After the optimization is completed, the well shut-in pressure recovery stage is entered, and then the next cycle operation is carried out.

[0065] This solution determines the discharge volume based on minimum and maximum oil pressures. The continuous flow production time is adjusted based on the discharge volume and the continuous flow adjustment time step. This avoids ineffective well shut-ins and overloaded operation during plunger lift operations without adding additional equipment, improving plunger lift efficiency and operational uptime. Based on the set load factor threshold and discharge volume, the plunger lift well is periodically cycled on and off, automatically optimizing the system and achieving efficient discharge and stable operation.

[0066] In the embodiment of the present invention, after the discharge volume is determined according to the minimum oil pressure and the maximum oil pressure, when the discharge volume is within a preset range, the continuous flow production time is maintained unchanged.

[0067] When the discharge volume is within the preset range, the continuous flow production time is maintained unchanged. After completion, the well shut-in pressure recovery stage is entered, and then the next cycle operation is carried out.

[0068] In step 108 of the embodiment of the present invention, the continuous flow production duration is adjusted according to the discharge volume and the continuous flow adjustment time step. The steps are shown in FIG2 and are specifically as follows:

[0069] Step 201: Set the minimum and maximum liquid discharge volumes based on historical production data of the gas well.

[0070] Step 202: When the discharge volume is less than the minimum discharge volume, the continuous flow production time is increased according to the continuous flow adjustment time step.

[0071] When the discharge volume is less than the minimum discharge volume, the plunger gas lift operates inefficiently and enters the continuous flow optimization process. The time step is adjusted according to the continuous flow to increase the continuous flow production time and improve the gas well opening rate. After the optimization is completed, the well shut-in pressure recovery stage is entered, and then the next cycle operation is carried out.

[0072] Step 203 : when the discharge volume is greater than the maximum discharge volume, shorten the continuous flow production time according to the continuous flow adjustment time step.

[0073] When the discharge volume is greater than the maximum discharge volume, the plunger lift volume is too large and the operation is overloaded. The continuous flow optimization process is also entered. The time step is adjusted according to the continuous flow to shorten the continuous flow production time and improve the stability of the plunger gas lift operation. After the optimization is completed, the well shut-in pressure recovery stage is entered, and then the next cycle operation is carried out.

[0074] The above scheme adjusts the continuous flow production time according to the discharge volume and the continuous flow adjustment time step, and realizes automatic optimization control of the plunger operation without adding equipment, avoiding ineffective well shut-in and liquid lifting overload operation during the plunger gas lift operation, and improving the plunger liquid lifting efficiency and operation normality rate.

[0075] FIG3 is a plunger gas lift operation curve of a gas well provided by an embodiment of the present invention. The plunger gas lift control method provided by the present invention will be described below using this gas well as an example.

[0076] In Figure 3, t1 is the well shut-in process, t2 is the well opening process, P1 is the minimum oil pressure during fluid discharge, P2 is the maximum oil pressure after fluid discharge, P1 is the minimum casing pressure after well opening, ΔP is the value of the casing pressure rising after the gas well begins to accumulate fluid after reaching the minimum value, and t is the set continuous production time.

[0077] In an embodiment of the present invention, 10 to 15 normal operating production cycles that can represent the production characteristics are selected through the historical curve of the gas well, and the plunger lift volume of 0.15 cubic meters is calculated based on P2 and P1. The minimum and maximum discharge volumes of the plunger gas lift of the gas well are set, and the minimum discharge volume is set to 0.08 cubic meters, and the maximum discharge volume is set to 0.3 cubic meters.

[0078] The initial continuous production time t of the gas well is set according to P1 and ΔP on the curve. The continuous production time of this well is set to 5 hours. At the same time, the continuous adjustment time step is set according to the change of ΔP. The continuous increase time is set to 30 minutes, and the continuous reduction time is set to 10 minutes.

[0079] The gas well opening load factor threshold is set according to the oil pressure, casing pressure and back pressure before the gas well is opened. It is set to 0.4 for this well.

[0080] After the setting is completed, the optimization parameters are started. During the well shut-in time t1, the changes in the gas well load coefficient are monitored in real time. When the load coefficient reaches 0.4, the well is opened and enters the t2 production stage.

[0081] During the t2 production phase, the changes in the gas well tubing pressure were monitored in real time. When the minimum oil pressure value appeared, the value was recorded. The plunger discharge volume of this period was calculated based on the minimum and maximum oil pressure values. The discharge volume of this period was 0.16 cubic meters.

[0082] Compare the current cycle's discharge volume with the set minimum and maximum discharge volumes. If the discharge volume is within the preset range, the continuous flow production duration remains unchanged. If the discharge volume is less than the minimum discharge volume, the continuous flow production duration is increased based on the continuous flow adjustment time step. If the discharge volume is greater than the maximum discharge volume, the continuous flow production duration is shortened based on the continuous flow adjustment time step.

[0083] After the continuous flow production time is completed, the well shut-in phase t1 is entered and the next cycle optimization operation begins. Then the operation is repeated periodically to achieve long-term stable operation of the plunger gas lift well.

[0084] After the optimized operation, the optimized operation curve is shown in Figure 4. Without adding any plunger gas lift supporting equipment, the gas well can achieve automatic optimization of parameters, without the need for manual analysis and management, and maintain long-term effective drainage and stable production of the gas well. The daily gas production has increased from 4,000 cubic meters to 13,000 cubic meters, an increase of 75%, and the liquid production has increased from 0.15 cubic meters to 0.48 cubic meters, with a significant production increase effect.

[0085] The present invention also provides a plunger gas lift control system, as described in the following embodiments. The system is shown in FIG5 and includes:

[0086] The setting unit 501 is used to obtain historical production data of the gas well and set the load factor threshold, maximum shut-in time, continuous flow production time and continuous flow adjustment time step according to the historical production data of the gas well;

[0087] The acquisition unit 502 is used to acquire the state parameters of the gas well production in real time;

[0088] The automatic execution unit 503 is used to calculate the load factor according to the state parameters of the gas well production, and to open the well when the load factor reaches a load factor threshold or the shut-in time reaches a maximum shut-in time;

[0089] The control unit 504 is used to determine the minimum and maximum oil pressures during the fluid discharge oscillation. The oil pressure is the pressure at the wellhead oil pipe of the gas well. The fluid discharge volume is determined based on the minimum and maximum oil pressures. When the fluid discharge volume is not within a preset range, the continuous flow production time is adjusted based on the fluid discharge volume and the continuous flow adjustment time step.

[0090] When the plunger gas lift well is in the shut-in state, the automatic execution unit monitors and analyzes the numerical changes of the gas well load coefficient in real time. When the load coefficient reaches the set value range, it executes the well opening command and sends the well opening command to the automatic control valve to realize the well opening.

[0091] After the well is opened, the plunger lifts the accumulated liquid in the wellbore upward. When the lifted liquid reaches the wellhead and is discharged, the pressure in the gas well tubing will show an oscillation feature, first decreasing and then increasing. The amplitude of the pressure oscillation can reflect the amount of liquid discharged from the gas well. When the plunger rises without lifting the accumulated liquid, there is no pressure oscillation feature.

[0092] In the embodiment of the present invention, the state parameters in gas well production include casing pressure, oil pressure, and back pressure. The automatic execution unit 503 is specifically used to:

[0093] The load factor is calculated based on the casing pressure, oil pressure, and back pressure; the casing pressure is the pressure in the wellhead casing annulus; and the back pressure is the pipeline transmission pressure.

[0094] In the embodiment of the present invention, the control unit 504 is further configured to:

[0095] After the discharge volume is determined based on the minimum and maximum oil pressures, when the discharge volume is within a preset range, the continuous flow production time is maintained unchanged.

[0096] In the embodiment of the present invention, the control unit 504 is specifically configured to:

[0097] Set the minimum and maximum discharge volumes based on the historical production data of the gas well;

[0098] When the discharge volume is less than the minimum discharge volume, the continuous flow production time is increased according to the continuous flow adjustment time step;

[0099] When the discharge volume is greater than the maximum discharge volume, the time step is adjusted according to the continuous flow to shorten the continuous flow production time.

[0100] When the plunger lifts the accumulated fluid to the wellhead, the discharge volume is determined based on the minimum and maximum oil pressures. When the discharge volume is within the set range, the continuous flow production time is maintained unchanged. After the continuous flow ends, the shut-in command is executed to enter the shut-in stage. If the discharge volume is less than the minimum discharge volume, it indicates that the well's fluid lifting effect is poor and the plunger is operating inefficiently. The continuous flow production time is increased according to the continuous flow adjustment time step, and the amount of liquid accumulated in the gas wellbore is increased, so that the plunger gas lift is in efficient fluid discharge operation. If the discharge volume is greater than the maximum discharge volume, it indicates that the plunger lifts too much fluid, which can easily cause the plunger to be unable to lift the accumulated fluid, resulting in the lifted fluid falling back to the bottom of the well, and eventually causing liquid accumulation and flooding. At this time, the continuous flow production time is shortened according to the continuous flow adjustment time step to reduce the amount of liquid accumulated in the wellbore. After the continuous flow ends, the shut-in command is executed to enter the shut-in stage.

[0101] In the embodiment of the present invention, the control unit 504 is specifically configured to:

[0102] The specific calculation formula for determining the displacement based on the minimum and maximum oil pressures is as follows: ΔPt=Pt(max)-Pt(min)

[0103] Ql represents the amount of liquid discharged during the plunger gas lift cycle, K represents the correction coefficient, ΔPt represents the pressure difference between the maximum and minimum oil pressures during plunger gas lift discharge, ρ represents the density of the produced liquid, g represents the acceleration of gravity, Pt(max) represents the maximum oil pressure, and Pt(min) represents the minimum oil pressure.

[0104] Since the principle of solving the problem by this system is similar to that of the plunger gas lift control method, the implementation of this system can refer to the implementation of the plunger gas lift control method, and the repeated parts will not be repeated.

[0105] In an embodiment of the present invention, historical production data of the gas well is obtained; a load factor threshold, a maximum shut-in time, a continuous flow production time and a continuous flow adjustment time step are set according to the historical production data of the gas well; state parameters in gas well production are collected in real time; a load factor is calculated according to the state parameters in gas well production; when the load factor reaches the load factor threshold or the shut-in time reaches the maximum shut-in time, well opening is performed; the minimum oil pressure and the maximum oil pressure during liquid discharge oscillation are determined; the oil pressure is the pressure at the wellhead oil pipe of the gas well; the liquid discharge volume is determined according to the minimum oil pressure and the maximum oil pressure; when the liquid discharge volume is not within a preset range, the continuous flow production time is adjusted according to the liquid discharge volume and the continuous flow adjustment time step. Compared with the prior art, the liquid discharge volume is determined according to the minimum oil pressure and the maximum oil pressure; the continuous flow production time is adjusted according to the liquid discharge volume and the continuous flow adjustment time step. Without adding equipment, invalid well shut-in and liquid discharge overload operation in plunger gas lift operation are avoided, thereby improving the plunger liquid discharge efficiency and the normal operation rate. The plunger gas lift well is periodically cycled on and off controlled and automatically optimized according to the set load factor threshold and discharge volume, achieving efficient discharge and stable operation of the plunger gas lift well.

[0106] It will be understood by those skilled in the art that embodiments of the present invention may be provided as methods, systems, or computer program products. Thus, the present invention may take the form of an entirely hardware embodiment, an entirely software embodiment, or an embodiment combining software and hardware. Furthermore, the present invention may take the form of a computer program product implemented on one or more computer-usable storage media (including but not limited to magnetic disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0107] The present invention is described with reference to the flowcharts and / or block diagrams of the methods, devices (systems), and computer program products according to embodiments of the present invention. It should be understood that each process and / or box in the flowchart and / or block diagram, as well as the combination of processes and / or boxes in the flowchart and / or block diagram, 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 for implementing the functions specified in one or more processes in the flowchart and / or one or more boxes in the block diagram.

[0108] These computer program instructions may also be stored in a computer-readable memory that can direct a computer or other programmable data processing device to operate in a specific manner, so that the instructions stored in the computer-readable memory produce a product including an instruction device that implements the functions specified in one or more processes in the flowchart and / or one or more boxes in the block diagram.

[0109] These computer program instructions can also be loaded onto a computer or other programmable data processing device so that a series of operating steps are executed on the computer or other programmable device to produce a computer-implemented process, so that the instructions executed on the computer or other programmable device provide steps for implementing the functions specified in one or more processes in the flowchart and / or one or more boxes in the block diagram.

[0110] 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.

Claims

1. A plunger gas lift control method, characterized in that: include: Obtain historical production data of gas wells; According to the historical production data of the gas well, the load factor threshold, the maximum shut-in time, the continuous flow production time and the continuous flow adjustment time step are set; Real-time collection of state parameters during gas well production; Calculate the load factor based on the state parameters in gas well production; When the load factor reaches the load factor threshold or the well shut-in time reaches the maximum well shut-in time, the well is controlled to be opened; Determine the minimum and maximum oil pressures during the discharge shock; the oil pressure is the pressure at the wellhead oil pipe of the gas well; Determine the discharge volume based on the minimum and maximum oil pressures; When the discharge volume is not within the preset range, the continuous flow production time is adjusted according to the discharge volume and the continuous flow adjustment time step.

2. The plunger gas lift control method according to claim 1, characterized in that: The state parameters in gas well production include casing pressure, oil pressure, and back pressure. The load factor is calculated based on the state parameters in gas well production, including: The load coefficient is calculated based on the casing pressure, oil pressure and back pressure; the casing pressure is the pressure at the wellhead casing annulus; the back pressure is the pipeline transmission pressure.

3. The plunger gas lift control method according to claim 1, characterized in that: After determining the amount of fluid to be discharged based on the minimum and maximum oil pressures, it also includes: When the discharge volume is within the preset range, the continuous flow production time is maintained unchanged.

4. The plunger gas lift control method according to claim 1, characterized in that: The adjusting of the continuous flow production time according to the discharge volume and the continuous flow adjustment time step includes: Set the minimum and maximum discharge volume according to the historical production data of the gas well; When the discharge volume is less than the minimum discharge volume, the continuous flow production time is increased according to the continuous flow adjustment time step; When the discharge volume is greater than the maximum discharge volume, the time step is adjusted according to the continuous flow to shorten the continuous flow production time.

5. The plunger gas lift control method according to claim 1, characterized in that: The specific calculation formula for determining the discharge volume based on the minimum and maximum oil pressures is as follows: ΔPt=Pt(max)-Pt(min) Ql represents the amount of liquid discharged during the plunger gas lift cycle, K represents the correction coefficient, ΔPt represents the pressure difference between the maximum oil pressure and the minimum oil pressure during plunger gas lift discharge, ρ represents the density of the produced liquid, g represents the acceleration of gravity, Pt(max) represents the maximum oil pressure, and Pt(min) represents the minimum oil pressure.

6. A computer device comprising a memory, a processor and a computer program stored in the memory and executable on the processor, characterized in that: When the processor executes the computer program, the following plunger gas lift control method is implemented: Obtain historical production data of gas wells; According to the historical production data of the gas well, the load factor threshold, the maximum shut-in time, the continuous flow production time and the continuous flow adjustment time step are set; Real-time collection of state parameters during gas well production; Calculate the load factor based on the state parameters in gas well production; When the load factor reaches the load factor threshold or the well shut-in time reaches the maximum well shut-in time, the well is controlled to be opened; Determine the minimum and maximum oil pressures during the discharge shock; the oil pressure is the pressure at the wellhead oil pipe of the gas well; Determine the discharge volume based on the minimum and maximum oil pressures; When the discharge volume is not within the preset range, the continuous flow production time is adjusted according to the discharge volume and the continuous flow adjustment time step.

7. The computer device according to claim 6, characterized in that The state parameters in gas well production include casing pressure, oil pressure, and back pressure. The load factor is calculated based on the state parameters in gas well production, including: The load coefficient is calculated based on the casing pressure, oil pressure and back pressure; the casing pressure is the pressure at the wellhead casing annulus; the back pressure is the pipeline transmission pressure.

8. The computer device according to claim 6, characterized in that After determining the amount of fluid to be discharged based on the minimum and maximum oil pressures, it also includes: When the discharge volume is within the preset range, the continuous flow production time is maintained unchanged.

9. The computer device according to claim 6, characterized in that The adjusting of the continuous flow production time according to the discharge volume and the continuous flow adjustment time step comprises: Set the minimum and maximum discharge volume according to the historical production data of the gas well; When the discharge volume is less than the minimum discharge volume, the continuous flow production time is increased according to the continuous flow adjustment time step; When the discharge volume is greater than the maximum discharge volume, the time step is adjusted according to the continuous flow to shorten the continuous flow production time.

10. The computer device according to claim 6, wherein: The specific calculation formula for determining the discharge volume based on the minimum and maximum oil pressures is as follows: ΔPt=Pt(max)-Pt(min) Ql represents the amount of liquid discharged during the plunger gas lift cycle, K represents the correction coefficient, ΔPt represents the pressure difference between the maximum oil pressure and the minimum oil pressure during plunger gas lift discharge, ρ represents the density of the produced liquid, g represents the acceleration of gravity, Pt(max) represents the maximum oil pressure, and Pt(min) represents the minimum oil pressure.

11. A computer-readable storage medium, characterized in that: The computer readable storage medium stores a computer program, and when the computer program is executed by the processor, the following plunger gas lift control method is implemented: Obtain historical production data of gas wells; According to the historical production data of the gas well, the load factor threshold, the maximum shut-in time, the continuous flow production time and the continuous flow adjustment time step are set; Real-time collection of state parameters during gas well production; Calculate the load factor based on the state parameters in gas well production; When the load factor reaches the load factor threshold or the well shut-in time reaches the maximum well shut-in time, the well is controlled to be opened; Determine the minimum and maximum oil pressures during the discharge shock; the oil pressure is the pressure at the wellhead oil pipe of the gas well; Determine the discharge volume based on the minimum and maximum oil pressures; When the discharge volume is not within the preset range, the continuous flow production time is adjusted according to the discharge volume and the continuous flow adjustment time step.

12. The computer-readable storage medium of claim 11, wherein: The state parameters in gas well production include casing pressure, oil pressure, and back pressure. The load factor is calculated based on the state parameters in gas well production, including: The load coefficient is calculated based on the casing pressure, oil pressure and back pressure; the casing pressure is the pressure at the wellhead casing annulus; the back pressure is the pipeline transmission pressure.

13. The computer-readable storage medium of claim 11, wherein: After determining the amount of fluid to be discharged based on the minimum and maximum oil pressures, it also includes: When the discharge volume is within the preset range, the continuous flow production time is maintained unchanged.

14. The computer-readable storage medium of claim 11, wherein: The adjusting of the continuous flow production time according to the discharge volume and the continuous flow adjustment time step comprises: Set the minimum and maximum discharge volume according to the historical production data of the gas well; When the discharge volume is less than the minimum discharge volume, the continuous flow production time is increased according to the continuous flow adjustment time step; When the discharge volume is greater than the maximum discharge volume, the time step is adjusted according to the continuous flow to shorten the continuous flow production time.

15. The computer-readable storage medium of claim 11, wherein: The specific calculation formula for determining the discharge volume based on the minimum and maximum oil pressures is as follows: ΔPt=Pt(max)-Pt(min) Ql represents the amount of liquid discharged during the plunger gas lift cycle, K represents the correction coefficient, ΔPt represents the pressure difference between the maximum oil pressure and the minimum oil pressure during plunger gas lift discharge, ρ represents the density of the produced liquid, g represents the acceleration of gravity, Pt(max) represents the maximum oil pressure, and Pt(min) represents the minimum oil pressure.

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