Parameter prediction method and device for gas well circulating gas lift fluid discharge, electronic equipment, storage medium and program product

Abstract

This application provides a method, apparatus, electronic device, storage medium, and program product for predicting parameters of gas well circulating gas lift drainage. The method includes: acquiring basic data of gas well circulating gas lift drainage; dividing the gas well circulating gas lift drainage process into stages based on the basic data and generating stage information; calculating adjustment parameters for each stage based on the basic data and stage information; and adjusting and optimizing each stage of gas well circulating drainage based on the adjustment parameters to generate optimization results, thereby improving drainage efficiency.

Description

Technical Field

[0001] This application relates to the field of oil and gas production, and in particular to a method, apparatus, electronic equipment, storage medium and program product for predicting parameters of circulating gas lift fluid discharge in gas wells. Background Technology

[0002] In oil and gas field development, gas wells often experience fluid accumulation problems during long-term production, leading to the formation of fluid buildup within the wellbore. This fluid buildup increases bottomhole flowing pressure, hinders the effective lifting of the gas-liquid mixture, and ultimately causes a decline in gas well production or even shutdown. To address this issue, the circulating gas lift-drainage gas production process is widely adopted.

[0003] In existing technologies, high-pressure gas is injected into the wellbore to reduce the density of the liquid column, thereby pushing the accumulated liquid out and restoring normal gas well production. During gas lift operations, multiple process parameters need to be monitored in real time.

[0004] However, in the existing technology, the monitoring and adjustment of process parameters require manual monitoring and adjustment, which leads to a decrease in drainage efficiency. Summary of the Invention

[0005] This application provides a method, apparatus, electronic device, storage medium, and program product for predicting parameters of circulating gas lift drainage in gas wells, in order to improve drainage efficiency.

[0006] In a first aspect, embodiments of this application provide a method for predicting parameters of circulating gas lift fluid discharge in gas wells, including:

[0007] Obtain basic data on circulating gas lift fluid discharge from gas wells;

[0008] Based on the basic data of gas well circulating gas lift fluid drainage, the gas well circulating gas lift fluid drainage process is divided into stages, and stage information is generated.

[0009] The adjustment parameters for each stage are calculated based on the basic data of the gas well circulation gas lift fluid discharge and the stage information.

[0010] The various stages of gas well circulation and drainage are adjusted and optimized based on the aforementioned adjustment parameters to generate optimization results.

[0011] In one possible implementation, when the stage information is a gas injection stage, the step of calculating the adjustment parameters for each stage based on the basic data of the gas well circulation gas lift and drainage and the stage information includes: calculating and generating the wellhead injection pressure based on the basic data of the gas well circulation gas lift and drainage using a static gas column pressure algorithm; calculating and generating the gas injection volume and gas injection time for the gas injection stage based on the wellhead injection pressure; and determining the gas injection volume and gas injection time for the gas injection stage as the adjustment parameters for the gas injection stage.

[0012] In one possible implementation, when the stage information is an overflow stage, the step of calculating the adjustment parameters for each stage based on the basic data of the gas well circulation gas lift drainage and the stage information includes: calculating the gas injection volume of the overflow stage based on the basic data of the gas well circulation gas lift drainage; calculating the completion time of the overflow stage based on the gas injection volume of the overflow stage; calculating the overflow flow rate based on the completion time of the overflow stage; and determining the overflow flow rate as the adjustment parameter for the overflow stage.

[0013] In one possible implementation, the stage information refers to the stage where gas-lifted gas enters the tubing. This stage includes a first stage of wellbore fluid discharge and a second stage of reaching the target flowing pressure. The calculation of adjustment parameters for each stage based on the basic data of the gas well circulation gas-lift fluid discharge and the stage information includes: initializing injection parameters and tubing and formation parameters based on the basic data of the gas well circulation gas-lift fluid discharge; calculating and generating adjustment parameters for the first stage using a gas-liquid phase flow algorithm based on the initialized injection parameters and tubing and formation parameters; calculating and generating adjustment parameters for the second stage using a gas-liquid phase flow algorithm based on the adjustment parameters for the first stage and the initialized tubing and formation parameters; and determining the adjustment parameters for the gas-lifted gas entering the tubing stage based on the adjustment parameters for the first stage and the adjustment parameters for the second stage.

[0014] In one possible implementation, the step of calculating and generating the adjustment parameters for the first stage using a gas-liquid phase flow algorithm based on the initialized gas injection parameters, tubing, and formation parameters includes: iteratively calculating the initialized gas injection parameters, tubing, and formation parameters using the gas-liquid phase flow algorithm at preset time intervals to generate iterated wellbore fluid accumulation and bottom hole flowing pressure; determining whether the iterated wellbore fluid accumulation and bottom hole flowing pressure meet preset thresholds; and if the iterated wellbore fluid accumulation and bottom hole flowing pressure meet the preset thresholds, then determining the iterated formation parameters and the cumulative gas injection volume of the first stage as the adjustment parameters for the first stage.

[0015] In one possible implementation, the step of generating the adjustment parameters for the second stage using a gas-liquid phase flow algorithm based on the adjustment parameters of the first stage and the initialized tubing and formation parameters includes: calculating the formation gas production flow rate and formation water production flow rate corresponding to the initial flowing pressure based on the adjustment parameters of the first stage and the initialized tubing and formation parameters; calculating the total gas production rate and the bottom hole flowing pressure of the second stage based on the formation gas production flow rate, the formation water production flow rate, and the gas injection rate of the second stage; and adjusting the gas injection rate and target flowing pressure of the second stage based on the total gas production rate and the bottom hole flowing pressure of the second stage to generate the adjustment parameters for the second stage.

[0016] Secondly, embodiments of this application provide a parameter prediction device for circulating gas lift fluid discharge in gas wells, comprising:

[0017] The acquisition module is used to acquire basic data on circulating gas lift fluid discharge from gas wells;

[0018] The segmentation module is used to divide the gas well circulating gas lift liquid discharge process into stages based on the basic data of gas well circulating gas lift liquid discharge and generate stage information.

[0019] The calculation module is used to calculate the adjustment parameters for each stage based on the basic data of the gas well circulating gas lift and the stage information;

[0020] The optimization module is used to adjust and optimize each stage of gas well circulation and drainage according to the adjustment parameters, and generate optimization results.

[0021] Thirdly, embodiments of this application provide an electronic device, including: a memory and a processor;

[0022] The memory stores computer-executed instructions;

[0023] The processor executes computer execution instructions stored in the memory, causing the processor to perform the first aspect and / or various possible implementations of the first aspect as described above.

[0024] Fourthly, embodiments of this application provide a computer-readable storage medium storing computer-executable instructions, which, when executed by a processor, are used to implement the first aspect and / or various possible implementations of the first aspect.

[0025] Fifthly, embodiments of this application provide a computer program product, including a computer program that, when executed by a processor, implements the first aspect and / or various possible implementations of the first aspect.

[0026] The parameter prediction method, device, electronic equipment, storage medium, and program product for circulating gas lift drainage of gas wells provided in this application embodiment acquire basic data of circulating gas lift drainage of gas wells, divide and identify the continuous circulating gas lift drainage process into stages, calculate the corresponding adjustment parameters for each stage, and adjust and optimize each stage according to the adjustment parameters, thereby improving drainage efficiency. Attached Figure Description

[0027] The accompanying drawings, which are incorporated in and form part of this specification, illustrate embodiments consistent with this application and, together with the description, serve to explain the principles of this application.

[0028] Figure 1 This is a schematic diagram of the system structure of a computer device provided in an embodiment of this application;

[0029] Figure 2Flowchart of the parameter prediction method for gas well circulating gas lift fluid discharge provided in this application Figure 1 ;

[0030] Figure 3 Flowchart of the parameter prediction method for gas well circulating gas lift fluid discharge provided in this application Figure 2 ;

[0031] Figure 4 Flowchart of the parameter prediction method for gas well circulating gas lift fluid discharge provided in this application Figure 3 ;

[0032] Figure 5 Flowchart of the parameter prediction method for gas well circulating gas lift fluid discharge provided in this application Figure 4 ;

[0033] Figure 6 A schematic diagram of the parameter prediction device for gas well circulating gas lift fluid discharge provided in this application;

[0034] Figure 7 A schematic diagram of the structure of the electronic device provided in this application.

[0035] The accompanying drawings illustrate specific embodiments of this application, which will be described in more detail below. These drawings and descriptions are not intended to limit the scope of the concept in any way, but rather to illustrate the concept of this application to those skilled in the art through reference to particular embodiments. Detailed Implementation

[0036] Exemplary embodiments will now be described in detail, examples of which are illustrated in the accompanying drawings. When the following description relates to the drawings, unless otherwise indicated, the same numbers in different drawings denote the same or similar elements. The embodiments described in the following exemplary embodiments do not represent all embodiments consistent with this application. Rather, they are merely examples of apparatuses and methods consistent with some aspects of this application as detailed in the appended claims.

[0037] First, let me explain the terms used in this application:

[0038] Gas lift: refers to an artificial oil extraction method that uses high-pressure gas injected into the wellbore to reduce the density of the liquid column and lift crude oil to the surface.

[0039] Gas lift drainage gas production: Gas lift drainage gas production is a gas production process that involves injecting high-pressure gas into the wellbore and using the gas expansion energy to lift the liquid accumulated at the bottom of the well to the surface.

[0040] In oil and gas field development, gas wells often experience fluid accumulation within the wellbore during long-term production, leading to fluid buildup. This fluid buildup increases bottomhole flowing pressure, hinders the effective lifting of the gas-liquid mixture, and ultimately causes a decline in well production or even shutdown. To address this issue, circulating gas lift drainage technology is widely adopted. Current technology involves injecting high-pressure gas into the wellbore to reduce the liquid column density, thereby discharging the accumulated fluid and restoring normal well production. During gas lift operations, multiple process parameters need to be monitored in real time. However, in existing technologies, the monitoring and adjustment of these parameters require manual intervention, resulting in reduced drainage efficiency.

[0041] To solve the above-mentioned technical problems, the present application proposes the following technical concept: The inventors considered dividing the process of circulating gas lift drainage into stages, using the characteristics of multiphase flow to calculate the adjustment parameters of each stage, and adjusting and optimizing according to the adjustment parameters corresponding to each stage, thereby improving the drainage efficiency.

[0042] Figure 1 This is a schematic diagram of the system architecture of the computer device provided in an embodiment of this application. Figure 1 As shown, the computer device includes: a receiving device 101, a processing device 102, and a display device 103.

[0043] It is understood that the structures illustrated in the embodiments of this application do not constitute a specific limitation on the parameter prediction method for gas well circulating gas lift drainage. In other feasible embodiments of this application, the above architecture may include more or fewer components than illustrated, or combine some components, or split some components, or arrange different components, which can be determined according to the actual application scenario and is not limited here. Figure 1 The components shown can be implemented in hardware, software, or a combination of both.

[0044] In the specific implementation process, the receiving device 101 can be an input / output interface or a communication interface, which can acquire the basic data of gas well circulating gas lift liquid discharge.

[0045] The processing device 102 can calculate the adjustment parameters for each stage of the gas well circulation gas lift drainage.

[0046] The display device 103 can be used to display the adjustment parameters for each of the above stages.

[0047] The display device can also be a touch screen, used to receive user commands while displaying the above content, so as to realize the operation interaction with the user.

[0048] It should be understood that the above-mentioned processing device can be implemented by a processor reading instructions from memory and executing those instructions, or it can be implemented by a chip circuit.

[0049] Furthermore, the network architecture and business scenarios described in the embodiments of this application are for the purpose of more clearly illustrating the technical solutions of the embodiments of this application, and do not constitute a limitation on the technical solutions provided in the embodiments of this application. As those skilled in the art will know, with the evolution of network architecture and the emergence of new business scenarios, the technical solutions provided in the embodiments of this application are also applicable to similar technical problems.

[0050] Figure 2 Flowchart of the parameter prediction method for gas well circulating gas lift fluid discharge provided in this application Figure 1 ,like Figure 2 As shown, the method includes:

[0051] S201: Obtain basic data for circulating gas lift fluid discharge from gas wells.

[0052] In this embodiment, the basic data for gas well circulation gas lift fluid discharge includes, but is not limited to, the fluid accumulation height. Deepening of oil pipes Depth of the middle layer Liquid production index Gas production index Initial bottom hole flowing pressure Maximum bottomhole flowing pressure during gas lift process Airlift target flow pressure Inner diameter of oil pipe , outer diameter Inner diameter of the casing cross-sectional area of ​​oil pipe Circular cross-sectional area Water production density Instantaneous flow rate of injected gas Injection gas density and the density of the produced gas .

[0053] S202: Based on the basic data of gas well circulating gas lift drainage, the gas well circulating gas lift drainage process is divided into stages, and stage information is generated.

[0054] In this embodiment, the stages of gas well circulation gas lift drainage include the period from the start of gas injection to overflow at the tubing wellhead, the period from the start of overflow to the gas lift gas entering the tubing, and the period from the gas lift gas entering the tubing to the achievement of the target flow pressure.

[0055] S203: Calculate the adjustment parameters for each stage based on the basic data and stage information of the gas well circulating gas lift drainage.

[0056] Specifically, when the stage information is the gas injection stage, the adjustment parameters for the gas injection stage are calculated using the static gas column pressure algorithm.

[0057] Specifically, when the stage information is the overflow stage, the gas injection volume, the completion time of the overflow stage, and the overflow flow rate are calculated, and the overflow flow rate is determined as the adjustment parameter of the overflow stage.

[0058] Specifically, when the stage information is the stage of gas lift gas entering the tubing, it is divided into the first stage of wellbore fluid discharge and the second stage of reaching the target flowing pressure, and the adjustment parameters for the first stage and the second stage are calculated.

[0059] S204: Adjust and optimize each stage of gas well circulation and drainage based on the adjustment parameters, and generate optimization results.

[0060] For example, the periodic gas injection volume to be adjusted during the parameter prediction phase. Represented as:

[0061]

[0062] The gas injection parameters for the entire cycle are adjusted based on the predicted gas injection volume for each of the three stages.

[0063] As can be seen from the above embodiments, by acquiring the basic data of circulating gas lift drainage from gas wells, the continuous circulating gas lift drainage process is divided into stages and identified. The adjustment parameters for each stage are calculated, and each stage is adjusted and optimized based on the adjustment parameters, thereby improving the drainage efficiency.

[0064] Figure 3 Flowchart of the parameter prediction method for gas well circulating gas lift fluid discharge provided in this application Figure 2 When the stage information is the gas injection stage, step S203 includes:

[0065] S301: The wellhead injection pressure is calculated and generated based on the basic data of gas well circulation gas lift and drainage using the static gas column pressure algorithm.

[0066] Specifically, the bottom pressure of the injection well (i.e., the gas pressure on the annular fluid surface) at the time of overflow is calculated based on the basic data. and the depth of the annular fluid level when overflow occurs The wellhead injection pressure is obtained based on the bottom hole pressure, annular fluid level depth, and the properties of the injected gas. .

[0067] Among them, bottom hole pressure The calculation formula is:

[0068]

[0069] Among them, the depth of the annular liquid level The calculation formula is:

[0070]

[0071]

[0072] In the formula, This indicates the amount of fluid entering the oil pipe when an overflow occurs; This indicates the amount of fluid that entered the formation before the overflow occurred; Indicates the gas injection time during the gas injection phase; This represents the bottom pressure of the injection well at time t during the gas injection phase. This indicates the liquid production index.

[0073] Among them, the maximum bottom hole flowing pressure during the gas lift process The calculation formula is:

[0074]

[0075] In the formula, Indicates wellhead back pressure; Represents gravitational acceleration; This indicates the pressure drop caused by the wellhead check valve and nozzles, which allow fluid to flow from the wellbore into the surface pipeline network.

[0076] S302: Calculate the gas injection volume and injection time for the gas injection stage based on the wellhead injection pressure.

[0077] In this embodiment, the gas injection volume during the gas injection phase is expressed as: .

[0078] Specifically, the temperature and pressure during the gas injection stage are obtained, and based on the obtained temperature and pressure values, the volume of gas is calculated. The standard volume of the injected gas is... .

[0079] In this embodiment, the gas injection time during the gas injection phase is expressed as: .

[0080] Among them, the gas injection volume during the gas injection phase The calculation formula is:

[0081]

[0082] In the formula, This indicates the instantaneous flow rate of the injected gas during the injection phase as a function of time.

[0083] Specifically, based on the gas injection volume during the gas injection phase Calculate the injection time during the injection phase. .

[0084] S303: The gas injection volume and gas injection time during the gas injection phase are determined as the adjustment parameters for the gas injection phase.

[0085] Specifically, the predicted parameter is the gas injection volume during the gas injection phase. and injection time The predicted parameters are used as adjustment parameters to adjust the gas injection process.

[0086] As can be seen from the above embodiments, the wellhead injection pressure is calculated by the static gas column pressure algorithm, and the core operating parameters of the gas injection stage, namely the gas injection volume and gas injection time, are calculated based on the wellhead injection pressure, which provides a calculation basis for the gas injection start-up process and improves the drainage efficiency.

[0087] Figure 4 Flowchart of the parameter prediction method for gas well circulating gas lift fluid discharge provided in this application Figure 3 When the stage information is the overflow stage, step S203 includes:

[0088] S401: Calculate the gas injection volume during the overflow stage based on the basic data of gas well circulation gas lift drainage.

[0089] Specifically, based on the bottom hole flowing pressure Gas injection wellbore bottom pressure when overflow occurs The average value is used to calculate the volume. The volume of gas under standard conditions is the injection volume during the overflow phase. .

[0090] S402: Calculate the completion time of the overflow stage based on the gas injection volume during the overflow stage.

[0091] In this embodiment, the gas injection volume during the overflow stage is The completion time of the overflow phase is .

[0092] in, The calculation formula is:

[0093]

[0094] In the formula, This indicates the flow rate of gas injected during the overflow phase.

[0095] S403: Calculate the overflow flow rate based on the completion time of the overflow phase.

[0096] Specifically, calculate the amount of fluid flowing into the formation. and the amount of overflow liquid The overflow flow rate is calculated based on the amount of fluid flowing into the formation and the amount of fluid flowing out. .

[0097] Among them, the amount of fluid flowing into the formation is calculated. The formula is:

[0098]

[0099] Among them, the outflow overflow volume is calculated. The formula is:

[0100]

[0101] In the formula, This indicates the depth of the annular liquid level at the end of the overflow phase.

[0102] Among them, the overflow flow rate is calculated. The formula is:

[0103]

[0104] S404: Determine the overflow flow rate as the adjustment parameter for the overflow stage.

[0105] Specifically, the overflow process is adjusted based on the gas injection volume during the overflow phase, the completion time of the overflow phase, the amount of fluid flowing into the formation, the amount of fluid flowing out of the overflow phase, and the overflow flow rate.

[0106] As can be seen from the above embodiments, by calculating the gas injection volume of the overflow stage based on the basic data of gas well circulation gas lift drainage, calculating the completion time of the overflow stage based on the gas injection volume, calculating the overflow flow rate based on the completion time of the overflow stage, and adjusting the parameters of the overflow stage based on the overflow flow rate, the quantitative description of the overflow dynamic process and the prediction of overflow stage parameters are realized, thereby improving the drainage efficiency.

[0107] Figure 5 Flowchart of the parameter prediction method for gas well circulating gas lift fluid discharge provided in this application Figure 4 When the stage information is "gas lift gas enters the tubing stage", step S203 includes:

[0108] S501: Initialize the gas injection parameters, tubing and formation parameters based on the basic data of gas well circulation gas lift fluid discharge.

[0109] In this embodiment, the initialization parameters for gas injection and tubing and formation parameters include, but are not limited to, tubing cross-sectional area, initial wellbore fluid volume, target bottom hole flowing pressure, constant instantaneous gas injection rate, wellhead oil pressure, initial bottom hole flowing pressure, formation gas production, water production capacity coefficient, and time step.

[0110] S502: The adjustment parameters for the first stage are calculated and generated based on the initial gas injection parameters, tubing and formation parameters using a gas-liquid phase flow algorithm.

[0111] Specifically, based on the set number of iterations, combined with the initialized gas injection parameters and tubing and formation parameters, the formation production, total gas volume entering the tubing, gas injection and liquid discharge volume and cumulative liquid discharge volume at the current time step are calculated, tubing fluid density, bottom hole flowing pressure and remaining wellbore fluid volume are determined, and it is determined whether the wellbore fluid volume is less than or equal to 0 or the bottom hole flowing pressure is reduced to the target flowing pressure. If either condition is met, the iterative calculation is stopped, and the adjustment parameters for the first stage are output: the completion time of the first stage, the gas injection volume of the first stage, the bottom hole flowing pressure of the first stage, the wellbore fluid state and other formation dynamic parameters.

[0112] S503: The adjustment parameters for the second stage are calculated and generated based on the adjustment parameters of the first stage and the initialized tubing and formation parameters using a gas-liquid phase flow algorithm.

[0113] Specifically, based on the adjustment parameters of the first stage and the initialized tubing and formation parameters, the formation gas production flow rate, formation water production flow rate, total gas production, and bottom hole flowing pressure of the second stage corresponding to the initial flowing pressure are calculated. The gas injection rate and target flowing pressure of the second stage are adjusted based on the total gas production and the bottom hole flowing pressure of the second stage to generate the adjustment parameters of the second stage.

[0114] S504: Determine the adjustment parameters for the gas lift gas entering the tubing stage based on the adjustment parameters of the first stage and the adjustment parameters of the second stage.

[0115] In this embodiment, the cumulative gas injection volume during the gas lift gas entering the tubing stage is... The formula is:

[0116]

[0117] In the formula, Indicates the target bottom hole flowing pressure; This represents the instantaneous injection volume during the wellbore fluid discharge phase at time t.

[0118] In this embodiment, the adjustment parameter for the gas lift gas entering the tubing stage is the sum of the adjustment parameters for the first stage and the adjustment parameters for the second stage, expressed as follows:

[0119]

[0120] As can be seen from the above embodiments, by dividing the gas lift gas into the tubing stage into two sub-stages, and by initializing parameters and applying the gas-liquid phase flow algorithm to calculate the adjustment parameters of the two sub-stages step by step, the relationship between gas injection and formation production can be coordinated more effectively, so as to achieve the goal of wellbore drainage and pressure recovery through the optimal path.

[0121] In one embodiment of this application, step S502 includes:

[0122] S5021: The gas-liquid phase flow algorithm iteratively calculates the initialized gas injection parameters, tubing and formation parameters according to a preset time interval to generate the iterated wellbore liquid accumulation and bottom hole flowing pressure.

[0123] Specifically, design wellhead oil pressure ,by Gas flow rate, overflow liquid volume The initial fluid volume is based on the wellhead oil pressure. Starting from this point, calculate the bottom hole flowing pressure. .

[0124] In this embodiment, the wellhead oil pressure The calculation formula is:

[0125]

[0126] In this embodiment, the time interval The value can be:

[0127]

[0128] In the formula, This indicates the instantaneous flow rate of the injected gas.

[0129] Specifically, the change in tubing fluid column density after the first time interval was calculated. and bottom hole flowing pressure .

[0130] Among them, the change in fluid column density in the tubing was calculated. The formula is:

[0131]

[0132] Among them, the bottom hole flowing pressure is calculated. The formula is:

[0133]

[0134] In the formula, This represents the tubing fluid density during the first time interval; This indicates the volume of injected gas at the bottom of the well during the first time interval of the wellbore fluid discharge phase. This indicates the gas phase flow rate under bottom hole flowing pressure conditions; Indicates the compression factor; Indicates the temperature of the wellhead tubing; Indicates the target bottom hole flowing pressure; Indicates the temperature at the depth of the tubing; Indicates the gas flow rate inside the oil pipe; This indicates the instantaneous injection volume during the wellbore fluid discharge phase. Indicates the flow rate of natural gas produced from the formation; This represents the bottom hole pressure that varies with time t.

[0135] Specifically, calculate the amount of fluid accumulated in the tubing after the second time interval. Changes in oil column density in tubing and bottom hole flowing pressure .

[0136] Among them, the change in fluid column density in the tubing was calculated. The formula is:

[0137]

[0138] In the formula, This indicates the volume of injected gas at the bottom of the well during the second time interval of the wellbore fluid discharge phase.

[0139] Among them, the bottom hole flowing pressure is calculated. The formula is:

[0140]

[0141] In the formula, This indicates the tubing fluid density during the second time interval; This represents the formation water production rate; n represents the number of time intervals.

[0142] Among them, the amount of fluid accumulated in the tubing after the second time interval is calculated. The formula is:

[0143]

[0144] S5022: Determine whether the wellbore fluid accumulation and bottom hole flowing pressure after iteration meet the preset threshold.

[0145] Specifically, calculate the instantaneous wellbore fluid accumulation and tubing fluid accumulation. And determine whether the amount of fluid accumulated in the oil pipe is less than or equal to 0.

[0146] Among them, the instantaneous wellbore fluid volume is calculated. The formula is:

[0147]

[0148] In the formula, This indicates the instantaneous flow rate of air-lift drainage.

[0149] in, The initial value is greater than Gradually approaching over time .

[0150] S5023: If the wellbore fluid accumulation and bottom hole flowing pressure after iteration meet the preset threshold, then the formation parameters after iteration and the cumulative gas injection volume of the first stage are determined as the adjustment parameters of the first stage.

[0151] Specifically, when the amount of fluid accumulated in the tubing is less than or equal to 0, the cumulative gas injection volume during the fluid discharge stage in the wellbore is calculated, and the cumulative gas injection volume during the fluid discharge stage in the wellbore is determined as the adjustment parameter for the first stage.

[0152] In this embodiment, the amount of fluid accumulated in the oil pipe The calculation formula is:

[0153]

[0154] In this embodiment, the cumulative gas injection volume during the wellbore fluid discharge stage .

[0155] Among them, the cumulative gas injection volume is calculated. The formula is:

[0156]

[0157] In the formula, Indicates the completion time of the wellbore fluid discharge stage; This indicates the instantaneous injection volume during the wellbore fluid discharge phase.

[0158] As can be seen from the above embodiments, by combining the gas-liquid phase flow algorithm with time intervals for iterative calculation, this method dynamically simulates the change of liquid accumulation as the drainage process progresses, realizes real-time quantitative tracking of drainage progress, and improves drainage efficiency.

[0159] In one embodiment of this application, step S503 includes:

[0160] S5031: Based on the adjustment parameters of the first stage and the initialized tubing and formation parameters, calculate the formation gas production flow rate and formation water production flow rate corresponding to the initial flowing pressure.

[0161] In this embodiment, the formation gas production flow rate includes the natural gas flow rate and the total gas production.

[0162] In this embodiment, the formula for calculating the natural gas flow rate is:

[0163]

[0164] In the formula, This represents the bottom hole pressure that varies with time t.

[0165] In this embodiment, the formula for calculating the formation water production rate is:

[0166]

[0167] In this embodiment, the formula for calculating the total gas production is:

[0168]

[0169] S5032: Calculate the total gas production and bottom hole flowing pressure of the second stage based on the formation gas production flow rate, formation water production flow rate, and the gas injection volume of the second stage.

[0170] Specifically, in the stage of achieving the target flowing pressure, the wellhead oil pressure is used as the reference. Starting from the gas-liquid two-phase flow algorithm, the bottom hole flowing pressure at the target flowing pressure realization stage is calculated. .

[0171] Specifically, the minimum fluid carrying capacity is calculated under the bottom hole flowing pressure condition during the target flowing pressure achievement stage. .

[0172] The formula for calculating the minimum liquid carrying capacity is:

[0173]

[0174] In the formula, This indicates the minimum gas velocity required to carry droplets out of the wellbore under bottom-hole conditions. This indicates the density of natural gas under the current bottom-hole flow conditions.

[0175] Specifically, if Less than Then increase until satisfied Greater than or equal to ,and .

[0176] In this embodiment, the total gas volume flow rate under bottom hole flow conditions The calculation formula is:

[0177]

[0178] Specifically, calculation Injection volume and time interval .

[0179]

[0180] Specifically, calculate the new gas injection volume. Until the flow pressure drops to the target value The amount of gas injected at this time This refers to the steady-state gas injection rate under the target flow pressure. .

[0181]

[0182] S5033: Adjust the gas injection volume and target flow pressure of the second stage based on the total gas production and the bottom-hole flowing pressure of the second stage to generate the adjustment parameters for the second stage.

[0183] Specifically, when the following conditions are met Greater than or equal to ,and Determine the steady-state gas injection rate for the second stage; the steady-state gas injection rate for the second stage is the adjustment parameter for the second stage.

[0184] As can be seen from the above embodiments, by combining formation parameters with the second-stage gas injection volume, the total gas production and target bottom hole flowing pressure of the second stage are calculated, and the gas injection volume and target flowing pressure are adjusted according to the calculation results. This ensures that formation energy is fully utilized in the process of reaching the target flowing pressure, and the gas injection volume is intelligently adjusted, thereby improving the drainage efficiency.

[0185] Figure 6 A schematic diagram of the parameter prediction device for gas well circulating gas lift fluid discharge provided in this application is shown below. Figure 6 As shown, the parameter prediction device 60 for gas well circulating gas lift drainage provided in this embodiment includes: an acquisition module 601, a division module 602, a calculation module 603, and an optimization module 604.

[0186] The acquisition module 601 is used to acquire basic data on gas well circulating gas lift fluid discharge.

[0187] The segmentation module 602 is used to segment the gas well circulating gas lift drainage process into stages based on the basic data of gas well circulating gas lift drainage, and generate stage information.

[0188] The calculation module 603 is used to calculate the adjustment parameters for each stage based on the basic data and stage information of the gas well circulating gas lift drainage.

[0189] The optimization module 604 is used to adjust and optimize each stage of the gas well circulation drainage according to the adjustment parameters and generate optimization results.

[0190] In one embodiment of this application, when the stage information is the gas injection stage, the calculation module 603 includes:

[0191] The first calculation unit is used to calculate and generate the wellhead injection pressure based on the basic data of gas well circulation gas lift and drainage using the static gas column pressure algorithm.

[0192] The second calculation unit is used to calculate the gas injection volume and injection time during the gas injection stage based on the wellhead injection pressure.

[0193] The first determining unit is used to determine the gas injection volume and gas injection time during the gas injection stage as adjustment parameters for the gas injection stage.

[0194] In one embodiment of this application, when the stage information is an overflow stage, the calculation module 603 further includes:

[0195] The third calculation unit is used to calculate the gas injection volume during the overflow stage based on the basic data of gas well circulation gas lift drainage.

[0196] The fourth calculation unit is used to calculate the completion time of the overflow stage based on the gas injection volume of the overflow stage.

[0197] The fifth calculation unit is used to calculate the overflow flow rate based on the completion time of the overflow phase.

[0198] The second determining unit is used to determine the overflow flow rate as the adjustment parameter for the overflow stage.

[0199] In one embodiment of this application, when the stage information is the stage where gas lift gas enters the tubing, the calculation module 603 further includes:

[0200] The initialization unit is used to initialize the gas injection parameters and tubing and formation parameters based on the basic data of gas well circulation gas lift and fluid discharge.

[0201] The sixth calculation unit is used to calculate and generate the adjustment parameters for the first stage based on the initialized gas injection parameters and the tubing and formation parameters using a gas-liquid phase flow algorithm.

[0202] The seventh calculation unit is used to calculate and generate the adjustment parameters for the second stage based on the adjustment parameters of the first stage and the initialized tubing and formation parameters using a gas-liquid phase flow algorithm.

[0203] The third determining unit is used to determine the adjustment parameters for the gas lift gas entering the tubing stage based on the adjustment parameters of the first stage and the adjustment parameters of the second stage.

[0204] In one embodiment of this application, the sixth computing unit includes:

[0205] The first calculation subunit is used to iteratively calculate the initialized gas injection parameters, tubing and formation parameters according to a preset time interval using a gas-liquid phase flow algorithm, and generate the iterated wellbore liquid accumulation and bottom hole flowing pressure.

[0206] The judgment sub-unit is used to determine whether the wellbore fluid accumulation and bottom hole flowing pressure after iteration meet the preset threshold.

[0207] The first determining sub-unit is used to determine the iterated formation parameters and the cumulative gas injection volume of the first stage as the adjustment parameters of the first stage if the wellbore fluid accumulation and bottom hole flowing pressure after iteration meet the preset threshold.

[0208] In one embodiment of this application, the seventh computing unit includes:

[0209] The second calculation subunit is used to calculate the formation gas production flow rate and formation water production flow rate corresponding to the initial flowing pressure, based on the adjustment parameters of the first stage and the initialized tubing and formation parameters.

[0210] The third calculation subunit is used to calculate the total gas production and the bottom hole flowing pressure of the second stage based on the formation gas production flow rate, formation water production flow rate, and the gas injection volume of the second stage.

[0211] The adjustment subunit is used to adjust the gas injection rate and target flow pressure of the second stage based on the total gas production and the bottom hole flowing pressure of the second stage, and to generate the adjustment parameters for the second stage.

[0212] The parameter prediction device for circulating gas lift drainage of gas wells provided in this embodiment can execute the method provided in the above method embodiment. Its implementation principle and technical effect are similar, and will not be described in detail here.

[0213] Figure 7 A schematic diagram of the structure of the electronic device provided in this application. Figure 7 As shown, the electronic device 70 provided in this embodiment includes at least one processor 701 and a memory 702. Optionally, the electronic device 70 further includes a communication component 703. The processor 701, memory 702, and communication component 703 are connected via a bus.

[0214] In the specific implementation process, at least one processor 701 executes computer execution instructions stored in memory 702, causing at least one processor 701 to execute the above-mentioned parameter prediction method for gas well circulating gas lift drainage.

[0215] The specific implementation process of processor 701 can be found in the above method embodiments, and its implementation principle and technical effect are similar. It will not be repeated here.

[0216] In the above embodiments, it should be understood that the processor can be a Central Processing Unit (CPU), or other general-purpose processors, digital signal processors (DSPs), application-specific integrated circuits (ASICs), etc. The general-purpose processor can be a microprocessor or any conventional processor. The steps of the method disclosed in this invention can be directly implemented by a hardware processor, or implemented by a combination of hardware and software modules within the processor.

[0217] The memory may include random access memory (RAM) and may also include non-volatile memory (NVM), such as at least one disk storage device.

[0218] The bus can be an Industry Standard Architecture (ISA) bus, a Peripheral Component Interconnect (PCI) bus, or an Extended Industry Standard Architecture (EISA) bus, etc. Buses can be categorized as address buses, data buses, control buses, etc. For ease of illustration, the buses shown in the accompanying drawings are not limited to a single bus or a single type of bus.

[0219] This application also provides a computer program product, including a computer program that, when executed by a processor, implements the above-described method for predicting parameters of gas well circulating gas lift drainage.

[0220] This application also provides a computer-readable storage medium storing computer-executable instructions, which, when executed by a processor, implement the above-described method for predicting parameters of gas well circulating gas lift drainage.

[0221] The aforementioned readable storage medium can be implemented by any type of volatile or non-volatile storage device or a combination thereof, such as static random access memory (SRAM), electrically erasable programmable read-only memory (EEPROM), erasable programmable read-only memory (EPROM), programmable read-only memory (PROM), read-only memory (ROM), magnetic storage, flash memory, magnetic disk, or optical disk. The readable storage medium can be any available medium accessible to a general-purpose or special-purpose computer.

[0222] An exemplary readable storage medium is coupled to a processor, enabling the processor to read information from and write information to the readable storage medium. Of course, the readable storage medium can also be a component of the processor. The processor and the readable storage medium can reside in an Application Specific Integrated Circuit (ASIC). Alternatively, the processor and the readable storage medium can exist as discrete components in the device.

[0223] The division of units is merely a logical functional division; in actual implementation, there may be other division methods. For example, multiple units or components may be combined or integrated into another system, or some features may be ignored or not executed. Furthermore, the coupling or direct coupling or communication connection shown or discussed may be indirect coupling or communication connection through some interfaces, devices, or units, and may be electrical, mechanical, or other forms.

[0224] The units described as separate components may or may not be physically separate. The components shown as units may or may not be physical units; that is, they may be located in one place or distributed across multiple network units. Some or all of the units can be selected to achieve the purpose of this embodiment according to actual needs.

[0225] In addition, the functional units in the various embodiments of the present invention can be integrated into one processing unit, or each unit can exist physically separately, or two or more units can be integrated into one unit.

[0226] If a function is implemented as a software functional unit and sold or used as an independent product, it can be stored in a computer-readable storage medium. Based on this understanding, the technical solution of this invention, or the part that contributes to the prior art, or a part of the technical solution, can be embodied in the form of a software product. This computer software product is stored in a storage medium and includes several instructions to cause a computer device (which may be a personal computer, server, or network device, etc.) to execute all or part of the steps of the methods of the various embodiments of this invention. The aforementioned storage medium includes various media capable of storing program code, such as USB flash drives, portable hard drives, read-only memory (ROM), random access memory (RAM), magnetic disks, or optical disks.

[0227] Those skilled in the art will understand that all or part of the steps of the above-described method embodiments can be implemented by hardware related to program instructions. The aforementioned program can be stored in a computer-readable storage medium. When executed, the program performs the steps of the above-described method embodiments; and the aforementioned storage medium includes various media capable of storing program code, such as ROM, RAM, magnetic disks, or optical disks.

[0228] Finally, it should be noted that other embodiments of the invention will readily occur to those skilled in the art upon consideration of the specification and practice of the invention disclosed herein. This invention is intended to cover any variations, uses, or adaptations of the invention that follow the general principles of the invention and include common knowledge or customary techniques in the art not disclosed herein, and is not limited to the precise structures described above and shown in the accompanying drawings, and various modifications and changes can be made without departing from its scope. The scope of the invention is limited only by the appended claims.

Claims

1. A method for predicting parameters of circulating gas lift fluid discharge in gas wells, characterized in that, include: Obtain basic data on circulating gas lift fluid discharge from gas wells; Based on the basic data of gas well circulating gas lift fluid drainage, the gas well circulating gas lift fluid drainage process is divided into stages, and stage information is generated. The adjustment parameters for each stage are calculated based on the basic data of the gas well circulation gas lift fluid discharge and the stage information. The various stages of gas well circulation and drainage are adjusted and optimized based on the aforementioned adjustment parameters to generate optimization results; The stage information refers to the stage when the gas lift gas enters the tubing, which includes the first stage of wellbore fluid discharge and the second stage of reaching the target flowing pressure. The calculation of adjustment parameters for each stage based on the basic data of the gas well circulating gas lift fluid discharge and the stage information includes: Initialize the gas injection parameters, tubing, and formation parameters based on the basic data of the gas well circulation gas lift fluid discharge. The first-stage adjustment parameters are generated by calculating the initial gas injection parameters, tubing and formation parameters using a gas-liquid phase flow algorithm. The adjustment parameters for the second stage are calculated and generated using a gas-liquid phase flow algorithm based on the adjustment parameters of the first stage and the initialized tubing and formation parameters. The adjustment parameters for the gas lift gas entering the tubing stage are determined based on the adjustment parameters of the first stage and the adjustment parameters of the second stage.

2. The method according to claim 1, characterized in that, When the stage information is the gas injection stage, the calculation of adjustment parameters for each stage based on the basic data of the gas well's circulating gas lift and fluid discharge and the stage information includes: The wellhead injection pressure is calculated and generated based on the basic data of the gas well circulation gas lift and fluid discharge using the static gas column pressure algorithm. The injection volume and injection time for the gas injection stage are calculated based on the wellhead injection pressure. The gas injection volume and gas injection time in the gas injection stage are determined as the adjustment parameters for the gas injection stage.

3. The method according to claim 1, characterized in that, When the stage information is the overflow stage, the calculation of adjustment parameters for each stage based on the basic data of the gas well circulating gas lift drainage and the stage information includes: The gas injection volume during the overflow stage is calculated based on the basic data of the gas well circulation gas lift drainage. The completion time of the overflow stage is calculated based on the gas injection volume during the overflow stage. Calculate the overflow flow rate based on the completion time of the overflow phase; The overflow flow rate is determined as the adjustment parameter for the overflow stage.

4. The method according to claim 1, characterized in that, The process of generating the first-stage adjustment parameters using a gas-liquid phase flow algorithm based on initialized gas injection parameters and tubing and formation parameters includes: The gas-liquid phase flow algorithm iteratively calculates the initial gas injection parameters, tubing and formation parameters according to a preset time interval to generate the iterative wellbore liquid accumulation and bottom hole flowing pressure. Determine whether the wellbore fluid accumulation and bottom hole flowing pressure after the iteration meet the preset thresholds; If the wellbore fluid accumulation and bottomhole flowing pressure after the iteration meet the preset threshold, then the iterated formation parameters and the cumulative gas injection volume of the first stage are determined as the adjustment parameters of the first stage.

5. The method according to claim 1, characterized in that, The process of generating the second-stage adjustment parameters using a gas-liquid phase flow algorithm based on the adjustment parameters of the first stage and the initialized tubing and formation parameters includes: Based on the adjustment parameters of the first stage and the initialized tubing and formation parameters, calculate the formation gas production flow rate and formation water production flow rate corresponding to the initial flowing pressure. Calculate the total gas production and the bottom hole flowing pressure of the second stage based on the formation gas production flow rate, the formation water production flow rate, and the gas injection volume of the second stage. The gas injection rate and target flow pressure for the second stage are adjusted based on the total gas production and the bottom-hole flowing pressure of the second stage to generate the adjustment parameters for the second stage.

6. A parameter prediction device for circulating gas lift fluid discharge in gas wells, characterized in that, include: The acquisition module is used to acquire basic data on gas well circulating gas lift fluid discharge. The segmentation module is used to divide the gas well circulating gas lift liquid discharge process into stages based on the basic data of gas well circulating gas lift liquid discharge and generate stage information. The calculation module is used to calculate the adjustment parameters for each stage based on the basic data of the gas well circulating gas lift and the stage information; The optimization module is used to adjust and optimize each stage of gas well circulation and drainage according to the adjustment parameters, and generate optimization results. The stage information refers to the stage when gas-lifted gas enters the tubing. This stage includes a first stage of wellbore fluid discharge and a second stage of reaching the target flowing pressure. The calculation module is specifically used to initialize injection parameters, tubing, and formation parameters based on the basic data of the gas well's circulating gas-lift fluid discharge. It then calculates and generates adjustment parameters for the first stage using a gas-liquid phase flow algorithm based on the initialized injection parameters and tubing and formation parameters. Finally, it calculates and generates adjustment parameters for the second stage using the same algorithm. Finally, it determines the adjustment parameters for the gas-lifted gas entering the tubing stage based on the adjustment parameters for the first and second stages.

7. An electronic device, characterized in that, include: Memory, processor; The memory stores computer-executed instructions; The processor executes computer execution instructions stored in the memory, causing the processor to perform the parameter prediction method for gas well circulating gas lift drainage as described in any one of claims 1 to 5.

8. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores computer-executable instructions, which, when executed by a processor, are used to implement the parameter prediction method for gas well circulating gas lift drainage as described in any one of claims 1 to 5.

9. A computer program product, characterized in that, The invention includes a computer program that, when executed by a processor, implements the parameter prediction method for gas well circulating gas lift drainage as described in any one of claims 1 to 5.

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