WO2024255065A1 - 柱塞气举控制方法及系统 - Google Patents

柱塞气举控制方法及系统 Download PDF

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Publication number
WO2024255065A1
WO2024255065A1 PCT/CN2023/127392 CN2023127392W WO2024255065A1 WO 2024255065 A1 WO2024255065 A1 WO 2024255065A1 CN 2023127392 W CN2023127392 W CN 2023127392W WO 2024255065 A1 WO2024255065 A1 WO 2024255065A1
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Prior art keywords
pressure
continuous flow
oil pressure
maximum
discharge volume
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Ceased
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PCT/CN2023/127392
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English (en)
French (fr)
Inventor
李旭日
田伟
刘毅
解永刚
王宪文
常永峰
贾友亮
王亦璇
李耀德
杨亚聪
惠艳妮
李彦彬
宋洁
龚航飞
谷诏闯
李丽
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Petrochina Co Ltd
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Petrochina Co Ltd
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Publication of WO2024255065A1 publication Critical patent/WO2024255065A1/zh
Anticipated expiration legal-status Critical
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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
    • E21B43/121—Lifting well fluids
    • E21B43/122—Gas lift
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/06—Measuring temperature or pressure
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
    • F04B—POSITIVE-DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS
    • F04B47/00—Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps

Definitions

  • the present invention relates to the technical field of plunger gas lift, and in particular to a plunger gas lift control method and system.
  • the plunger gas lift technology controls the plunger liquid lifting operation by setting appropriate operating parameters.
  • the commonly used control method is the timed and constant pressure well switching method. It requires manual calculation and setting of operating parameters based on the energy recovery of the gas well and the liquid volume. The setting process is labor-intensive and if the analysis is not timely or accurate, it will affect the technical effect.
  • An embodiment of the present invention provides a plunger gas lift control method for improving plunger liquid lift efficiency and normal operation rate, the method comprising:
  • the load factor threshold, the maximum shut-in time, the continuous flow production time and the continuous flow adjustment time step are set;
  • the well is controlled to be opened;
  • the oil pressure is the pressure at the wellhead oil pipe of the gas well
  • the continuous flow production time is adjusted according to the discharge volume and the continuous flow adjustment time step.
  • An embodiment of the present invention further provides a computer device, including a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor implements the following plunger gas lift control method when executing the computer program:
  • the load factor threshold, the maximum shut-in time, the continuous flow production time and the continuous flow adjustment time step are set;
  • the well is controlled to be opened;
  • the oil pressure is the pressure at the wellhead oil pipe of the gas well
  • the continuous flow production time is adjusted according to the discharge volume and the continuous flow adjustment time step.
  • An embodiment of the present invention further provides a computer-readable storage medium, wherein the computer-readable storage medium stores a computer program, and when the computer program is executed by a processor, the following plunger gas lift control method is implemented:
  • the load factor threshold, the maximum shut-in time, the continuous flow production time and the continuous flow adjustment time step are set;
  • the well is controlled to be opened;
  • the oil pressure is the pressure at the wellhead oil pipe of the gas well
  • the continuous flow production time is adjusted according to the discharge volume and the continuous flow adjustment time step.
  • 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; the 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, the well is opened; the minimum oil pressure and the maximum oil pressure during the fluid discharge oscillation are determined; the oil pressure is the pressure at the wellhead oil pipe of the gas well; the fluid discharge volume is determined according to the minimum oil pressure and the maximum oil pressure; when the fluid discharge volume is not within a preset range, the continuous flow production time step is adjusted according to the fluid discharge volume and the continuous flow adjustment time step.
  • the fluid discharge volume is determined according to the minimum oil pressure and the maximum oil pressure; the continuous flow production is adjusted according to the fluid discharge volume and the continuous flow adjustment time step. Time, without adding equipment, to avoid invalid well shut-in and overload operation of plunger gas lift, improve plunger lift efficiency and normal operation rate. According to the set load factor threshold and discharge volume, the plunger gas lift well is periodically cycled and automatically optimized to achieve efficient discharge and stable operation of the plunger gas lift well.
  • FIG1 is a schematic flow chart of a plunger gas lift control method provided by the present invention.
  • FIG2 is a schematic flow chart of a plunger gas lift control method provided by the present invention.
  • FIG3 is a schematic diagram of a plunger gas lift operation curve of a gas well provided by the present invention.
  • FIG4 is a schematic diagram of the plunger gas lift operation curve after optimization of the gas well provided by the present invention.
  • FIG5 is a schematic diagram of a plunger gas lift control system provided by the present invention.
  • FIG. 1 is a flow chart of a plunger gas lift control method according to an embodiment of the present invention. As shown in FIG. 1 , the method includes:
  • Step 101 obtaining historical production data of gas wells.
  • Step 102 setting the load factor threshold, maximum shut-in time, continuous production time and continuous adjustment time step according to the historical production data of the gas well.
  • the gas well operation parameters are analyzed, and the load factor threshold, maximum shut-in time, continuous flow production time and continuous flow adjustment time step are set.
  • the duration of continuous production is determined according to the change of casing pressure during the continuous production period.
  • the gas well After the plunger lifts the liquid to the wellhead, the gas well enters the continuous production stage, and the change of casing pressure of the gas well is monitored in real time.
  • the time for opening the well is determined as the continuous production time.
  • the setting basis is the increase in casing pressure during the continuous production process, that is, the increase in the oil-casing pressure difference reflects that liquid accumulation has begun to appear in the gas well.
  • Step 103 collect state parameters of the gas well during production in real time.
  • Step 104 calculating the load factor according to the state parameters in the gas well production.
  • the state parameters in gas well production include casing pressure, oil pressure and back pressure.
  • casing pressure refers to the pressure in the wellhead casing annulus; the back pressure refers to the pipeline transmission pressure.
  • 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 pressure after wellhead throttling, i.e., the back pressure.
  • 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 for plunger lift.
  • the ratio of the two is the comparison between resistance and power. The smaller the value, the more favorable it is to the plunger liquid lift operation.
  • Step 105 when the load factor reaches a load factor threshold or the well shut-in duration reaches a maximum well shut-in duration, opening the well is performed.
  • the load coefficient is monitored and analyzed in real time.
  • 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.
  • Step 106 determining the minimum and maximum oil pressures during the discharge oscillation.
  • Oil pressure is the pressure at the oil pipe at the wellhead of the gas well.
  • Step 107 determining the amount of fluid discharged according to the minimum oil pressure and the maximum oil pressure.
  • 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.
  • the oil pressure reaches the minimum value and then increases, the discharge shock occurs, and the discharge volume is automatically calculated based on the pressure difference between the minimum oil pressure and the maximum oil pressure.
  • Ql represents the amount of liquid discharged during the plunger gas lift cycle
  • K represents the correction coefficient
  • ⁇ Pt represents the pressure difference between the maximum oil pressure and the minimum oil pressure during plunger gas lift discharge
  • ⁇ represents the density of the produced liquid
  • g represents the acceleration of gravity
  • Pt(max) represents the maximum oil pressure
  • Pt(min) represents the minimum oil pressure.
  • Step 108 when the discharge volume is not within the preset range, adjusting the continuous flow production time according to the discharge volume and the continuous flow adjustment time step.
  • the minimum and maximum values of the liquid discharge volume are set according to the historical production data of the gas well.
  • the plunger gas lift 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 continuous flow production time is increased according to the continuous flow adjustment time step to 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.
  • the plunger lifts too much liquid and is overloaded, and the flow optimization process is also entered.
  • the flow optimization time step is adjusted according to the flow to shorten the flow production time and improve the operation stability of the plunger gas lift. After the optimization is completed, the well shut-in pressure recovery stage is entered before the next cycle is carried out.
  • the above scheme determines the discharge volume according to the minimum and maximum oil pressures; adjusts the continuous flow production time according to the discharge volume and the continuous flow adjustment time step, and avoids invalid well shut-in and liquid lifting overload operation during plunger gas lift operation without adding equipment, thereby improving the plunger lift efficiency and normal operation rate.
  • the plunger gas lift well is periodically cycled and switched on and off and automatically optimized according to the set load factor threshold and discharge volume, achieving efficient liquid discharge and stable operation of the plunger gas lift well.
  • the continuous flow production time is kept unchanged.
  • 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, and the step flow is shown in FIG2 , and is specifically as follows:
  • Step 201 setting a minimum and a maximum discharge volume according to historical production data of the gas well.
  • 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.
  • the plunger gas lift 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 continuous flow production time is increased according to the continuous flow adjustment time step to 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.
  • 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.
  • the plunger lifts too much liquid and is overloaded, and the flow optimization process is also entered.
  • the flow optimization time step is adjusted according to the flow to shorten the flow production time and improve the operation stability of the plunger gas lift. After the optimization is completed, the well shut-in pressure recovery stage is entered before the next cycle is carried out.
  • the above scheme adjusts the continuous flow production time according to the discharge volume and the continuous flow adjustment time step, realizes automatic optimization control of the plunger operation without adding equipment, avoids invalid well shut-in and liquid lifting overload operation during plunger gas lift operation, and improves the plunger lifting efficiency and normal operation rate.
  • FIG3 is a plunger gas lift operation curve of a gas well provided in an embodiment of the present invention.
  • the plunger gas lift control method provided in the present invention is described below using the gas well as an example.
  • t1 is the well closing 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
  • ⁇ P is the increase in casing pressure after the gas well begins to accumulate fluid after the casing pressure reaches the minimum value
  • t is the set continuous production time.
  • 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.
  • the initial continuous flow production time t of the gas well is set according to P1 and ⁇ P on the curve.
  • the continuous flow production time of this well is set to 5 hours.
  • the continuous flow adjustment time step is set according to the change of ⁇ P.
  • the continuous flow increase time is set to 30 minutes, and the continuous flow reduction time is set to 10 minutes.
  • 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, and it is set to 0.4 for this well.
  • the optimization parameters are started.
  • the changes in the load coefficient of the gas well are monitored in real time.
  • the load coefficient reaches 0.4, the well is opened and enters the t2 production stage.
  • the changes in the gas well tubing pressure are monitored in real time. When the minimum oil pressure appears, the value is recorded. When the minimum oil pressure appears, the value is recorded at the same time.
  • the plunger discharge volume of this cycle is calculated based on the minimum oil pressure and the maximum oil pressure. The discharge volume of this cycle is 0.16 cubic meters.
  • 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.
  • the optimized operation curve is shown in Figure 4.
  • 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.
  • the present invention also provides a plunger gas lift control system, as described in the following embodiments.
  • the system is shown in FIG5 , and the system includes:
  • the setting unit 501 is used to obtain the historical production data of the gas well, and set the load factor threshold, the maximum shut-in time, the continuous flow production time and the continuous flow adjustment time step according to the historical production data of the gas well;
  • the acquisition unit 502 is used to acquire the state parameters of the gas well production in real time
  • the automatic execution unit 503 is used to calculate the load factor according to the state parameters in the gas well production, and to open the well when the load factor reaches the load factor threshold or the well shut-in time reaches the maximum well shut-in time;
  • the control unit 504 is used to determine the minimum and maximum oil pressures during the fluid discharge oscillations.
  • 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.
  • the automatic execution unit monitors and analyzes the numerical changes of the gas well load coefficient in real time.
  • the load coefficient reaches the set numerical range, the well opening command is executed and sent to the automatic control valve to realize the well opening.
  • the plunger lifts the accumulated liquid in the wellbore upward.
  • the pressure in the gas well tubing will show an oscillation feature of first decreasing and then increasing.
  • the amplitude of the pressure oscillation can reflect the amount of liquid discharged from the gas well.
  • the state parameters in the gas well production include casing pressure, oil pressure, and back pressure.
  • the automatic execution unit 503 is specifically used for:
  • 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.
  • control unit 504 is further configured to:
  • the continuous flow production time is maintained unchanged.
  • control unit 504 is specifically used for:
  • the continuous flow production time is increased according to the continuous flow adjustment time step
  • the time step is adjusted according to the continuous flow to shorten the continuous flow production time.
  • the discharge volume is determined according to the minimum and maximum oil pressures. When the discharge volume is within the set range, the continuous flow production time is kept unchanged. After the continuous flow ends, the well shut-in command is executed to enter the well shut-in stage. If the discharge volume is less than the minimum discharge volume, it indicates that the well has a poor lifting effect and the plunger is inefficient.
  • the continuous flow production time is increased to increase the amount of liquid accumulated in the gas wellbore, so that the plunger gas lift is in efficient liquid discharge operation; if the discharge volume is greater than the maximum discharge volume, it indicates that the plunger lifts too much liquid, and it is easy to cause the plunger to lift the accumulated liquid, resulting in the liquid falling back to the bottom of the well, and eventually causing the accumulated liquid to flood.
  • the continuous flow production time is shortened to reduce the amount of liquid accumulated in the wellbore.
  • control unit 504 is specifically used for:
  • Ql represents the amount of liquid discharged during the plunger gas lift cycle
  • K represents the correction coefficient
  • ⁇ Pt represents the pressure difference between the maximum oil pressure and the minimum oil pressure during plunger gas lift discharge
  • ⁇ represents the density of the produced liquid
  • g represents the acceleration of gravity
  • Pt(max) represents the maximum oil pressure
  • Pt(min) represents the minimum oil pressure.
  • 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; the 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, the well is opened; the minimum oil pressure and the maximum oil pressure during the fluid discharge oscillation are determined; the oil pressure is the pressure at the wellhead oil pipe of the gas well; the fluid discharge volume is determined according to the minimum oil pressure and the maximum oil pressure; when the fluid discharge volume is not within a preset range, the continuous flow production time step is adjusted according to the fluid discharge volume and the continuous flow adjustment time step.
  • the fluid discharge volume is determined according to the minimum oil pressure and the maximum oil pressure; the continuous flow production is adjusted according to the fluid discharge volume and the continuous flow adjustment time step. Time, without adding equipment, to avoid invalid well shut-in and overload operation of plunger gas lift, improve plunger lift efficiency and normal operation rate. According to the set load factor threshold and discharge volume, the plunger gas lift well is periodically cycled and automatically optimized to achieve efficient discharge and stable operation of the plunger gas lift well.
  • embodiments of the present invention may be provided as methods, systems, or computer program products. Therefore, the present invention may take the form of a complete hardware embodiment, a complete software embodiment, or an embodiment combining software and hardware. Moreover, 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 disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.
  • computer-usable storage media including but not limited to disk storage, CD-ROM, optical storage, etc.
  • each process and/or box in the flowchart and/or block diagram, as well as the combination of the process and/or box 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.
  • 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 work in a specific manner, so that the instructions stored in the computer-readable memory produce a manufactured 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.
  • These computer program instructions may also be loaded onto a computer or other programmable data processing device so that a series of operational steps are executed on the computer or other programmable device to produce a computer-implemented process, whereby 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.

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Abstract

一种柱塞气举控制方法，包括：获取气井历史生产数据；根据气井历史生产数据设定载荷系数阈值、最大关井时长、续流生产时长及续流调整时间步长；实时采集气井生产中的状态参数；根据气井生产中的状态参数计算载荷系数；在载荷系数达到载荷系数阈值或关井时长达到最大关井时长时，执行开井；确定排液震荡时油压最小值及油压最大值；油压为气井井口油管处的压力；根据油压最小值及油压最大值确定排液量；在排液量不处于预设范围内时，根据排液量及续流调整时间步长调整续流生产时长。还包括一种计算机设备和一种计算机可读存储介质。该方法、计算机和计算机可读存储介质可根据设定载荷系数阈值和排液量对柱塞气举井进行周期性循环开关控制和自动优化，实现柱塞气举井高效排液和稳定运行。

Description

柱塞气举控制方法及系统 技术领域
本发明涉及柱塞气举技术领域，尤其涉及柱塞气举控制方法及系统。
背景技术
本部分旨在为权利要求书中陈述的本发明实施例提供背景或上下文。此处的描述不因为包括在本部分中就承认是现有技术。
柱塞气举技术通过设定合适运行参数来控制柱塞举液运行，目前常用的控制方式为定时、定压开关井方法，需要人工根据气井能量恢复情况和液量判断，定期计算设定运行参数，设定过程工作量大，当分析不及时或不准确时，会影响技术效果。
随着柱塞气举应用井数增多，由于人工调参工作量大、控制精细化不足，现有的控制方法不能满足控制需要，使气井出现积液水淹，影响气井产能发挥，降低气井采收率，因此，亟需柱塞气举控制，用以解决上述问题。
发明内容
本发明实施例提供一种柱塞气举控制方法，用以提高柱塞举液效率和运行正常率，该方法包括：
获取气井历史生产数据；
根据气井历史生产数据设定载荷系数阈值、最大关井时长、续流生产时长及续流调整时间步长；
实时采集气井生产中的状态参数；
根据气井生产中的状态参数计算载荷系数；
在载荷系数达到载荷系数阈值或关井时长达到最大关井时长时，控制执行开井；
确定排液震荡时油压最小值及油压最大值；油压为气井井口油管处的压力；
根据油压最小值及油压最大值确定排液量；
在排液量不处于预设范围内时，根据排液量及续流调整时间步长调整续流生产时长。
本发明实施例还提供一种计算机设备，包括存储器、处理器及存储在存储器上并可在处理器上运行的计算机程序，所述处理器执行所述计算机程序时实现如下柱塞气举控制方法：
获取气井历史生产数据；
根据气井历史生产数据设定载荷系数阈值、最大关井时长、续流生产时长及续流调整时间步长；
实时采集气井生产中的状态参数；
根据气井生产中的状态参数计算载荷系数；
在载荷系数达到载荷系数阈值或关井时长达到最大关井时长时，控制执行开井；
确定排液震荡时油压最小值及油压最大值；油压为气井井口油管处的压力；
根据油压最小值及油压最大值确定排液量；
在排液量不处于预设范围内时，根据排液量及续流调整时间步长调整续流生产时长。
本发明实施例还提供一种计算机可读存储介质，所述计算机可读存储介质存储有计算机程序，所述计算机程序被处理器执行时实现如下柱塞气举控制方法：
获取气井历史生产数据；
根据气井历史生产数据设定载荷系数阈值、最大关井时长、续流生产时长及续流调整时间步长；
实时采集气井生产中的状态参数；
根据气井生产中的状态参数计算载荷系数；
在载荷系数达到载荷系数阈值或关井时长达到最大关井时长时，控制执行开井；
确定排液震荡时油压最小值及油压最大值；油压为气井井口油管处的压力；
根据油压最小值及油压最大值确定排液量；
在排液量不处于预设范围内时，根据排液量及续流调整时间步长调整续流生产时长。
本发明实施例中，获取气井历史生产数据；根据气井历史生产数据设定载荷系数阈值、最大关井时长、续流生产时长及续流调整时间步长；实时采集气井生产中的状态参数；根据气井生产中的状态参数计算载荷系数；在载荷系数达到载荷系数阈值或关井时长达到最大关井时长时，执行开井；确定排液震荡时油压最小值及油压最大值；油压为气井井口油管处的压力；根据油压最小值及油压最大值确定排液量；在排液量不处于预设范围内时，根据排液量及续流调整时间步长调整续流生产时长，与现有技术相比，根据油压最小值及油压最大值确定排液量；根据排液量及续流调整时间步长调整续流生产 时间，在不增加设备情况下，避免柱塞气举运行中无效关井和举液过载运行，提高了柱塞举液效率和运行正常率。根据设定载荷系数阈值和排液量对柱塞气举井进行周期性循环开关控制和自动优化，实现柱塞气举井高效排液和稳定运行。
附图说明
为了更清楚地说明本发明实施例或现有技术中的技术方案，下面将对实施例或现有技术描述中所需要使用的附图作简单地介绍，显而易见地，下面描述中的附图仅仅是本发明的一些实施例，对于本领域普通技术人员来讲，在不付出创造性劳动的前提下，还可以根据这些附图获得其他的附图。在附图中：
图1为本发明提供的柱塞气举控制方法的流程示意图；
图2为本发明提供的柱塞气举控制方法的流程示意图；
图3为本发明提供的气井的柱塞气举运行曲线的示意图；
图4为本发明提供的气井优化后的柱塞气举运行曲线的示意图；
图5为本发明提供的柱塞气举控制系统的示意图。
具体实施方式
为使本发明实施例的目的、技术方案和优点更加清楚明白，下面结合附图对本发明实施例做进一步详细说明。在此，本发明的示意性实施例及其说明用于解释本发明，但并不作为对本发明的限定。
图1为本发明实施例提供的一种柱塞气举控制方法所对应的流程示意图，如图1所示，该方法包括：
步骤101，获取气井历史生产数据。
步骤102，根据气井历史生产数据设定载荷系数阈值、最大关井时长、续流生产时长及续流调整时间步长。
根据气井历史生产数据，分析气井运行参数，设定载荷系数阈值、最大关井时长、续流生产时长及续流调整时间步长。
本发明实施例中，续流生产时长是根据套管压力在续流生产时间段变化来确定。柱塞举液到达井口后，气井进入续流阶段，实时监测气井套管压力变化情况，当套管压力 出现升高时，则确定所开井的时间为续流生产时长，设定依据是续流生产过程中套管压力升高，即油套压差增大反映气井开始出现积液。
步骤103，实时采集气井生产中的状态参数。
步骤104，根据气井生产中的状态参数计算载荷系数。
气井生产中的状态参数包括套压、油压、回压。
根据套压、油压、回压计算载荷系数。
需要说明的是，其中，套压为井口油套环空处的压力；回压为管线输压。
采用关井套压和关井油压的差值与关井套压和井口节流后压力即回压的差值之比值计算载荷系数。
关井套压和关井油压的差值反映气井井筒积液情况，为柱塞气举运行的阻力，关井套压和井口节流后压力的差值反映柱塞举升提供纯动力，两者比值为阻力和动力的对比，其值越小对柱塞举液运行越有利。
步骤105，在载荷系数达到载荷系数阈值或关井时长达到最大关井时长时，执行开井。
柱塞气举井在关井状态下，实时监测分析载荷系数，当达到设定的载荷系数阈值后，执行开井；若一直无法达到载荷系数阈值，则在关井时长达到最大关井时长时，执行开井。
步骤106，确定排液震荡时油压最小值及油压最大值。
油压为气井井口油管处的压力。
步骤107，根据油压最小值及油压最大值确定排液量。
开井后，监测柱塞举液到达井口信息，实时跟踪分析气井油压变化，当油压出现最小值后再升高，即出现排液震荡，根据油压最小值和油压最大值之间压差自动计算排液量。
具体计算公式如下：

ΔPt＝Pt(max)-Pt(min)
Ql表示柱塞气举周期排液量，K表示修正系数，ΔPt表示柱塞气举排液时油压最大值与油压最小值之间的压差值，ρ表示产出液体密度，g表示重力加速度，Pt(max)表示油压最大值，Pt(min)表示油压最小值。
步骤108，在排液量不处于预设范围内时，根据排液量及续流调整时间步长调整续流生产时长。
本发明实施例中，根据气井历史生产数据设定排液量最小值和排液量最大值。
当排液量小于排液量最小值时，柱塞气举低效举液运行，进入续流优化流程，根据续流调整时间步长增加续流生产时长，提高气井开井时率，优化完成后，进入关井压力恢复阶段，之后再进行下个周期运行。
当排液量大于排液量最大值时，柱塞举液量过大，超负荷运行，同样进入续流优化流程，根据续流调整时间步长缩短续流生产时长，提升柱塞气举运行稳定性，优化完成后，进入关井压力恢复阶段，之后再进行下个周期运行。
上述方案，根据油压最小值及油压最大值确定排液量；根据排液量及续流调整时间步长调整续流生产时间，在不增加设备情况下，避免柱塞气举运行中无效关井和举液过载运行，提高了柱塞举液效率和运行正常率。根据设定载荷系数阈值和排液量对柱塞气举井进行周期性循环开关控制和自动优化，实现柱塞气举井高效排液和稳定运行。
本发明实施例在根据油压最小值及油压最大值确定排液量之后，在排液量处于预设范围内时，则保持续流生产时长不变。
在排液量处于预设范围内时，则保持续流生产时长不变，完成后进入关井压力恢复阶段，之后再进行下个周期运行。
本发明实施例在步骤108中，所述根据排液量及续流调整时间步长调整续流生产时长，步骤流程如图2所示，具体如下：
步骤201，根据气井历史生产数据设定排液量最小值和排液量最大值。
步骤202，当排液量小于排液量最小值时，根据续流调整时间步长增加续流生产时长。
当排液量小于排液量最小值时，柱塞气举低效举液运行，进入续流优化流程，根据续流调整时间步长增加续流生产时长，提高气井开井时率，优化完成后，进入关井压力恢复阶段，之后再进行下个周期运行。
步骤203，当排液量大于排液量最大值时，根据续流调整时间步长缩短续流生产时长。
当排液量大于排液量最大值时，柱塞举液量过大，超负荷运行，同样进入续流优化流程，根据续流调整时间步长缩短续流生产时长，提升柱塞气举运行稳定性，优化完成后，进入关井压力恢复阶段，之后再进行下个周期运行。
上述方案，根据排液量及续流调整时间步长调整续流生产时间，在不增加设备情况下，实现对柱塞运行自动优化控制，避免柱塞气举运行中无效关井和举液过载运行，提高了柱塞举液效率和运行正常率。
图3为本发明实施例提供的气井的柱塞气举运行曲线，下面以该气井为例对本发明提供的柱塞气举控制方法进行说明。
图3中，t1为关井过程，t2为开井过程，P1为排液时油压最小值，P2为开井排液后油压最大值，P1为开井后套压最小值，ΔP为套管压力达到最小值后，气井开始出现积液后升高值，t为设定的续流生产时长。
本发明实施例中，通过该气井历史曲线，选定10至15个能够代表生产特征的正常运行生产周期，根据P2、P1计算出柱塞举液量0.15方，设定该气井柱塞气举最小排液量和最大排液量，最小排液量设定为0.08方，最大排液量设定为0.3方。
根据曲线上的P1和ΔP设定气井初始续流生产时长t，本井设定续流生产时长为5小时，同时根据ΔP变化情况设定续流调整时间步长，续流增加时间设定为30分钟，续流缩短时间设定为10分钟。
根据气井开井前油压、套压和回压设定气井开井载荷系数阈值，该井设定为0.4。
设定完成后，开始运行优化参数，在关井时间t1时间内，实时监测气井载荷系数数值变化，当载荷系数达到0.4后，执行开井，进入t2生产阶段。
在t2生产阶段，实时监测气井油管压力变化情况，当出现油压最小值后，记录数值，出现油压最小值时，同时记录数值，根据油压最小值与油压最大值计算本周期柱塞排液量，本周期排液量为0.16方。
将本周期排液量与设定的排液量最小值、排液量最大值进行对比，在排液量处于预设范围内时，则保持续流生产时长不变。当排液量小于排液量最小值时，根据续流调整 时间步长增加续流生产时长；当排液量大于排液量最大值时，根据续流调整时间步长缩短续流生产时长。
执行完续流生产时长后，进入关井阶段t1，开始下一个周期优化运行，然后再按照周期性重复运行，实现柱塞气举井长期稳定运行。
优化运行后，优化运行曲线如图4所示，气井在不增加柱塞气举配套设备情况下，实现自动优化参数，无需人工分析管理，保持气井长期有效排液稳定生产，统计日产气量由4000方提高至13000方，增幅达75％，产液量由0.15方增加至0.48方，增产效果显著。
本发明实施例中还提供了一种柱塞气举控制系统，如下面的实施例所述。该系统如图5所示，所述系统包括：
设定单元501，用于获取气井历史生产数据，根据气井历史生产数据设定载荷系数阈值、最大关井时长、续流生产时长及续流调整时间步长；
采集单元502，用于实时采集气井生产中的状态参数；
自动执行单元503，用于根据气井生产中的状态参数计算载荷系数，在载荷系数达到载荷系数阈值或关井时长达到最大关井时长时，执行开井；
控制单元504，用于确定排液震荡时油压最小值及油压最大值，油压为气井井口油管处的压力，根据油压最小值及油压最大值确定排液量，在排液量不处于预设范围内时，根据排液量及续流调整时间步长调整续流生产时长。
柱塞气举井处于关井状态时，自动执行单元实时监测和分析气井载荷系数的数值变化情况，当载荷系数达到设定数值范围后，执行开井命令，将开井命令发送给自动控制阀门，实现气井开井。
开井后，柱塞举升井筒积液上行，当举液达到井口被排出，此时气井油管压力会出现一个先下降后上升的震荡特征，压力震荡幅度能够反映气井排液量大小，当柱塞上升无举升积液时，则无压力震荡特征。
本发明实施例中，气井生产中的状态参数包括套压、油压、回压，所述自动执行单元503具体用于：
根据套压、油压、回压计算载荷系数；其中，套压为井口油套环空处的压力；回压为管线输压。
本发明实施例中，所述控制单元504还用于：
在根据油压最小值及油压最大值确定排液量之后，在排液量处于预设范围内时，则保持续流生产时长不变。
本发明实施例中，所述控制单元504具体用于：
根据气井历史生产数据设定排液量最小值和排液量最大值；
当排液量小于排液量最小值时，根据续流调整时间步长增加续流生产时长；
当排液量大于排液量最大值时，根据续流调整时间步长缩短续流生产时长。
当柱塞举升积液到达井口后，根据油压最小值及油压最大值确定排液量，当排液量在设定范围时，则保持续流生产时长不变，续流结束后执行关井命令进入关井阶段。若排液量小于排液量最小值时，则表明该井举液效果较差，柱塞低效运行，根据续流调整时间步长增加续流生产时长，增加气井井筒积液量，使柱塞气举处于高效排液运行；若排液量大于排液量最大值，表明柱塞举液量过大，同时容易引起柱塞举不动积液，出现举液回落井底，最终出现积液水淹情况，此时根据续流调整时间步长缩短续流生产时长，减少井筒积液量，续流结束后执行关井命令进入关井阶段。
本发明实施例中，所述控制单元504具体用于：
根据油压最小值及油压最大值确定排液量的具体计算公式如下：

ΔPt＝Pt(max)-Pt(min)
Ql表示柱塞气举周期排液量，K表示修正系数，ΔPt表示柱塞气举排液时油压最大值与油压最小值之间的压差值，ρ表示产出液体密度，g表示重力加速度，Pt(max)表示油压最大值，Pt(min)表示油压最小值。
由于该系统解决问题的原理与柱塞气举控制方法相似，因此该系统的实施可以参见柱塞气举控制方法的实施，重复之处不再赘述。
本发明实施例中，获取气井历史生产数据；根据气井历史生产数据设定载荷系数阈值、最大关井时长、续流生产时长及续流调整时间步长；实时采集气井生产中的状态参数；根据气井生产中的状态参数计算载荷系数；在载荷系数达到载荷系数阈值或关井时长达到最大关井时长时，执行开井；确定排液震荡时油压最小值及油压最大值；油压为气井井口油管处的压力；根据油压最小值及油压最大值确定排液量；在排液量不处于预设范围内时，根据排液量及续流调整时间步长调整续流生产时长，与现有技术相比，根据油压最小值及油压最大值确定排液量；根据排液量及续流调整时间步长调整续流生产 时间，在不增加设备情况下，避免柱塞气举运行中无效关井和举液过载运行，提高了柱塞举液效率和运行正常率。根据设定载荷系数阈值和排液量对柱塞气举井进行周期性循环开关控制和自动优化，实现柱塞气举井高效排液和稳定运行。
本领域内的技术人员应明白，本发明的实施例可提供为方法、系统、或计算机程序产品。因此，本发明可采用完全硬件实施例、完全软件实施例、或结合软件和硬件方面的实施例的形式。而且，本发明可采用在一个或多个其中包含有计算机可用程序代码的计算机可用存储介质(包括但不限于磁盘存储器、CD-ROM、光学存储器等)上实施的计算机程序产品的形式。
本发明是参照根据本发明实施例的方法、设备(系统)、和计算机程序产品的流程图和/或方框图来描述的。应理解可由计算机程序指令实现流程图和/或方框图中的每一流程和/或方框、以及流程图和/或方框图中的流程和/或方框的结合。可提供这些计算机程序指令到通用计算机、专用计算机、嵌入式处理机或其他可编程数据处理设备的处理器以产生一个机器，使得通过计算机或其他可编程数据处理设备的处理器执行的指令产生用于实现在流程图一个流程或多个流程和/或方框图一个方框或多个方框中指定的功能的装置。
这些计算机程序指令也可存储在能引导计算机或其他可编程数据处理设备以特定方式工作的计算机可读存储器中，使得存储在该计算机可读存储器中的指令产生包括指令装置的制造品，该指令装置实现在流程图一个流程或多个流程和/或方框图一个方框或多个方框中指定的功能。
这些计算机程序指令也可装载到计算机或其他可编程数据处理设备上，使得在计算机或其他可编程设备上执行一系列操作步骤以产生计算机实现的处理，从而在计算机或其他可编程设备上执行的指令提供用于实现在流程图一个流程或多个流程和/或方框图一个方框或多个方框中指定的功能的步骤。
以上所述的具体实施例，对本发明的目的、技术方案和有益效果进行了进一步详细说明，所应理解的是，以上所述仅为本发明的具体实施例而已，并不用于限定本发明的保护范围，凡在本发明的精神和原则之内，所做的任何修改、等同替换、改进等，均应包含在本发明的保护范围之内。

Claims (15)

  1. 一种柱塞气举控制方法，其特征在于，包括：
    获取气井历史生产数据；
    根据气井历史生产数据设定载荷系数阈值、最大关井时长、续流生产时长及续流调整时间步长；
    实时采集气井生产中的状态参数；
    根据气井生产中的状态参数计算载荷系数；
    在载荷系数达到载荷系数阈值或关井时长达到最大关井时长时，控制执行开井；
    确定排液震荡时油压最小值及油压最大值；油压为气井井口油管处的压力；
    根据油压最小值及油压最大值确定排液量；
    在排液量不处于预设范围内时，根据排液量及续流调整时间步长调整续流生产时长。
  2. 如权利要求1所述的柱塞气举控制方法，其特征在于，气井生产中的状态参数包括套压、油压、回压，所述根据气井生产中的状态参数计算载荷系数，包括：
    根据套压、油压、回压计算载荷系数；其中，套压为井口油套环空处的压力；回压为管线输压。
  3. 如权利要求1所述的柱塞气举控制方法，其特征在于，在根据油压最小值及油压最大值确定排液量之后，还包括：
    在排液量处于预设范围内时，则保持续流生产时长不变。
  4. 如权利要求1所述的柱塞气举控制方法，其特征在于，所述根据排液量及续流调整时间步长调整续流生产时长，包括：
    根据气井历史生产数据设定排液量最小值和排液量最大值；
    当排液量小于排液量最小值时，根据续流调整时间步长增加续流生产时长；
    当排液量大于排液量最大值时，根据续流调整时间步长缩短续流生产时长。
  5. 如权利要求1所述的柱塞气举控制方法，其特征在于，根据油压最小值及油压最大值确定排液量的具体计算公式如下：

    ΔPt＝Pt(max)-Pt(min)
    Ql表示柱塞气举周期排液量，K表示修正系数，ΔPt表示柱塞气举排液时油压最大值与油压最小值之间的压差值，ρ表示产出液体密度，g表示重力加速度，Pt(max)表示油压最大值，Pt(min)表示油压最小值。
  6. 一种计算机设备，包括存储器、处理器及存储在存储器上并可在处理器上运行的计算机程序，其特征在于，所述处理器执行所述计算机程序时实现如下柱塞气举控制方法：
    获取气井历史生产数据；
    根据气井历史生产数据设定载荷系数阈值、最大关井时长、续流生产时长及续流调整时间步长；
    实时采集气井生产中的状态参数；
    根据气井生产中的状态参数计算载荷系数；
    在载荷系数达到载荷系数阈值或关井时长达到最大关井时长时，控制执行开井；
    确定排液震荡时油压最小值及油压最大值；油压为气井井口油管处的压力；
    根据油压最小值及油压最大值确定排液量；
    在排液量不处于预设范围内时，根据排液量及续流调整时间步长调整续流生产时长。
  7. 如权利要求6所述的计算机设备，其特征在于，气井生产中的状态参数包括套压、油压、回压，所述根据气井生产中的状态参数计算载荷系数，包括：
    根据套压、油压、回压计算载荷系数；其中，套压为井口油套环空处的压力；回压为管线输压。
  8. 如权利要求6所述的计算机设备，其特征在于，在根据油压最小值及油压最大值确定排液量之后，还包括：
    在排液量处于预设范围内时，则保持续流生产时长不变。
  9. 如权利要求6所述的计算机设备，其特征在于，所述根据排液量及续流调整时间步长调整续流生产时长，包括：
    根据气井历史生产数据设定排液量最小值和排液量最大值；
    当排液量小于排液量最小值时，根据续流调整时间步长增加续流生产时长；
    当排液量大于排液量最大值时，根据续流调整时间步长缩短续流生产时长。
  10. 如权利要求6所述的计算机设备，其特征在于，根据油压最小值及油压最大值确定排液量的具体计算公式如下：

    ΔPt＝Pt(max)-Pt(min)
    Ql表示柱塞气举周期排液量，K表示修正系数，ΔPt表示柱塞气举排液时油压最大值与油压最小值之间的压差值，ρ表示产出液体密度，g表示重力加速度，Pt(max)表示油压最大值，Pt(min)表示油压最小值。
  11. 一种计算机可读存储介质，其特征在于，所述计算机可读存储介质存储有计算机程序，所述计算机程序被处理器执行时实现如下柱塞气举控制方法：
    获取气井历史生产数据；
    根据气井历史生产数据设定载荷系数阈值、最大关井时长、续流生产时长及续流调整时间步长；
    实时采集气井生产中的状态参数；
    根据气井生产中的状态参数计算载荷系数；
    在载荷系数达到载荷系数阈值或关井时长达到最大关井时长时，控制执行开井；
    确定排液震荡时油压最小值及油压最大值；油压为气井井口油管处的压力；
    根据油压最小值及油压最大值确定排液量；
    在排液量不处于预设范围内时，根据排液量及续流调整时间步长调整续流生产时长。
  12. 如权利要求11所述的计算机可读存储介质，其特征在于，气井生产中的状态参数包括套压、油压、回压，所述根据气井生产中的状态参数计算载荷系数，包括：
    根据套压、油压、回压计算载荷系数；其中，套压为井口油套环空处的压力；回压为管线输压。
  13. 如权利要求11所述的计算机可读存储介质，其特征在于，在根据油压最小值及油压最大值确定排液量之后，还包括：
    在排液量处于预设范围内时，则保持续流生产时长不变。
  14. 如权利要求11所述的计算机可读存储介质，其特征在于，所述根据排液量及续流调整时间步长调整续流生产时长，包括：
    根据气井历史生产数据设定排液量最小值和排液量最大值；
    当排液量小于排液量最小值时，根据续流调整时间步长增加续流生产时长；
    当排液量大于排液量最大值时，根据续流调整时间步长缩短续流生产时长。
  15. 如权利要求11所述的计算机可读存储介质，其特征在于，根据油压最小值及油压最大值确定排液量的具体计算公式如下：

    ΔPt＝Pt(max)-Pt(min)
    Ql表示柱塞气举周期排液量，K表示修正系数，ΔPt表示柱塞气举排液时油压最大值与油压最小值之间的压差值，ρ表示产出液体密度，g表示重力加速度，Pt(max)表示油压最大值，Pt(min)表示油压最小值。
PCT/CN2023/127392 2023-06-13 2023-10-27 柱塞气举控制方法及系统 Ceased WO2024255065A1 (zh)

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