A plunger gas lift wellbore parameter monitoring device and loss amount calculation method

Abstract

The embodiment of the specification relates to the technical field of gas well plunger displacement technology, and provides a plunger gas lift wellbore parameter monitoring device and a loss amount calculation method, the device is arranged on the plunger and comprises a shell and a liquid level monitoring module, a running position monitoring module, a pressure monitoring module and a control module arranged in the shell; the liquid level monitoring module is used for monitoring the liquid level in the wellbore; the running position monitoring module is used for monitoring the running position of the plunger in the wellbore at different moments; the pressure monitoring module is used for monitoring the pressure of the running position of the plunger; and the control module is used for calculating the loss amount at a moment in the plunger gas lift process according to the data collected by the pressure monitoring module, the liquid level monitoring module and the running position monitoring module; and generating early warning information according to the loss amount. Through the embodiment of the specification, the liquid level in the wellbore, the running position of the plunger and the corresponding pressure can be accurately monitored, and the loss amount in the plunger gas lift process can be calculated.

Description

Technical Field

[0001] This specification relates to the field of gas well plunger drainage technology, and in particular to a plunger gas lift wellbore parameter monitoring device and a method for calculating leakage. Background Technology

[0002] Plunger gas lift is an economical, environmentally friendly, and easy-to-operate and maintain drainage and gas production process. It fully utilizes the elastic energy of the gas well itself, using a plunger as the gas-liquid separation interface in the wellbore to periodically lift and remove accumulated liquid at the bottom of the well, maintaining stable gas well production. With the deepening of exploration and development, more and more shale gas wells are entering the mid-to-late stages of development, and plunger gas lift has been widely applied. The plunger gas lift process mainly involves the periodic operation of the plunger in the wellbore with water, and a plunger retainer restricts the plunger's position. Its effectiveness is affected by many factors, including the plunger's operating position, the wellbore fluid level, and fluid loss during the plunger's ascent. Because the fluid level at the upper end of the plunger retainer is unclear, during the shut-in and repressurization period, the fluid at the upper end of the retainer is forced back into the formation during pressure recovery, resulting in no fluid at the upper end of the retainer and ineffective plunger lift. Furthermore, since the leakage rate of the plunger is generally greater in deviated well sections than in vertical well sections, excessive fluid loss during the plunger's ascent can lead to no fluid being lifted when it reaches the wellhead.

[0003] Therefore, to clarify the reasons for the poor fluid-carrying effect of plunger lift, it is necessary to measure multiple wellbore parameters during the plunger gas lift process. This will provide support for plunger scheme design, subsequent system optimization, and tool selection, effectively avoiding ineffective plunger lift and improving the implementation effect and efficiency of the plunger process. However, existing plunger gas lift wellbore parameter measurement devices can only monitor parameters such as wellbore pressure, temperature, and depth, and do not provide a technical solution for analyzing leakage in the plunger process by combining wellbore fluid level monitoring and plunger position monitoring. Therefore, there is an urgent need for a plunger gas lift wellbore parameter monitoring device and a leakage calculation method that can accurately monitor the plunger operating position and wellbore fluid level position, and analyze the plunger gas lift leakage based on the monitoring data. Summary of the Invention

[0004] To address the aforementioned problems in the prior art, the purpose of the embodiments in this specification is to provide a plunger gas lift wellbore parameter monitoring device and a leakage calculation method, so as to accurately monitor the plunger operating position and the wellbore fluid level position, and to analyze the plunger gas lift leakage based on the monitoring data.

[0005] To solve the above-mentioned technical problems, the specific technical solutions of the embodiments in this specification are as follows:

[0006] On one hand, the embodiments of this specification provide a plunger gas lift wellbore parameter monitoring device, the device being mounted on the plunger, including: a housing and a liquid level monitoring module, an operating position monitoring module, a pressure monitoring module, and a control module disposed in the housing;

[0007] The liquid level monitoring module is used to monitor the liquid level height inside the wellbore.

[0008] The running position monitoring module is used to monitor the running position of the plunger in the wellbore at different times;

[0009] The pressure monitoring module is used to monitor the pressure at the plunger's operating position;

[0010] The control module is connected to the pressure monitoring module, liquid level monitoring module, and operating position monitoring module, and is used to provide control signals to each module in the device; based on the data collected by the pressure monitoring module, liquid level monitoring module, and operating position monitoring module, it calculates the height difference between the height of the pure liquid column above the plunger when the plunger is in the preset locking position and the height of the pure liquid column above the plunger at a certain moment during the plunger gas lift process; it calculates the leakage amount at a certain moment during the plunger gas lift process based on the height difference; and it generates early warning information based on the leakage amount.

[0011] Preferably, the liquid level monitoring module includes a liquid probe and a liquid inlet chamber;

[0012] The liquid probe is disposed inside the inlet chamber, with the tip of the liquid probe exposed at the opening of the inlet chamber, for acquiring a liquid level signal when liquid flows into the inlet chamber from the wellbore;

[0013] The liquid inlet chamber is disposed inside the shell and is located on the side wall of the shell. The liquid inlet chamber is used to prevent water vapor in the wellbore from interfering with the liquid level signal detection.

[0014] Preferably, the operating position monitoring module includes a calculation module and at least two sets of eddy current sensors, the two sets of eddy current sensors being respectively disposed at different opposing positions within the housing, for detecting the oil pipe coupling signal;

[0015] The calculation module is connected to the eddy current sensor and is used to calculate the running position of the plunger in the wellbore based on the tubing coupling signal and the tubing depth.

[0016] Preferably, the eddy current sensor has a polyetheretherketone (PEEK) housing to prevent metal objects in the wellbore from interfering with the eddy current signal.

[0017] Preferably, the control module includes a circuit board, a power supply module, a real-time clock module, a data storage module, and a processor;

[0018] The circuit board is used to provide control signals to the various modules within the device;

[0019] The power module is used to provide power for the operation of each module in the device;

[0020] The real-time clock module is used to record the time points monitored by each module in the device in real time.

[0021] The data storage module is used to store the data collected by the liquid level monitoring module, the operating position monitoring module, and the pressure monitoring module;

[0022] The processor is used to calculate the leakage during the plunger gas lift process based on the data collected by the pressure monitoring module, the liquid level monitoring module, and the operating position monitoring module, and to generate early warning information based on the leakage.

[0023] On the other hand, embodiments of this specification provide a method for calculating leakage in a plunger gas lift process. This method is applied to the control module of any of the aforementioned devices and includes:

[0024] Acquire data collected by the pressure monitoring module, liquid level monitoring module, and operating position monitoring module;

[0025] Based on the data collected by the pressure monitoring module, liquid level monitoring module and operating position monitoring module, the height difference between the height of the pure liquid column above the plunger when the plunger is in the preset locking position and the height of the pure liquid column above the plunger at a certain moment during the plunger gas lift process is calculated.

[0026] The leakage at a certain moment during the plunger gas lift process is calculated based on the height difference.

[0027] Early warning information is generated based on the leakage amount.

[0028] Furthermore, the acquisition of data collected by the pressure monitoring module, liquid level monitoring module, and operating position monitoring module includes:

[0029] When the plunger descends to the wellbore fluid level, the wellbore fluid level height is obtained from the fluid level monitoring module;

[0030] When the plunger descends to the preset locking position, the first operating position is obtained from the operating position monitoring module;

[0031] At a certain moment during the plunger gas lift process, the second operating position is obtained from the operating position monitoring module and the pressure corresponding to the second operating position is obtained from the pressure monitoring module.

[0032] Further, the calculation of the height difference between the height of the pure liquid column above the plunger when the plunger is in the preset locking position and the height of the pure liquid column above the plunger at a certain moment during the plunger gas lift process includes:

[0033] Based on the first operating position and the wellbore fluid level, the height of the first pure fluid column above the plunger when the plunger is located at the preset locking device position is calculated;

[0034] Based on the pressure corresponding to the second operating position, the height of the second pure liquid column above the plunger at a certain moment during the plunger gas lift process is calculated.

[0035] The height difference is calculated based on the height of the first pure liquid column and the height of the second pure liquid column.

[0036] Further, the step of calculating the height of the second pure liquid column above the plunger at a certain moment during the plunger gas lift process based on the pressure corresponding to the second operating position includes:

[0037] The height of the second pure liquid column above the plunger at a certain moment during the plunger gas lift process can be calculated using the following formula:

[0038]

[0039] Among them, H t H3 represents the height of the second pure liquid column above the plunger at a certain moment during the plunger gas lift process, P3 represents the pressure corresponding to the second operating position, P represents the wellhead oil pressure, and ρ represents the second operating position. 气 ρ represents the density of the gas in the wellbore, g represents the acceleration due to gravity, and ρ represents the acceleration due to gravity. 液 Represents the wellbore liquid density.

[0040] Further, the calculation of the leakage at a certain moment during the plunger gas lift process based on the height difference includes:

[0041] The leakage at a certain moment during the plunger gas lift process can be calculated using the following formula:

[0042] Z t =ρ 液 gΔH;

[0043] Among them, Z t ρ represents the leakage at a certain moment during the plunger lift process. 液 denoted by ρ, g represents the density of the fluid in the wellbore, g represents the acceleration due to gravity, and ΔH represents the height difference.

[0044] Using the above technical solution, the plunger gas lift wellbore parameter monitoring device and leakage calculation method provided in the embodiments of this specification can accurately monitor the liquid level height, plunger operating position and corresponding pressure in the wellbore during the plunger gas lift process through the liquid level monitoring module, operating position monitoring module and pressure monitoring module. Thus, the leakage during the plunger gas lift process can be calculated based on the liquid level height, plunger operating position and corresponding pressure in the wellbore, and early warning information can be generated based on the leakage to avoid ineffective plunger lifting, thereby improving the implementation effect and efficiency of the plunger process.

[0045] The above description is merely an overview of some embodiments of the technical solutions in this specification. In order to better understand the technical means of some embodiments of this specification and to implement them in accordance with the content of the specification, and to make the above and other objects, features and advantages of the embodiments of this specification more apparent and understandable, preferred embodiments are described below in detail with reference to the accompanying drawings. Attached Figure Description

[0046] To more clearly illustrate the technical solutions in the embodiments or prior art of this specification, the drawings used in the description of the embodiments or prior art will be briefly introduced below. Obviously, the drawings described below are only some embodiments of this specification. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0047] Figure 1 This specification shows a schematic diagram of the structure of a plunger gas lift wellbore parameter monitoring device in some embodiments;

[0048] Figure 2 A schematic diagram of another embodiment of a plunger gas lift wellbore parameter monitoring device, as shown in some embodiments of this specification, is illustrated.

[0049] Figure 3 A flowchart illustrating a method for calculating leakage in a plunger gas lift process, as shown in some embodiments of this specification, is presented.

[0050] Figure 4 This specification shows a flowchart illustrating the process of acquiring data from the pressure monitoring module, liquid level monitoring module, and operating position monitoring module in some embodiments.

[0051] Figure 5 This specification shows a flowchart illustrating the calculation of the height difference of the pure liquid column in some embodiments;

[0052] Figure 6 This specification shows schematic diagrams of the plunger rising process in some embodiments;

[0053] Figure 7A schematic diagram of the structure of a computer device is shown in this specification.

[0054] Explanation of symbols in the attached drawings:

[0055] 1. Shell;

[0056] 2. Liquid level monitoring module;

[0057] 21. Liquid probe;

[0058] 22. Liquid inlet tank;

[0059] 3. Operational location monitoring module;

[0060] 31. First eddy current sensor;

[0061] 32. Second eddy current sensor;

[0062] 33. Shell made of polyetheretherketone (PEEK);

[0063] 4. Pressure monitoring module;

[0064] 41. First pressure sensor;

[0065] 42. Second pressure sensor;

[0066] 5. Control module;

[0067] 51. Circuit board;

[0068] 52. Power supply module;

[0069] 53. Real-time clock module;

[0070] 54. Data storage module;

[0071] 55. Processor;

[0072] 702. Computer equipment;

[0073] 704, Processor;

[0074] 706. Memory;

[0075] 708. Drive mechanism;

[0076] 710. Input / Output Module;

[0077] 712. Input devices;

[0078] 714. Output devices;

[0079] 716. Presentation equipment;

[0080] 718. Graphical User Interface;

[0081] 720. Network interface;

[0082] 722. Communication link;

[0083] 724. Communication bus. Detailed Implementation

[0084] The technical solutions in the embodiments of this specification will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of this specification, and not all embodiments. Based on the embodiments in this specification, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of this specification.

[0085] To address the aforementioned issues, this specification provides a plunger gas lift wellbore parameter monitoring device and a method for calculating leakage. Figure 1 This is a schematic diagram of a plunger gas lift wellbore parameter monitoring device provided in the embodiments of this specification. This specification provides the operational steps of the methods described in the embodiments or flowcharts, but based on conventional or non-inventive labor, more or fewer operational steps may be included. The order of steps listed in the embodiments is merely one possible execution order among many and does not represent the only possible execution order. In actual system or device products, the methods shown in the embodiments or accompanying drawings can be executed sequentially or in parallel.

[0086] It should be noted that the terms "first," "second," etc., used in this specification, claims, and the foregoing drawings are used to distinguish similar objects and are not necessarily used to describe a specific order or sequence. It should be understood that such data can be interchanged where appropriate so that the embodiments described herein can be implemented in orders other than those illustrated or described herein. Furthermore, the terms "comprising" and "having," and any variations thereof, are intended to cover a non-exclusive inclusion; for example, a process, method, apparatus, product, or device that comprises a series of steps or units is not necessarily limited to those steps or units explicitly listed, but may include other steps or units not explicitly listed or inherent to such processes, methods, products, or devices.

[0087] Reference Figure 1 As shown in the figure, this specification provides a plunger gas lift wellbore parameter monitoring device. The device is mounted on the plunger and includes: a housing 1 and a liquid level monitoring module 2, an operating position monitoring module 3, a pressure monitoring module 4, and a control module 5 disposed in the housing 1.

[0088] The housing 1 serves as the carrier of the entire device, protecting the internal modules from the influence of the external environment, thereby ensuring the accuracy of the monitoring data of each internal module.

[0089] The liquid level monitoring module 2 is used to monitor the liquid level height inside the wellbore.

[0090] The running position monitoring module 3 is used to monitor the running position of the plunger in the wellbore at different times.

[0091] The pressure monitoring module 4 is used to monitor the pressure at the plunger's operating position.

[0092] The control module 5 is connected to the pressure monitoring module 4, the liquid level monitoring module 2, and the operating position monitoring module 3, and is used to provide control signals to each module in the device; and to calculate the height difference between the height of the pure liquid column above the plunger when the plunger is in the preset locking position and the height of the pure liquid column above the plunger at a certain moment during the plunger gas lift process, based on the data collected by the pressure monitoring module 4, the liquid level monitoring module 2, and the operating position monitoring module 3; to calculate the leakage amount at a certain moment during the plunger gas lift process based on the height difference; and to generate early warning information based on the leakage amount.

[0093] It can be understood that since the plunger process relies on the operation of the plunger in the tubing to lift fluid, its process effect is affected by many factors, including the plunger's running position, the fluid level in the wellbore, and the fluid loss during the plunger's upward movement. The problems caused by this are: (1) The plunger process is mainly completed by the plunger running in the wellbore with water, and the plunger is restricted to the position of the plunger. Shale gas wells are mostly horizontal wells with a large inclination. The plunger is usually designed to descend to a depth of about 60° of well inclination. However, since the plunger's falling position is unclear, it is unclear whether it has reached the plunger, which may lead to the failure to meet the expected effect of the process design; (2) The fluid level at the upper end of the plunger is unclear. During the shut-in and pressure recovery period, the fluid at the upper end of the plunger is pushed back into the formation during the pressure recovery process, resulting in no fluid at the upper end of the plunger, which leads to ineffective plunger lifting; (3) The leakage of the plunger in the deviated section is generally greater than that in the vertical section. Therefore, the fluid leakage during the plunger's upward movement is too large, resulting in no fluid being lifted when it reaches the wellhead. Therefore, to clarify the reasons for the poor fluid-carrying effect of the plunger lift, it is necessary to measure multiple wellbore parameters during the plunger gas lift process. In the embodiments of this specification, during the plunger gas lift process, the liquid level monitoring module, the operating position monitoring module, and the pressure monitoring module accurately monitor the liquid level in the wellbore, the plunger operating position, and the corresponding pressure. This allows for the calculation of leakage during the plunger gas lift process based on the liquid level in the wellbore, the plunger operating position, and the corresponding pressure. Early warning information is then generated based on the leakage amount, thereby avoiding ineffective plunger lift and improving the implementation effect and efficiency of the plunger gas lift process.

[0094] In some embodiments of this specification, such as Figure 2As shown, the liquid level monitoring module 2 includes a liquid probe 21 and an inlet chamber 22. The liquid probe 21 is disposed within the inlet chamber 22, with its tip exposed at the opening of the inlet chamber 22. It is used to acquire a liquid level signal when liquid flows into the inlet chamber from the wellbore. It can be understood that the liquid probe 21 typically has good conductivity, and its tip is intentionally designed to be exposed at the opening of the inlet chamber so that it can directly contact the liquid. When the device is outside the wellbore or above the liquid surface, the exposed portion of the liquid probe 21 will not contact the liquid, thus the probe remains open, and the liquid level monitoring module will not emit any liquid level signal. When the device descends below the liquid surface with the wellbore, liquid begins to flow into the inlet chamber 22. Because the tip of the probe is exposed at the opening, the liquid will directly contact the probe, causing a short circuit at the top of the probe (i.e., the exposed portion). This short circuit triggers a change in the internal circuitry of the liquid level monitoring module 2, thereby generating a liquid level signal. This signal can be transmitted to the control module to indicate the position of the liquid level or to perform other related liquid level control operations.

[0095] The liquid inlet chamber 22 is disposed within the housing 1 and located on the side wall of the housing. The liquid inlet chamber 22 is used to prevent water vapor inside the wellbore from interfering with liquid level signal detection. It can be understood that, as a carrier of the liquid probe 21, the liquid inlet chamber 22 is responsible for guiding the liquid in the wellbore to flow in and forming contact with the exposed part of the liquid probe 21. Therefore, the design of the liquid inlet chamber 22 should ensure that the liquid can flow in smoothly while protecting other parts of the probe from liquid erosion. In this embodiment, the liquid inlet chamber 22 is disposed on the side wall of the housing 1, allowing it to contact the liquid inside the wellbore more directly, while effectively avoiding the area of ​​strong water vapor that may exist in the center of the wellbore. Furthermore, the side wall position also helps to reduce turbulence and eddies during liquid flow, allowing the liquid to flow into the liquid inlet chamber more smoothly, thereby improving the accuracy of liquid level detection. Water vapor may exist inside the wellbore; if it directly contacts the liquid probe, it may cause the probe surface to become wet or form tiny water droplets, leading to false detections. Therefore, the liquid inlet chamber 22 is set on the side wall, which creates a relatively closed space inside. This space can slow down the penetration and diffusion of water vapor, and further reduce the interference of water vapor on the liquid surface signal detection.

[0096] In some embodiments of this specification, such as Figure 2As shown, the operating position monitoring module 3 includes a calculation module (not shown) and at least two sets of eddy current sensors, namely a first eddy current sensor 31 and a second eddy current sensor 32. The first eddy current sensor 31 and the second eddy current sensor 32 are respectively disposed at different opposing positions within the housing for detecting tubing coupling signals. It can be understood that the eddy current sensor utilizes the principle of electromagnetic induction. When the tubing (especially the tubing coupling) passes through the sensor, eddy currents are generated in the sensor. The magnitude and phase of these eddy currents are related to the metallic properties and distance of the tubing coupling. By detecting these eddy current signals, the sensor can detect the tubing coupling signals. This embodiment includes at least two sets of eddy current sensors, which are disposed at different opposing positions within the housing to ensure that the sensors can fully cover the tubing within the wellbore, thereby capturing the tubing coupling signals. In other embodiments, different numbers and positions of eddy current sensors can be set according to different wellbore or tubing shapes. Thus, this module can be applied to tubing of different diameters and materials, as well as wellbore environments of different depths and complexities.

[0097] The calculation module is connected to the first eddy current sensor 31 and the second eddy current sensor 32, and is used to calculate the plunger's operating position in the wellbore based on the tubing coupling signal and the tubing depth. Specifically, based on the occurrence sequence and frequency of the tubing coupling signal, combined with the known tubing depth and coupling spacing, the calculation module can accurately calculate the plunger's current operating position in the wellbore. In other embodiments, the calculation module can also record the plunger's operating position data and transmit it to the control module via wired or wireless means for real-time monitoring and analysis by the operator. Thus, through the cooperation of the eddy current sensors and the calculation module, the operating position monitoring module 3 can achieve accurate monitoring of the plunger's operating position with small errors and high reliability.

[0098] In other embodiments, such as Figure 2 As shown, the first eddy current sensor 31 and the second eddy current sensor 32 have polyetheretherketone (PEEK) housings 33 to prevent interference from metal objects in the wellbore with the eddy current signal. Various metal objects, such as tubing, casing, and drill pipe, may exist in the wellbore, generating their own electromagnetic fields that could interfere with the normal operation of the eddy current sensor. Eddy current sensors using PEEK housings effectively isolate these external electromagnetic field interferences, ensuring that the eddy current sensor can accurately capture the tubing coupling signal. Furthermore, the insulation properties of the PEEK housing also help prevent short circuits or grounding faults between the eddy current sensor and other metal objects in the wellbore, thereby further improving the reliability and safety of the eddy current sensor.

[0099] In some embodiments of this specification, such as Figure 2As shown, the pressure monitoring module 4 includes at least two sets of high-precision pressure sensors, namely a first pressure sensor 41 and a second pressure sensor 42, capable of capturing pressure changes within the wellbore in real time. The two sets of pressure sensors are respectively positioned at the upper and lower parts of the device to ensure independent pressure monitoring of the upper and lower regions of the wellbore, thereby providing a more comprehensive understanding of the pressure distribution within the wellbore. Both sets of pressure sensors have openings on their outer walls, allowing the pressure within the wellbore to be directly transmitted to the sensors, ensuring that the sensors can capture pressure changes within the wellbore accurately and in real time.

[0100] In other embodiments, the plunger gas lift wellbore parameter monitoring device further includes a temperature monitoring module. This module comprises at least two sets of high-precision temperature sensors capable of capturing real-time temperature changes within the wellbore. The two sets of temperature sensors are respectively positioned at the top and bottom of the device to ensure independent temperature monitoring of the upper and lower regions of the wellbore, thereby providing a more comprehensive understanding of the temperature environment within the wellbore. The high-precision temperature sensors enable real-time monitoring of temperature changes within the wellbore, which is crucial for understanding the current state of the wellbore, predicting potential problems, and taking timely measures. In other embodiments, the temperature and pressure monitoring module can be preset with a data acquisition frequency, recording as much data as possible while minimizing power consumption of the power module.

[0101] In some embodiments of this specification, such as Figure 2 As shown, the control module 5 includes a circuit board 51, a power supply module 52, a real-time clock module 53, a data storage module 54, and a processor 55. The circuit board 51 provides control signals to each module within the device, ensuring normal coordination between them. The power supply module 52 uses a high-temperature resistant lithium battery to provide power for the operation of each module. The real-time clock module 53 records the monitoring time points of each module in real time, allowing for the analysis of collected data such as pressure, liquid level, and operating position on the same time axis. The data storage module 54 stores the data collected by the liquid level monitoring module 2, the operating position monitoring module 3, and the pressure monitoring module 4. The processor 55 calculates the leakage during the plunger gas lift process based on the data collected by the pressure monitoring module, the liquid level monitoring module, and the operating position monitoring module, and generates early warning information based on the leakage. Thus, through the coordinated work of its various modules, the control module 5 achieves effective control and management of each module within the device. It not only records monitoring data and stores important information in real time but also performs data processing and analysis, providing strong support for the stable operation and fault early warning of the device.

[0102] Based on the plunger gas lift wellbore parameter monitoring device described above, this specification also provides a corresponding method for calculating leakage during the plunger gas lift process. The method is applied to the processor of any of the devices described above. Based on the same innovative concept, the methods in one or more embodiments provided in this specification are as described in the following embodiments. Since the implementation scheme of the method to solve the problem is similar to that of the device, the specific implementation of the method in this specification can be referred to the implementation of the aforementioned device, and repeated details will not be repeated. As used below, the terms "unit" or "module" can refer to a combination of software and / or hardware that performs a predetermined function.

[0103] Specifically, Figure 3 This is a flowchart illustrating a method for calculating leakage in a plunger gas lift process, as provided in an embodiment of this specification. The method is applied to the control module of any of the aforementioned devices. (Refer to...) Figure 3 As shown in the embodiments of this specification, a method for calculating leakage in a plunger gas lift process includes:

[0104] S301: Acquire data collected by the pressure monitoring module, liquid level monitoring module and operating position monitoring module;

[0105] S302: Based on the data collected by the pressure monitoring module, liquid level monitoring module and operating position monitoring module, calculate the height difference between the height of the pure liquid column above the plunger when the plunger is in the preset locking position and the height of the pure liquid column above the plunger at a certain moment during the plunger gas lift process.

[0106] S303: Calculate the leakage amount at a certain moment during the plunger gas lift process based on the height difference;

[0107] S304: Generate early warning information based on the leakage amount.

[0108] Using the above method, the leakage amount at a certain moment during the plunger gas lift process can be calculated based on the data collected by the pressure monitoring module, liquid level monitoring module, and operating position monitoring module, and early warning information can be generated based on the leakage amount, thereby avoiding ineffective gas lift of the plunger and improving the implementation effect and efficiency of the plunger process.

[0109] In the embodiments of this specification, in step S301, refer to Figure 4 The acquisition of data collected by the pressure monitoring module, liquid level monitoring module, and operating position monitoring module includes:

[0110] S401: When the plunger descends to the wellbore fluid level, the wellbore fluid level height is obtained from the fluid level monitoring module;

[0111] S402: When the plunger descends to the preset locking position, the first operating position is obtained from the operating position monitoring module;

[0112] S403: At a certain moment during the plunger gas lift process, a second operating position is obtained from the operating position monitoring module and the pressure corresponding to the second operating position is obtained from the pressure monitoring module.

[0113] Specifically, the plunger gas lift process includes the following four stages: (1) Plunger descending stage: the wellhead is closed, and the plunger falls through the gas column and accumulated liquid in the tubing under its own gravity until it sits firmly on the buffer spring of the bottom-hole retainer; (2) Pressure recovery stage: the plunger stays on the buffer spring of the retainer for a period of time. During this period, the energy at the bottom of the well gradually recovers, and oil and gas gradually accumulate around the wellbore. The gas and liquid produced in the formation enter the annulus and tubing. Due to the bottom-hole device and the accumulated liquid in the wellbore, most of the gas enters the annulus, while most of the liquid and a small amount of gas enter the tubing. When the pressure recovers to a level sufficient to carry the plunger and the liquid above it out of the wellhead, the well is opened for production; (3) Plunger ascending stage: after the well is opened for production, the gas in the tubing flows out of the wellbore and into the surface low-pressure pipeline, and the oil pressure decreases. Gas in the annulus and formation gas enter the tubing and expand. When the pressure at the bottom of the plunger is greater than the sum of the surface oil pressure, the weight of the plunger and its upper liquid section, and the friction between the plunger and the pipe wall as it moves upward, the gas will push the plunger and its upper liquid section away from the locking device and move upward along the tubing. (4) When the plunger reaches the wellhead and discharges the liquid from the wellbore, the plunger is captured in the wellhead blowout preventer. At this time, the well is shut in again for pressure repressurization, and the next working cycle begins.

[0114] Therefore, in this embodiment of the specification, during one monitoring cycle, the monitoring device is first placed into the blowout preventer catcher, the wellhead is closed, and the monitoring device begins to fall along with the plunger. During the fall, the position monitoring module begins to record the number of tubing couplings passed. When the plunger reaches the wellbore fluid level, the fluid level monitoring module generates a short-circuit signal due to the entry of fluid, and records the fluid level position as H1. The plunger continues to fall to the preset locking position, and the first operating position is recorded as H2. At the same time, the temperature and pressure monitoring modules record the temperature and pressure at this position as T2 and P2, respectively. Subsequently, the wellhead is opened, and the plunger begins to rise. When the plunger reaches a certain position at time t, the second operating position is recorded as H3, and the temperature and pressure on the upper surface of the device at this point are recorded as T3 and P3, respectively.

[0115] To make the calculation method for plunger gas lift leakage clearer and more convenient, such as Figure 6 As shown, during the plunger's ascent, the plunger is considered an ideal sealing surface. The upper part of the sealing surface consists of a pure gas column and a pure liquid column, with a gas-water interface present. Therefore, in the leakage calculation method of this embodiment, the pressure balance formula at the upper part of the plunger should be: P3 = ... 液 +Pure air column pressure P 气+Wellhead oil pressure P, where the upper end face pressure P3 of the plunger is obtained by the pressure monitoring module at the top of the device, and the wellhead oil pressure P is read directly from the wellhead pressure gauge.

[0116] In the embodiments of this specification, in step S302, refer to Figure 5 The step of calculating the height difference between the height of the pure liquid column above the plunger when the plunger is in the preset locking position and the height of the pure liquid column above the plunger at a certain moment during the plunger gas lift process, based on the data collected by the pressure monitoring module, liquid level monitoring module, and operating position monitoring module, includes:

[0117] S501: Based on the first operating position and the wellbore fluid level, calculate the height of the first pure fluid column above the plunger when the plunger is located at the preset locking device position;

[0118] S502: Based on the pressure corresponding to the second operating position, calculate the height of the second pure liquid column above the plunger at a certain moment during the plunger gas lift process;

[0119] S503: The height difference is calculated based on the height of the first pure liquid column and the height of the second pure liquid column.

[0120] Specifically, the pure liquid column pressure P 液 =ρ 液 gH t H t Let ρ be the height of the second pure liquid column above the plunger at a certain moment t during the plunger lift process. 液 The density is the liquid density. The pressure P of the pure gas column is... 气 =ρ 气 gH 界 , where ρ 气 H is the gas density. 界 Let H be the depth of the gas-water interface, which is also the height of the pure gas column above the plunger at time t during the plunger lift process. This can be expressed as H. 界 =H3-H t Therefore, based on the upper pressure balance formula, the height of the second pure liquid column above the plunger at a certain moment t during the plunger gas lift process can be derived as follows:

[0121]

[0122] Among them, H t H3 represents the height of the second pure liquid column above the plunger at a certain moment during the plunger gas lift process, P3 represents the pressure corresponding to the second operating position, P represents the wellhead oil pressure, and ρ represents the second operating position. 气 ρ represents the density of the gas in the wellbore, g represents the acceleration due to gravity, and ρ represents the acceleration due to gravity. 液 Represents the wellbore liquid density.

[0123] In this embodiment, when the plunger is in the preset locking position, the height H0 of the first pure liquid column above the plunger can be determined by the liquid surface position H1 and the first running position H2, thereby obtaining H0 = H2 - H1.

[0124] In this embodiment, the leakage Z at a certain moment t during the plunger gas lift process is... t It should be expressed as:

[0125] Z t =ρ 液 gΔH

[0126] Among them, Z t ρ represents the leakage at a certain moment during the plunger lift process. 液 denoted by ρ, g represents the gravitational acceleration, and ΔH represents the height difference between the height of the pure liquid column above the plunger when the plunger is in the preset locking position and the height of the pure liquid column above the plunger at a certain moment during the plunger gas lift process.

[0127] Therefore, the specific formula for calculating the plunger leakage at the air lift moment t is:

[0128]

[0129] Among them, Z t ρ represents the leakage at a certain moment during the plunger lift process. 液 The density of the wellbore fluid is given by ρ, g is the acceleration due to gravity, H1 is the fluid level, H2 is the first operating position, P3 is the pressure corresponding to the second operating position, and P is the wellhead oil pressure. 气 H3 indicates the gas density in the wellbore, and H3 indicates the second operating position.

[0130] In summary, the plunger gas lift wellbore parameter monitoring device and leakage calculation method provided in this embodiment can quickly monitor the plunger's operating position, leakage, and the wellbore's fluid level and pressure status. The monitoring accuracy is high and the cost is low, facilitating data analysis by operators. Based on this monitoring device, the dynamic parameters of the plunger's operation can be obtained more efficiently and accurately, and the current wellbore fluid level gauge pressure status can be determined. This provides support for plunger scheme design, subsequent system optimization, and tool selection, effectively avoiding ineffective plunger lifting and improving the effectiveness and efficiency of the plunger process.

[0131] It should be noted that the user information (including but not limited to user device information, user personal information, etc.) and data (including but not limited to data used for analysis, stored data, displayed data, etc.) involved in this application are all information and data authorized by the user or fully authorized by all parties. Furthermore, the acquisition, storage, use, and processing of data in the technical solutions described in the embodiments of this application all comply with relevant regulations.

[0132] Reference Figure 7 As shown, based on the above-described method for calculating leakage in a plunger gas lift process, an embodiment of this specification also provides a computer device 702, wherein the above method operates on the computer device 702. The computer device 702 may include one or more processors 704, such as one or more central processing units (CPUs), each of which can implement one or more hardware threads. The computer device 702 may also include any memory 706 for storing any kind of information such as code, settings, data, etc. Non-limitingly, for example, the memory 706 may include any type of RAM, any type of ROM, flash memory, hard disk, optical disk, etc. More generally, any memory can use any technology to store information. Further, any memory can provide volatile or non-volatile retention of information. Further, any memory can represent a fixed or removable component of the computer device 702. In one case, when the processor 704 executes associated instructions stored in any memory or combination of memories, the computer device 702 can perform any operation of the associated instructions. The computer device 702 also includes one or more drive mechanisms 708 for interacting with any memory, such as a hard disk drive mechanism, an optical disk drive mechanism, etc.

[0133] Computer device 702 may also include an input / output module 710 (I / O) for receiving various inputs (via input device 712) and providing various outputs (via output device 714). A specific output mechanism may include a presentation device 716 and an associated graphical user interface (GUI) 718. In other embodiments, the input / output module 710 (I / O), input device 712, and output device 714 may be omitted, and the device may function solely as a computer device within a network. Computer device 702 may also include one or more network interfaces 720 for exchanging data with other devices via one or more communication links 722. One or more communication buses 724 couple the components described above together.

[0134] Communication link 722 can be implemented in any way, such as via a local area network, a wide area network (e.g., the Internet), a point-to-point connection, or any combination thereof. Communication link 722 may include any combination of hardwired links, wireless links, routers, gateway functions, name servers, etc., governed by any protocol or combination of protocols.

[0135] Corresponding to, for example Figures 3 to 5 In addition to the method shown, embodiments of this specification also provide a computer-readable storage medium storing a computer program that, when executed by a processor, performs the steps of the above-described method.

[0136] This specification also provides computer-readable instructions, wherein when a processor executes the instructions, the program therein causes the processor to perform the following... Figures 3 to 5 The method shown.

[0137] This specification also provides a computer program product, including at least one instruction or at least one program segment, wherein the at least one instruction or the at least one program segment is loaded and executed by a processor to achieve the following: Figures 3 to 5 The method shown.

[0138] It should be understood that in the various embodiments of this specification, the sequence number of each process does not imply the order of execution. The execution order of each process should be determined by its function and internal logic, and should not constitute any limitation on the implementation process of the embodiments of this specification.

[0139] It should also be understood that, in the embodiments of this specification, the term "and / or" is merely a description of the relationship between related objects, indicating that three relationships can exist. For example, A and / or B can represent: A existing alone, A and B existing simultaneously, and B existing alone. Additionally, the character " / " in this specification generally indicates that the preceding and following related objects have an "or" relationship.

[0140] Those skilled in the art will recognize that the units and algorithm steps of the various examples described in conjunction with the embodiments disclosed in this specification can be implemented in electronic hardware, computer software, or a combination of both. To clearly illustrate the interchangeability of hardware and software, the components and steps of each example have been generally described in terms of functionality in the foregoing description. Whether these functions are implemented in hardware or software depends on the specific application and design constraints of the technical solution. Those skilled in the art can use different methods to implement the described functions for each specific application, but such implementation should not be considered beyond the scope of this specification.

[0141] Those skilled in the art will clearly understand that, for the sake of convenience and brevity, the specific working processes of the systems, devices, and units described above can be referred to the corresponding processes in the foregoing method embodiments, and will not be repeated here.

[0142] In the several embodiments provided in this specification, it should be understood that the disclosed systems, apparatuses, and methods can be implemented in other ways. For example, the apparatus embodiments described above are merely illustrative; for instance, the division of units is only a logical functional division, and 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 couplings or direct couplings or communication connections shown or discussed may be indirect couplings or communication connections through some interfaces, devices, or units, or they may be electrical, mechanical, or other forms of connection.

[0143] 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 the embodiments described in this specification, depending on actual needs.

[0144] Furthermore, the functional units in the various embodiments of this specification 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. The integrated unit can be implemented in hardware or as a software functional unit.

[0145] If the integrated unit 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 specification, in essence, or the part that contributes to the prior art, or all or 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 described in the various embodiments of this specification. 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.

[0146] This specification uses specific embodiments to illustrate the principles and implementation methods of this specification. The descriptions of the above embodiments are only for the purpose of helping to understand the methods and core ideas of this specification. At the same time, for those skilled in the art, there will be changes in the specific implementation methods and application scope based on the ideas of this specification. Therefore, the content of this specification should not be construed as a limitation of this specification.

Claims

1. A plunger gas lift wellbore parameter monitoring device, wherein the device is mounted on the plunger, characterized in that, The device includes: a housing and a liquid level monitoring module, an operating position monitoring module, a pressure monitoring module, and a control module disposed within the housing; The liquid level monitoring module is used to monitor the liquid level height inside the wellbore. The running position monitoring module is used to monitor the running position of the plunger in the wellbore at different times; The pressure monitoring module is used to monitor the pressure at the plunger's operating position; The control module is connected to the pressure monitoring module, liquid level monitoring module, and operating position monitoring module, and is used to provide control signals to each module in the device; based on the data collected by the pressure monitoring module, liquid level monitoring module, and operating position monitoring module, it calculates the height difference between the height of the pure liquid column above the plunger when the plunger is in the preset locking position and the height of the pure liquid column above the plunger at a certain moment during the plunger gas lift process; it calculates the leakage amount at a certain moment during the plunger gas lift process based on the height difference; and it generates early warning information based on the leakage amount.

2. The apparatus according to claim 1, characterized in that, The liquid level monitoring module includes a liquid probe and a liquid inlet chamber; The liquid probe is disposed inside the inlet chamber, with the tip of the liquid probe exposed at the opening of the inlet chamber, for acquiring a liquid level signal when liquid flows into the inlet chamber from the wellbore; The liquid inlet chamber is disposed inside the housing and is located on the side wall of the housing. The liquid inlet chamber is used to prevent water vapor in the wellbore from interfering with the liquid level signal detection.

3. The apparatus according to claim 1, characterized in that, The operating position monitoring module includes a calculation module and at least two sets of eddy current sensors. The two sets of eddy current sensors are respectively set at different opposing positions inside the housing and are used to detect the oil pipe coupling signal. The calculation module is connected to the eddy current sensor and is used to calculate the running position of the plunger in the wellbore based on the tubing coupling signal and the tubing depth.

4. The apparatus according to claim 3, characterized in that, The eddy current sensor has a polyetheretherketone (PEEK) housing to prevent metal objects in the wellbore from interfering with the eddy current signal.

5. The apparatus according to claim 1, characterized in that, The control module includes a circuit board, a power supply module, a real-time clock module, a data storage module, and a processor; The circuit board is used to provide control signals to the various modules within the device; The power module is used to provide power for the operation of each module in the device; The real-time clock module is used to record the time points monitored by each module in the device in real time. The data storage module is used to store the data collected by the liquid level monitoring module, the operating position monitoring module, and the pressure monitoring module; The processor is used to calculate the leakage during the plunger gas lift process based on the data collected by the pressure monitoring module, the liquid level monitoring module, and the operating position monitoring module, and to generate early warning information based on the leakage.

6. A method for calculating leakage in a plunger gas lift process, characterized in that, The method is applied to the control module of the device according to any one of claims 1-5, comprising: Acquire data collected by the pressure monitoring module, liquid level monitoring module, and operating position monitoring module; Based on the data collected by the pressure monitoring module, liquid level monitoring module and operating position monitoring module, the height difference between the height of the pure liquid column above the plunger when the plunger is in the preset locking position and the height of the pure liquid column above the plunger at a certain moment during the plunger gas lift process is calculated. The leakage amount at a certain moment during the plunger gas lift process is calculated based on the height difference. Early warning information is generated based on the leakage amount.

7. The method according to claim 6, characterized in that, The data acquired by the pressure monitoring module, liquid level monitoring module, and operating position monitoring module includes: When the plunger descends to the wellbore fluid level, the wellbore fluid level height is obtained from the fluid level monitoring module; When the plunger descends to the preset locking position, the first operating position is obtained from the operating position monitoring module; At a certain moment during the plunger gas lift process, the second operating position is obtained from the operating position monitoring module and the pressure corresponding to the second operating position is obtained from the pressure monitoring module.

8. The method according to claim 7, characterized in that, The calculation of the height difference between the height of the pure liquid column above the plunger when the plunger is in the preset locking position and the height of the pure liquid column above the plunger at a certain moment during the plunger gas lift process includes: Based on the first operating position and the wellbore fluid level, the height of the first pure fluid column above the plunger when the plunger is located at the preset locking device position is calculated; Based on the pressure corresponding to the second operating position, the height of the second pure liquid column above the plunger at a certain moment during the plunger gas lift process is calculated. The height difference is calculated based on the height of the first pure liquid column and the height of the second pure liquid column.

9. The method according to claim 8, characterized in that, The step of calculating the height of the second pure liquid column above the plunger at a certain moment during the plunger gas lift process, based on the second operating position and the pressure corresponding to the second operating position, includes: The height of the second pure liquid column above the plunger at a certain moment during the plunger gas lift process can be calculated using the following formula: Among them, H t H3 represents the height of the second pure liquid column above the plunger at a certain moment during the plunger gas lift process, P3 represents the pressure corresponding to the second operating position, P represents the wellhead oil pressure, and ρ represents the second operating position. 气 ρ represents the density of the gas in the wellbore, g represents the acceleration due to gravity, and ρ represents the acceleration due to gravity. 液 Represents the wellbore liquid density.

10. The method according to claim 8, characterized in that, The calculation of the leakage at a certain moment during the plunger gas lift process based on the height difference includes: The leakage at a certain moment during the plunger gas lift process can be calculated using the following formula: Z t =ρ 液 gΔH; Among them, Z t ρ represents the leakage at a certain moment during the plunger lift process. 液 denoted by ρ, g represents the density of the fluid in the wellbore, g represents the acceleration due to gravity, and ΔH represents the height difference.

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