Old gas well oscillation reactivation digital intelligent yield increasing method and system

Abstract

The invention relates to the technical field of oil and gas production, and discloses an old gas well oscillation reactivation digital intelligent yield increasing method and system. The method comprises the steps that real-time downhole parameters in a tubing string are obtained, and the real-time downhole parameters comprise the pressure, the temperature and the position of a plunger; on the basis of real-time underground parameters, the ascending and descending motion periods of the plunger are controlled through an underground microcontroller; in the ascending process of the plunger, the first turbulent flow device arranged on the plunger is driven to act, so that gas-liquid mixed oscillation is generated around the plunger, and the liquid discharging efficiency is improved; and in the descending process of the plunger, a second turbulent flow device arranged on the plunger is driven to act, so that the fluid resistance of descending of the plunger is reduced. According to the method, gas-liquid mixing optimization and resistance reduction are achieved through real-time monitoring and intelligent control of the turbulent flow device, the recovery efficiency of an old gas well is improved, the production life is prolonged, the operation cost is reduced, and digital transformation of the oil and gas industry is promoted.

Description

Technical Field

[0001] The present invention relates to the field of oil and gas production technology, and in particular to a digital and intelligent production-increasing method and system for oscillating and reviving old gas wells. Background Art

[0002] In the oil and gas extraction industry, production enhancement technology for older gas wells has always been a key area for improving recovery rates, extending the production life of oil and gas fields, and reducing operating costs. With the continued growth of global energy demand and the increasing depletion of oil and gas resources, older gas wells often enter a low-yield or exhaustion stage, with their recovery rates significantly declining and production efficiency low, leading to resource waste and increased economic losses. Traditional oil and gas extraction methods mainly rely on mechanical lifting or gas injection and pressurization. Among them, plunger gas lift technology, as a common artificial lifting method, is widely used in gas well production. This technology utilizes the reciprocating motion of the plunger in the tubing string. The gas pressure at the bottom of the hole pushes the plunger upward to carry liquid to the surface. When descending, it relies on its own weight to fall back, achieving continuous liquid drainage and increased production.

[0003] The core of plunger gas lift technology lies in the effective separation and lifting of gas-liquid two-phase flow, but existing technologies have many limitations. First, during the movement of the plunger, the gas-liquid mixing is often insufficient, resulting in low efficiency of upward drainage and inability to maximize the utilization of bottomhole gas energy. Secondly, the fluid resistance in the downward phase is large, which can easily cause energy loss and plunger jamming, affecting overall production stability. In addition, traditional systems lack the ability to monitor and dynamically adjust downhole parameters in real time, making it difficult to adapt to complex changes in gas wells, such as pressure fluctuations, temperature variations, and increased water content. These problems make it difficult to break through the bottleneck of the recovery rate of old gas wells, and operating costs remain high. At the same time, they also face environmental pressures such as increased carbon emissions and inefficient resource utilization.

[0004] With the advancement of digital transformation in the oil and gas industry, technologies such as big data analysis, artificial intelligence, and remote monitoring are gradually being introduced into production processes. However, existing plunger gas lift systems still lack intelligence. Most equipment relies on manual intervention or simple timed control, which prevents precise parameter optimization and predictive maintenance. This leads to delayed production decisions and makes it difficult to cope with multi-well linkage or extreme operating conditions. While some international improvements have been proposed, such as optimizing plunger structure or introducing basic sensors, these methods still do not completely resolve the dynamic imbalance of gas-liquid flow and lack material durability and system integration. Domestic oil and gas field development faces similar challenges. Many old gas wells have been forced to shut down due to outdated technology. There is an urgent need for efficient and environmentally friendly production-enhancing technologies to overcome traditional limitations and promote sustainable development in the industry. This demand for technology stems not only from improving economic efficiency but also from the strategic significance of ensuring energy security and promoting green mining. Summary of the Invention

[0005] The purpose of the present invention is to address the shortcomings of the existing technology and propose a digital intelligent production increase method and system for oscillating revival of old gas wells. To achieve the above purpose, the embodiment of the present invention adopts the following technical solutions:

[0006] In a first aspect, embodiments of the present invention provide a digitally intelligent production enhancement method for oscillating revitalization of aged gas wells. The method is applied to a gas well in which a tubing string is installed with a plunger, and the plunger reciprocates in the tubing string in an upward and downward direction, comprising the following steps:

[0007] Obtain real-time downhole parameters in the tubing string, including pressure, temperature, and plunger position;

[0008] Based on real-time downhole parameters, the plunger's upward and downward movement cycles are controlled by a downhole microcontroller;

[0009] During the upward movement of the plunger, the first flow disturbing device provided on the plunger is driven to operate, so as to generate gas-liquid mixing oscillation around the plunger, thereby improving the liquid discharge efficiency;

[0010] During the downward movement of the plunger, the second flow-turbulating device provided on the plunger is driven to operate so as to reduce the fluid resistance of the downward movement of the plunger.

[0011] Preferably, the first spoiler is a built-in pop-up spoiler, which includes a spoiler plate. The steps of driving the first spoiler provided on the plunger to operate include:

[0012] The driving plunger ejects the spoiler from the inside of the main body to create gas-liquid mixing oscillation.

[0013] Preferably, the second spoiler is an external swinging spoiler, which includes spoiler wings. The steps of driving the second spoiler provided on the plunger to operate include:

[0014] The spoiler wings are driven to swing with the fluid to reduce the downward resistance of the plunger.

[0015] Preferably, the method further comprises the following steps:

[0016] The real-time downhole parameters and control data collected by the downhole microcontroller are uploaded to the ground big data platform for storage and processing through the data acquisition and monitoring device.

[0017] Preferably, historical data stored in the ground big data platform is used to train a machine learning model to predict the production trend of gas wells.

[0018] Preferably, the method further comprises the following steps:

[0019] Based on the production trend prediction results of the machine learning model, the control algorithm of the downhole microcontroller or the upward and downward movement cycle of the plunger are adjusted automatically or via remote commands to optimize production decisions.

[0020] Preferably, the method further comprises the following steps:

[0021] Through the remote control platform on the ground, the system receives diagnostic or control instructions from remote experts and makes online adjustments to the control algorithm of the downhole microcontroller.

[0022] Preferably, the downhole microcontroller calculates the comprehensive efficiency in real time based on a computing power calculation model including the plunger speed, the efficiency coefficient of the spoiler device and the wellbore pressure, and adaptively adjusts the working mode of the first spoiler device and the second spoiler device according to the comprehensive efficiency.

[0023] In a second aspect, an embodiment of the present invention provides a digital and intelligent production stimulation system for oscillatingly revitalizing an old gas well, comprising a plunger installed in an oil tubing string of the gas well, and further comprising: a first flow disruptor and a second flow disruptor provided on the plunger; a downhole sensor device provided in the oil tubing string for monitoring real-time downhole parameters; and a downhole microcontroller electrically connected to the downhole sensor device, the downhole microcontroller being configured to: during the upward movement of the plunger, control the operation of the first flow disruptor to generate gas-liquid mixing oscillation; and during the downward movement of the plunger, control the operation of the second flow disruptor to reduce fluid resistance;

[0024] The main body of the plunger is made of titanium-aluminum alloy, and a ceramic coating or a hard alloy inlaid layer is provided on its easily worn parts; the first spoiler is a built-in pop-up spoiler arranged inside the plunger body, and the second spoiler is an external swinging spoiler arranged outside the bottom of the plunger.

[0025] Preferably, it further includes a ground part, which includes:

[0026] A data acquisition and monitoring device for communicating with a downhole microcontroller and collecting downhole data; and a remote control platform connected to the data acquisition and monitoring device, which is used to analyze and visualize the collected data and to perform remote diagnosis and control.

[0027] Beneficial effects:

[0028] The present invention provides a digitally intelligent production-enhancing method and system for reviving aged gas wells through oscillation. This method acquires downhole parameters such as pressure, temperature, and plunger position in real time within the tubing string, and uses a downhole microcontroller to dynamically control the plunger's upward and downward motion cycles based on these parameters, achieving precise control of the production process. During the upward movement, this method activates a first flow disturbance device to generate gas-liquid mixing oscillations, effectively improving drainage efficiency and overcoming the low recovery rate caused by inadequate gas-liquid separation in traditional plunger gas lift technology. During the downward movement, a second flow disturbance device is activated to reduce fluid resistance, minimizing energy loss and the risk of plunger jamming, thereby improving overall system stability and operational reliability. Compared to existing technologies, this method significantly improves the recovery rate of aged gas wells, extends the production life of oil and gas fields, and reduces operating costs and maintenance frequency. Through intelligent adaptive regulation, it adapts to the dynamic changes of gas wells, avoids the lag associated with manual intervention, and promotes the digital transformation of the oil and gas industry. Furthermore, this method reduces resource waste and carbon emissions, promotes green mining and sustainable development, and provides a reliable solution for the efficient revitalization of aged gas wells, with broad application prospects and economic value. BRIEF DESCRIPTION OF THE DRAWINGS

[0029] Various other advantages and benefits will become apparent to those skilled in the art upon reading the detailed description of the preferred embodiment below. The accompanying drawings are for illustration purposes only and are not to be considered as limiting the present invention. The same reference numerals are used throughout the accompanying drawings to denote the same components. In the accompanying drawings:

[0030] Figure 1 A schematic diagram of a flow chart of a digital and intelligent production enhancement method for oscillating revival of old gas wells provided in one embodiment of the present invention;

[0031] Figure 2 A schematic diagram of the structure of an oscillation-based digital stimulation system for revitalizing old gas wells provided by one embodiment of the present invention;

[0032] Figure 3 This is a diagram showing the operating principle of the digital and intelligent production increase system for oscillating resurrection of old gas wells provided in one embodiment of the present invention. DETAILED DESCRIPTION

[0033] Embodiments of the present invention are described in detail below, examples of which are shown in the accompanying drawings, wherein the same or similar reference numerals throughout represent the same or similar elements or elements having the same or similar functions. The embodiments described below with reference to the accompanying drawings are exemplary and are intended only to explain the present invention and are not to be construed as limiting the present invention. It should be noted that similar reference numerals and letters represent similar items in the following drawings, and therefore, once an item is defined in one drawing, it does not need to be further defined or explained in subsequent drawings.

[0034] First, see Figure 1 、 Figure 2 and Figure 3 As shown, an oscillation-based digital production enhancement method for revitalizing old gas wells, proposed in an embodiment of the present invention, is applied to an oscillation-based digital production enhancement system for old gas wells. The oscillation-based digital production enhancement system for old gas wells can be executed, but is not limited to, by a computer device with certain computing resources, such as a personal computer (PC, a multi-purpose computer with a size, price, and performance suitable for personal use; desktops, laptops, small laptops, tablets, and ultrabooks are all PCs), a smartphone, a personal digital assistant (PAD), or a platform server. This embodiment provides an oscillation-based digital production enhancement method for revitalizing old gas wells, applied to a gas well equipped with a tubing string equipped with a plunger, which reciprocates in both upward and downward directions within the tubing string. Specifically, the method is designed for old gas wells in the oil and gas extraction industry, which often suffer from problems such as reduced recovery rates and low production efficiency due to long-term production. Although traditional plunger gas lift technology is widely used, it has limitations such as insufficient gas-liquid mixing, high downward resistance, and a lack of dynamic adjustment capabilities. This method achieves precise control of plunger movement through real-time monitoring, control, and flow optimization, thereby improving drainage efficiency, reducing resistance, and ultimately increasing the recovery rate of mature gas wells. The specific steps of this method are as follows:

[0035] Step S1, obtaining real-time downhole parameters in the tubing string, including pressure, temperature and plunger position.

[0036] In this step, the first step is to deploy a downhole sensor system to collect data in real time. These sensors are installed on the tubing string, close to the working area of ​​the plunger, such as above the perforation section. Specifically, the pressure sensor uses a high-precision piezoresistive or fiber optic pressure sensor that can withstand the high temperature and high pressure environment downhole, and monitor the fluid pressure changes in the wellbore in real time to capture the dynamic characteristics of the gas-liquid two-phase flow. The temperature sensor uses a thermistor or thermocouple type to monitor downhole temperature fluctuations, which is crucial for evaluating fluid viscosity and phase changes. The plunger position sensor can use a magnetic induction or ultrasonic positioning device to accurately track the up and down position of the plunger in the tubing string with a resolution of up to centimeters.

[0037] The data acquisition process is coordinated by a dedicated downhole microcontroller, which integrates an A / D converter module to convert analog signals into digital signals and collect data at a specific sampling frequency, such as 10 to 100 times per second. To ensure data reliability, a built-in filtering algorithm eliminates noise interference, such as signal fluctuations caused by downhole vibration or fluid turbulence. Furthermore, given the extreme downhole environment, the sensor housing is coated with corrosion-resistant materials, such as stainless steel or titanium alloy, to prevent corrosion from acidic media. The collected real-time downhole parameters are not only used for local control but also initially processed via wired or wireless communication modules and stored in the microcontroller's flash memory. This step addresses the problem of untimely parameter monitoring in traditional technologies. In mature gas wells, downhole parameters often change dynamically over time and during production stages, such as pressure drops that reduce gas lift efficiency. Failure to obtain these parameters in real time can lead to further declines in recovery. Accurate monitoring in this step provides a data foundation for subsequent control, ensuring the operability and stability of the method.

[0038] Step S2, based on real-time downhole parameters, the up and down movement cycles of the plunger are controlled by a downhole microcontroller.

[0039] After acquiring real-time downhole parameters, a downhole microcontroller, acting as the core control unit, analyzes and processes this data. The microcontroller utilizes an embedded processor, such as the ARM Cortex-M series, with a built-in real-time operating system capable of multitasking and parallel computing. The control logic is based on pre-defined algorithms, such as an adaptive algorithm combining PID control with fuzzy logic. First, the microcontroller analyzes pressure and temperature data to calculate the gas energy availability at the bottom of the well. Simultaneously, based on plunger position data, it determines the current movement phase (upward or downward).

[0040] Specific methods for controlling the piston movement cycle include adjusting the timing of valve opening and closing and the amount of gas injected. In traditional piston gas lift, the piston is pushed downward by its own weight and upward by gas, but the cycle is fixed and cannot adapt to changes. In this method, the microcontroller dynamically adjusts according to real-time parameters. For example, if the pressure is lower than the threshold (calculated after temperature correction), the microcontroller can extend the downward time to accumulate more liquid; conversely, if the piston position shows that the upward speed is too slow, the upward cycle can be shortened by auxiliary gas injection. The control output is realized through an actuator, such as a solenoid valve that controls the opening and closing of the valve at the bottom of the piston.

[0041] To optimize control, the microcontroller integrates adaptive adjustment capabilities and uses preliminary machine learning models, such as simple neural networks, to predict the adjustment amount for the next cycle based on historical parameter trends. This ensures that the system responds to dynamic changes in the gas well. For example, when the water content increases and the density changes, the drainage time is automatically extended. The entire control process is executed locally underground, reducing transmission delays and improving real-time performance. At the same time, the microcontroller has a fault diagnosis function. If the parameters are abnormal, such as excessive temperature, it can trigger a safety mode and suspend movement to protect the equipment. The core of this step is to convert real-time data into control signals, breaking through the rigid cycle limitations of traditional technology. Through this parameter-based dynamic control, not only the flexibility of the system is improved, but also energy loss is reduced, laying the foundation for subsequent turbulence optimization.

[0042] Step S3: During the upward movement of the plunger, the first flow-turbulating device provided on the plunger is driven to operate so as to generate gas-liquid mixing oscillation around the plunger to improve the liquid discharge efficiency.

[0043] During the upward movement, the plunger carries the liquid upward, and the first flow-disturbing device is activated to enhance gas-liquid interaction. Preferably, the first flow-disturbing device is a built-in pop-up flow-disturbing device, which includes a spoiler. The step of driving the first flow-disturbing device disposed on the plunger to operate includes: driving the plunger to pop out the spoiler from within the main body to generate gas-liquid mixing oscillation.

[0044] In practice, a built-in pop-up spoiler is installed inside the plunger body. The spoiler is made of a lightweight alloy (such as aluminum alloy) and has a multi-blade structure that can be ejected by a spring or hydraulic mechanism. Upon detecting the start of upward movement, the microcontroller sends a signal to activate the pop-up mechanism. The spoiler extends from the interior of the plunger at an adjustable angle. The gas pushes against it to generate turbulence, causing the gas-liquid interface to oscillate. This oscillation promotes the uniform distribution of bubbles in the liquid, enhancing lift and preventing slippage losses caused by gas-liquid separation.

[0045] The spoiler blade curvature can be designed using simulation software to ensure that the oscillation frequency matches the plunger speed. During the ejection process, the device balances structural strength and flexibility, and finite element analysis is used to verify durability. Compared with traditional non-turbine designs, this device can significantly improve drainage efficiency because the oscillation increases the gas-liquid contact area and optimizes energy transfer. In addition, the device's retraction mechanism is automatically triggered at the end of the upward movement, reducing unnecessary resistance. The entire drive process is coordinated by a microcontroller to ensure synchronization with the cycle control of step S2. If temperature parameters indicate high fluid viscosity, the microcontroller can increase the ejection angle to enhance the oscillation intensity.

[0046] Step S4: During the downward movement of the plunger, the second flow-turbulating device provided on the plunger is driven to operate so as to reduce the fluid resistance of the plunger during its downward movement.

[0047] During the downward process, the plunger falls back under its own weight, at which time the second spoiler is activated to minimize resistance. Preferably, the second spoiler is an external swinging spoiler, which includes spoiler wings. The step of driving the second spoiler provided on the plunger to operate includes: driving the spoiler wings to swing with the fluid to reduce the resistance of the plunger downward. The external swinging spoiler is installed on the outside of the bottom of the plunger. The spoiler wings are made of flexible material and can swing freely under the action of the fluid. The microcontroller activates the swing mode at the beginning of the downward movement: the spoiler wings automatically adjust their angles according to the direction of the fluid to form a streamlined profile, reduce the generation of vortices, and thus reduce the drag coefficient.

[0048] The device design takes dynamic performance into consideration, with the airfoil optimized through experiments to minimize drag at descending speeds. Material selection emphasizes corrosion resistance and lightweight, such as a titanium-aluminum alloy body with a ceramic coating for extended life. During the swinging motion, the airfoils are designed to produce slight oscillations, further dispersing the fluid boundary layer and preventing sticking. This step, in conjunction with the upward movement mechanism, ensures balanced plunger motion. Synchronously controlled by a microcontroller, if pressure parameters indicate high drag, the swing frequency is increased to optimize the path.

[0049] Furthermore, the method also includes the following steps: uploading the real-time downhole parameters and control data collected by the downhole microcontroller to the ground big data platform for storage and processing through the data acquisition and monitoring device.

[0050] During data upload, the downhole microcontroller packages the collected pressure, temperature, and position data, along with the control log, and transmits it to the surface via the wellhead communication interface. The data acquisition and monitoring device, located at the wellhead and integrated with an edge computing unit, performs preliminary cleaning and compression to reduce bandwidth usage. The data is then uploaded to the surface big data platform, which uses distributed storage to ensure data security and prevent data loss through encryption and redundant backups. The processing includes data standardization and aggregation, such as integrating multi-well data into a time-series database for subsequent analysis. This step expands the intelligence level of the method and achieves a closed-loop data loop from downhole to the surface.

[0051] Preferably, historical data stored in the ground big data platform is used to train a machine learning model to predict the production trend of gas wells.

[0052] Historical data accumulated on the big data platform, such as parameter records from the past few months, is used to train the model. The model uses supervised learning algorithms, such as LSTM neural networks, with input features including pressure, temperature, and position sequences, and outputs production forecasts. The training process consists of phases: data preprocessing, model construction, and validation. The prediction model considers gas well dynamics, such as incorporating the influence of water cut. Through periodic retraining, the model adapts to new data, achieving accurate trend predictions, such as providing early warning of production declines.

[0053] Preferably, the following steps are also included: based on the production trend prediction results of the machine learning model, the control algorithm of the downhole microcontroller or the upward and downward movement cycle of the plunger is automatically adjusted or via remote instructions to optimize production decisions.

[0054] Prediction results are fed back to the system. If the model predicts a decrease in production, algorithm parameters are automatically adjusted, such as increasing the upcycle to improve drainage. Alternatively, remote instructions can be issued, such as through expert review and subsequent revision of control thresholds. This adjustment mechanism uses an optimizer, such as a genetic algorithm, to determine the optimal cycle combination. In automatic mode, the microcontroller's built-in rules engine executes the results; remote mode ensures manual intervention in complex scenarios. This step achieves closed-loop optimization, driving the transition from empirical to data-driven production decision-making.

[0055] Preferably, the method further includes the following steps: receiving diagnostic or control instructions issued by remote experts through a remote control platform on the ground, and performing online adjustment on the control algorithm of the downhole microcontroller.

[0056] The remote control platform is cloud-based and supports multi-terminal interaction. Experts use a visual interface to view data, diagnose issues such as abnormal oscillation, and issue commands, such as algorithm parameter updates. Communication utilizes a secure protocol to ensure low latency. Online adjustments, such as firmware upgrades or parameter adjustments, take effect immediately upon receipt by the microcontroller. This enhances system maintainability, especially in remote gas wells.

[0057] Preferably, the downhole microcontroller calculates the comprehensive efficiency in real time based on a computing power calculation model including the plunger speed, the efficiency coefficient of the spoiler device and the wellbore pressure, and adaptively adjusts the working mode of the first spoiler device and the second spoiler device according to the comprehensive efficiency.

[0058] The calculation model of computing power is based on the modified plunger gas lift theory, and the definition symbol is: Q is the gas-liquid mixed flow rate (m 3 / s), P is pressure (Pa), v is plunger speed (m / s), Rd is downward resistance coefficient, Ru is upward drainage efficiency coefficient, Cf is the efficiency coefficient of the spoiler, η is the comprehensive efficiency, and Δt is the time step (s).

[0059] Basic assumptions: gas-liquid mixing is ideal, and turbulence efficiency is proportional to velocity. Model derivation:

[0060] Gas-liquid mixed flow rate: Q = Cf·v·A (A is the wellbore area).

[0061] Downward resistance: Rd = Rd0·e^(-Cf·v) (initial value of Rd0).

[0062] Uplink efficiency: Ru = Ru0 + Cf·v (initial value of Ru0).

[0063] Overall efficiency: η = Ru / Rd.

[0064] Production forecast: Vprod = Q·Δt.

[0065] The microcontroller calculates η in real time. If η falls below a threshold, it adaptively adjusts: increasing Cf (by adjusting the ejection angle) or optimizing v (by adjusting the cycle). In a simplified model, Cf is a piecewise function, using the empirical formula Q = k1·P + k2·v + k3·Cf (k1-k3 fitting coefficients). This model enables self-optimization and ensures efficient operation.

[0066] In terms of materials, the plunger body is made of titanium-aluminum alloy, which is lightweight, high-strength and corrosion-resistant. Parts prone to wear are supplemented with ceramic coatings or cemented carbide inlays to extend their service life. The installation method can be optional, either segmented or integrated tubing. Preliminary preparations include geological surveys and equipment selection. Communication stability is tested during debugging. This embodiment fully realizes the intelligent production increase of old gas wells through the above steps and preferred expansion. Combining turbulence design, intelligent control and large number calculation method, this method not only improves the recovery rate, but also reduces costs and promotes sustainable development.

[0067] On the second aspect, Figure 2 and Figure 3 As shown, an oscillation resurrection digital production increase system for old gas wells provided in this embodiment is applied to the oil and gas extraction industry, and is especially designed for the production increase needs of old gas wells. Old gas wells often suffer from problems such as decreased recovery rate, low gas-liquid separation efficiency and increased operating costs due to long-term exploitation. Although the traditional plunger gas lift system can achieve basic lifting functions, it has the limitations of insufficient gas-liquid mixing, large downward resistance and lack of intelligent regulation. This system realizes dynamic optimization of the plunger movement by integrating mechanical spoiler devices, sensors and control modules, thereby improving drainage efficiency, reducing fluid resistance and extending equipment life. This system is not only suitable for various types of oil and gas wells, but is especially suitable for old gas wells that need to increase production. It can significantly improve recovery rate, reduce costs, and promote the digital transformation of the industry. The main components of the system include:

[0068] A plunger installed in a gas well tubing string also includes: a first and second flow disruptor mounted on the plunger; a downhole sensor device mounted in the tubing string for monitoring real-time downhole parameters; and a downhole microcontroller electrically connected to the downhole sensor device. The downhole microcontroller is configured to: during the plunger's upward movement, control the first flow disruptor to generate gas-liquid mixing oscillation; and during the plunger's downward movement, control the second flow disruptor to reduce fluid resistance.

[0069] Specifically, the plunger, the system's core moving component, is installed inside the tubing string above the perforating section. The plunger's function is to move up and down within the tubing, carrying a column of fluid to the surface for continuous discharge. A valve at its base opens during downward movement to allow fluid in, and closes during upward movement, using well gas or injected gas to propel the plunger upward. The plunger's body is made of a titanium-aluminum alloy, a lightweight, high-strength, and corrosion-resistant material that withstands the extreme downhole environment of high temperatures, high pressures, and corrosive media. Furthermore, ceramic coatings or carbide inlays are applied to high-wear areas of the plunger, such as the bottom valve contact surface and sidewall friction zones. The ceramic coating is made of aluminum oxide or silicon carbide, applied via plasma spraying to reduce wear. The carbide inlays are made of a WC-Co alloy, secured by brazing to enhance impact resistance. These material choices and processing techniques address the corrosion and wear issues inherent in traditional equipment in downhole environments, extending equipment life and reducing maintenance costs. Through extensive experiments and simulation optimization, we ensure balanced material performance and economic efficiency. For example, in high-temperature and high-pressure simulation tests, the durability of coated components is improved.

[0070] The first spoiler device is a built-in pop-up spoiler device arranged inside the plunger body. The device includes a spoiler with a multi-blade structure and a material of a lightweight alloy, such as an aluminum-magnesium alloy, with a smooth surface to reduce additional resistance. The function of the device is to pop out the spoiler from the inside of the main body when the plunger moves upward, creating gas-liquid mixing oscillations. During specific operation, the spoiler is popped out by a built-in spring or hydraulic actuator, and the angle is adjustable. Under the push of the gas, a turbulent effect is generated, which promotes the uniform distribution of bubbles and improves the drainage efficiency. The difficulty of the design lies in taking into account the structural strength, flexibility and durability. The geometric shape is optimized through finite element analysis. For example, the blade curvature design is based on the principles of fluid mechanics to ensure that the oscillation frequency matches the plunger speed. Compared with the traditional non-spoiler design, this device enhances the gas-liquid mixing effect and breaks through the bottleneck of low gas-liquid separation efficiency.

[0071] The second spoiler device is an external swinging spoiler device arranged on the outside of the bottom of the plunger. The device includes a spoiler wing, which is made of a flexible composite material, such as carbon fiber reinforced plastic, and is connected to the bottom of the plunger by a hinge. The function of the device is to drive the spoiler wing to swing with the fluid when the plunger descends, thereby reducing the downward resistance. In a specific implementation, the spoiler wing automatically adjusts its angle under the action of the fluid to form a streamlined profile, reducing eddy currents and boundary layer separation. The airfoil optimization is simulated using aerodynamic software (such as ANSYS Fluent) to ensure that the drag coefficient Rd is reduced during the downward process. The material is supplemented with a ceramic coating to enhance wear resistance. The dynamic performance of the entire device has been verified experimentally. For example, in a simulated wellbore test, the downward resistance is significantly reduced, thereby improving the upward drainage efficiency.

[0072] Downhole sensors are installed within the tubing string, near the plunger's operating area, to monitor real-time downhole parameters, including pressure, temperature, and plunger position. The pressure sensor is a high-precision piezoresistive type with a range of 0-100 MPa and an accuracy of ±0.1%. The temperature sensor is a platinum resistance type with a range of -50°C to 200°C and an accuracy of ±0.5°C. The position sensor uses magnetic induction or ultrasonic technology. The sensor system integrates a power module and signal amplifier to withstand the corrosive downhole environment. It connects to the downhole microcontroller via cable or wirelessly. Data acquisition can reach 100 times per second, and a built-in filtering algorithm eliminates noise to ensure data accuracy.

[0073] The downhole microcontroller is the intelligent core of the system. It is electrically connected to the sensor device and uses an embedded processor (such as the STM32 series) with a built-in RTOS operating system to support multi-tasking. The microcontroller is configured to control the spoiler based on real-time parameters: during the upward process, after detecting the position signal, the first spoiler is activated to pop out the spoiler and generate oscillations; during the downward process, the second spoiler is activated to swing the spoiler wings to reduce resistance. The control algorithm combines PID and fuzzy logic to achieve adaptive regulation, such as automatically adjusting the pop-up angle or swing frequency according to pressure changes. The microcontroller also integrates a computing power calculation model for real-time performance evaluation. Model definition symbol: Q is the gas-liquid mixture flow rate (m 3 / s), P is pressure (Pa), v is plunger velocity (m / s), Rd is the downward resistance coefficient, Ru is the upward drainage efficiency coefficient, Cf is the spoiler efficiency coefficient (typically 0.8), and η is the overall efficiency. The derived formulas include: Q = Cf·v·A (A is the wellbore area); Rd = Rd0·e^(-Cf·v) (Rd0 = 1.2); Ru = Ru0 + Cf·v (Ru0 = 0.6); η = Ru / Rd. Through these calculations, the microcontroller optimizes the model in real time. For example, if η < 0.8, Cf is increased to improve efficiency. This model is based on a modification of traditional plunger gas lift theory, ignoring minor factors such as interfacial tension, focusing on key variables, and ensuring robustness.

[0074] Preferably, the system also includes a ground part, which includes: a data acquisition and monitoring device for communicating with the downhole microcontroller and collecting downhole data; and a remote control platform connected to the data acquisition and monitoring device, the remote control platform is used to analyze and visualize the collected data, and for remote diagnosis and control. The data acquisition and monitoring device is installed at the wellhead, integrated with a communication interface (such as Modbus or wireless 4G / 5G module), and receives downhole data in real time, including parameters and control logs. The device has edge computing capabilities, performs preliminary processing such as data compression and anomaly detection, and then uploads it to the big data platform. The platform is based on cloud storage (such as Alibaba Cloud or AWS), supports multi-well data aggregation, and uses machine learning algorithms to train models, such as using LSTM to predict production trends. The historical data training process includes preprocessing, model building and verification to ensure accurate predictions.

[0075] The remote control platform is built on a web-based architecture and supports multi-device interaction (PC, tablet, and mobile phone). The interface visualizes data such as pressure curves and plunger trajectory. Experts can perform remote diagnostics, such as analyzing abnormal oscillations and issuing instructions to adjust microcontroller algorithms. Communication is secure and low-latency, achieved through an encrypted protocol. The platform also supports collaborative control and real-time consultation among multiple experts to resolve complex issues such as equipment failures.

[0076] This system uses flow disturbance design, high-quality materials, intelligent control, big data analysis, remote control and modularization. Compared with existing technologies, it can improve recovery rate, reduce costs, reduce carbon emissions and promote sustainable development. Assuming the well is 3000m deep and the initial production is 500m 3 / day, after application, calculated by model, Q = 0.04m 3 / s, Rd decreased by 33%, Ru increased by 67%, η increased by 60%, and the output increased significantly.

[0077] On the third aspect, the present invention also discloses a computer program product, including a computer program / instruction, which, when executed by a processor, implements the steps of the above-mentioned digital production increase method for oscillation revival of old gas wells provided by the present invention. The computer program product should be understood as a software product that mainly implements its solution through a computer program, such as a program product integrated in the cloud or a software library.

[0078] Throughout this specification, reference to terms such as "one embodiment," "some embodiments," "example," "specific example," "one implementation," "a preferred implementation," or "some examples" means that the specific features, structures, materials, or characteristics described in conjunction with that embodiment or example are included in at least one embodiment or example of the present invention. In this specification, schematic representations of the above terms do not necessarily refer to the same embodiment or example. Furthermore, the specific features, structures, materials, or characteristics described may be combined in any suitable manner in any one or more embodiments or examples.

[0079] While embodiments of the present invention have been shown and described, it will be appreciated by those skilled in the art that various changes, modifications, substitutions, and variations may be made to the embodiments without departing from the principles and spirit of the invention, and that the scope of the invention is defined by the claims and their equivalents.

Claims

1. A digital and intelligent production stimulation method for oscillating revitalization of old gas wells, the method being applied to a gas well in which a tubing string is installed with a plunger, the plunger reciprocating in the tubing string in an upward and downward direction, characterized in that: The following steps are involved: Acquiring real-time downhole parameters in the tubing string, the real-time downhole parameters including pressure, temperature, and position of the plunger; Based on the real-time downhole parameters, controlling the upward and downward movement cycles of the plunger by a downhole microcontroller; During the upward movement of the plunger, a first flow disturbing device provided on the plunger is driven to operate, so as to generate gas-liquid mixing oscillation around the plunger, thereby improving the liquid discharge efficiency; During the downward movement of the plunger, the second flow-turbulating device provided on the plunger is driven to operate so as to reduce the fluid resistance of the downward movement of the plunger.

2. The method according to claim 1, characterized in that The first spoiler is a built-in pop-up spoiler, which includes a spoiler plate. The steps of driving the first spoiler provided on the plunger to operate include: The plunger is driven to eject the spoiler from the interior of the main body to produce gas-liquid mixing oscillation.

3. The method according to claim 2, characterized in that The second spoiler is an external swing spoiler, and the external swing spoiler includes spoiler wings. The steps of driving the second spoiler provided on the plunger to operate include: The spoiler wings are driven to swing along with the fluid to reduce the downward resistance of the plunger.

4. The method according to claim 3, characterized in that The following steps are also included: The real-time downhole parameters and control data collected by the downhole microcontroller are uploaded to the ground big data platform through the data acquisition and monitoring device for storage and processing.

5. The method according to claim 4, characterized in that The historical data stored in the ground big data platform is used to train a machine learning model to predict the production trend of gas wells.

6. The method according to claim 5, characterized in that The following steps are also included: Based on the production trend prediction results of the machine learning model, the control algorithm of the downhole microcontroller or the upward and downward movement cycles of the plunger are adjusted automatically or via remote instructions to optimize production decisions.

7. The method according to claim 4, characterized in that The following steps are also included: The remote control platform of the ground part receives the diagnosis or control instructions issued by the remote expert and performs online adjustment on the control algorithm of the downhole microcontroller.

8. The method according to claim 1, characterized in that The downhole microcontroller calculates the comprehensive efficiency in real time based on a calculation model including the plunger speed, the efficiency coefficient of the spoiler device and the wellbore pressure, and adaptively adjusts the working modes of the first spoiler device and the second spoiler device according to the comprehensive efficiency.

9. A digital intelligent production stimulation system for oscillating and revitalizing old gas wells, comprising a plunger installed in the oil tubing string of the gas well, characterized in that: Also includes: a first flow-turbulating device and a second flow-turbulating device provided on the plunger; A downhole sensor device disposed in the oil tubing string for monitoring real-time downhole parameters; and a downhole microcontroller electrically connected to the downhole sensor device, wherein the downhole microcontroller is configured to: control the first flow disrupting device to operate so as to generate gas-liquid mixing oscillation during the upward movement of the plunger; During the downward movement of the plunger, the second flow-disturbing device is controlled to operate to reduce fluid resistance; The main body of the plunger is made of titanium-aluminum alloy, and a ceramic coating or a hard alloy inlaid layer is provided on its easily worn parts; the first spoiler is a built-in pop-up spoiler arranged inside the plunger main body, and the second spoiler is an external swinging spoiler arranged outside the bottom of the plunger.

10. The system according to claim 9, characterized in that Also included is a ground portion, the ground portion comprising: A data acquisition and monitoring device for communicating with the downhole microcontroller and collecting downhole data; and a remote control platform connected to the data acquisition and monitoring device, the remote control platform being used for analyzing and visualizing the collected data and for remote diagnosis and control.

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