Split plunger for gas well production, regulating control system and regulating control method

Abstract

The application discloses a split type plunger for gas well production, an adjusting and controlling system and an adjusting and controlling method, which comprises a sealing ball and a plunger body, the plunger body comprises a plunger barrel, an umbrella surface, an umbrella rib assembly, an umbrella drive assembly and a first control module, a hollow sliding shaft is fixed in the plunger barrel, the umbrella rib assembly is installed on the sliding shaft, the first control module can control the umbrella drive assembly to drive the umbrella rib assembly to make the umbrella surface expand and contract, the umbrella drive assembly is arranged to automatically control the umbrella rib assembly to drive the umbrella surface to expand and contract according to the temperature change in the gas well, and the sealing ball and the bottom of the plunger barrel can be mechanically combined and sealed or mechanically separated in the gas well. The umbrella drive assembly designed in the application has the functions of passive autonomous expansion and passive expansion, the umbrella surface is tightly attached to the inner wall of the gas well in the rising process, the gas slip-up is reduced, the umbrella surface is adjusted to contract in the falling process, the falling speed is autonomously adjustable, and the drainage gas recovery efficiency is improved.

Description

Technical Field

[0001] The present invention relates to the technical field of natural gas extraction, and in particular to a split plunger, a regulating control system and a regulating control method for gas well production. Background Art

[0002] During the natural gas extraction process, the initial production is generally relatively high. However, as the reservoir energy decays, in the middle and late stages of production, the gas production will be less than the critical liquid carrying rate. The insufficient liquid carrying capacity will cause liquid accumulation in the wellbore, resulting in a drop in wellhead pressure, a decrease in gas permeability, and "water intrusion" and "water lock" in the production layer, which seriously affects the sustainable development of the gas well. Appropriate drainage and gas production technology is often used to drain the wellbore liquid and restore normal production of the gas well.

[0003] The plunger drainage gas production process is a common and important drainage gas production process. It uses the energy of the gas well itself to push the plunger in the wellbore to lift the accumulated liquid. It is similar to the principle of a long-stroke pump. The oil pipe is used as the pump barrel and the plunger is used as the piston. The plunger and the liquid column above the plunger are lifted to the ground under the action of gas pressure. This process method uses the mechanical isolation interface between the power source lifting gas and the produced liquid formed by the plunger structure. It does not require other power equipment and has the characteristics of low cost and wide application. It can reduce gas upward slippage and is of great significance for drainage gas production. However, with the continuous increase in the demand for low-pressure, low-yield, and low-abundance gas well exploitation, and the production of traditional plunger processes, there are many problems to be solved, specifically:

[0004] 1) After each plunger lift, the plunger falls back due to the effect of gas in the wellbore and the downward resistance, resulting in a slow migration speed, low drainage circulation efficiency, and a long shut-in time. The cycle control of intermittent production is limited by the shut-in time and cannot achieve optimal efficiency.

[0005] 2) To achieve plunger gas lift drainage without shutting down the well, patent CN103670337B proposes designing the integrated plunger as a split plunger, which consists of a plunger body and a split seal. After being lifted to the vicinity of the wellhead, the plunger body and the split seal are mechanically separated by impact with the wellhead buffer device, and then fall to the bottom of the well to reassemble into an integrated plunger. There is a risk of poor sealing and slippage in the rising section of the wellbore, and there is a problem of premature combination of the plunger body and the split seal during the falling process of the wellbore, which makes it difficult to fall and reduces the drainage efficiency.

[0006] 3) The switch well and the fine control of the choke valve flow in the plunger gas lift production are of great significance to avoid overproduction of gas well and rapid depletion of formation pressure, to stabilize the gas well production, and to prolong the effective production time. The traditional intermittent production control method mainly depends on the wellhead and ground measurement parameters, including wellhead casing pressure, wellhead tubing pressure, gas production, liquid production, etc. The automatic intermittent production method is usually adopted according to experience or remote manual control. The lack of automatic intelligent means leads to insufficient timeliness of operation and missed best opportunity for production process intervention. In addition, the downhole state is not monitored during the production process, especially the rapid sensing of the full profile characteristic parameters of the wellbore, such as temperature, pressure, liquid level, etc. The downhole factors of production fluctuation cannot be quickly identified, and the gas well production recovery time cannot be accurately grasped, which leads to the failure of intermittent switch well to achieve optimal production efficiency.

[0007] Therefore, there is an urgent need for a split plunger for gas well production, a regulating control system and a regulating control method. SUMMARY

[0008] The present application aims to solve the above technical problems, that is, to solve the following problems, first, after the completion of plunger lifting each time, the plunger falls back slowly under the influence of gas in the wellbore and downward resistance, the liquid discharge circulation efficiency is low, the shut-in time is long, and the cycle control of intermittent production is limited by the shut-in time and cannot achieve optimal efficiency; second, in order to realize the plunger gas lift liquid discharge without shut-in, the existing technology designs an integrated plunger as a split plunger, which is composed of a plunger body and a split sealing element to form a closed whole plunger. After being lifted to the vicinity of the wellhead, the two are separated by mechanical impact of the wellhead buffer device, and then fall to the bottom of the well to combine into a whole plunger again. There is a risk of sealing and slipping in the ascending section of the wellbore, and the plunger body and the split sealing element may combine too early during the falling process of the wellbore, which causes difficulty in falling and reduces the liquid discharge efficiency; third, the traditional intermittent production control method mainly depends on the wellhead and ground measurement parameters, including wellhead casing pressure, wellhead tubing pressure, gas production, liquid production, etc. The automatic intermittent production method is usually adopted according to experience or remote manual control. The lack of automatic intelligent means leads to insufficient timeliness of operation and missed best opportunity for production process intervention. In addition, the downhole state is not monitored during the production process, especially the rapid sensing of the full profile characteristic parameters of the wellbore, such as temperature, pressure, liquid level, etc. The downhole factors of production fluctuation cannot be quickly identified, and the gas well production recovery time cannot be accurately grasped, which leads to the failure of intermittent switch well to achieve optimal production efficiency.

[0009] To this end, in a first aspect, the present invention provides a split plunger for gas well production, comprising a sealing ball and a plunger body, the plunger body comprising a plunger barrel, an umbrella canopy, an umbrella rib assembly, an umbrella drive assembly and a first control module, the interior of the plunger barrel being a through hollow structure, a hollow sliding shaft being fixed in the plunger barrel, at least three umbrella rib assemblies distributed circumferentially along the plunger barrel being mounted on the sliding shaft, an opening being provided on the side wall of the plunger barrel at a position corresponding to the umbrella rib assembly, the umbrella canopy being sleeved on the outside of the plunger barrel and connected to the umbrella rib assembly through the opening, The umbrella drive assembly is installed on the sliding shaft in the plunger barrel and is electrically connected to the first control module. The first control module is installed in the plunger barrel and can control the umbrella drive assembly to drive the umbrella rib assembly to expand and retract the umbrella surface. The umbrella drive assembly is configured to automatically control the umbrella rib assembly to drive the umbrella surface to expand and retract according to temperature changes in the gas well, and the umbrella surface is in close contact with the inner wall of the gas well in the expanded state and in the outer wall of the plunger barrel in the retracted state. The sealing ball and the bottom of the plunger barrel can be mechanically combined and sealed or mechanically separated in the gas well.

[0010] In the specific embodiment of the split plunger for gas well production mentioned above, the plunger cylinder includes an impact cylinder, an expansion cylinder and a sealing cylinder fixedly connected in sequence from top to bottom in the lifting direction, the sliding shaft is fixed in the expansion cylinder, the opening is opened on the outer peripheral wall of the expansion cylinder, the inner wall surface of the bottom end of the sealing cylinder is a circular arc surface and matches the curvature radius of the sealing ball, and the outer peripheral walls of the impact cylinder, the expansion cylinder and the sealing cylinder are provided with a plurality of equally spaced annular grooves, and the cross-section of the annular groove is an arc shape.

[0011] In a specific embodiment of the above-mentioned split plunger for gas well production, the first control module includes a first processing circuit, an acoustic wave sensor and a heater. The first processing circuit and the heater are both installed on the chassis. The acoustic wave sensor is installed on the inner wall of the sealing cylinder for detecting the liquid level depth in the gas well. The heater is configured to provide a heating current to the umbrella drive assembly. The first processing circuit includes a first microprocessor, a first power supply unit electrically connected to the first microprocessor, a first clock unit, a first communication unit and a first control unit. The acoustic wave sensor and the heater are both electrically connected to the first microprocessor.

[0012] In a specific embodiment of the split plunger for gas well production described above, the sealing ball includes a shell, an intelligent sensing microsystem and a filler. The intelligent sensing microsystem is installed in the shell, and the filler is filled between the shell and the intelligent sensing microsystem. The intelligent sensing microsystem includes a second processing circuit, a temperature sensor, a pressure sensor, an acceleration sensor and an angular rate sensor. The second processing circuit includes a second microprocessor, a second power supply unit electrically connected to the second microprocessor, a second communication unit, a second clock unit and a state switching unit. The temperature sensor, pressure sensor, acceleration sensor and angular rate sensor are all electrically connected to the second microprocessor.

[0013] In the specific embodiment of the split plunger for gas well production mentioned above, the umbrella drive assembly includes a chassis, a sliding cylinder, a tension spring and a wire drawing. The chassis is in a circular ring shape and is fixed to the bottom end of the expansion cylinder. The sliding cylinder is sleeved on the sliding shaft. The top end of the sliding cylinder is connected to the sliding shaft through a tension spring, and the bottom end of the sliding cylinder is connected to the chassis through a wire drawing. The chassis and the wire drawing are both made of shape memory alloy. The wire drawing is in a pre-tightened state at room temperature. The heater is electrically connected to the wire drawing to provide heating current to the wire drawing. The sliding cylinder can slide up and down relative to the sliding shaft under the joint action of the wire drawing and the tension spring.

[0014] ] a gear train connected to the first end of the cam and the second end of the cam, and a gear train connected to the first end of the cam and the second end of the cam, so that the cam can rotate with the cam, so that the cam can move freely.

[0015] In a second aspect, the present application also provides a smart gas well production optimization adjustment control system, comprising a smart adjustable wellhead module and the split-type plunger for gas well production as claimed in any one of the first aspect, the smart adjustable wellhead module comprising a smart production control unit, an adjustable choke valve and a wellhead switch in communication connection with the smart production control unit, the smart production control unit being in wireless communication connection with the split-type plunger, the smart production control unit being configured to automatically regulate the choke valve size according to the wellhead parameter information and the gas well internal parameter information obtained from the split-type plunger, and automatically control the opening and closing of the wellhead switch and whether to execute the split-type plunger lifting and liquid discharge.

[0016] In a specific embodiment of the above-mentioned smart gas well production optimization adjustment control system, the adjustable choke valve comprises a choke valve actuator and a choke valve controller, the choke valve actuator being connected with the choke valve controller, the choke valve controller being in communication connection with the smart production control unit, the wellhead switch comprising a wellhead switch valve, a pressure gauge and a flow meter, the wellhead switch valve, the pressure gauge and the flow meter being in communication connection with the smart production control unit.

[0017] In a third aspect, the present application also provides a smart gas well production optimization adjustment control method, which is executed by using the smart gas well production optimization adjustment control system as claimed in any one of the second aspect, the adjustment control method comprising the following steps:

[0018] adjusting the multi-stage choke valve size step by step according to the set size in a set time period in the early production stage, and obtaining the initial characteristic parameter corresponding to each stage of the choke valve size related to the gas well, wherein the characteristic parameter comprises wellhead tubing pressure, wellhead casing pressure, gas production, water production, gas well internal temperature, gas well internal pressure and gas well internal fluid depth;

[0019] inputting the initial characteristic parameter into a convolutional neural network model for training to obtain a predicted choke valve size and pressure drop training model;

[0020] in the open well state, obtaining the current characteristic parameter in real time and inputting it into the predicted choke valve size and pressure drop training model to obtain the predicted choke valve size value and the predicted pressure drop interval;

[0021] controlling the choke valve size adjustment of the adjustable choke valve to the predicted choke valve size value, and judging whether the current pressure drop value is within the predicted pressure drop interval;

[0022] if the current pressure drop value is not within the predicted pressure drop interval, controlling the choke valve size of the adjustable choke valve to gradually increase or decrease according to the choke valve set step distance until the current pressure drop value is within the predicted pressure drop interval.

[0023] In a specific embodiment of the above-mentioned intelligent gas well production optimization regulation and control method, the regulation and control method further includes:

[0024] Inputting the initial characteristic parameters into a long short-term memory neural network model for training to obtain a predicted production training model, a predicted shut-in time training model, and a critical plunger lift pressure training model within a future set time period;

[0025] Under the production state of the gas well, the current characteristic quantity parameters are obtained in real time and inputted into the predicted production training model, the predicted shut-in time training model and the critical plunger lift pressure training model respectively to obtain the corresponding current predicted production, the current predicted shut-in time and the critical plunger lift pressure threshold;

[0026] Calculate the predicted production per unit time based on the current predicted production, and compare the predicted production with the gas content in the critical liquid carrying flow rate;

[0027] If the predicted production per unit time is less than the gas content in the critical liquid carrying flow rate, the difference between the wellhead casing pressure and the wellhead tubing pressure is compared with the critical plunger lift pressure threshold.

[0028] If the difference between the wellhead casing pressure and the wellhead tubing pressure is greater than or equal to the critical plunger lift pressure threshold, the wellhead switch is controlled to open to perform plunger lift and drainage;

[0029] If the difference between the wellhead casing pressure and the wellhead tubing pressure is less than the critical plunger lift pressure threshold, the wellhead switch is controlled to be in a closed state and timing is started. When the predicted shut-in time is reached, the wellhead switch is controlled to open for plunger lift and drainage.

[0030] Compared with the prior art, the present invention has the following beneficial effects:

[0031] 1. The wire drawing in the umbrella drive assembly designed in the present invention is made of shape memory alloy. Based on the material property of shape memory alloy that generates driving force by high-temperature phase change and contraction, as the plunger body rises, as the temperature in the gas well decreases, the wire drawing recovers from the contracted state to its original length, thereby driving the umbrella ribs to unfold the umbrella surface, realizing a passive autonomous unfolding function. The umbrella surface is tightly attached to the inner wall of the gas well, combining turbulent seal with umbrella-shaped seal to reduce gas slippage and upward migration. During the falling process of the plunger, the wire drawing is heated by a heater, and the wire drawing temperature increases and contracts, so that the umbrella ribs drive the umbrella surface to perform a folding action, achieving the function of controllable and orderly folding of the umbrella surface, realizing autonomous adjustment of the falling speed, and improving the drainage and gas recovery efficiency.

[0032] 2. The sealing ball designed in the present invention is integrated with a temperature sensor, a pressure sensor, an acceleration sensor, and an angular rate sensor. The plunger body is integrated with an acoustic sensor for measuring the depth of accumulated liquid. These parameters can be transmitted to the intelligent production control unit at the wellhead, providing multi-source sensing data for the control algorithm of the intermittent switch and the oil nozzle fine adjustment. At the same time, the sensor parameters integrated in the sealing ball are used to enable the sealing ball to have a low-power self-wake-up function for autonomous switching state, saving energy and extending the service life.

[0033] 3. The present invention considers the impact of nozzle flow rate on liquid carrying efficiency. From the perspectives of improving production capacity, reducing plunger lifting frequency, protecting the reservoir, and avoiding rapid formation pressure depletion, it predicts the optimal parameters of the nozzle diameter and the reasonable pressure drop range. Based on the deviation between the actual wellhead pressure drop and the nozzle diameter, the nozzle diameter is automatically adjusted, realizing automated closed-loop control adjustment and prediction functions, which helps to increase the total output value of the entire production cycle, reduce liquid accumulation and well shut-in times, and improve production efficiency.

[0034] 4. The present invention utilizes multiple characteristic parameters at the wellhead and inside the gas well, based on a long-short-term memory neural network model, to obtain the critical plunger lift pressure threshold, predict future gas well production changes and predict the shut-in time, and combines the difference between the wellhead casing pressure and the wellhead oil pipe pressure with the size of the critical plunger lift pressure threshold to independently determine the timing of plunger lift start-up and automatically control the gas well switch. It has the characteristics of rapid response, timely process intervention, fast oil pressure recovery, reduced labor costs and improved production efficiency. BRIEF DESCRIPTION OF THE DRAWINGS

[0035] The preferred embodiments of the present invention are described below with reference to the accompanying drawings, in which:

[0036] Figure 1 This is a schematic structural diagram of the umbrella rib assembly in the split plunger for gas well production provided by the present invention in an expanded state;

[0037] Figure 2 yes Figure 1 Bottom view of

[0038] Figure 3 This is a structural diagram showing that the plunger body and the sealing ball are in a separated state and the rib assembly is in a folded state;

[0039] Figure 4 It is a structural diagram of the sealing ball;

[0040] Figure 5 It is a logic diagram of the first control module on the plunger body;

[0041] Figure 6 It is the logic diagram of the intelligent sensing microsystem of the sealing ball;

[0042] Figure 7It is a flowchart of the steps of the intelligent gas well production optimization regulation control method provided by the present invention.

[0043] List of reference numerals:

[0044] 100. Sealing ball; 101. Shell; 102. Filler; 103. Rigid-flexible circuit board; 104. Pressure sensor; 105. Temperature sensor; 200. Plunger body; 201. Sealing cylinder; 202. Chassis; 203. Retracting cylinder; 204. Wire drawing; 205. Sliding cylinder; 206. Tension spring; 207. Fixing sleeve; 208. Sliding shaft; 209. Umbrella rib rod; 210. Umbrella cover; 211. Impact cylinder; 212. Opening. DETAILED DESCRIPTION

[0045] To make the objectives, technical solutions, and advantages of the present invention more clear, the technical solutions of the present invention will be clearly and completely described below with reference to the accompanying drawings. Obviously, the embodiments described are only some of the embodiments of the present invention, not all of them. All other embodiments derived by persons of ordinary skill in the art based on the embodiments of the present invention without inventive effort are within the scope of protection of the present invention.

[0046] In the description of the present invention, it should be noted that the terms "upper," "lower," "inner," and "outer," etc., indicating orientations or positional relationships, are based on the orientations or positional relationships shown in the accompanying drawings and are intended solely to facilitate description and simplify the present invention. They are not intended to indicate or imply that the systems or components referred to must have, be constructed, or operate in a specific orientation, and therefore should not be construed as limitations on the present invention. Furthermore, the use of terms such as "first" and "second" to define components is intended solely to facilitate distinction between such components. Unless otherwise stated, these terms have no special meanings and should not be construed as indicating or implying relative importance.

[0047] In the description of the present invention, it should be noted that, unless otherwise expressly specified or limited, the terms "installed," "installed," and "connected" should be understood in a broad sense. For example, they may refer to fixed, detachable, or integral connections; mechanical or electrical connections; direct or indirect connections through an intermediate medium; and internal communication between two components. Those skilled in the art will understand the specific meanings of the above terms in the present invention based on the specific circumstances.

[0048] The present invention relates to the field of natural gas extraction technology, and in particular to a split plunger, a regulating control system and a regulating control method for gas well production. The purpose is to solve the following problems: first, after each plunger lift is completed, the plunger falls back due to the effect of the gas in the wellbore and the downward resistance, the migration speed is slow, the drainage circulation efficiency is low, the well shut-in time is long, and the cycle control of intermittent production is limited by the well shut-in time and cannot achieve optimal efficiency; second, in order to achieve plunger gas lift drainage without shutting down the well, the existing technology designs the integrated plunger as a split plunger, which is composed of a plunger body and a split seal to form a sealed integral plunger. After being lifted to the vicinity of the wellhead, the two are separated by mechanical impact of the wellhead buffer device, and fall to the bottom of the well to be reassembled into an integral plunger. There is a risk of poor sealing and slippage in the rising section of the wellbore, and there is a problem of premature combination of the plunger body and the split seal during the falling process of the wellbore. , causing difficulty in falling and reducing drainage efficiency; thirdly, the traditional intermittent production control method is mainly based on wellhead and ground measurement parameters, including wellhead casing pressure, wellhead tubing pressure, gas production, liquid production, etc., and often relies on experience to adopt a timed or constant pressure automatic intermittent production method, or remote manual control. The lack of automated and intelligent means leads to insufficient timeliness of operation and missed the best time to intervene in the production process. In addition, there is a lack of monitoring of the downhole status during the production process, especially the rapid perception of the full profile characteristic parameters of the wellbore, such as temperature, pressure, liquid level, etc. The downhole factors of production fluctuations cannot be quickly identified, and it is difficult to accurately grasp the gas well production recovery time, resulting in the intermittent switching wells unable to achieve optimal production efficiency. For this purpose, the present invention provides a split plunger for gas well production, an intelligent gas well production optimization adjustment control system and an adjustment control method to solve the above technical problems.

[0049] Hereinafter, the split plunger for gas well production, the intelligent gas well production optimization regulation and control system, and the regulation and control method provided by the embodiments of the present invention will be described in detail with reference to the accompanying drawings.

[0050] See Figure 1-3The present invention provides a split plunger for gas well production, including a sealing ball 100 and a plunger body 200. The plunger body 200 includes a plunger barrel, an umbrella cover 210, an umbrella rib assembly, an umbrella drive assembly, and a first control module. The interior of the plunger barrel is a through hollow structure. A hollow sliding shaft 208 is fixed in the plunger barrel. At least three umbrella rib assemblies distributed along the circumference of the plunger barrel are installed on the sliding shaft 208. An opening 212 is provided on the side wall of the plunger barrel at a position corresponding to the umbrella rib assembly. The umbrella cover 210 is sleeved on the outside of the plunger barrel and is connected to the umbrella rib assembly through the opening 212. Then, the umbrella drive assembly is installed on the sliding shaft 208 in the plunger barrel and is electrically connected to the first control module. The first control module is installed in the plunger barrel and can control the umbrella drive assembly to drive the umbrella rib assembly to make the umbrella cover 210 expand and contract. The umbrella drive assembly is configured to automatically control the umbrella rib assembly to drive the umbrella cover 210 to expand and contract according to the temperature change in the gas well. The umbrella cover 210 is in close contact with the inner wall of the gas well in the expanded state and in the closed state. The sealing ball 100 and the bottom of the plunger barrel can be mechanically combined and sealed or mechanically separated in the gas well.

[0051] Specifically, the plunger cylinder includes an impact cylinder 211, a retracting cylinder 203, and a sealing cylinder 201, which are fixedly connected in sequence from top to bottom in the lifting direction. The sliding shaft 208 is fixed in the retracting cylinder 203. The outer peripheral wall of the retracting cylinder 203 has an opening 212. The inner wall surface of the bottom end of the sealing cylinder 201 is a circular arc surface that matches the curvature radius of the sealing ball 100. The outer peripheral walls of the impact cylinder 211, the retracting cylinder 203, and the sealing cylinder 201 are each provided with a plurality of equally spaced annular grooves, each having an arc-shaped cross-section. The preferred relationship between the arc radius r of the annular groove and the center-to-center spacing L of adjacent annular grooves along the axial direction of the corresponding impact cylinder 211, the retracting cylinder 203, or the sealing cylinder 201 should satisfy the following: L = 2.5 × R, achieving turbulent sealing during the plunger lifting process.

[0052] In one embodiment, see Figure 5 The first control module includes a first processing circuit, an acoustic wave sensor, and a heater. The first processing circuit and the heater are both mounted on the chassis 202. The acoustic wave sensor is mounted on the inner wall of the sealing cylinder 201 to detect the liquid level depth in the gas well. The heater is configured to provide a heating current to the umbrella drive assembly. The first processing circuit includes a first microprocessor, a first power supply unit electrically connected to the first microprocessor, a first clock unit, a first communication unit, and a first control unit. The acoustic wave sensor and the heater are both electrically connected to the first microprocessor.

[0053] More specifically, the impact cylinder 211, the expansion cylinder 203 and the sealing cylinder 201 are all screwed together through the flange of the cylinder wall. The sealing cylinder 201, the expansion cylinder 203 and the impact cylinder 211 are all hollow annular structures. The inner surface cross-section of one end of the sealing cylinder 201 is arc-shaped and adapted to the curvature radius of the sealing ball 100, and an elastic seal is provided on the surface, which has buffering, shock absorption and sealing functions, and is preferably made of high-performance and long-life rubber material. The other end of the sealing cylinder is a first flange annular disc with an inner fold. The first flange annular disc is provided with a stepped through hole, which is connected to the first threaded hole at the corresponding end of the expansion cylinder. The inner wall of the sealing cylinder is arranged with an acoustic wave sensor probe, and the rear end wiring of the acoustic wave sensor is electrically connected and transmits data with the first microprocessor arranged in the expansion cylinder through a split sealed electrical connector. Limiting grooves are provided at the top and bottom ends of the expansion cylinder.

[0054] Sliding shaft 208 is a thin-walled hollow cylinder with a circular flange. Its inner diameter is larger than the outer diameter of the wellhead striker assembly, and its length is equal to that of the deployment and retraction cylinder 203. Its sidewall is provided with a weight-reducing groove. One end is inserted into the inner annular disk of the chassis 202, while the other end has a circular flange. Three narrow beams connect the inner and outer rings, providing fluid passages and reducing weight. It is securely connected to the other end of the deployment and retraction cylinder 203 and the striker cylinder 211 via screws. The outer side of sliding shaft 208 is fitted with a sliding cylinder 205 and a fixed sleeve 207, from bottom to top. Sliding cylinder 205 can slide up and down relative to sliding shaft 208, while fixed sleeve 207 is fixedly connected to sliding shaft 208.

[0055] In one embodiment, the umbrella drive assembly includes a chassis 202, a sliding cylinder 205, a tension spring 206 and a wire drawing 204. The chassis 202 is in a circular ring shape and is fixed to the bottom end of the expansion and contraction cylinder 203. The sliding cylinder 205 is sleeved on the sliding shaft 208. The top end of the sliding cylinder 205 is connected to the sliding shaft 208 through the tension spring 206. The bottom end of the sliding cylinder 205 is connected to the chassis 202 through the wire drawing 204. The wire drawing 204 is made of shape memory alloy. The wire drawing 204 is in a pre-tightened state at room temperature. The heater is electrically connected to the wire drawing 204 to provide a heating current to the wire drawing 204. The sliding cylinder can slide up and down relative to the sliding shaft under the joint action of the wire drawing and the tension spring.

[0056] Specifically, chassis 202 comprises an inner annular disc and an outer annular disc. The inner annular disc is located inside the outer annular disc and is fixedly connected via at least three connecting beams. The outer annular disc has an outer diameter greater than the inner diameter of the deployment tube. The outer annular disc is threaded into a retaining groove at the bottom of deployment tube 203. The first threaded hole of deployment tube 203 is provided on the outer annular disc. The first threaded hole on the outer annular disc connects with the stepped through-hole on the first flange annular disc to achieve a fixed connection between sealing tube 201 and deployment tube 203. The heater and first processing circuit in the first control module are both mounted on the inner annular disc.

[0057] More specifically, the wires 204 are made of a shape memory alloy, a temperature-sensitive phase-change material. Above the phase-transition temperature, the material transforms from martensite to austenite, contracting to generate a restoring force that serves as a non-electrical motive force for the rib assembly's movement. Below the phase-transition temperature, the material reverts from austenite to martensite, returning to its original length. Nickel-based alloy wire from DYNALLOY is preferred, with a diameter less than 1 mm and a recovery strain greater than 3.5%. The phase-transition temperature is determined by selecting a material composition with varying elemental composition to accommodate temperatures between 70°C and 100°C, determined based on the depth of the gas well reservoir. The number of wires 204 can be three evenly distributed, with crimping sleeves secured at each end. The crimping sleeve at one end of the wire 204 is fixedly connected to the connecting beam on the chassis 202, while the other end of the wire 204 passes through a perforation in the sliding cylinder 205 and is secured to the connecting beam via the crimping sleeve. After mechanical assembly, the ends of the wire 204 are electrically connected to the leads of the first control module. Active control of the phase change state of the wire 204 is achieved by applying current, while passive control of the phase change state of the wire 204 is achieved by changes in the bottom-of-hole ambient temperature. This allows the umbrella 210 to automatically expand and contract, or actively control the expansion and contraction of the umbrella 210 through heating.

[0058] The sliding cylinder 205 is a thin-walled hollow ring structure. The inner diameter of the ring and the outer diameter of the sliding shafts 208 and 208 have a clearance fit of H8 / e7. The sidewalls are provided with weight-reducing grooves. When the high-temperature phase transformation of the shape memory alloy generates a driving force, the cylinder moves axially downward. When the shape memory alloy driving force is removed, the cylinder returns to its normal temperature equilibrium position, where the tension of the tension spring 206 is balanced with the weight of the sliding cylinder 205, frictional resistance, and the preload of the wire 204. Three holes are provided at one end of the sliding cylinder 205 for winding the wire 204. A hook is provided at the other end for mounting the tension spring 206. The number of tension springs 206 can be three, evenly distributed around the circumference.

[0059] In one embodiment, the umbrella rib assembly comprises a fixed sleeve 207 fixed on the sliding shaft 208 above the sliding cylinder 205, the top end of the tension spring is fixedly connected with the fixed sleeve, and the umbrella rib assembly comprises a first adjusting rod, a second adjusting rod, a third adjusting rod and an umbrella rib rod 209. The first adjusting rod and the second adjusting rod are arranged side by side, and one end of each of the first adjusting rod and the second adjusting rod is rotatably connected with the fixed sleeve 207, and the other end of each of the first adjusting rod and the second adjusting rod is rotatably connected with the umbrella rib rod 209. The length of the second adjusting rod is greater than the length of the first adjusting rod. One end of the third adjusting rod is rotatably connected with the sliding cylinder 205, and the other end of the third adjusting rod is rotatably connected with the umbrella rib rod 209. The third adjusting rod can drive the umbrella rib rod 209 to expand or contract to make the umbrella surface 210 expand or contract during the up-down sliding of the sliding cylinder 205. The umbrella rib rod 209 is in an expanded state when the tension wire 204 is in a normal temperature state.

[0060] When the sliding cylinder 205 is in a normal temperature equilibrium position, the umbrella rib rod 209 is in an expanded state. When the sliding cylinder 205 moves downward, the umbrella rib rod 209 is in a contracted state and is located in the opening 212 of the sidewall of the expanding and contracting cylinder 203, as shown in FIG. 6. The length direction of the opening 212 is consistent with the axis direction of the sliding shaft 208. Figure 3

[0061] The umbrella surface 210 is preferably a flexible, wear-resistant and waterproof thin film polymer material, has certain stretchability and shape maintaining ability, and is polyvinyl chloride film and the like. The umbrella surface is annularly wound outside the expanding and contracting cylinder, and has three cylindrical sleeves designed to be inserted into the umbrella rib rod and fixed on the umbrella rib rod by crimping. The umbrella surface is installed on the outside of the expanding and contracting cylinder, is tightly attached to the inner wall of the wellbore in the expanded state, reduces the risk of slipping of the wellbore lifting section, is tightly attached to the outer wall of the expanding and contracting cylinder in the contracted state, reduces the falling resistance of the wellbore, and improves the drainage efficiency.

[0062] ​The umbrella rib assembly has the function of adjusting the sealing state and lifting speed for the plunger body 200. Specifically, during the rising process of the plunger body 200 and the sealing ball 100, the sealing tube 201, the expansion tube 203 and the annular groove on the side wall of the impact tube 211 perform turbulent sealing. At the same time, after leaving the high-temperature environment at the bottom of the well and falling below the phase transition temperature of the shape memory alloy material, the wire drawing 204 made of the shape memory alloy recovers to allow the umbrella rib assembly to unfold autonomously, and an umbrella-shaped seal is achieved by the umbrella surface 210 being close to the inner wall of the gas wellbore. The sealing method combining turbulent sealing and umbrella-shaped sealing reduces gas slippage and increases liquid lifting efficiency. During the descent, the timed heating function of the first control module actively heats the wire 204. The heating start and end times and current level can be set via a remote control, enabling the controlled and orderly retraction of the rib assembly. After heating stops, the wire 204 recovers under the influence of ambient temperature, causing the rib assembly to open. By varying the resistance to fall, the falling speed of the plunger body 200 is adjusted, reducing the risk of premature engagement with the sealing ball 100. After sinking to the bottom of the well, due to the well temperature exceeding the phase transition temperature of the shape memory alloy, the wire 204 contracts, causing the rib assembly to autonomously retract, facilitating the deposition of the accumulated liquid and improving drainage and gas recovery efficiency.

[0063] In one embodiment, see Figure 4 and Figure 6 The sealing ball 100 includes a shell 101, an intelligent sensing microsystem and a filler 102. The intelligent sensing microsystem is installed in the shell 101. The filler 102 is filled between the shell 101 and the intelligent sensing microsystem. The intelligent sensing microsystem includes a second processing circuit, a temperature sensor 105, a pressure sensor 104, an acceleration sensor and an angular rate sensor. The second processing circuit includes a second microprocessor, a second power supply unit electrically connected to the second microprocessor, a second communication unit, a second clock unit and a state switching unit. The temperature sensor 105, the pressure sensor 104, the acceleration sensor and the angular rate sensor are all electrically connected to the second microprocessor.

[0064] Specifically, housing 101 is an impact-resistant, enclosed spherical structure, preferably made of a high-strength, pressure-bearing material, such as stainless steel, titanium alloy, or polydimethylsiloxane (PDMS). Temperature and pressure through-holes are reserved in housing 101 for contact measurement by temperature sensor 105 and pressure sensor 104. Filler 102 is preferably encapsulated with epoxy resin, which provides heat resistance, insulation, shock and vibration resistance, and reduces density.

[0065] The acceleration sensor is a MEMS acceleration sensor, and the angular rate sensor is a MEMS angular rate sensor. The temperature sensor 105 is preferably a micro thermocouple, one end of which is electrically connected to the rigid-flexible circuit board 103, and the other end is pre-buried in the temperature through-hole of the shell 101, so as to realize contact measurement of the temperature outside the sealing ball 100. The pressure sensor 104 adopts a core-type piezoresistive sensor, one end of which is connected to the pressure through-hole of the shell 101, and the other end is electrically connected to the rigid-flexible circuit board 103. The data collected by the temperature sensor 105, the pressure sensor 104, the MEMS acceleration sensor and the MEMS angular rate sensor are transmitted to the second microprocessor through the serial port protocol, and the temperature, pressure and the distance between the sealing ball 100 and the wellhead of the gas well are sensed and stored. The second microprocessor can convert the distance between the sealing ball 100 and the wellhead according to the data collected by the acceleration sensor and the angular rate sensor, thereby realizing the function of sensing the location of the sealing ball 100.

[0066] When the sealing ball 100, in combination with the plunger body 200, rises to a designated position near the wellhead, it receives a communication command from the intelligent control unit, and the second communication unit starts wireless data transmission with the intelligent control unit. After completion, the second communication unit is controlled to shut down according to the communication shutdown command sent by the intelligent control unit. Of course, the above description of the activation and deactivation of the second communication unit is merely an example, and other methods are also possible. Specifically, the second microprocessor calculates the depth value of the sealing ball 100 from the wellhead based on the data collected by the acceleration sensor and the angular rate sensor. When the position of the sealing ball 100 rises to the depth threshold specified by the wellhead attachment, the second communication unit is controlled to automatically start to communicate with the intelligent control unit. After the data transmission is completed, the second communication unit remains in the on state until the position of the sealing ball 100 exceeds the depth threshold, at which time the second communication unit is automatically controlled to shut down.

[0067] In addition, the sealing ball 100 has a self-wake-up function that allows it to autonomously switch states. During its stay at the bottom of the gas well, based on the real-time measurements of the temperature sensor 105, pressure sensor 104, acceleration sensor, and angular rate sensor, if the data from these four sensors remain relatively stable with minimal fluctuations for a certain period (preferably five minutes), and the acceleration and angular rate data, updated using the quaternion method, show a motion velocity close to zero, it is assumed that the sealing ball 100 has not yet begun the process of draining water and recovering gas at the bottom of the well. The sealing ball 100's intelligent sensing microsystem then autonomously enters a low-power sleep mode, retaining only the temperature sensor 105 and pressure sensor 104, which have a sampling rate of 1Hz, while the other sensors enter sleep mode. If the difference between the real-time measurement results of the temperature sensor 105 and pressure sensor 104 and the previous measurement exceeds a preset difference, indicating a significant change, i.e., a significant temperature gradient or pressure gradient, indicating that the sealing ball 100 is experiencing movement, the intelligent sensing microsystem switches from sleep mode to active mode, with all sensors functioning normally. In this way, the power consumption of the intelligent sensing microsystem on the sealing ball 100 is reduced, and the service life is extended.

[0068] The power supply unit is preferably a 150°C-resistant micro-rechargeable battery. The second microprocessor is preferably an STM32 low-power processing chip, providing clock, communication, and data processing functions. It acquires sensor measurement data via serial communication, time-tags it, and wirelessly transmits it to the intelligent production control unit. It can also receive ground-based remote control commands for active state switching. The second processing circuit combines two rigid circuit boards that fold together and a flexible circuit board. The rigid circuit board is a flat, multi-layer structure, housing the second microprocessor, the second power supply unit, the second clock unit, the second communication unit, and the state switching unit, as well as the MEMS acceleration and angular rate sensors. These components are mechanically and electrically connected via the rigid circuit board. The flexible circuit board connects the two rigid circuit boards in an arc-shaped bend and is used only for the electrical connection of the circuitry and the sensing components.

[0069] On the other hand, the present application also provides an intelligent gas well production optimization and regulation control system, including an intelligent adjustable wellhead module and a split plunger for gas well production as described in any of the above embodiments. The intelligent adjustable wellhead module includes an intelligent production control unit, an adjustable oil nozzle and a wellhead switch communicatively connected to the intelligent production control unit. The intelligent production control unit and the split plunger are wirelessly connected. The intelligent production control unit is configured to automatically adjust the nozzle diameter size of the adjustable oil nozzle according to the wellhead parameter information and the internal parameter information of the gas well obtained from the split plunger, as well as automatically control the opening and closing of the wellhead switch and whether to execute the split plunger lifting and drainage.

[0070] Specifically, the adjustable choke valve includes a choke valve actuator and a choke valve controller, the choke valve actuator is connected with the choke valve controller, the choke valve controller is connected with the intelligent production control unit in communication, the wellhead switch includes a wellhead switch valve, a pressure gauge and a flow meter, and the wellhead switch valve, the pressure gauge and the flow meter are connected with the intelligent production control unit in communication.

[0071] The wellhead switch valve can be an electrically controlled throttle valve, which is driven by a motor to move up and down on a valve rod to control the opening degree of the valve.

[0072] The pressure gauge and the flow meter are used to continuously and accurately measure the wellhead oil pressure, the wellhead annulus pressure, the gas production and the water production, and transmit the data to the intelligent production control unit.

[0073] The choke valve actuator adopts a combination of a primary fixed choke valve and a secondary adjustable choke valve, preferably an outer cage sleeve type electrically controlled choke valve, which is resistant to erosion, has low noise and is not easy to block, and the minimum adjustment amount of the choke valve diameter is 0.2mm per change calculated according to the motor step distance, to execute the instruction of the choke valve controller.

[0074] The choke valve controller is mainly used to drive the motor of the adjustable choke valve, receive the instruction of the intelligent production control unit, and feed back the motor working parameters to the intelligent production control unit for monitoring.

[0075] In addition, referring to Figure 7 The application also provides an intelligent gas well production optimization adjustment and control method, which is executed by the intelligent gas well production optimization adjustment and control system described in any one of the above embodiments, and the adjustment and control method comprises the following steps:

[0076] S1, in a set time period in the early stage of production, gradually adjusting according to a set multi-stage choke valve diameter, and obtaining initial characteristic parameter corresponding to each choke valve diameter related to the gas well, wherein the characteristic parameter includes wellhead tubing pressure, wellhead casing pressure, gas production, water production, gas well internal temperature, gas well internal pressure and gas well internal fluid depth; in the above step, the value of the set time period is not limited in the application, which is set according to the actual situation; in this step, the multi-stage choke valve diameter means that the choke valve diameter is divided into multiple sizes according to the size from small to large, and the initial characteristic parameter is obtained by adjusting the choke valve diameter according to each size;

[0077] S2, inputting the obtained initial characteristic parameters into a convolutional neural network model for training to obtain a predicted choke valve diameter and pressure drop training model;

[0078] S3, in the open well state, real-time acquiring current characteristic parameters and inputting the current characteristic parameters into the predicted choke valve diameter and pressure drop training model to obtain a predicted choke valve diameter value and a predicted pressure drop interval;

[0079] S4, controlling the nozzle diameter of the adjustable nozzle to be adjusted to the predicted nozzle diameter value, and determining whether the current pressure drop value is within the predicted pressure drop range;

[0080] S5, if the current pressure drop value is not within the predicted pressure drop range, the nozzle diameter of the adjustable nozzle is controlled to gradually increase or decrease according to the nozzle setting step until the current pressure drop value is within the predicted pressure drop range.

[0081] If the current pressure drop value is within the predicted pressure drop range, adjust the nozzle diameter to the predicted nozzle diameter value and maintain it unchanged.

[0082] In step S5, the predicted pressure drop interval is an interval range, and the minimum value of the interval is The maximum value of the interval is If the current voltage drop is less than , then the nozzle diameter of the adjustable nozzle is controlled to increase gradually according to the nozzle setting step. If the current pressure drop value is greater than , then the nozzle diameter of the adjustable nozzle is controlled to be reduced step by step according to the nozzle setting step.

[0083] In the above-mentioned embodiment, the present invention considers the effect of nozzle flow rate on liquid carrying efficiency, and predicts the optimal parameters of the nozzle diameter and the reasonable pressure drop range from the perspectives of improving production capacity, reducing the plunger lifting frequency, protecting the reservoir, and avoiding excessive formation pressure depletion. The nozzle diameter is automatically adjusted according to the deviation between the actual wellhead pressure drop and the nozzle diameter, thereby realizing automated closed-loop control adjustment and prediction functions, which helps to increase the total output value of the entire production cycle, reduce the number of liquid accumulation and well shut-in times, and improve production efficiency.

[0084] In one embodiment, the regulation control method further includes:

[0085] S6, inputting the initial feature quantity parameters into the long short-term memory neural network model for training to obtain a predicted production training model, a predicted shut-in time training model, and a critical plunger lift pressure training model for a future set time period; in this step, the future set time period is not specifically limited in this application, for example, five days, and can be flexibly set according to actual requirements;

[0086] S7, in the gas well production state, obtaining current feature parameters in real time and inputting them into a production prediction training model, a shut-in duration prediction training model, and a critical plunger lift pressure training model, respectively, to obtain the corresponding current predicted production, current predicted shut-in duration, and critical plunger lift pressure threshold; and inputting the current feature parameters as initial feature parameters for a new round into a long short-term memory neural network model for training to obtain a new round of production prediction training models, shut-in duration prediction training models, and critical plunger lift pressure training models for a set future time period;

[0087] S8, calculating the predicted production per unit time based on the current predicted production, and comparing it with the gas content in the critical liquid carrying flow rate;

[0088] S9, if the predicted production per unit time is less than the gas content in the critical liquid carrying flow rate, then comparing the difference between the wellhead casing pressure and the wellhead tubing pressure with the critical plunger lift pressure threshold;

[0089] S10, if the difference between the wellhead casing pressure and the wellhead tubing pressure is greater than or equal to the critical plunger lift pressure threshold, then control the wellhead switch to open to perform plunger lift and drainage;

[0090] S11, if the difference between the wellhead casing pressure and the wellhead tubing pressure is less than the critical plunger lift pressure threshold, the wellhead switch is controlled to be in a closed state and the timing is started. When the predicted shut-in time is reached, the wellhead switch is controlled to open to perform plunger lift and drainage.

[0091] In step S6, the long short-term memory neural network model includes three different models, namely, a first long short-term memory neural network model is used to train to obtain a predicted production training model, a second long short-term memory neural network model is used to train to obtain a predicted shut-in time training model, and a third long short-term memory neural network model is used to train to obtain a critical plunger lift pressure training model.

[0092] In this application, the specific calculation formula of critical night flow Q is as follows:

[0093]

[0094] Where S is the nozzle cross-sectional area, V represents the critical liquid carrying velocity, and the calculation formula for S is:

[0095]

[0096] Where D represents the nozzle diameter.

[0097] The formula for calculating V is as follows:

[0098]

[0099] in, Indicates the density of gas-liquid mixed produced gas, represents gas density, C represents adjustment coefficient, and according to the Turner vertical well model parameter C is set to 5.48.

[0100] It should be noted that the sequence of steps S1-S5 for performing the nozzle caliber adjustment and steps S6-S13 for performing the plunger lift start timing determination and the gas wellhead switch control can be performed simultaneously. Alternatively, the nozzle caliber adjustment can be performed first, followed by the plunger lift start timing determination and the gas wellhead switch control. Alternatively, the plunger lift start timing determination and the gas wellhead switch control can be performed first, followed by the nozzle caliber adjustment. Preferably, both are performed simultaneously.

[0101] In the above embodiment, the present invention utilizes multiple characteristic parameters at the wellhead and inside the gas well, based on the long-short-term memory neural network model, to obtain the critical plunger lift pressure threshold, predict future gas well production changes and predict the shut-in time, and combines the difference between the wellhead casing pressure and the wellhead tubing pressure with the size of the critical plunger lift pressure threshold to autonomously determine the timing of plunger lift start-up and automatically control the gas well switch, which has the characteristics of rapid response, timely process intervention, fast oil pressure recovery, reduced labor costs and improved production efficiency.

[0102] Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of the present invention, rather than to limit it. Although the present invention has been described in detail with reference to the aforementioned embodiments, those skilled in the art should understand that they can still modify the technical solutions described in the aforementioned embodiments, or make equivalent replacements for some of the technical features therein. However, these modifications or replacements do not deviate the essence of the corresponding technical solutions from the protection scope of the technical solutions of the various embodiments of the present invention.

Claims

1. A split plunger for gas well production, characterized in that: The umbrella canopy is sleeved on the outside of the plunger barrel and is connected to the rib assembly through the opening. The umbrella canopy is sleeved on the outside of the plunger barrel and is connected to the rib assembly through the opening. The umbrella canopy is sleeved on the outside of the plunger barrel and is connected to the rib assembly through the opening. The umbrella drive assembly is installed on the sliding shaft in the plunger barrel and is electrically connected to the first control module. The first control module is installed in the plunger barrel and can The umbrella driving assembly can be controlled to drive the umbrella rib assembly to make the umbrella surface expand and contract. The umbrella driving assembly is configured to automatically control the umbrella rib assembly to drive the umbrella surface to expand and contract according to the temperature change in the gas well, and the umbrella surface is in close contact with the inner wall of the gas well in the expanded state and in the closed state. The sealing ball and the bottom of the plunger tube can be mechanically combined and sealed or mechanically separated in the gas well. The first control module includes a first processing circuit, an acoustic wave sensor and a heater. The first processing circuit and the heater are both installed on the chassis. The acoustic wave sensor is installed on the inner wall of the sealing tube to detect the liquid level depth in the gas well. The heater is configured to provide a heating current to the umbrella driving assembly. The first processing circuit includes a first microprocessor, a first power supply unit electrically connected to the first microprocessor, a first clock unit, a first communication unit and a first control unit, the acoustic wave sensor and the heater are electrically connected to the first microprocessor, the umbrella drive assembly includes a chassis, a sliding cylinder, a tension spring and a wire drawing, the chassis is in a circular ring shape and is fixed to the bottom end of the retracting cylinder, the sliding cylinder is sleeved on the sliding shaft, the top end of the sliding cylinder is connected to the sliding shaft through a tension spring, the bottom end of the sliding cylinder is connected to the chassis through a wire drawing, the wire drawing is made of shape memory alloy, the wire drawing is in a pre-tightened state at room temperature, the heater is electrically connected to the wire drawing to provide heating current to the wire drawing, and the sliding cylinder is relatively under the joint action of the wire drawing and the tension spring. The cam is connected to the umbrella rib by a first adjusting rod, a second adjusting rod and a third adjusting rod, the first adjusting rod and the second adjusting rod being connected to each other with a first end and a second end thereof being connected to the umbrella rib by a second end.The umbrella ribs are in an unfolded state when the wire drawing is at room temperature.

2. The split plunger for gas well production according to claim 1, characterized in that: The sliding shaft is fixed in the expansion and retraction cylinder, the opening is opened on the outer peripheral wall of the expansion and retraction cylinder, the inner wall surface of the bottom end of the sealing cylinder is an arc surface and matches the curvature radius of the sealing ball, and the outer peripheral walls of the impact cylinder, the expansion and retraction cylinder and the sealing cylinder are provided with a plurality of annular grooves arranged at equal intervals, and the cross-section of the annular groove is an arc shape.

3. The split plunger for gas well production according to claim 2, characterized in that: The sealing ball includes a shell, an intelligent sensing microsystem and a filler. The intelligent sensing microsystem is installed in the shell, and the filler is filled between the shell and the intelligent sensing microsystem. The intelligent sensing microsystem includes a second processing circuit, a temperature sensor, a pressure sensor, an acceleration sensor and an angular rate sensor. The second processing circuit includes a second microprocessor, a second power supply unit electrically connected to the second microprocessor, a second communication unit, a second clock unit and a state switching unit. The temperature sensor, pressure sensor, acceleration sensor and angular rate sensor are all electrically connected to the second microprocessor.

4. An intelligent gas well production optimization and regulation control system, characterized in that: It comprises an intelligent adjustable wellhead module and a split plunger for gas well production as described in any one of claims 1-3, the intelligent adjustable wellhead module comprises an intelligent production control unit, an adjustable oil nozzle and a wellhead switch communicatively connected to the intelligent production control unit, the intelligent production control unit is wirelessly connected to the split plunger, and the intelligent production control unit is configured to automatically adjust the nozzle diameter of the adjustable oil nozzle according to wellhead parameter information and internal parameter information of the gas well obtained from the split plunger, as well as automatically control the opening and closing of the wellhead switch and whether to execute the split plunger lifting and drainage.

5. The intelligent gas well production optimization and regulation control system according to claim 4 is characterized in that: The adjustable nozzle includes a nozzle actuator and a nozzle controller, the nozzle actuator is connected to the nozzle controller, the nozzle controller is communicatively connected to the intelligent production control unit, the wellhead switch includes a wellhead switch valve, a pressure gauge and a flow meter, and the wellhead switch valve, pressure gauge and flow meter are all communicatively connected to the intelligent production control unit.

6. An intelligent gas well production optimization and regulation control method, characterized in that: The regulation control method is executed by using the intelligent gas well production optimization regulation control system according to any one of claims 4 to 5, and the regulation control method includes the following steps: During a set time period at the beginning of production, the multi-stage nozzle caliber is adjusted step by step according to the set caliber, and initial characteristic parameters corresponding to each stage nozzle caliber related to the gas well are obtained, wherein the characteristic parameters include wellhead tubing pressure, wellhead casing pressure, gas production rate, water production rate, gas well internal temperature, gas well internal pressure, and gas well internal liquid accumulation depth; Inputting the initial characteristic parameters into a convolutional neural network model for training to obtain a training model for predicting nozzle caliber and pressure drop; In the open well state, the current characteristic quantity parameters are obtained in real time and input into the predicted nozzle diameter and pressure drop training model to obtain the predicted nozzle diameter value and the predicted pressure drop range; Controlling the nozzle diameter of the adjustable nozzle to be adjusted to a predicted nozzle diameter value, and determining whether the current pressure drop value is within the predicted pressure drop range; If the current pressure drop value is not within the predicted pressure drop range, the nozzle diameter of the adjustable nozzle is controlled to gradually increase or decrease according to the nozzle setting step until the current pressure drop value is within the predicted pressure drop range.

7. The intelligent gas well production optimization and regulation control method according to claim 6 is characterized in that: The regulation control method further includes: Inputting the initial characteristic parameters into a long short-term memory neural network model for training to obtain a predicted production training model, a predicted shut-in time training model, and a critical plunger lift pressure training model within a future set time period; Under the production state of the gas well, the current characteristic quantity parameters are obtained in real time and inputted into the predicted production training model, the predicted shut-in time training model and the critical plunger lift pressure training model respectively to obtain the corresponding current predicted production, the current predicted shut-in time and the critical plunger lift pressure threshold; Calculate the predicted production per unit time based on the current predicted production, and compare the predicted production with the gas content in the critical liquid carrying flow rate; If the predicted production per unit time is less than the gas content in the critical liquid carrying flow rate, then comparing the difference between the wellhead casing pressure and the wellhead tubing pressure with the critical plunger lift pressure threshold; If the difference between the wellhead casing pressure and the wellhead tubing pressure is greater than or equal to the critical plunger lift pressure threshold, the wellhead switch is controlled to open to perform plunger lift and drainage; If the difference between the wellhead casing pressure and the wellhead tubing pressure is less than the critical plunger lift pressure threshold, the wellhead switch is controlled to be in a closed state and timing is started. When the predicted shut-in time is reached, the wellhead switch is controlled to open for plunger lift and drainage.

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