A deepwater Christmas tree control system and method

Abstract

The invention discloses a deepwater Christmas tree control system and method. A LedaFlow dynamic model is established. Two groups of temperature and pressure PID controllers are respectively arranged on the wellbore pipeline of the deepwater Christmas tree. The variable of the first temperature PID controller is the reservoir temperature. The reading of the downhole temperature transmitter is fixed, and the reservoir temperature is adjusted to match the downhole temperature and be consistent with the actual temperature data. The variable of the second temperature PID controller is the wellbore heat transfer coefficient. The reading of the second temperature transmitter is fixed, and the wellbore heat transfer coefficient is adjusted to match the nozzle upstream temperature and be consistent with the actual temperature data. The variable of the first pressure PID controller is the reservoir pressure. The reading of the downhole pressure transmitter is fixed, and the reservoir pressure is adjusted to match the downhole pressure and be consistent with the actual pressure data. The variable of the second pressure PID controller is the wellbore roughness. The reading of the second pressure transmitter is fixed, and the wellbore roughness is adjusted to match the nozzle upstream pressure and be consistent with the actual data, so as to more accurately simulate the temperature and pressure data of the Christmas tree under the working conditions of initial startup, production increase or restart.

Description

Technical Field

[0001] The invention relates to a production process of offshore oil engineering, and is a deepwater Christmas tree control system and method. Background Art

[0002] A downhole temperature and pressure transmitter is usually installed in the wellbore of a deepwater Christmas tree to monitor the bottom hole temperature and pressure. A temperature and pressure transmitter is usually installed upstream of the nozzle of a deepwater Christmas tree to monitor the temperature and pressure of the Christmas tree. Operators regularly evaluate the subsequent development potential of the reservoir and the corrosion condition of the wellbore based on the downhole temperature and pressure data and the temperature and pressure data of the Christmas tree, and formulate a production allocation and development plan for deepwater oil and gas fields and a frequency cycle for well repairs.

[0003] In related technologies, engineering projects or underwater digital twin system models are usually used to simulate wellbore temperature, pressure, etc. However, the above method is prone to inaccurate model data, deviation from field data, and poor consistency. Summary of the invention

[0004] The technical problem to be solved by the present invention is to provide a deepwater Christmas tree control system and method, which can accurately and real-timely calibrate the temperature and pressure loss of the wellbore online, ensure the consistency and accuracy of the model data with the field measured data, and improve the control accuracy of the deepwater Christmas tree.

[0005] In order to solve the above technical problems, the present invention provides a deepwater Christmas tree control system, comprising an oil reservoir, a wellbore, a deepwater Christmas tree, a nozzle, a subsea manifold, a submarine pipeline, a riser and a processing platform, wherein the oil reservoir is connected to the wellbore, the wellbore is connected to the deepwater Christmas tree, the deepwater Christmas tree outlet is connected to the subsea manifold through the nozzle, the subsea manifold is connected to the submarine pipeline, and the submarine pipeline is connected to the processing platform through the riser; the system also includes:

[0006] The first pressure transmitter is used to monitor reservoir pressure and downhole pressure;

[0007] a first pressure PID controller connected to the first pressure transmitter, wherein the control variable of the first pressure PID controller is the reservoir pressure, the downhole pressure value of the first pressure transmitter is fixed, and the reservoir pressure is adjusted by the first pressure PID controller so that the downhole pressure value matches the measured pressure data;

[0008] A second pressure transmitter is used to monitor the wellbore roughness and the pressure upstream of the nozzle;

[0009] a second pressure PID controller connected to the second pressure transmitter, wherein the control variable of the second pressure PID controller is the wellbore roughness, the nozzle upstream pressure value of the second pressure transmitter is fixed, and the wellbore roughness is adjusted by the second pressure PID controller so that the nozzle upstream pressure value matches the measured pressure data;

[0010] The first temperature transmitter is used to collect reservoir temperature and downhole temperature;

[0011] a first temperature PID controller connected to the first temperature transmitter, wherein the control variable of the first temperature PID controller is the oil reservoir temperature, the downhole temperature value of the first temperature transmitter is fixed, and the oil reservoir temperature is adjusted by using the first temperature PID controller so that the downhole temperature value matches the field measured temperature data;

[0012] The second temperature transmitter is used to collect the temperature upstream of the oil nozzle and the heat transfer coefficient of the wellbore;

[0013] The second temperature PID controller is connected to the second temperature transmitter. The control variable of the second temperature PID controller is the wellbore heat transfer coefficient. The temperature value upstream of the oil nozzle is fixed. The second temperature PID controller is used to adjust the wellbore heat transfer coefficient so that the temperature value upstream of the oil nozzle matches the field measured temperature data.

[0014] In one embodiment of the present disclosure, the submarine pipeline is used to connect back to the processing platform, and the processing platform can separate, process and transport oil, gas and water.

[0015] In one embodiment of the present disclosure, the first temperature PID controller is used to adjust and match the data of the reading of the first temperature transmitter; the second temperature PID controller is used to adjust and match the data of the reading of the second temperature transmitter;

[0016] The first pressure PID controller is used to adjust and match the data of the reading of the first pressure transmitter; the second pressure PID controller is used to adjust and match the data of the reading of the second pressure transmitter.

[0017] According to another aspect of the present disclosure, a deepwater Christmas tree control method is provided, which is applied to the deepwater Christmas tree control system according to any one of claims 1 to 3, and the method comprises:

[0018] S1: Establish a LedaFlow dynamic model based on reservoir temperature, reservoir pressure, wellbore parameters, the first temperature transmitter, the second temperature transmitter, the first pressure transmitter, the second pressure transmitter, and the length of the submarine pipeline;

[0019] S2: controlling the reservoir temperature according to the first temperature transmitter and the first temperature PID controller logic, and controlling the wellbore heat transfer coefficient according to the second temperature transmitter and the second temperature PID controller logic;

[0020] S3: controlling the reservoir pressure according to the first pressure transmitter and the first pressure PID controller logic, and controlling the wellbore roughness according to the second pressure transmitter and the second PID controller logic;

[0021] S4: The parameter setting value of the first temperature PID controller is the reading of the first temperature transmitter, and the first temperature PID controller adjusts the reservoir temperature so that the downhole temperature value obtained by the reading of the first temperature transmitter matches the field measured temperature data; the parameter setting value of the second temperature PID controller is the reading of the second temperature transmitter, and the second temperature PID controller adjusts the wellbore heat transfer coefficient so that the upstream temperature value of the oil nozzle obtained by the reading of the second temperature transmitter matches the measured temperature data;

[0022] S5: The parameter setting value of the first pressure PID controller is the reading of the first pressure transmitter, and the first pressure PID controller adjusts the reservoir pressure so that the downhole pressure value obtained by the reading of the first pressure transmitter matches the measured pressure data; the parameter setting value of the second pressure PID controller is the reading of the second pressure transmitter, and the second pressure PID controller adjusts the wellbore roughness so that the nozzle upstream pressure value obtained by the reading of the second pressure transmitter matches the measured pressure data;

[0023] S6: The LedaFlow dynamic model calculates multiple groups of readings from the first temperature transmitter and the second temperature transmitter, so that the temperature data of the LedaFlow dynamic model accurately matches the temperature data actually measured on site; the LedaFlow dynamic model calculates multiple groups of readings from the first pressure transmitter and the second pressure transmitter, so that the pressure data of the LedaFlow dynamic model accurately matches the pressure data actually measured on site.

[0024] In one embodiment of the present disclosure, in step S1 , a LedaFlow dynamic model is established using LedaFlow software and a LedaFlow controller.

[0025] In one embodiment of the present disclosure, in step S2, a temperature PID controller is set according to the downhole temperature value obtained by the first temperature transmitter reading and the nozzle upstream temperature value obtained by the second temperature transmitter reading.

[0026] In one embodiment of the present disclosure, in step S3, a pressure PID controller is set according to the downhole pressure value obtained by the first pressure transmitter reading and the nozzle upstream pressure value obtained by the second pressure transmitter reading.

[0027] In one embodiment of the present disclosure, the LedaFlow dynamic model in step S6 calculates at least 5 groups of the first temperature transmitter readings and multiple groups of the second temperature transmitter readings, at least 5 groups of the first pressure transmitter readings and multiple groups of the second pressure transmitter readings, so as to accurately match the simulated system temperature and pressure data with the field measured temperature and pressure data.

[0028] The technical effect of the present invention is that the deepwater Christmas tree control system of the present invention includes an oil reservoir, a wellbore, a deepwater Christmas tree, a nozzle, a submarine pipeline, a riser and a processing platform. The oil reservoir is connected to the wellbore, the wellbore is connected to the deepwater Christmas tree, the deepwater Christmas tree outlet is connected to the submarine pipeline through the nozzle, and the submarine pipeline is connected to the processing platform through the riser; the system also includes: a first pressure transmitter for monitoring the reservoir pressure and the downhole pressure; a second pressure transmitter for monitoring the wellbore roughness and the upstream pressure of the nozzle; a first pressure PID controller is connected to the first pressure transmitter; and a second pressure PID controller is connected to the first pressure transmitter. The controller is connected to the second pressure transmitter, the control variable of the first pressure PID controller is the reservoir pressure, and the control variable of the second pressure PID controller is the wellbore roughness. The downhole pressure value of the first pressure transmitter and the upstream pressure value of the nozzle of the second pressure transmitter are fixed. The two pressure PID controllers are used to adjust the reservoir pressure and the wellbore roughness, so that the downhole pressure value and the upstream pressure value of the nozzle match the measured pressure data, so that the system pressure data of the LedaFlow dynamic model accurately matches the field measured pressure data; the first temperature transmitter is used to collect the reservoir temperature and the downhole temperature; the second temperature transmitter is used to collect the upstream temperature of the nozzle and the wellbore heat transfer coefficient; the first temperature PID controller is connected to the first temperature transmitter, and the second temperature PID controller is connected to the second temperature transmitter. The control variables of the two temperature PID controllers are the reservoir temperature and the wellbore heat transfer coefficient. The downhole temperature value of the first temperature transmitter and the upstream temperature value of the nozzle are fixed. The two temperature PID controllers are used to adjust the reservoir temperature and the wellbore heat transfer coefficient, so that the downhole temperature value and the upstream temperature value of the deepwater oil production tree nozzle match the field measured temperature data, so that The system temperature data of the LedaFlow dynamic model accurately matches the field-measured temperature data. When modeling engineering projects or underwater digital twin systems, the temperature and pressure PID controllers set on the wellbore pipeline are used to calibrate the wellbore heat transfer coefficient and roughness in real time to ensure that the simulation system data accurately matches the field-measured data. The temperature and pressure data of the Christmas tree under initial startup, production increase or restart conditions are more accurately simulated, the well opening procedure and time are optimized, the use of thermodynamic inhibitors during the well opening process is reduced, and the online calibration model is used to analyze the impact of different wellbore structures on the temperature and pressure changes of the Christmas tree. BRIEF DESCRIPTION OF THE DRAWINGS

[0029] Figure 1 It is a structural schematic diagram of a deepwater Christmas tree control system of the present invention;

[0030] Figure 2 It is a flow chart of the deepwater Christmas tree control method of the present invention.

[0031] Description of the main numbers in the figure:

[0032] 1-oil reservoir, 2-wellbore, 3-deepwater Christmas tree, 4-first temperature PID controller, 5-second temperature PID controller, 6-first pressure PID controller, 7-second pressure PID controller, 8-nozzle, 9-underwater manifold, 10-subsea pipeline, 11-riser, 12-processing platform. DETAILED DESCRIPTION

[0033] The present invention is further described below in conjunction with the accompanying drawings and specific embodiments so that those skilled in the art can better understand the present invention and implement it, but the embodiments are not intended to limit the present invention.

[0034] In related technologies, engineering projects or underwater digital twin system models are usually used to simulate wellbore temperature, pressure, etc.

[0035] Due to the influence of wellbore heat transfer and roughness, the calculated downhole temperature and pressure values ​​and the calculated temperature and pressure values ​​upstream of the deepwater oil tree nozzle in the engineering project or underwater digital twin system model are often inconsistent with the actual temperature and pressure data measured on site, resulting in inaccurate data in the engineering development model or digital twin model, and certain errors with the field data. It is impossible to accurately evaluate the temperature and pressure data of the oil tree under initial startup, production increase or restart conditions, which affects the analysis of the well opening procedure, time and the amount of thermodynamic inhibitors used during the well opening process.

[0036] Figure 1 Schematic diagram of the structure of the deepwater Christmas tree control system of the present invention. Figure 1 As shown, in one embodiment, a deepwater Christmas tree control system includes an oil reservoir 1, a wellbore 2, a deepwater Christmas tree 3, a nozzle 8, a submarine pipeline 10, a riser 11 and a processing platform 12. The oil reservoir 1 is connected to the wellbore 2, the wellbore 2 is connected to the deepwater Christmas tree 3, the outlet of the deepwater Christmas tree 3 is connected to the underwater manifold 7 through the nozzle 8, the bottom end of the underwater manifold 7 is connected to the submarine pipeline 10, and the submarine pipeline 10 is connected to the processing platform 12 through the riser 11.

[0037] In one embodiment, an oil reservoir 1 disposed at the bottom of a deepwater well is connected to the bottom end of a wellbore 2, the top of the wellbore 2 is connected to a Christmas tree 3, the liquid outlet of the Christmas tree 3 is connected to an outlet pipeline, the end of the outlet pipeline is connected to an underwater manifold 7; the bottom of the underwater manifold 7 is connected to a submarine pipeline 10, and the submarine pipeline 10 is connected to a processing platform 12 through a riser 11.

[0038] In one embodiment, a nozzle 8 is provided on the outlet pipeline. The nozzle 8 can control the pressure of the production of the Christmas tree 3 and the flow rate of the production fluid by adjusting the opening size, thereby ensuring the stable production of the oil and gas field. The opening of the nozzle 8 is also called the opening degree. When the opening degree of the nozzle 8 is larger, the flow rate of the production fluid through the nozzle 8 is larger. The flow area of ​​the nozzle 8 increases with the increase of the diameter or the opening degree, so that the speed of the production fluid passing through the nozzle 8 is reduced and the flow rate is increased; correspondingly, when the nozzle opening degree is smaller, the flow rate of the production fluid through the nozzle 8 is smaller.

[0039] In one embodiment, the deepwater Christmas tree control system further comprises:

[0040] The first pressure transmitter PT1 is used to monitor reservoir pressure and downhole pressure;

[0041] A first pressure proportional integral differential (PID) controller 6 is connected to the first pressure transmitter PT1. The control variable of the first pressure PID controller 6 is the reservoir 1 pressure. The downhole pressure value of the first pressure transmitter PT1 is fixed. The reservoir 1 pressure is adjusted by the first pressure PID controller 6 so that the downhole pressure value matches the measured pressure data.

[0042] The second pressure transmitter PT2 is used to monitor the roughness of the wellbore and the pressure upstream of the oil nozzle 8;

[0043] The second pressure PID controller 7 is connected to the second pressure transmitter PT2. The control variable of the second pressure PID controller 7 is the wellbore roughness. The upstream pressure value of the nozzle of the second pressure transmitter PT2 is fixed. The second pressure PID controller 7 is used to adjust the wellbore roughness so that the upstream pressure value of the nozzle matches the measured pressure data, so that the system pressure data of the LedaFlow dynamic model accurately matches the field measured pressure data.

[0044] The first temperature transmitter TT1 is used to collect the temperature of the oil reservoir 1 and the downhole temperature;

[0045] The first temperature PID controller 4 is connected to the first temperature transmitter TT1. The control variable of the first temperature PID controller 4 is the temperature of the oil reservoir 1. The downhole temperature value of the first temperature transmitter TT1 is fixed. The temperature of the oil reservoir 1 is adjusted by the first temperature PID controller 4 so that the downhole temperature value matches the field measured temperature data, so that the system temperature data of the LedaFlow dynamic model accurately matches the field measured temperature data.

[0046] The second temperature transmitter TT2 is used to collect the upstream temperature of the oil nozzle 8 and the heat transfer coefficient of the wellbore;

[0047] The second temperature PID controller 5 is connected to the second temperature transmitter TT2. The control variable of the second temperature PID controller 5 is the heat transfer coefficient of the wellbore. The temperature value upstream of the oil nozzle 8 is fixed. The second temperature PID controller 5 is used to adjust the heat transfer coefficient of the wellbore so that the temperature value upstream of the oil nozzle 8 matches the actual temperature data measured on site, so that the system temperature data of the LedaFlow dynamic model accurately matches the actual temperature data measured on site.

[0048] The first pressure transmitter PT1 is arranged at the oil reservoir 1, and the second pressure transmitter PT2 is arranged on the outlet pipeline upstream of the oil nozzle 8, so as to monitor the downhole pressure, the oil reservoir pressure, the pressure upstream of the oil nozzle and the roughness of the wellbore.

[0049] The first temperature transmitter TT1 is arranged at the oil reservoir 1, and the second temperature transmitter TT2 is arranged on the outlet pipeline upstream of the oil nozzle 8, so as to monitor the downhole temperature, the temperature of the oil reservoir 1, the temperature upstream of the oil nozzle and the heat transfer coefficient of the wellbore.

[0050] It should be noted that multiphase flow sensors can be used for both the above-mentioned temperature transmitter and pressure transmitter, and can detect the temperature, pressure, flow, oil and gas field output, etc. of the measured production fluid.

[0051] PID controller is an automatic controller, which consists of a proportional unit P, an integral unit I and a differential unit D. By setting the three parameters Kp, Ki and Kd, it can be used for systems that are basically linear and whose dynamic characteristics do not change with time.

[0052] In one embodiment, the control variable of the first pressure PID controller 6 is the reservoir pressure; the control variable of the second pressure PID controller 7 is the wellbore roughness. The reservoir pressure and the wellbore roughness are adjusted by fixing the downhole pressure value and the upstream pressure value of the nozzle. The downhole pressure value and the upstream pressure value of the nozzle can be the field measured pressure data, so that the pressure reading of the LedaFlow dynamic model accurately matches the field measured pressure data, thereby improving the effectiveness and reliability of deepwater oil production tree control.

[0053] It should be noted that the amount of data that needs to be collected for different control variables can be determined based on actual needs. The more data there is, the more detailed the classification is, and the higher the adjustment accuracy is.

[0054] In one embodiment, the control variable of the first temperature PID controller 4 is the temperature of the reservoir 1, and the control variable of the second temperature PID controller 5 is the heat transfer coefficient of the wellbore 2. The temperature of the reservoir 1 and the heat transfer coefficient of the wellbore 2 are adjusted by fixing the downhole temperature value and the temperature value upstream of the nozzle 8. The downhole temperature value and the temperature value upstream of the nozzle 8 can be set to the field measured temperature data, so that the temperature reading of the LedaFlow dynamic model accurately matches the field measured temperature data.

[0055] It should be noted that the control logic of the temperature PID controller is similar to that of the pressure PID controller, which will not be described in detail here.

[0056] In one implementation, the first temperature PID controller 4 is used to adjust and match the reading of the first temperature transmitter TT1; the second temperature PID controller 5 is used to adjust and match the reading of the second temperature transmitter TT2;

[0057] The first pressure PID controller 6 is used to adjust and match the reading of the first pressure transmitter PT1; the second pressure PID controller 7 is used to adjust and match the reading of the second pressure transmitter PT2.

[0058] The deepwater Christmas tree control system of the present invention utilizes the temperature and pressure PID controllers set on the wellbore pipeline to calibrate the heat transfer coefficient and roughness of the wellbore in real time when modeling an engineering project or an underwater digital twin system, thereby ensuring that the simulation system data accurately matches the field measured data, more accurately simulating the temperature and pressure data of the Christmas tree under the initial startup, production increase or restart conditions, optimizing the well opening procedure and time, reducing the amount of thermodynamic inhibitors used during the well opening process, and utilizing the online calibration model to analyze the effects of different wellbore structures on the temperature and pressure changes of the Christmas tree.

[0059] In one embodiment, the submarine pipeline 10 is connected back to the processing platform 12, and the processing platform 12 can separate, process and transport oil, gas and water.

[0060] The processing platform 12 can be used to separate, process and transport oil, gas and water production fluids. The processing platform 12 can be equipped with a multiphase separator, a pressure relief system, a flare system, etc., which are not limited in the present disclosure.

[0061] Figure 2 FIG. 1 is a flow chart of the deepwater Christmas tree control method of the present invention. Figure 2 As shown, in one embodiment, a deepwater Christmas tree control method is applied to the deepwater Christmas tree control system in the above embodiment, and the method comprises the following steps:

[0062] S1: Establish a LedaFlow dynamic model according to the temperature of reservoir 1, the pressure of reservoir 1, the parameters of wellbore 2, the first temperature transmitter TT1, the second temperature transmitter TT2, the first pressure transmitter PT1, the second pressure transmitter PT2, and the length of submarine pipeline 10;

[0063] S2: logically controlling the temperature of the reservoir 1 according to the first temperature transmitter TT1 and the first temperature PID controller 4, and logically controlling the heat transfer coefficient of the wellbore 2 according to the second temperature transmitter TT2 and the second temperature PID controller 5;

[0064] S3: Control the reservoir 1 pressure according to the logic of the first pressure transmitter PT1 and the first pressure PID controller 6, and control the roughness of the wellbore 2 according to the logic of the second pressure transmitter PT2 and the second pressure PID controller 7;

[0065] S4: The parameter setting value of the first temperature PID controller 4 is the reading of the first temperature transmitter TT1, and the first temperature PID controller 4 adjusts the temperature of the oil reservoir 1 so that the downhole temperature value obtained by the reading of the first temperature transmitter TT1 matches the field measured temperature data; the parameter setting value of the second temperature PID controller 5 is the reading of the second temperature transmitter TT2, and the second temperature PID controller 5 adjusts the heat transfer coefficient of the wellbore 2 so that the upstream temperature value of the oil nozzle 8 obtained by the reading of the second temperature transmitter TT2 matches the measured temperature data;

[0066] S5: The parameter setting value of the first pressure PID controller 6 is the reading of the first pressure transmitter PT1, and the first pressure PID controller 6 adjusts the pressure of the reservoir 1 so that the downhole pressure value obtained by the reading of the first pressure transmitter PT1 matches the measured pressure data; the parameter setting value of the second pressure PID controller 7 is the reading of the second pressure transmitter PT2, and the second pressure PID controller 7 adjusts the roughness of the wellbore 2 so that the upstream pressure value of the nozzle 8 obtained by the reading of the second pressure transmitter PT2 matches the measured pressure data;

[0067] S6: The LedaFlow dynamic model calculates multiple sets of readings from the first temperature transmitter TT1 and the second temperature transmitter TT2, so that the temperature data of the LedaFlow dynamic model accurately matches the temperature data actually measured on site; the LedaFlow dynamic model calculates multiple sets of readings from the first pressure transmitter PT1 and the second pressure transmitter PT2, so that the pressure data of the LedaFlow dynamic model accurately matches the pressure data actually measured on site.

[0068] In one embodiment: in step S1 , a LedaFlow dynamic model is established using LedaFlow software and a LedaFlow controller.

[0069] In one embodiment: in step S2, the first temperature PID controller 4 is set according to the downhole temperature value obtained by reading the first temperature transmitter TT1; the second temperature PID controller 5 is set according to the upstream temperature value of the nozzle 8 obtained by reading the second temperature transmitter TT2.

[0070] In one embodiment: in step S3, the first pressure PID controller 6 is set according to the downhole pressure value obtained by the reading of the first pressure transmitter PT1; the second pressure PID controller 7 is set according to the upstream pressure value of the nozzle 8 obtained by the reading of the second pressure transmitter PT2.

[0071] In one embodiment: in step S6, the LedaFlow dynamic model calculates at least 5 groups of first temperature transmitter TT1 readings and multiple groups of second temperature transmitter TT2 readings, at least 5 groups of first pressure transmitter PT1 readings and multiple groups of second pressure transmitter PT2 readings, so as to accurately match the simulated system temperature and pressure data with the field measured temperature and pressure data.

[0072] It should be noted that the implementation of the method embodiment is similar to the implementation of the system embodiment, and the similarities are not repeated here.

[0073] In the embodiment of the present invention, a LedaFlow dynamic model is established according to reservoir 1 pressure, reservoir 1 temperature, wellbore structure, wellbore parameters, two groups of temperature transmitters, two groups of pressure transmitters, submarine pipeline 10, riser 11, etc., and two groups of temperature and pressure PID controllers are set in the deepwater oil production tree wellbore pipeline. The variable of the first temperature PID controller 4 is the temperature of the reservoir 1, and the reading of the downhole temperature transmitter is fixed. The first temperature PID controller 4 is used to adjust the temperature of the reservoir 1 to match the reading of the downhole temperature transmitter; the variable of the second temperature PID controller 5 is the wellbore heat transfer coefficient, and the reading of the temperature transmitter upstream of the deepwater oil production tree nozzle is fixed. The second temperature PID controller 5 is used to adjust the wellbore heat transfer coefficient to match the reading of the temperature transmitter upstream of the deepwater oil production tree nozzle; the control variable of the first pressure PID controller 6 is the reservoir pressure, and the downhole pressure is fixed. The first pressure PID controller 6 is used to adjust the reservoir pressure to match the downhole pressure transmitter reading; the second pressure PID controller 7 controls the wellbore roughness as the variable, fixes the deepwater Christmas tree nozzle upstream pressure transmitter reading, and uses the second pressure PID controller 7 to adjust the wellbore roughness to match the deepwater Christmas tree nozzle upstream pressure transmitter reading; when modeling an engineering project or an underwater digital twin system, the temperature and pressure PID controllers set on the wellbore pipeline are used to calibrate the wellbore heat transfer coefficient and roughness in real time to ensure that the simulation system data accurately matches the field measured data, more accurately simulate the temperature and pressure data of the Christmas tree under initial startup, production increase or restart and other working conditions, optimize the well opening procedure and time, reduce the use of thermodynamic inhibitors during the well opening process, and use the online calibration model to analyze the impact of different wellbore structures on the temperature and pressure changes of the Christmas tree.

[0074] The above embodiments are only preferred embodiments for fully illustrating the present invention, and the protection scope of the present invention is not limited thereto. Equivalent substitutions or changes made by those skilled in the art based on the present invention are within the protection scope of the present invention. The protection scope of the present invention shall be subject to the claims.

Claims

1. A deepwater Christmas tree control system, characterized in that: It includes an oil reservoir, a wellbore, a deepwater Christmas tree, a nozzle, a subsea manifold, a submarine pipeline, a riser and a processing platform, wherein the oil reservoir is connected to the wellbore, the wellbore is connected to the deepwater Christmas tree, the deepwater Christmas tree outlet is connected to the subsea manifold through the nozzle, the subsea manifold is connected to the submarine pipeline, and the submarine pipeline is connected to the processing platform through the riser; The system is used for real-time calibration of wellbore heat transfer coefficient and roughness, and the system further comprises: The first pressure transmitter is used to monitor reservoir pressure and downhole pressure; a first pressure PID controller connected to the first pressure transmitter, the first pressure PID controller being used to adjust and match the data of the reading of the first pressure transmitter; the control variable of the first pressure PID controller is the reservoir pressure, the downhole pressure value of the first pressure transmitter is fixed, and the reservoir pressure is adjusted by using the first pressure PID controller so that the downhole pressure value matches the measured pressure data; A second pressure transmitter is used to monitor the wellbore roughness and the pressure upstream of the nozzle; a second pressure PID controller connected to the second pressure transmitter, and used to adjust and match the reading of the second pressure transmitter; a control variable of the second pressure PID controller is the wellbore roughness, a nozzle upstream pressure value of the second pressure transmitter is fixed, and the wellbore roughness is adjusted by the second pressure PID controller, so that the nozzle upstream pressure value matches the measured pressure data; The first temperature transmitter is used to collect reservoir temperature and downhole temperature; a first temperature PID controller connected to the first temperature transmitter, the first temperature PID controller being used to adjust and match the data of the reading of the first temperature transmitter; the control variable of the first temperature PID controller is the reservoir temperature, the downhole temperature value of the first temperature transmitter is fixed, and the reservoir temperature is adjusted by the first temperature PID controller so that the downhole temperature value matches the field measured temperature data; The second temperature transmitter is used to collect the upstream temperature of the oil nozzle and the heat transfer coefficient of the wellbore; The second temperature PID controller is connected to the second temperature transmitter, and is used to adjust the reading of the second temperature transmitter and match the data; the control variable of the second temperature PID controller is the wellbore heat transfer coefficient, the temperature value upstream of the oil nozzle is fixed, and the second temperature PID controller is used to adjust the wellbore heat transfer coefficient so that the temperature value upstream of the oil nozzle matches the field measured temperature data.

2. A deepwater Christmas tree control system according to claim 1, characterized in that: The submarine pipeline is used to connect back to the processing platform, and the processing platform can separate, process and transport oil, gas and water.

3. A deepwater Christmas tree control method, characterized in that: Applied to the deepwater Christmas tree control system according to any one of claims 1 to 2, the method comprising: S1: Establish a LedaFlow dynamic model based on reservoir temperature, reservoir pressure, wellbore parameters, the first temperature transmitter, the second temperature transmitter, the first pressure transmitter, the second pressure transmitter, and the length of the submarine pipeline; S2: controlling the reservoir temperature according to the first temperature transmitter and the first temperature PID controller logic, and controlling the wellbore heat transfer coefficient according to the second temperature transmitter and the second temperature PID controller logic; S3: controlling the reservoir pressure according to the first pressure transmitter and the first pressure PID controller logic, and controlling the wellbore roughness according to the second pressure transmitter and the second PID controller logic; S4: The parameter setting value of the first temperature PID controller is the reading of the first temperature transmitter, and the first temperature PID controller adjusts the reservoir temperature so that the downhole temperature value obtained by the reading of the first temperature transmitter matches the field measured temperature data; the parameter setting value of the second temperature PID controller is the reading of the second temperature transmitter, and the second temperature PID controller adjusts the wellbore heat transfer coefficient so that the upstream temperature value of the oil nozzle obtained by the reading of the second temperature transmitter matches the measured temperature data; S5: The parameter setting value of the first pressure PID controller is the reading of the first pressure transmitter, and the first pressure PID controller adjusts the reservoir pressure so that the downhole pressure value obtained by the reading of the first pressure transmitter matches the measured pressure data; the parameter setting value of the second pressure PID controller is the reading of the second pressure transmitter, and the second pressure PID controller adjusts the wellbore roughness so that the nozzle upstream pressure value obtained by the reading of the second pressure transmitter matches the measured pressure data; S6: The LedaFlow dynamic model calculates multiple groups of readings of the first temperature transmitter and the second temperature transmitter, so that the temperature data of the LedaFlow dynamic model accurately matches the temperature data measured on site; the LedaFlow dynamic model calculates multiple groups of readings of the first pressure transmitter and the second pressure transmitter, so that the pressure data of the LedaFlow dynamic model accurately matches the pressure data measured on site; In step S2, a temperature PID controller is set according to the downhole temperature value obtained by the first temperature transmitter reading and the nozzle upstream temperature value obtained by the second temperature transmitter reading; In step S3, a pressure PID controller is set according to the downhole pressure value obtained by the reading of the first pressure transmitter and the nozzle upstream pressure value obtained by the reading of the second pressure transmitter.

4. A deepwater Christmas tree control method according to claim 3, characterized in that: In step S1, a LedaFlow dynamic model is established using LedaFlow software and a LedaFlow controller.

5. A deepwater Christmas tree control method according to claim 3, characterized in that: The LedaFlow dynamic model in step S6 calculates at least 5 groups of the first temperature transmitter readings and multiple groups of the second temperature transmitter readings, at least 5 groups of the first pressure transmitter readings and multiple groups of the second pressure transmitter readings, so as to accurately match the simulated system temperature and pressure data with the field measured temperature and pressure data.

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