A dynamic regulation method of stratified control valve based on yield-pressure double fitting

Abstract

The application discloses a kind of based on yield-pressure double fitting's hierarchical control valve dynamic regulation and control method, comprising: according to the historical real-time data of oil well production layer, fitting flow coefficient;According to the real-time response data of oil well production layer history control valve after regulation and control, fitting wellbore reservoir coefficient;Cross generation regulation and control scheme;Calculate the single well daily production of oil well when not disturbed and the single well daily production when disturbed under given regulation and control scheme;Calculate the interference coefficient of oil well production under given regulation and control scheme;Calculate the water cut influence factor and oil production influence factor under given regulation and control scheme, combined with interference coefficient, obtain the comprehensive score of regulation and control scheme;Select the regulation and control scheme with minimum score, that is, the optimal scheme and the like steps.The application can simultaneously fit liquid production and pressure dynamics, establish high-precision model fully considering annular reservoir effect, and provide reliable optimization means, so as to truly realize scientific and accurate dynamic regulation and control of hierarchical control valve, break through the effect bottleneck of existing separate mining technology.

Description

Technical Field

[0001] This invention belongs to the field of stratified intelligent oil recovery technology, specifically relating to a dynamic control method for stratified control valves based on production-pressure dual fitting of annular reservoir effect. Background Technology

[0002] In the multi-layer synergistic development of modern oil and gas fields, the application of downhole stratified control valve technology has significantly enhanced the exploitation capacity of complex reservoirs. This technology effectively suppresses inter-layer interference and fully taps the potential of low-permeability layers by physically isolating and independently controlling each producing layer, thereby improving the final recovery rate. However, how to scientifically determine and dynamically optimize the opening configuration of each layer's control valves remains a key challenge in field production practice.

[0003] Currently, field control mainly relies on two methods: one is the engineer's experience method based on production logging and well testing results. While this method is direct, it is highly subjective, has a long control cycle, and is costly, making it difficult to achieve refined management and real-time optimization. The other is predictive control based on reservoir numerical simulation. This method establishes numerical models for historical data fitting and production prediction, providing a theoretical basis for optimization decisions. However, existing numerical simulation methods have significant shortcomings. Most fitting work only targets historical production data. Although matching production curves can be achieved by adjusting multiple sets of parameters, this single-data fitting suffers from significant "multiple solutions" problems. More importantly, existing methods do not adequately consider or oversimplify the annular reservoir effect unique to stratified control valve wells. Ignoring this effect leads to models that cannot accurately depict the complex flow characteristics near the wellbore. Summary of the Invention

[0004] This invention is proposed to solve the problems existing in the prior art, and its purpose is to provide a dynamic control method for a stratified control valve based on the production-pressure double fitting of the annular storage effect.

[0005] This invention is achieved through the following technical solution: A dynamic control method for a stratified control valve based on a production-pressure dual-fit includes the following steps: S1. Fit the flow coefficient of the i-th production layer based on the historical real-time data of the i-th production layer of the oil well; S2. Fit the wellbore reservoir coefficient of the i-th production layer based on the real-time response data after the historical control valve adjustment of the i-th production layer. S3. Based on the methods in steps S1 and S2, obtain the flow coefficient and wellbore storage coefficient of all production layers in the oil well; S4. Generate 10 opening values ​​for each production layer of the oil well from 0 to 100 in increments of 10, for a total of 10 cross-generated values. n A well control scheme is proposed, where n is the number of production layers; S5. Calculate the daily production of a single well under each control scheme (i.e., the opening degree of each layer of control valve) generated in step S4 when the oil well is not disturbed (the bottom flow pressure of each layer is taken as the minimum bottom flow pressure among all production layers when there is no disturbance) and the daily production of a single well when the oil well is disturbed (the bottom flow pressure of each layer is taken as the actual bottom flow pressure of each layer during production). S6. Based on the daily production of the oil well when it is undisturbed and the daily production of the oil well when it is disturbed, obtained in step S5, calculate the interference coefficient of each production layer of the oil well under each control scheme generated in step S4. S7. Calculate the water cut influence factor and oil production influence factor of the oil well under each control scheme generated in step S4, and calculate the comprehensive score of each control scheme by combining the interference coefficient obtained in step S6. S8. Based on step S7, obtain the comprehensive score of each control scheme, and select the control scheme with the smallest comprehensive score as the optimal scheme.

[0006] In the above technical solution, step S1, which involves fitting the flow coefficient of the i-th production layer based on historical real-time data of the i-th production layer of the oil well, specifically includes the following steps: S11. Based on the control valve opening, control valve flow area, bottom hole pressure, fluid density, and annular pressure at a certain time point of the i-th production layer, the flow coefficient of the i-th production layer is given; the control valve production rate at that time point is calculated according to the control valve production capacity equation. S12. By adjusting the value of the flow coefficient of the i-th production layer, calculate the output of the control valve at each historical time point according to step S11, and fit the calculated output of the control valve of the production layer at each time point with the actual output. After the fitting is completed, the flow coefficient of the i-th production layer is obtained.

[0007] In the above technical solution, the production capacity equation of the control valve is:

[0008] In the formula: The output of the control valves in the i-th production layer is expressed in m³. 3 / d; Let be the flow coefficient of the i-th production layer, which is dimensionless; Let be the opening degree of the i-th production layer, which is dimensionless; The flow area of ​​the stratified control valve is shown in mm. 2 ; The annular pressure of the i-th production layer is expressed in MPa. The bottom-hole flowing pressure of the i-th layer is expressed in MPa. Let be the fluid density of the i-th production layer, kg / m³ 3 .

[0009] In the above technical solution, step S2, which involves fitting the wellbore reservoir coefficient of the i-th production layer based on the real-time response data after the historical control valve adjustment of the i-th production layer, specifically includes the following steps: S21. The first time step state after the control valve is adjusted is taken as the time starting point. S22. Substitute the annular pressure, formation pressure and fluid production index of the i-th production layer at this time into the well productivity equation to calculate the annular inflow production at the time starting point of the production layer. The oil well productivity equation is as follows:

[0010] In the formula: The annular inflow output of the i-th production layer, in m³. 3 / d; The fluid collection index for the i-th production layer is expressed in m. 3 / (d·MPa); is the formation pressure of the i-th production layer, in MPa; S23. Based on the flow coefficient of the i-th production layer and the control valve capacity equation obtained after fitting in step S1, calculate the control valve output of the i-th production layer under the current annular pressure. S24, Based on the i-th production layer annular inflow output obtained in step S22, the i-th production layer control valve output under the current annular pressure obtained in step S23, and the valve adjustment duration at the next time point. Given the wellbore reservoir coefficient, the annular pressure change of the i-th production layer at the next time step is calculated using the annular pressure change equation, thus obtaining the duration of the i-th production layer after valve regulation. The annular pressure at that time; S25. Repeat steps S22 to S24 to calculate the annular pressure at different time points after the control valve of the i-th production layer is adjusted. S26. Adjust the given value of the wellbore storage coefficient of the i-th production layer. Calculate the annular pressure at each time point after the control valve is adjusted according to step S25. Fit the calculated annular pressure with the actual annular pressure. After the fitting is completed, the wellbore storage coefficient of the i-th layer is obtained.

[0011] In the above technical solution, the equation for the change in annular pressure is:

[0012] In the formula: The duration after valve regulation for the i-th production layer is... The change in annular pressure over time, in MPa; The output of the control valves in the i-th production layer is calculated using the fitted flow coefficient, in m³.3 / d; The annular inflow output of the i-th production layer, in m³. 3 / d; The duration after valve adjustment at the i-th production level is equal to the duration from the start of time, expressed in days. Let be the wellbore reservoir coefficient of the i-th production layer, which is dimensionless.

[0013] In the above technical solution, "uninterrupted oil well" means that the bottom flow pressure of each layer is taken as the minimum bottom flow pressure among all production layers; "interrupted oil well" means that the bottom flow pressure of each layer is taken as the actual bottom flow pressure of each layer during production.

[0014] In the above technical solution, step S5, which calculates the daily production of a single well under each control scheme generated in step S4 when the well is undisturbed and when the well is disturbed, specifically includes the following steps: S51. Using the flow coefficient and wellbore storage coefficient of the i-th production layer obtained in step S3, and based on the valve opening of the i-th production layer in the valve opening control scheme, the control valve output and annular pressure of the i-th production layer after control are obtained in steps S21 to S25. S52. When the calculated annular pressure of the i-th production layer no longer changes with time, the output of the control valve at this time is the output of the control valve at this opening degree. S53. Obtain the output of control valves for all production layers according to steps S51 and S52, and sum the output of control valves for all production layers to obtain the daily output of a single well under the control valve regulation scheme.

[0015] In the above technical solution, the formula for calculating the interference coefficient is:

[0016] In the formula: The interference coefficient for oil well production is dimensionless. This represents the daily production of a single well when it is undisturbed, in m³. 3 / d; This represents the daily production of a single well when the well is disturbed, in m³. 3 / d.

[0017] In the above technical solution, the formula for calculating the water cut influencing factor of the oil well is:

[0018] In the formula: The water cut in oil wells is a dimensionless factor. Let be the water cut of the i-th production layer of the oil well, %, dimensionless; This represents the daily production of a single well when the well is disturbed, in m³. 3 / d; n is the number of production layers in the oil well; The formula for calculating the oil production influencing factor of the oil well is as follows:

[0019] In the formula: This represents the influence of oil well production on oil production, and is dimensionless. The lowest historical daily oil production of the well, in m³. 3 / d; This represents the highest historical daily oil production of the well, expressed in cubic meters (m³). 3 / d; n is the number of producing layers in the oil well.

[0020] In the above technical solution, the formula for calculating the comprehensive score of the control scheme is as follows:

[0021] In the formula: The overall score for the control plan is dimensionless. The interference coefficient is dimensionless. This represents the influence of water cut in oil wells, and is dimensionless. This represents the influence value on oil well production, and is dimensionless. a, b, and c are the weights of the interference coefficient, water cut factor, and oil production factor, respectively, and are dimensionless.

[0022] The beneficial effects of this invention are: This invention provides a dynamic control method for stratified control valves based on a dual fitting of production and pressure using the annular reservoir effect. This method simultaneously achieves dual fitting of production and pressure, effectively combining the annular reservoir effect and fundamentally solving the problem of multiple solutions in existing technologies. Furthermore, this invention overcomes the blindness problem inherent in the control of stratified control valves in oil wells, avoiding damage to downhole operations caused by improper control. In addition, the fitting process is implemented through programming, significantly improving work efficiency and making the fitting process more time-saving and labor-saving. This invention has strong versatility and promotional value. Attached Figure Description

[0023] Figure 1 This is a flowchart of the method of the present invention; Figure 2 This is a fitting diagram of the three-layer combined sampling fluid in this invention; Figure 3 This is a pressure fitting diagram of the three-layer combined mining process in this invention.

[0024] For those skilled in the art, other related figures can be obtained from the above figures without any creative effort. Detailed Implementation

[0025] To enable those skilled in the art to better understand the technical solution of the present invention, the technical solution of the present invention will be further described below with reference to the accompanying drawings and specific embodiments.

[0026] Example 1

[0027] like Figure 1 As shown, a dynamic control method for a stratified control valve based on a production-pressure double fitting of the annular storage effect includes the following steps: S1. Fit the flow coefficient of the i-th production layer based on the historical real-time data of the i-th production layer of the oil well; Specifically, the following steps are included: S11. Based on the control valve opening, control valve flow area, bottom hole pressure, fluid density, and annular pressure at a certain time point of the i-th production layer, the flow coefficient of the i-th production layer is given; the control valve production rate at that time point is calculated according to the control valve production capacity equation. S12. By adjusting the value of the flow coefficient of the i-th production layer, calculate the output of the control valve at each historical time point according to step S11, and fit the calculated output of the control valve of the production layer at each time point with the actual output. After the fitting is completed, the flow coefficient of the i-th production layer is obtained.

[0028] In the above technical solution, the production capacity equation of the control valve is:

[0029] In the formula: The output of the control valves in the i-th production layer is expressed in m³. 3 / d; Let be the flow coefficient of the i-th production layer, which is dimensionless; Let be the opening degree of the i-th production layer, which is dimensionless; The flow area of ​​the stratified control valve is shown in mm. 2 ; The annular pressure of the i-th production layer is expressed in MPa. The bottom-hole flowing pressure of the i-th layer is expressed in MPa. Let be the fluid density of the i-th production layer, kg / m³ 3 .

[0030] S2. Fit the wellbore reservoir coefficient of the i-th production layer based on the real-time response data after the historical control valve adjustment of the i-th production layer. Specifically, the following steps are included: S21. The first time step state after the control valve is adjusted is taken as the time starting point. S22. Substitute the annular pressure, formation pressure and fluid production index of the i-th production layer at this time into the well productivity equation to calculate the annular inflow production at the time starting point of the production layer. The oil well productivity equation is as follows:

[0031] In the formula: The annular inflow output of the i-th production layer, in m³. 3 / d; The fluid collection index for the i-th production layer is expressed in m. 3 / (d·MPa); is the formation pressure of the i-th production layer, in MPa; S23. Based on the flow coefficient of the i-th production layer and the control valve capacity equation obtained after fitting in step S1, calculate the control valve output of the i-th production layer under the current annular pressure. S24, Based on the i-th production layer annular inflow output obtained in step S22, the i-th production layer control valve output under the current annular pressure obtained in step S23, and the valve adjustment duration at the next time point. Given the wellbore reservoir coefficient, the annular pressure change of the i-th production layer at the next time step is calculated using the annular pressure change equation, thus obtaining the duration of the i-th production layer after valve regulation. The annular pressure at that time; S25. Repeat steps S22 to S24 to calculate the annular pressure at different time points after the control valve of the i-th production layer is adjusted. S26. Adjust the given value of the wellbore storage coefficient of the i-th production layer. Calculate the annular pressure at each time point after the control valve is adjusted according to step S25. Fit the calculated annular pressure with the actual annular pressure. After the fitting is completed, the wellbore storage coefficient of the i-th layer is obtained.

[0032] In the above technical solution, the equation for the change in annular pressure is:

[0033] In the formula: The duration after valve regulation for the i-th production layer is... The change in annular pressure over time, in MPa; The output of the control valves in the i-th production layer is calculated using the fitted flow coefficient, in m³. 3 / d; The annular inflow output of the i-th production layer, in m³. 3 / d; The duration after valve adjustment at the i-th production level is equal to the duration from the start of time, expressed in days. Let be the wellbore reservoir coefficient of the i-th production layer, which is dimensionless.

[0034] S3. Based on the methods in steps S1 and S2, obtain the flow coefficient and wellbore storage coefficient of all production layers in the oil well; S4. Generate 10 opening values ​​for each production layer of the oil well from 0 to 100 in increments of 10, for a total of 10 cross-generated values. n A well control scheme is proposed, where n is the number of production layers; S5. Calculate the daily production of a single well under each control scheme (i.e., the opening degree of each layer of control valve) generated in step S4 when the oil well is not disturbed (the bottom flow pressure of each layer is taken as the minimum bottom flow pressure among all production layers when there is no disturbance) and the daily production of a single well when the oil well is disturbed (the bottom flow pressure of each layer is taken as the actual bottom flow pressure of each layer during production). Specifically, the following steps are included: S51. Using the flow coefficient and wellbore storage coefficient of the i-th production layer obtained in step S3, and based on the valve opening of the i-th production layer in the valve opening control scheme, the control valve output and annular pressure of the i-th production layer after control are obtained in steps S21 to S25. S52. When the calculated annular pressure of the i-th production layer no longer changes with time, the output of the control valve at this time is the output of the control valve at this opening degree. S53. Obtain the output of control valves for all production layers according to steps S51 and S52, and sum the output of control valves for all production layers to obtain the daily output of a single well under the control valve regulation scheme.

[0035] S6. Based on the daily production of the oil well when it is undisturbed and the daily production of the oil well when it is disturbed, obtained in step S5, calculate the interference coefficient of each production layer of the oil well under each control scheme generated in step S4. The formula for calculating the interference coefficient is:

[0036] In the formula: The interference coefficient for oil well production is dimensionless. This represents the daily production of a single well when it is undisturbed, in m³. 3 / d; This represents the daily production of a single well when the well is disturbed, in m³. 3 / d.

[0037] S7. Calculate the water cut influence factor and oil production influence factor of the oil well under each control scheme generated in step S4, and calculate the comprehensive score of each control scheme by combining the interference coefficient obtained in step S6. The formula for calculating the water cut influencing factor of the oil well is as follows:

[0038] In the formula: The water cut in oil wells is a dimensionless factor. Let be the water cut of the i-th production layer of the oil well, %, dimensionless; This represents the daily production of a single well when the well is disturbed, in m³. 3 / d; n is the number of production layers in the oil well; The formula for calculating the oil production influencing factor of the oil well is as follows:

[0039] In the formula: This represents the influence of oil well production on oil production, and is dimensionless. The lowest historical daily oil production of the well, in m³. 3 / d; This represents the highest historical daily oil production of the well, expressed in cubic meters (m³). 3 / d; n is the number of producing layers in the oil well.

[0040] S8. Based on step S7, obtain the comprehensive score of each control scheme, and select the control scheme with the smallest comprehensive score as the optimal scheme.

[0041] The formula for calculating the comprehensive score of the control scheme is as follows:

[0042] In the formula: The overall score for the control plan is dimensionless. The interference coefficient is dimensionless. This represents the influence of water cut in oil wells, and is dimensionless. The value representing the impact on oil well production is dimensionless; a, b, and c are the weights of the interference coefficient, water cut factor, and oil production factor, respectively, and are dimensionless.

[0043] Taking the A1 well of a certain offshore intelligent A oilfield with three-layer combined production as an example, the flow area of ​​the control valve for this oil well is 13mm. 2 The fluid density is 911 kg / m³ 3 The remaining parameters are shown in Table 1. Based on these parameters, production fluid fitting and pressure fitting were performed on the three production layers of well A1. The flow coefficient and wellbore storage coefficient obtained from steps S1 to S3 are shown in Table 1. The production fluid fitting and pressure fitting effect diagrams are shown in... Figure 2 and Figure 3The production fluid fitting errors were 3.18%, 5.26%, and 2.51%, respectively, and the pressure fitting errors were 5.64%, 4.28%, and 2.13%, respectively. Based on the fitted parameters, according to steps S4 to S8, the comprehensive score of the well opening combination was calculated with a bottomhole flowing pressure of 5 MPa. Some opening combination scores are shown in Table 2, and the optimal opening combination was selected as: 0-100-100.

[0044] Table 1: Parameter Table for Well A1

[0045] Table 2 Scoring of Partial Opening Combinations

[0046] The method of this invention constructs a high-precision and high-reliability reservoir numerical model through dual data constraints of production volume and annular pressure, and realizes precise optimization and dynamic control of the opening degree of the stratified control valve based on the model, which can effectively improve oil well production and recovery rate.

[0047] The applicant declares that the above description is only a specific embodiment of the present invention, but the protection scope of the present invention is not limited thereto. Those skilled in the art should understand that any changes or substitutions that can be easily conceived by those skilled in the art within the technical scope disclosed in the present invention fall within the protection and disclosure scope of the present invention.

Claims

1. A dynamic control method for a stratified control valve based on a production-pressure double fitting, characterized in that: Includes the following steps: S1. Fit the flow coefficient of the i-th production layer based on the historical real-time data of the i-th production layer of the oil well; S2. Fit the wellbore reservoir coefficient of the i-th production layer based on the real-time response data after the historical control valve adjustment of the i-th production layer. S3. Based on the methods in steps S1 and S2, obtain the flow coefficient and wellbore storage coefficient of all production layers in the oil well; S4. Generate 10 opening values ​​for each production layer of the oil well from 0 to 100 in increments of 10, for a total of 10 cross-generated values. n A well control scheme is proposed, where n is the number of production layers; S5. Calculate the daily production of a single well when the oil well is undisturbed and the daily production of a single well when the oil well is disturbed under each control scheme generated in step S4. S6. Based on the daily production of the oil well when it is undisturbed and the daily production of the oil well when it is disturbed, obtained in step S5, calculate the interference coefficient of each production layer of the oil well under each control scheme generated in step S4. S7. Calculate the water cut influence factor and oil production influence factor of the oil well under each control scheme generated in step S4, and calculate the comprehensive score of each control scheme by combining the interference coefficient obtained in step S6. S8. Based on step S7, obtain the comprehensive score of each control scheme, and select the control scheme with the smallest comprehensive score as the optimal scheme.

2. The dynamic control method for a stratified control valve based on production-pressure double fitting according to claim 1, characterized in that: Step S1, which involves fitting the flow coefficient of the i-th production layer based on historical real-time data of the i-th production layer of the oil well, specifically includes the following steps: S11. Based on the control valve opening, control valve flow area, bottom hole pressure, fluid density, and annular pressure at a certain time point of the i-th production layer, the flow coefficient of the i-th production layer is given; the control valve production rate at that time point is calculated according to the control valve production capacity equation. S12. By adjusting the value of the flow coefficient of the i-th production layer, calculate the output of the control valve at each historical time point according to step S11, and fit the calculated output of the control valve of the production layer at each time point with the actual output. After the fitting is completed, the flow coefficient of the i-th production layer is obtained.

3. The dynamic control method for a stratified control valve based on production-pressure double fitting according to claim 2, characterized in that: The power production equation of the control valve is: In the formula: The output of the control valves in the i-th production layer is expressed in m³. 3 / d; Let be the flow coefficient of the i-th production layer, which is dimensionless; Let be the opening degree of the i-th production layer, which is dimensionless; The flow area of ​​the stratified control valve is shown in mm. 2 ; The annular pressure of the i-th production layer is expressed in MPa. The bottom-hole flowing pressure of the i-th layer is expressed in MPa. Let be the fluid density of the i-th production layer, kg / m³ 3 .

4. The dynamic control method for a stratified control valve based on production-pressure double fitting according to claim 1, characterized in that: Step S2, which involves fitting the wellbore reservoir coefficient of the i-th production layer based on the real-time response data after historical control valve regulation of the i-th production layer, specifically includes the following steps: S21. The first time step state after the control valve is adjusted is taken as the time starting point. S22. Substitute the annular pressure, formation pressure and fluid production index of the i-th production layer at this time into the well productivity equation to calculate the annular inflow production at the time starting point of the production layer. The oil well productivity equation is as follows: In the formula: The annular inflow output of the i-th production layer, in m³. 3 / d; The fluid collection index for the i-th production layer is expressed in m. 3 / (d·MPa); is the formation pressure of the i-th production layer, in MPa; S23. Based on the flow coefficient of the i-th production layer and the control valve capacity equation obtained in step S1, calculate the control valve output of the i-th production layer under the current annular pressure. S24, Based on the i-th production layer annular inflow output obtained in step S22, the i-th production layer control valve output under the current annular pressure obtained in step S23, and the valve adjustment duration at the next time point. Given the wellbore reservoir coefficient, the annular pressure change of the i-th production layer at the next time step is calculated using the annular pressure change equation, thus obtaining the duration of the i-th production layer after valve regulation. The annular pressure at that time; S25. Repeat steps S22 to S24 to calculate the annular pressure at different time points after the control valve of the i-th production layer is adjusted. S26. Adjust the given value of the wellbore storage coefficient of the i-th production layer. Calculate the annular pressure at each time point after the control valve is adjusted according to step S25. Fit the calculated annular pressure with the actual annular pressure. After the fitting is completed, the wellbore storage coefficient of the i-th layer is obtained.

5. The dynamic control method for a stratified control valve based on production-pressure double fitting according to claim 4, characterized in that: The equation for the change in annular pressure is: In the formula: The duration after valve regulation for the i-th production layer is... The change in annular pressure over time, in MPa; The output of control valves for the i-th production layer is calculated using the control valve capacity equation, in units of m. 3 / d; The annular inflow output of the i-th production layer, in m³. 3 / d; The duration after valve adjustment at the i-th production level is equal to the duration from the start of time, expressed in days. Let be the wellbore reservoir coefficient of the i-th production layer, which is dimensionless.

6. The dynamic control method for a stratified control valve based on production-pressure double fitting according to claim 1, characterized in that: The statement that the oil well is undisturbed means that the bottom flow pressure of each layer is taken as the minimum bottom flow pressure among all the production layers; the statement that the oil well is disturbed means that the bottom flow pressure of each layer is taken as the actual bottom flow pressure of each layer during production.

7. The dynamic control method for a stratified control valve based on production-pressure double fitting according to claim 1, characterized in that: Step S5, which calculates the daily production of a single well under each control scheme generated in step S4 when the well is undisturbed and when the well is disturbed, specifically includes the following steps: S51. Using the flow coefficient and wellbore storage coefficient of the i-th production layer obtained in step S3, and based on the valve opening of the i-th production layer in the valve opening control scheme, the control valve output and annular pressure of the i-th production layer after control are obtained in steps S21 to S25. S52. When the calculated annular pressure of the i-th production layer no longer changes with time, the output of the control valve at this time is the output of the control valve at this opening degree. S53. Obtain the output of control valves for all production layers according to steps S51 and S52, and sum the output of control valves for all production layers to obtain the daily output of a single well under the control valve regulation scheme.

8. The dynamic control method for a stratified control valve based on production-pressure double fitting according to claim 1, characterized in that: The formula for calculating the interference coefficient is: In the formula: The interference coefficient for oil well production is dimensionless. This represents the daily production of a single well when it is undisturbed, in m³. 3 / d; This represents the daily production of a single well when the well is disturbed, in m³. 3 / d.

9. The dynamic control method for a stratified control valve based on production-pressure double fitting according to claim 1, characterized in that: The formula for calculating the water cut influencing factor of the oil well is as follows: In the formula: The water cut in oil wells is a dimensionless factor. Let be the water cut of the i-th production layer of the oil well, %, dimensionless; This represents the daily production of a single well when the well is disturbed, in m³. 3 / d; n is the number of production layers in the oil well; The formula for calculating the oil production influencing factor of the oil well is as follows: In the formula: This represents the influence of oil well production on oil production, and is dimensionless. The lowest historical daily oil production of the well, in cubic meters (m³). 3 / d; This represents the highest historical daily oil production of the well, expressed in cubic meters (m³). 3 / d; n is the number of producing layers in the oil well.

10. The dynamic control method for a stratified control valve based on production-pressure double fitting according to claim 1, characterized in that: The formula for calculating the comprehensive score of the control scheme is as follows: In the formula: The overall score for the control plan is dimensionless. The interference coefficient is dimensionless. This represents the influence of water cut in oil wells, and is dimensionless. This represents the influence value on oil well production, and is dimensionless. a, b, and c are the weights of the interference coefficient, water cut factor, and oil production factor, respectively, and are dimensionless.

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