Method for simulating settlement change of water-containing emulsified crude oil on offshore platform

Abstract

The invention discloses a method for simulating settlement change of water-containing emulsified crude oil of an offshore platform. The method comprises the following steps: establishing other substance components except crude oil according to related physical property parameters of the crude oil extracted from the offshore platform; according to test data of crude oil extracted from the offshore platform, oil cutting is conducted on the crude oil composition, and crude oil virtual components are generated; according to the water content test data of the extracted crude oil, virtual components used for representing the emulsion in the water-containing crude oil are established; according to related equipment parameters of an offshore platform oil treatment separator, a water-containing emulsified crude oil settlement change model of the separator is constructed; values are taken according to related production data of the oil treatment separator and according to a time sequence; according to the change model and the time sequence values of the related parameters, coupling a regression equation of the demulsifier concentration to the water content of the settled water-containing emulsified crude oil; and solving the change model by adopting a simultaneous solution method. According to the simulation method, the reliability and effectiveness of separator moisture content analysis are improved.

Description

Technical Field

[0001] This invention relates to a method for simulating the sedimentation changes of water-containing emulsified crude oil on offshore platforms, belonging to the field of offshore platform oil and gas process simulation. Background Technology

[0002] In this invention, the offshore platform oil and gas process refers to FPSO, which stands for Floating Production Storage and Offloading. This system uses the principle of emulsification and sedimentation of water-containing crude oil to separate oil and water in offshore oil production, achieving dehydration of the crude oil. This technology has the advantages of good dehydration effect, long equipment service life, and resistance to deformation.

[0003] Offshore platform crude oil-water separation refers to the process where water-containing crude oil extracted from subsea pipelines is heated by a heater and then sent to a multi-stage separator to separate free water. Demulsifiers are added at each stage of the separator to further settle the emulsified water in the crude oil. Finally, chemical demulsifiers are used to accelerate the natural settling process, ultimately reducing the water content of the crude oil to below 0.5 wt%.

[0004] Currently, due to the wide variety of emulsions and their complex mechanisms of action, the monitoring of crude oil water content in on-site production is generally achieved through laboratory testing. Online detection instruments have low accuracy, and there is no simulation calculation method for the sedimentation of water-containing emulsified crude oil in petrochemical simulation software. Industrial production requires a simulation calculation method to guide the adjustment of process parameters and the use of demulsifiers.

[0005] Existing simulation methods have the following shortcomings:

[0006] 1) The correlation of laboratory data is poor, the practicality of the model has not been further verified, and there are large errors in the calculation and prediction of actual industry.

[0007] 2) The influence of emulsion on the calculation of oil-water balance is ignored. Existing simulation methods for oil-water systems can only perform simple oil-water balance calculations, and the emulsification phenomenon that exists in actual production cannot be simulated.

[0008] 3) Emulsions are diverse and complex in structure, and the correction of their physical properties requires a large number of experiments. Summary of the Invention

[0009] The purpose of this invention is to provide a simulation method for the settling changes of water-containing emulsified crude oil on offshore platforms, used to calculate the water content of water-containing emulsified crude oil after settling treatment in real time. This method considers the composition of the oil-water phase, the density difference between the oil and water phases, the oil-water flow rate, the crude oil residence time, and the crude oil temperature when the water-containing emulsified crude oil flows inside the separator. It also couples the demulsifier concentration in the water-containing crude oil with the water content after settling, thereby improving the existing simulation methods for the settling changes of water-containing emulsified crude oil. This makes the quantitative analysis results of the water content of the water-containing emulsified crude oil settling inside the separator more closely reflect actual conditions, improving the accuracy and effectiveness of the process design for water-containing emulsified crude oil on offshore platforms.

[0010] The method for simulating the settling changes of water-containing emulsified crude oil on offshore platforms provided by this invention includes the following steps:

[0011] S1. Based on the relevant physical property parameters of crude oil extracted from offshore platforms, establish the composition of other substances besides crude oil;

[0012] S2. Based on the analysis data of crude oil extracted from the offshore platform, the composition of the crude oil is segmented and virtual components of the crude oil are generated.

[0013] S3. Based on the water content test data of the extracted crude oil, establish virtual components in the water-containing crude oil to characterize the emulsion;

[0014] S3. Based on the relevant equipment parameters of the oil processing separator on the offshore platform, construct a sedimentation change model of water-containing emulsified crude oil in the separator to calculate the water content of the crude oil after sedimentation and related influencing factors.

[0015] S4. Take values ​​based on the relevant production data of the oil treatment separator, and take values ​​in chronological order;

[0016] S5. Based on the sedimentation change model of the water-containing emulsified crude oil and the time sequence values ​​of the relevant parameters, couple the regression equation of demulsifier concentration on the water content of the water-containing emulsified crude oil after sedimentation.

[0017] S6. Using the simultaneous solution method, solve the sedimentation variation model of the water-containing emulsified crude oil in the separator to obtain the dynamic response results of the sedimentation of the water-containing emulsified crude oil and the water content of the sedimentation of the water-containing crude oil.

[0018] Preferably, in step S3, the relevant parameters of the sedimentation change model of the water-containing emulsified crude oil include:

[0019] The residence time of water-containing emulsified crude oil, the settling height of oil droplets, the settling time of oil droplets, and the particle size distribution coefficient of water droplets when the crude oil flows inside the separator.

[0020] Preferably, in step S3, the initial value of the separator liquid holdup in the water-containing emulsified crude oil settling variation model is obtained through parameters inlet flow rate, temperature, pressure, and composition, specifically according to the following formula:

[0021]

[0022] V 混 ·z i =V 液 ·x i +V 气 ·u i

[0023] V 混 =V 液 +V 气

[0024] In the formula: Q 液,in Q represents the volumetric flow rate of the liquid feed; 气,in Q represents the gas phase feed volumetric flow rate; 液,out Q represents the liquid phase discharge volumetric flow rate; 气,out Indicates the gas phase discharge volumetric flow rate; x i Indicates the molar concentration of the liquid phase; u i Indicates the molar concentration of the solid phase; z i V represents the total molar concentration; 混 V represents the total volume of the two phases; 液 V represents the volume of the liquid phase. 气 The gas phase volume is represented by N; the total mass transfer rate is represented by N.

[0025] Preferably, in step S3, the initial value of the total enthalpy within the separator in the water-containing emulsified crude oil settling variation model is obtained through parameters such as inlet flow rate, temperature, pressure, and composition, specifically according to the following formula:

[0026]

[0027] In the formula: H in - Indicates the enthalpy value at the inlet; H holdup Q represents the total enthalpy of the tank in the previous round; Q represents the heat input from the outside; Q S This indicates the amount of heat dissipated.

[0028] Preferably, in step S3, the phase equilibrium constant of the separator in the sedimentation variation model of the water-containing emulsified crude oil is obtained by simultaneously solving the parameters inlet flow rate, temperature, pressure, composition, initial values ​​of separator liquid holdup, and initial values ​​of total enthalpy within the separator, as shown in the following formula:

[0029]

[0030] In the formula: x i y represents the molar amount of the i-th component in the liquid phase;i k represents the gaseous molar amount of the i-th component; i z represents the gas-phase equilibrium constant of the i-th component; i α represents the compressibility factor of the i-th component; α represents the gas phase fraction of the i-th component.

[0031] Preferably, in step S3, the percentage of separable water droplets in the oil is obtained by simultaneously iterating the residence time of the water-containing emulsified crude oil in the liquid phase, the settling height of the oil droplets, the settling time of the oil droplets, and the water droplet size distribution coefficient.

[0032] The crude oil residence time is calculated using the separator inlet velocity and separator liquid holdup. The water droplet distribution coefficient of the water-containing crude oil is then calculated based on the flow velocity, using the following formula:

[0033] y = a + b*Co + c*Co 2

[0034]

[0035] In the formula: y represents the droplet distribution coefficient; Co represents the reciprocal of the flow velocity; a represents the adjustment coefficient; b represents the adjustment coefficient; c represents the adjustment coefficient; length represents the tank length; Vs represents the volumetric flow rate;

[0036] The normal distribution of water droplets can be obtained through the droplet distribution coefficient, and the critical droplet size can be calculated. Combined with the droplet size distribution, the percentage of droplets larger than the critical droplet size can be obtained, as shown in the following formula:

[0037]

[0038]

[0039]

[0040]

[0041] In the formula: d represents the droplet size; σ represents the standard deviation of lnd; μ represents the mean of lnd, which is calculated from the relationship between the droplet distribution coefficient and the reciprocal of the flow velocity;

[0042] Settlement time is calculated based on settlement height and settlement velocity, using the following formula:

[0043]

[0044] In the formula: t represents the settling time of the water droplet; h0 represents the settling height; wo represents the settling velocity;

[0045] Preferably, the settling velocity of the water-containing emulsified crude oil in the separator is calculated from the viscosity and density of the medium, as shown in the following formula:

[0046]

[0047]

[0048] In the formula: Wo represents the settling velocity of the oil droplet; e represents the natural constant; dm represents the critical droplet size of the water droplet; do represents the oil density; dw represents the water density; vis represents the viscosity of the oil-water mixture; viso represents the oil viscosity; visw represents the water viscosity; f represents the water content of the emulsified crude oil;

[0049] The critical droplet diameter is calculated using iterative calculations based on the droplet diameter. The percentage of separated droplets is then calculated. Based on the percentage of separated droplets and the temperature, flow rate, and composition of the gas and liquid phases inside the separator, iterative calculations are performed to obtain the parameters such as the temperature, pressure, flow rate, and composition of the three phases of water, oil, and gas after separation.

[0050] Preferably, the step of taking the time sequence value in step S5 is as follows:

[0051] By using production data such as temperature, pressure, and interface information from the oil separator, the production data is filtered to remove invalid and distorted data. The production data is then processed at a frequency consistent with the data collection time to ensure continuity and smoothness.

[0052] Preferably, the regression equation for the coupling demulsifier concentration on the water content of the water-containing emulsified crude oil after settling is shown below:

[0053] P=(1+dT+eT^2+f / T)*(100+n / C^0.4+m / t^2.4)*a

[0054] In the formula: P represents the water content of crude oil after settling; T represents the temperature; e represents the natural constant; f represents the water content of emulsified crude oil; C represents the demulsifier concentration; t represents the residence time; a represents the regression coefficient; n represents the regression coefficient; m represents the regression coefficient.

[0055] Compared with the prior art, the present invention has the following effective and beneficial effects:

[0056] This invention considers the residence time of water-containing emulsified crude oil during its flow within the separator in offshore platform oil processing, as well as the effects of oil droplet settling height, settling time, and water droplet size distribution coefficient. It employs production data such as temperature, pressure, and interface conditions from the oil processing separator, inputting them into the model in chronological order. The influence of demulsifier concentration on the water content of the water-containing emulsified crude oil after settling is coupled into the model, thus establishing a new simulation method for the settling changes of water-containing emulsified crude oil on offshore platforms. This provides a theoretical basis and approach for analyzing the accuracy, economy, and reliability of offshore platform crude oil processing technologies. Attached Figure Description

[0057] Figure 1 This is a flowchart of the method for simulating the sedimentation changes of water-containing emulsified crude oil according to the present invention.

[0058] Figure 2 This is a schematic diagram of the principle of the simulation method for sedimentation changes of water-containing emulsified crude oil of the present invention.

[0059] Figure 3 The simulation method of this invention is used to calculate the outlet moisture content in the embodiments. Detailed Implementation

[0060] Unless otherwise specified, the experimental methods used in the following examples are conventional methods.

[0061] Unless otherwise specified, all materials and reagents used in the following examples are commercially available.

[0062] This invention takes into account the influence of factors such as the residence time of crude oil inside water-containing crude oil, the settling height of oil droplets, the settling time of oil droplets, and the droplet size distribution coefficient, and proposes a method for simulating the settling changes of water-containing emulsified crude oil.

[0063] The simulation method for water-bearing crude oil subsidence changes on offshore platforms according to the present invention will be further described below with reference to the accompanying drawings and specific embodiments. (Reference) Figure 1-2 As shown, it includes the following steps:

[0064] In step S13, based on the relevant physical property parameters of crude oil extracted from the offshore platform, the composition of other substances besides crude oil is established;

[0065] In step S14, based on the analysis data of crude oil extracted from the offshore platform, the composition of the crude oil is segmented and virtual components of the crude oil are generated.

[0066] In step S15, based on the water content test data of the extracted crude oil, a virtual component for characterizing the emulsion in the water-containing crude oil is established.

[0067] Furthermore, the virtual components in the aqueous crude oil used to characterize the emulsion include:

[0068] Virtual components and their properties of emulsion are created by combining data such as crude oil emulsion content and water-oil volume fraction from the analysis data of water-containing crude oil with the physical properties of virtual crude oil components.

[0069] In step S16, a sedimentation variation model of water-containing emulsified crude oil inside the separator is constructed based on the relevant equipment parameters of the offshore platform oil treatment separator.

[0070] In step S17, values ​​are taken from the relevant production data of the oil treatment separator, such as temperature, pressure, and interface, and are taken in chronological order.

[0071] In step S18, based on the sedimentation change model of the water-containing emulsified crude oil in the separator and the time sequence values ​​of the relevant parameters, a regression equation of the demulsifier concentration on the water content of the water-containing emulsified crude oil after sedimentation is coupled.

[0072] In step S19, the model is solved using a simultaneous solution method to obtain the dynamic response results of the sedimentation of water-containing emulsified crude oil and the water content results of the water-containing crude oil after sedimentation.

[0073] To aid understanding, the method of the present invention will be described below with reference to specific embodiments:

[0074] The method provided by this invention is used to simulate and calculate the sedimentation changes of water-bearing crude oil on offshore platforms, and the calculated oil water content is verified in conjunction with laboratory reports.

[0075] (1) Establish the composition of substances other than crude oil

[0076] The components and properties of substances other than crude oil are shown in Table 1;

[0077] Table 1 Associated Gas and Light Hydrocarbon Components

[0078]

[0079]

[0080] (2) Perform oil product segmentation on crude oil composition and generate virtual crude oil components.

[0081] Table 2 shows the boiling point data of crude oil distillation, providing data for three oilfields: North, South, and West.

[0082] Table 2 Oil Distillation Report

[0083]

[0084] The cubic spline interpolation method was used to perform virtual component segmentation on the crude oil distillation true boiling point data. Five segments were segmented, and the composition and properties of the virtual components are shown in Table 3.

[0085] Table 3 Pseudo-components of crude oil

[0086]

[0087] The content of the virtual components was corrected based on the test data. The physical properties of the virtual components of crude oil are shown in Table 4.

[0088] Table 4. Crude oil analysis data and crude oil virtual component data

[0089]

[0090] (3) Establish virtual components in water-containing crude oil for characterizing emulsions.

[0091] Table 5 shows the water content data for crude oil, providing water content data from three sampling points on the offshore platform.

[0092] Table 5. Test Report on Crude Oil Moisture Content at Separator Inlet

[0093]

[0094] Based on the crude oil water content analysis data, the virtual components and physical property parameters of the emulsion were calculated by combining the volume ratio of free water to emulsion with the average physical property of the crude oil virtual components. The physical property parameters of the emulsion virtual components are shown in Table 6.

[0095] Table 6. Virtual component properties of the emulsion

[0096]

[0097] (4) Construct a sedimentation variation model for water-containing emulsified crude oil in the separator

[0098] The initial values ​​of temperature, flow rate, and composition of the separated water-containing emulsified crude oil were obtained by establishing mass balance, enthalpy balance, and phase balance equations and calculating them simultaneously.

[0099] The initial values ​​of gas-liquid phase temperature, flow rate, and composition inside the separator are obtained through iteration.

[0100] The residence time of crude oil is calculated by the inlet flow velocity of the separator and the liquid holdup of the separator, and the water droplet distribution coefficient of the water-containing crude oil is calculated based on the flow velocity.

[0101] The normal distribution of water droplets can be obtained from the water droplet distribution coefficient, and the critical droplet size can be calculated. Combined with the droplet size distribution, the percentage of droplets larger than the critical size range (removable droplets) can be obtained.

[0102] Water droplets whose settling time is less than their residence time will be separated by settling. The settling time is affected by the settling distance and the settling velocity.

[0103] The settling velocity of water-containing emulsified crude oil in the separator is affected by factors such as the viscosity and density of the medium.

[0104] The critical droplet diameter is calculated using iterative calculations based on the droplet diameter. Droplets larger than this diameter can be separated. The droplet diameter distribution and droplet growth rate are calculated based on factors such as flow rate, temperature, and viscosity, thereby obtaining the percentage of droplets that can be separated.

[0105] Based on the percentage of separated water droplets and the temperature, flow rate, and composition of the gas and liquid phases inside the separator, iterative calculations are performed to obtain the temperature, pressure, flow rate, and composition of the three phases of water, oil, and gas after separation, which is the sedimentation model of water-containing emulsified crude oil.

[0106] (5) By using the production data such as temperature, pressure and interface of the oil treatment separator, filter the production-related data, remove invalid and distorted data in the production data, and make the production data continuous and smooth according to the frequency consistent with the production data collection time.

[0107] (6) Regression equation of coupling demulsifier concentration on water content of water-containing emulsified crude oil after settling.

[0108] (7) The model is solved by using the simultaneous solution method to obtain the dynamic response results of the sedimentation of water-containing emulsified crude oil and the water content of the water-containing crude oil after sedimentation.

[0109] The moisture content obtained by inputting 40 hours of production data using this method is as follows: Figure 3 As shown in Table 7, the sedimentation water content of water-containing emulsified crude oil is as follows. The average water content measured by the actual production unit is 25.1250V / V, and the average calculated water content is 23.4851V / V, with a deviation of -6.5269%. This verifies that the water content obtained by the method of this invention meets the requirements for actual use and provides good support for the calculation of water content of water-containing emulsified crude oil.

[0110] Table 7 Water content in sedimentation of water-containing emulsified crude oil

[0111]

[0112] This invention overcomes many shortcomings of the prior art, and its features are:

[0113] 1) The influence of oil-water separation emulsion layer was considered.

[0114] When offshore platforms transport water-containing crude oil, an emulsion layer forms, which requires a certain amount of time to settle spontaneously, and complete settling may require the addition of a demulsifier. This invention considers the residence time of the water-containing emulsion crude oil flowing inside the separator, the settling height of the oil droplets, the settling time of the oil droplets, and the water droplet size distribution coefficient, and establishes a theoretical calculation model for the settling changes of water-containing emulsion crude oil. This model satisfies the production material balance criterion and can reasonably analyze the changes in the emulsion layer composed of crude oil and water mixture inside the separator.

[0115] 2) The effect of demulsifiers on crude oil water content was determined through laboratory data analysis.

[0116] When offshore platform oil production pipelines transport water-containing crude oil, the water and oil phases mix as the crude oil flows, forming an emulsion layer. This emulsion layer requires a certain amount of time to settle spontaneously, and complete settling may require the addition of a demulsifier. This invention considers the impact of demulsifiers on the settling of water-containing emulsion crude oil and employs a data regression approach, coupling a regression equation between demulsifier concentration and the water content of the water-containing emulsion crude oil after settling. This makes the simulation and calculation of emulsion settling more accurate.

Claims

1. A method for simulating the settling changes of water-containing emulsified crude oil on offshore platforms, comprising the following steps: S1. Based on the relevant physical property parameters of crude oil extracted from offshore platforms, establish the composition of other substances besides crude oil; S2. Based on the analysis data of crude oil extracted from the offshore platform, the composition of the crude oil is segmented and virtual components of the crude oil are generated. S3. Based on the water content test data of the extracted crude oil, establish virtual components in the water-containing crude oil to characterize the emulsion; S4. Based on the relevant equipment parameters of the oil processing separator on the offshore platform, construct a sedimentation change model of water-containing emulsified crude oil in the separator to calculate the water content of the crude oil after sedimentation and related influencing factors. S5. Take values ​​based on the relevant production data of the oil treatment separator, and take values ​​in chronological order; S6. Based on the sedimentation change model of the water-containing emulsified crude oil and the time sequence values ​​of the relevant parameters, couple the regression equation of demulsifier concentration on the water content of the water-containing emulsified crude oil after sedimentation. S7. Using the simultaneous solution method, solve the sedimentation variation model of the water-containing emulsified crude oil in the separator to obtain the dynamic response results of the sedimentation of the water-containing emulsified crude oil and the water content of the sedimentation of the water-containing crude oil.

2. The simulation method according to claim 1, characterized in that: In step S4, the relevant parameters of the sedimentation change model of the water-containing emulsified crude oil include: The residence time of water-containing emulsified crude oil, the settling height of oil droplets, the settling time of oil droplets, and the particle size distribution coefficient of water droplets when the crude oil flows inside the separator.

3. The simulation method according to claim 1 or 2, characterized in that: In step S4, the initial value of the separator liquid holdup in the water-containing emulsified crude oil settling variation model is obtained through parameters such as inlet flow rate, temperature, pressure, and composition, specifically according to the following formula: V 混 ·z i =V 液 ·x i +V 气 ·u i V 混 =V 液 +V 气 In the formula: Q 液,in Q represents the volumetric flow rate of the liquid feed; 气,in Q represents the gas phase feed volumetric flow rate; 液,out Q represents the liquid phase discharge volumetric flow rate; 气,out Indicates the gas phase discharge volumetric flow rate; x i Indicates the molar concentration of the liquid phase; u i Indicates the molar concentration of the solid phase; z i V represents the total molar concentration; 混 V represents the total volume of the two phases; 液 V represents the volume of the liquid phase. 气 The gas phase volume is represented by N; the total mass transfer rate is represented by N.

4. The simulation method according to claim 3, characterized in that: In step S4, the initial value of the total enthalpy within the separator in the water-containing emulsified crude oil settling variation model is obtained through parameters such as inlet flow rate, temperature, pressure, and composition, specifically according to the following formula: In the formula: H in - Indicates the enthalpy value at the inlet; H holdup Q represents the total enthalpy of the tank in the previous round; Q represents the heat input from the outside; Q S This indicates the amount of heat dissipated.

5. The simulation method according to claim 4, characterized in that: In step S4, the phase equilibrium constant of the separator in the sedimentation change model of the water-containing emulsified crude oil is obtained by simultaneously solving the parameters inlet flow rate, temperature, pressure, composition, initial values ​​of separator liquid holdup, and initial values ​​of total enthalpy within the separator, as shown in the following formula: In the formula: x i y represents the molar amount of the i-th component in the liquid phase; i k represents the gaseous molar amount of the i-th component; i z represents the gas-phase equilibrium constant of the i-th component; i α represents the compressibility factor of the i-th component; α represents the gas phase fraction of the i-th component.

6. The simulation method according to claim 5, characterized in that: In step S4, the percentage of separable water droplets in the oil is obtained by simultaneously iterating the residence time of the water-containing emulsified crude oil in the liquid phase, the settling height of the oil droplets, the settling time of the oil droplets, and the water droplet size distribution coefficient. The crude oil residence time is calculated using the separator inlet velocity and separator liquid holdup. The water droplet distribution coefficient of the water-containing crude oil is then calculated based on the flow velocity, using the following formula: y=a+b*Co+c*Co 2 In the formula: y represents the droplet distribution coefficient; Co represents the reciprocal of the flow velocity; a represents the adjustment coefficient; b represents the adjustment coefficient; c represents the adjustment coefficient; length represents the tank length; Vs represents the volumetric flow rate; The normal distribution of water droplets can be obtained through the droplet distribution coefficient, and the critical droplet size can be calculated. Combined with the droplet size distribution, the percentage of droplets larger than the critical droplet size can be obtained, as shown in the following formula: In the formula: d represents the droplet size; σ represents the standard deviation of lnd; μ represents the mean of lnd, which is calculated from the relationship between the droplet distribution coefficient and the reciprocal of the flow velocity; Settlement time is calculated based on settlement height and settlement velocity, using the following formula: In the formula: t represents the settling time of the water droplet; h0 represents the settling height; and wo represents the settling velocity.

7. The simulation method according to claim 6, characterized in that: The settling velocity of the water-containing emulsified crude oil in the separator is calculated from the viscosity and density of the medium, using the following formula: In the formula: Wo represents the settling velocity of the oil droplet; e represents the natural constant; dm represents the critical droplet size of the water droplet; do represents the oil density; dw represents the water density; vis represents the viscosity of the oil-water mixture; viso represents the oil viscosity; visw represents the water viscosity; f represents the water content of the emulsified crude oil; The critical droplet diameter is calculated using iterative calculations based on the droplet diameter. The percentage of separated droplets is then calculated. Based on the percentage of separated droplets and the temperature, flow rate, and composition of the gas and liquid phases inside the separator, iterative calculations are performed to obtain the parameters such as the temperature, pressure, flow rate, and composition of the three phases of water, oil, and gas after separation.

8. The simulation method according to claim 7, characterized in that: The steps for retrieving values ​​in time sequence in step S5 are as follows: By using production data such as temperature, pressure, and interface information from the oil separator, the production data is filtered to remove invalid and distorted data. The production data is then processed at a frequency consistent with the data collection time to ensure continuity and smoothness.

9. The simulation method according to claim 8, characterized in that: The regression equation for the coupling demulsifier concentration on the water content of water-containing emulsified crude oil after settling is shown below: P=(1+dT+eT^2+f / T)*(100+n / C^0.4+m / t^2.4)*a In the formula: P represents the water content of crude oil after settling; T represents the temperature; e represents the natural constant; f represents the water content of emulsified crude oil; C represents the demulsifier concentration; t represents the residence time; a represents the regression coefficient; n represents the regression coefficient; m represents the regression coefficient.

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