A method for continuous metering of oil, gas and water three-phase flow of oil well

Abstract

The application discloses a kind of oil well oil-gas-water three-phase flow continuous metering methods, it is related to numerical metrology field, comprising: in the inside of pumping unit connecting pipeline selected position deployment sensing module, based on each sensing module real-time sensing the oil-gas-water basic parameters of transmission produced material in pipeline, the produced material oil-gas-water basic parameters of real-time sensing are stored;The application is realized to the real-time accurate sensing and dynamic storage of oil-gas-water three-phase flow parameters by designing and deploying sensing module in the inside of pumping unit connecting pipeline, and based on multidimensional parameters such as flow rate, distance, constructs homologous parameter identification logic and content calculation model, by weighting calculation model and operating cycle self-adaptive adjustment mechanism, the space-time precision of oil, gas, water content measurement is significantly improved.

Description

Technical Field

[0001] This invention relates to the field of numerical metrology technology, specifically to a continuous metering method for three-phase flow of oil, gas and water in oil wells. Background Technology

[0002] Oil well oil, gas and water metering is a core component of oilfields. Its role is to monitor changes in production capacity and composition, provide data for reservoir analysis, production optimization and production accounting, and ensure the efficient development of oilfields.

[0003] Patent application number 202210292192.2 discloses a continuous metering method for three-phase flow of oil, gas, and water in an oil well, comprising the following steps: Step 1: Assemble a three-phase flow continuous measuring device. Metering tank one is placed on a weighbridge one, and metering tank two is placed on a weighbridge two. The top gas phase outlets of metering tank one and metering tank two are respectively connected to the inlet of an exhaust tee via flexible hoses. A gas flow meter is installed at the outlet of the exhaust tee. An inlet branch pipe one is connected to the upper side wall of metering tank one, which is connected to the metering inlet main pipe via a solenoid valve one. An inlet branch pipe two is connected to the upper side wall of metering tank two, which is connected to the metering inlet main pipe via a solenoid valve three. The lower part of the side wall is connected to a drain branch pipe, which is connected to the metering drain main pipe through solenoid valve two; the lower part of the side wall of metering tank two is connected to a drain branch pipe, which is connected to the metering drain main pipe through solenoid valve four; Step 2: Transport the three-phase flow continuous measurement device to the site and connect it to the wellhead process; Step 3: Initialize the three-phase flow continuous measurement device; Step 4: Solenoid valve one is opened, the oil well produced fluid enters metering tank one, the associated gas overflows, and is discharged after being measured by the gas flow meter; when metering tank one reaches the set full level, solenoid valve one is closed; then solenoid valve three is opened, and the oil well produced fluid enters metering tank two; Step 5: Solenoid valve two is opened, metering tank one is emptied, and solenoid valve two... Step 6: When metering tank 2 is filled with liquid, associated gas overflows, is measured by the gas flow meter, and then discharged. When metering tank 2 reaches the set full level, solenoid valve 3 closes. Then solenoid valve 1 opens, and the oil well produced fluid enters metering tank 1. Step 7: Solenoid valve 4 opens, metering tank 2 is emptied, and then solenoid valve 4 closes. Step 8: When metering tank 1 is filled with liquid, associated gas overflows, is measured by the gas flow meter, and then discharged. When metering tank 1 reaches the set full level, solenoid valve 1 closes. Then solenoid valve 3 opens, and the oil well produced fluid enters metering tank 2. Step 9: Return to step 5 and repeat until the measurement is completed. Step 10: Accumulate the gas flow rate during the measurement period to obtain the total gas flow rate. Flow rate: The weight and volume of the mixture in the two metering tanks are accumulated, and the crude oil production and water content are calculated based on the crude oil density. This application aims to address the problem that "since traditional oil wellheads do not have diversion manifold devices, installing a flow calibration device at the wellhead requires hot work to re-cut and weld joints, altering the wellhead flow. For oilfield pipelines, hot work carries high risks, requiring strict approval processes and rigorous explosion-proof and fire-prevention measures. In short, hot work at the well site poses significant construction risks and major safety hazards, impacting oil well production, and the original process flow cannot be restored after the pipeline is cut and welded."

[0004] However, in the three-phase metering scenario of oil well oil, gas and water, there is not only a need for real-time comprehensive oil, gas and water content metering, but also a need for oil, gas and water content metering at a specific moment. However, the metering results of existing technologies are often singular and often cannot accurately reflect the oil, gas and water content at a specific moment. To address this, a continuous metering method for three-phase flow of oil, gas and water in oil wells is proposed. Summary of the Invention

[0005] In view of the above-mentioned shortcomings of the existing technology, the present invention provides a continuous metering method for three-phase flow of oil, gas and water in oil wells, which can effectively solve the problems of the existing technology.

[0006] To achieve the above objectives, the present invention is implemented through the following technical solutions; This invention discloses a method for continuous metering of three-phase flow of oil, gas and water in oil wells, comprising: Sensor modules are deployed at selected locations inside the pumping unit's connecting pipeline. These modules sense and store the basic parameters of the produced oil, gas, and water in real time. The most recently stored parameters are retrieved from the stored parameters, and the combined oil, gas, and water content in the current produced oil is estimated. Based on the flow rate and volume of the produced oil in the pipeline, common parameters are identified within the stored parameters. The oil, gas, and water content in the pumping unit's output is analyzed based on these common parameters at corresponding times. The estimated combined oil, gas, and water content in the produced oil and the analysis results of the pumping unit's output at corresponding times are obtained in real time. The well's production safety is assessed based on the estimation and analysis results.

[0007] Furthermore, the selection of a location to deploy the sensor within the oil pump connection pipeline conforms to the following: The oil pump connecting pipeline is segmented based on the bend location, and a set of sensing modules is deployed at the node location of each adjacent two pipeline segments; The number of sensor modules deployed on a pipe section with a length of not less than 5m shall not be less than two, and the sensor modules deployed on the pipe section with a length of not less than 5m shall be deployed at the nodes of the adjacent pipe sections, in an equidistant manner. The sensing module is composed of sensors that can detect the content of oil, gas and water in the produced material and the flow rate of the produced material. The basic parameters of oil, gas and water in the produced material are the oil, gas and water content.

[0008] Furthermore, when the basic parameters of the produced oil, gas and water are stored, they are distinguished and stored based on the source sensor module of the basic parameters of the produced oil, gas and water. The basic parameters of the produced oil, gas and water stored in each distinguished storage interval are sorted and stored based on the acquisition time sequence. Each group of basic parameters of the produced oil, gas and water is marked with the corresponding flow rate. The sensing module operates synchronously with the oil pump, and the operating cycle of the sensing module follows the following: ; In the formula: For the next operating cycle of the sensing module; This serves as the baseline for the sensor module's operating cycle. For sensing modules based During runtime, the oil content sensed in the latest run is compared with the oil content sensed in the previous run; For sensing modules based During operation, the gas content sensed in the latest operation is compared with the gas content sensed in the previous operation; For sensing modules based During runtime, the water content sensed in the latest run is compared with the water content sensed in the previous run; Based on the above formula, the next sensor module operating cycle is calculated and applied within each sensor module operating cycle. During the calculation, the basic parameters of oil, gas and water are referenced from the sensing module closest to the oil pump.

[0009] Furthermore, when retrieving the latest stored basic parameters of produced oil, gas and water from the stored basic parameters of produced oil, gas and water, the target is the storage interval of each region. ; In the formula: The total oil content in the extracted material; This represents the total number of sensor modules; The oil content sensed by the i-th sensing module; The configuration weights for the i-th sensor; The calculation logic for the combined gas and water content is the same as the above formula, and the configuration weights applied when calculating the combined gas and water content are consistent with the configuration weights applied in the formula for calculating the combined oil content.

[0010] Furthermore, the configuration weight of the i-th sensor The value follows: ; In the formula: Let be the total length of the oil pump connecting pipe, and the distance from the i-th sensor to the oil pump output end defined by the oil pump connecting pipe; The total number of sensors and the number of sensors in the direction of the i-th sensor relative to the output end of the oil pump. The maximum values ​​of the inner wall roughness and the inner wall storage capacity of the pipe where the i-th sensor is located; The maximum roughness of the inner wall of the pipeline is taken as the maximum acceptable roughness of the oil pump connecting pipeline during the manufacturing stage, which meets the factory standards.

[0011] Furthermore, the identification logic for the basic parameters of the homologous produced oil, gas, and water is expressed as follows: Select the sensor module deployed at the location closest to the output end of the oil pump to distinguish any set of basic parameters of produced oil, gas and water in the storage area, and identify the flow rate corresponding to the marked parameter set. Obtain the distance from each sensor module on the oil pump connection pipeline to the selected sensor module that provides the basic parameters of the produced oil, gas and water. The basic parameters of oil, gas and water from the same source are: The selected basic parameters of produced oil, gas and water, and the basic parameters of produced oil, gas and water sensed by each sensor module in each operation, are compared with... The shortest time interval indicates the basic parameters of the produced oil, gas and water. In the formula: The sensing time for the selected basic parameters of produced oil, gas and water; The length of the pipeline from the source sensing module to the target sensing module for the basic parameters of the extracted oil, gas and water. The flow rate is marked for the basic parameters of the selected produced oil, gas and water. Among them, the oil pump is the starting point. Before selecting the source sensing module for the basic parameters of produced oil, gas, and water, the target sensing module then... middle" "Take -, or vice versa." middle" Take +.

[0012] Furthermore, the analysis of the oil, gas, and water content of the produced material output by the oil pump at the corresponding time stage is the earliest timestamp of the sensing time of each group of parameters in each source parameter. If there are fewer than three sets of homologous parameters, the analysis of oil, gas, and water content in the extracted material will not be performed. ; In the formula: This represents the oil content in the extract at the corresponding time. This represents the total number of parameters from the same origin. The oil content in the j-th parameter group; Let be the weight of the j-th group of parameters; The calculation logic for the gas and water content in the extracted material at the corresponding time is the same as the above formula, and the configuration weights applied when calculating the gas and water content are consistent with the weights applied in the oil content calculation formula.

[0013] Furthermore, the weights of the j-th group of parameters The value follows: In identifying common-source parameters, by selecting certain basic parameters of produced oil, gas, and water, the larger the ratio of the number of common-source parameter groups to the number of sensor modules, the greater the weight value assigned to the oil content among the selected basic parameters of produced oil, gas, and water. This is denoted as... ; The weights of each group of parameters originating from the same source are then expressed as follows: ; And obey: An increasing sequence, and All terms in the table are non-zero positive numbers. The sum is 1.

[0014] Furthermore, the estimation and analysis results are continuously stored in electronic log format after acquisition.

[0015] Furthermore, in the stage of assessing the safety of oil well production, the electronic logs storing the estimation and analysis results are traversed. If the combined oil and gas content in the estimation results shows a continuous downward trend or the oil and gas content in the analysis results shows a continuous downward trend, the oil well production is assessed as unsafe, indicating that the oil well may be depleted. Conversely, the oil well production is assessed as safe.

[0016] Compared with the known prior art, the technical solution provided by this invention has the following beneficial effects: This invention provides a continuous metering method for three-phase flow of oil, gas, and water in oil wells. During execution, this method utilizes sensor modules designed and deployed within the connecting pipeline of the oil pump to achieve real-time, accurate sensing and dynamic storage of parameters of the three-phase flow. Based on multi-dimensional parameters such as flow velocity and distance, it constructs a logic for identifying common-source parameters and a content calculation model. Through a weighted calculation model and an adaptive adjustment mechanism for the operating cycle, it significantly improves the spatiotemporal accuracy of oil, gas, and water content metering. Particularly in the design of pipeline segment deployment rules and weighting algorithms, it overcomes the limitations of single-location detection, enabling collaborative analysis of multi-node data. Furthermore, combined with continuous electronic log storage and trend analysis mechanisms, it can provide real-time early warning of oil well depletion risks, providing an intelligent and continuous monitoring method for safe oil well production. Compared to traditional metering methods, it offers superior performance in terms of data acquisition density, analysis timeliness, and safety early warning capabilities. Attached Figure Description

[0017] To more clearly illustrate the technical solutions in the embodiments of the present invention or the prior art, the accompanying drawings used in the description of the embodiments or the prior art will be briefly introduced below. Obviously, the drawings described below are merely some embodiments of the present invention. For those skilled in the art, other drawings can be obtained based on these drawings without any creative effort.

[0018] Figure 1 This is a schematic diagram of a continuous metering method for three-phase flow of oil, gas and water in an oil well. Detailed Implementation

[0019] To make the objectives, technical solutions, and advantages of the embodiments of the present invention clearer, the technical solutions of the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some, not all, of the embodiments of the present invention. All other embodiments obtained by those skilled in the art based on the embodiments of the present invention without creative effort are within the scope of protection of the present invention.

[0020] The present invention will be further described below with reference to embodiments.

[0021] Example: This embodiment provides a method for continuous metering of three-phase flow of oil, gas, and water in an oil well, such as... Figure 1 As shown, it includes: Sensor modules are deployed at selected locations inside the oil pump connecting pipeline. Based on the real-time sensing of the basic parameters of oil, gas and water of the extracted material transmitted in the pipeline by each sensor module, the real-time sensing of the basic parameters of oil, gas and water of the extracted material is stored. When selecting a location to deploy the sensor within the oil pump connection pipeline, the following should be observed: The oil pump connecting pipeline is segmented based on the bend location, and a set of sensing modules is deployed at the node location of each adjacent two pipeline segments; The number of sensor modules deployed on a pipe section with a length of not less than 5m shall not be less than two, and the sensor modules deployed on the pipe section with a length of not less than 5m shall be deployed at the nodes of the adjacent pipe sections, in an equidistant manner. The sensing module is composed of sensors that can sense the content of oil, gas and water in the extracted material and the flow rate of the extracted material. The basic parameters of oil, gas and water in the extracted material are the oil, gas and water content. When performing storage operations, the basic parameters of produced oil, gas and water are stored separately based on the sensor module that is the source of the basic parameters of produced oil, gas and water. The basic parameters of produced oil, gas and water stored in each storage interval are sorted and stored according to the acquisition time sequence. Each group of basic parameters of produced oil, gas and water is marked with the corresponding flow rate. The sensor module operates synchronously with the oil pump, and its operating cycle follows the following rules: ; In the formula: For the next operating cycle of the sensing module; This serves as the baseline for the sensor module's operating cycle. For sensing modules based During runtime, the oil content sensed in the latest run is compared with the oil content sensed in the previous run; For sensing modules based During operation, the gas content sensed in the latest operation is compared with the gas content sensed in the previous operation; For sensing modules based During runtime, the water content sensed in the latest run is compared with the water content sensed in the previous run; Based on the above formula, the next sensor module operating cycle is calculated and applied within each sensor module operating cycle. During the calculation, the basic parameters of oil, gas and water sensed by the sensor module closest to the oil pump are referenced. The above formula is used to control the operating cycle of the sensing module, ensuring that the sensing module's perception of the three-phase content of oil, gas and water is more valuable, thereby improving the accuracy of the output measurement results during the execution of this method. When retrieving the latest stored basic parameters of produced oil, gas and water from the stored basic parameters of produced oil, gas and water, the target is the storage interval of each region. ; In the formula: The total oil content in the extracted material; This represents the total number of sensor modules; The oil content sensed by the i-th sensing module; The configuration weights for the i-th sensor; The calculation logic for the combined gas and water content is the same as the above formula, and the configuration weights applied when calculating the combined gas and water content are consistent with the configuration weights applied in the formula for calculating the combined oil content. Configuration weight of the i-th sensor The value follows: ; In the formula: Let be the total length of the oil pump connecting pipe, and the distance from the i-th sensor to the oil pump output end defined by the oil pump connecting pipe; The total number of sensors and the number of sensors in the direction of the i-th sensor relative to the output end of the oil pump. The maximum values ​​of the inner wall roughness and the inner wall storage capacity of the pipe where the i-th sensor is located; Among them, the maximum roughness of the inner wall of the pipeline is taken as the maximum acceptable roughness of the oil pump connecting pipeline during the manufacturing stage, which meets the factory standard. The combined content of oil, gas and water in the extracted material is calculated using the above logical formula. Retrieve the latest stored basic parameters of produced oil, gas and water from the stored basic parameters of produced oil, gas and water, and estimate the comprehensive content of oil, gas and water in the current produced oil based on the retrieved basic parameters of produced oil, gas and water. Based on the flow rate and volume of the extracted material transported in the pipeline, identify the common parameters among the basic parameters of the stored extracted oil, gas and water. Based on the same source parameters, analyze the oil, gas and water content of the pump output at the corresponding time. The identification logic for the basic parameters of oil, gas and water from the same source is expressed as follows: Select the sensor module deployed at the location closest to the output end of the oil pump to distinguish any set of basic parameters of produced oil, gas and water in the storage area, and identify the flow rate corresponding to the marked parameter set. Obtain the distance from each sensor module on the oil pump connection pipeline to the selected sensor module that provides the basic parameters of the produced oil, gas and water. The basic parameters of oil, gas and water from the same source are: The selected basic parameters of produced oil, gas and water, and the basic parameters of produced oil, gas and water sensed by each sensor module in each operation, are compared with... The shortest time interval indicates the basic parameters of the produced oil, gas and water. In the formula: The sensing time for the selected basic parameters of produced oil, gas and water; The length of the pipeline from the source sensing module to the target sensing module for the basic parameters of the extracted oil, gas and water. The flow rate is marked for the basic parameters of the selected produced oil, gas and water. Among them, the oil pump is the starting point. Before selecting the source sensing module for the basic parameters of produced oil, gas, and water, the target sensing module then... middle" "Take -, or vice versa." middle" Take +; The analysis focuses on the stages of oil, gas, and water content in the produced material output by the oil pump at corresponding times. The corresponding time is the earliest timestamp of the sensing time for each group of parameters from the same source. If there are fewer than three sets of common parameters, the analysis of oil, gas, and water content in the extracted material will not be performed; ; In the formula: This represents the oil content in the extract at the corresponding time. This represents the total number of parameters from the same origin. The oil content in the j-th parameter group; Let be the weight of the j-th group of parameters; The calculation logic for the gas and water content in the extracted material at the corresponding time is the same as the above formula, and the configuration weights applied when calculating the gas and water content are consistent with the weights applied in the oil content calculation formula. The weights of the j-th group of parameters The value follows: In identifying common-source parameters, by selecting certain basic parameters of produced oil, gas, and water, the larger the ratio of the number of common-source parameter groups to the number of sensor modules, the greater the weight value assigned to the oil content among the selected basic parameters of produced oil, gas, and water. This is denoted as... ; The weights of each group of parameters originating from the same source are then expressed as follows: ; And obey: An increasing sequence, and All terms in the table are non-zero positive numbers. The sum is 1; Real-time estimation results of the combined oil, gas and water content in the produced material and analysis results of the oil, gas and water content in the produced material output by the pump at the corresponding time are obtained, and the production safety of the oil well is assessed based on the estimation results and analysis results. The above logic and formulas provide a more refined measurement logic for the oil, gas, and water content at a specified time. The estimation and analysis results are continuously stored in electronic log format after acquisition; During the assessment of oil well production safety, the electronic logs storing the estimated and analyzed results are traversed. If the combined oil and gas content in the estimated results or the oil and gas content in the analyzed results show a continuous downward trend, the oil well is assessed as unsafe to produce, indicating that the oil well may be depleted. Conversely, if the oil well production safety is assessed, the oil well is assessed as safe to produce.

[0022] In this embodiment, the oil, gas and water content of the extracted material in the oil pump connecting pipeline is comprehensively estimated and the oil, gas and water content at a specified time is specifically analyzed through the methods described in the above embodiments. This effectively monitors key information during the oil well production process and simultaneously assesses the depletion of the oil well through this information, thus effectively ensuring the stability of the oil well production process.

[0023] The following is an example application of the method described in the above embodiments: The A-08 well in the xx oilfield is a pumping unit well with a depth of 3200 meters and a daily liquid production of about 100 cubic meters. The gas content fluctuates greatly, so it is necessary to continuously measure the three-phase flow of oil, gas and water and assess the production safety.

[0024] Sensor module deployment: The oil pump connecting pipeline (total length 40 meters, including 3 bends) is divided into 4 sections according to the bend positions. A set of sensor modules is deployed at adjacent nodes in each section. For pipeline sections with a length of ≥5 meters (such as the first section which is 12 meters long), 2 sets of sensor modules are deployed, and they are distributed equidistantly from the adjacent node modules.

[0025] Each sensing module integrates an oil, gas and water content sensor and a flow rate sensor, which collects data in real time and stores it according to its source, marking the collection time sequence and flow rate.

[0026] Key calculation steps: Comprehensive content estimation: Retrieve the latest data from each module and apply the formula. The combined content of oil, gas, and water is calculated, with weights determined based on parameters such as the distance of the sensor from the oil pump output end and the roughness of the pipeline inner wall. For example, the module closest to the pump has a weight of 0.3, and the weights of modules farther away decrease accordingly.

[0027] Same-source parameter identification: Select a set of parameters from the module closest to the pump outlet (e.g., flow velocity 1.5 m / s, sensing time). ), calculate the distance difference between this module and other modules, according to Determine the timestamps of the source parameters and filter the data groups with the shortest time intervals.

[0028] Content analysis: The oil, gas and water content at the corresponding time is calculated for the same parameters (≥3 groups) according to the weight. The weight is adjusted according to the ratio of the number of modules to the number of same parameter groups, and the baseline module has a higher weight.

[0029] Safety assessment: Continuously store electronic logs of estimated and analytical results. If the oil and gas content shows a continuous downward trend (e.g., a decrease of more than 5% for 3 consecutive days), the well is deemed unsafe to produce, indicating potential depletion; otherwise, it is safe.

[0030] In summary, the method described in the above embodiments, by designing and deploying sensing modules within the oil pump connecting pipeline, achieves real-time and accurate perception and dynamic storage of three-phase flow parameters of oil, gas, and water. Based on multi-dimensional parameters such as flow velocity and distance, it constructs a logic for identifying common-source parameters and a content calculation model. Through a weighted calculation model and an adaptive adjustment mechanism for the operating cycle, it significantly improves the spatiotemporal accuracy of oil, gas, and water content measurement. Especially in the design of pipeline segment deployment rules and weighting algorithms, it overcomes the limitations of single-location detection, enabling collaborative analysis of multi-node data. Furthermore, combined with continuous electronic log storage and trend analysis mechanisms, it can provide real-time early warning of oil well depletion risks, providing intelligent and continuous monitoring methods for safe oil well production. Compared to traditional measurement methods, it is more effective in terms of data acquisition density, analysis timeliness, and safety early warning capabilities.

[0031] The above embodiments are only used to illustrate the technical solutions of the present invention, and are not intended to limit it. Although the present invention has been described in detail with reference to the foregoing embodiments, those skilled in the art should understand that modifications can still be made to the technical solutions described in the foregoing embodiments, or equivalent substitutions can be made to some of the technical features. Such modifications or substitutions will not cause the essence of the corresponding technical solutions to deviate from the spirit and scope of the technical solutions of the embodiments of the present invention.

Claims

1. A method for continuous metering of three-phase flow of oil, gas, and water in an oil well, characterized in that, include: Sensor modules are deployed at selected locations inside the oil pump connecting pipeline. Based on the real-time sensing of the basic parameters of oil, gas and water of the extracted material transmitted in the pipeline by each sensor module, the real-time sensing of the basic parameters of oil, gas and water of the extracted material is stored. Retrieve the latest stored basic parameters of produced oil, gas and water from the stored basic parameters of produced oil, gas and water, and estimate the comprehensive content of oil, gas and water in the current produced oil based on the retrieved basic parameters of produced oil, gas and water. When retrieving the latest stored basic parameters of produced oil, gas and water from the stored basic parameters of produced oil, gas and water, the target is the storage interval of each region. ； In the formula: The total oil content in the extracted material; This represents the total number of sensor modules; The oil content sensed by the i-th sensing module; The configuration weights for the i-th sensor; The calculation logic for the combined gas and water content is the same as the above formula, and the configuration weights applied when calculating the combined gas and water content are consistent with the configuration weights applied in the formula for calculating the combined oil content. Based on the flow rate and volume of the extracted material transported in the pipeline, identify the common parameters among the basic parameters of the stored extracted oil, gas and water. The identification logic of the homology parameter is represented as follows: Select the sensor module deployed at the location closest to the output end of the oil pump to distinguish any set of basic parameters of produced oil, gas and water in the storage area, and identify the flow rate corresponding to the marked parameter set. Obtain the distance from each sensor module on the oil pump connection pipeline to the selected sensor module that provides the basic parameters of the produced oil, gas and water. The basic parameters of oil, gas and water from the same source are: The selected basic parameters of produced oil, gas and water, and the basic parameters of produced oil, gas and water sensed by each sensor module in each operation, are compared with... The shortest time interval indicates the basic parameters of the produced oil, gas and water. In the formula: The sensing time for the selected basic parameters of produced oil, gas and water; The length of the pipeline from the source sensing module to the target sensing module for the basic parameters of the extracted oil, gas and water. The flow rate is marked for the basic parameters of the selected produced oil, gas and water. Among them, the oil pump is the starting point. Before selecting the source sensing module for the basic parameters of produced oil, gas, and water, the target sensing module then... middle" "Take -, or vice versa." middle" Take +; Based on the same source parameters, analyze the oil, gas and water content of the pump output at the corresponding time. The analysis of the oil, gas and water content of the pump output at the corresponding time stage is the earliest timestamp of the sensing time of each group of parameters in the same source parameters. Real-time estimation results of the combined oil, gas and water content in the produced material and analysis results of the oil, gas and water content in the produced material output by the pump at the corresponding time are obtained, and the production safety of the oil well is assessed based on the estimation results and analysis results. The sensing module is composed of sensors that can detect the content of oil, gas and water in the produced material and the flow rate of the produced material. The basic parameters of oil, gas and water in the produced material are the oil, gas and water content.

2. The method for continuous metering of three-phase flow of oil, gas and water in an oil well according to claim 1, characterized in that, When selecting a location to deploy the sensor within the oil pump connection pipeline, the following shall apply: The oil pump connecting pipeline is segmented based on the bend location, and a set of sensing modules is deployed at the node location of each adjacent two pipeline segments; The number of sensor modules deployed on a pipe section with a length of not less than 5m shall not be less than two, and the sensor modules deployed on the pipe section with a length of not less than 5m shall be deployed at the nodes of adjacent pipe sections in an equidistant manner.

3. The method for continuous metering of three-phase flow of oil, gas and water in an oil well according to claim 1, characterized in that, When the basic parameters of the produced oil, gas and water are stored, they are distinguished and stored based on the source sensor module of the basic parameters of the produced oil, gas and water. The basic parameters of the produced oil, gas and water stored in each distinguished storage area are sorted and stored based on the acquisition time sequence. Each group of basic parameters of the produced oil, gas and water is marked with the corresponding flow rate. The sensing module operates synchronously with the oil pump, and the operating cycle of the sensing module follows the following: ； In the formula: For the next operating cycle of the sensing module; This serves as the baseline for the sensor module's operating cycle. For sensing modules based During runtime, the oil content sensed in the latest run is compared with the oil content sensed in the previous run; For sensing modules based During operation, the gas content sensed in the latest operation is compared with the gas content sensed in the previous operation; For sensing modules based During runtime, the water content sensed in the latest run is compared with the water content sensed in the previous run; Based on the above formula, the next sensor module operating cycle is calculated and applied within each sensor module operating cycle. During the calculation, the basic parameters of oil, gas and water are referenced from the sensing module closest to the oil pump.

4. The method for continuous metering of three-phase flow of oil, gas and water in an oil well according to claim 1, characterized in that, The configuration weight of the i-th sensor The value follows: ； In the formula: Let be the total length of the oil pump connecting pipe, and the distance from the i-th sensor to the oil pump output end defined by the oil pump connecting pipe; The total number of sensors and the number of sensors in the direction of the i-th sensor relative to the output end of the oil pump. The maximum values ​​of the inner wall roughness and the inner wall storage capacity of the pipe where the i-th sensor is located; The maximum roughness of the inner wall of the pipeline is taken as the maximum acceptable roughness of the oil pump connecting pipeline during the manufacturing stage, which meets the factory standards.

5. The method for continuous metering of three-phase flow of oil, gas and water in an oil well according to claim 1, characterized in that, If there are fewer than three sets of homologous parameters, the analysis of oil, gas, and water content in the extracted material will not be performed. ； In the formula: This represents the oil content in the extract at the corresponding time. This represents the total number of parameters from the same origin. The oil content in the j-th parameter group; Let be the weight of the j-th group of parameters; The calculation logic for the gas and water content in the extracted material at the corresponding time is the same as the above formula, and the configuration weights applied when calculating the gas and water content are consistent with the weights applied in the oil content calculation formula.

6. The method for continuous metering of three-phase flow of oil, gas and water in an oil well according to claim 5, characterized in that, The weights of the j-th group of parameters The value follows: In identifying common-source parameters, by selecting certain basic parameters of produced oil, gas, and water, the larger the ratio of the number of common-source parameter groups to the number of sensor modules, the greater the weight value assigned to the oil content among the selected basic parameters of produced oil, gas, and water. This is denoted as... ; The weights of each group of parameters originating from the same source are then expressed as follows: ； And obey: An increasing sequence, and All terms in the table are non-zero positive numbers. The sum is 1.

7. The method for continuous metering of three-phase flow of oil, gas and water in an oil well according to claim 1, characterized in that, The estimation and analysis results are continuously stored in electronic log format after being acquired.

8. The method for continuous metering of three-phase flow of oil, gas and water in an oil well according to claim 1, characterized in that, During the assessment of oil well production safety, the electronic logs storing the estimation and analysis results are traversed. If the combined oil and gas content in the estimation results shows a continuous downward trend or the oil and gas content in the analysis results shows a continuous downward trend, the oil well production is assessed as unsafe, indicating that the oil well may be depleted. Conversely, if the oil well production is assessed as safe, the oil well production is assessed as safe.

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