Oil gas recovery amount comprehensive verification method based on data model

Abstract

The invention discloses an oil and gas recovery amount comprehensive verification method based on a data model, and relates to the technical field of oil and gas recovery, and the method comprises the steps: collecting basic parameters, environmental parameters, equipment operation parameters and actual recovery amount metering values in real time, and forming original data; based on the basic parameters, determining the oil gas treatment efficiency, the cumulative oil distribution time of the day and the recovery amount per unit time, and calculating the theoretical recovery amount; pressure, humidity and equipment operation correction coefficients are generated in combination with the environment parameters and the equipment operation parameters, and the theoretical recovery amount is corrected to obtain the corrected recovery amount; and comparing the corrected recovery amount with an actual recovery amount metering value to calculate a deviation rate, if the deviation rate is within a preset threshold value, outputting the corrected recovery amount as a final recovery amount, and if the deviation rate exceeds the preset threshold value, positioning a deviation reason in combination with equipment operation parameters and generating an early warning signal. The recovery amount verification reliability can be improved, and deviation positioning is assisted.

Description

Technical Field

[0001] This invention relates to the field of oil and gas recovery technology, and in particular to a comprehensive verification method for oil and gas recovery volume based on a data model. Background Technology

[0002] In the operation and management of oil and gas recovery systems, accurate verification of oil and gas recovery volume is the core link to ensure that the recovery efficiency meets the standards and environmental emission requirements. Its core requirement is to determine whether the recovery system is in normal operation by comparing the theoretical recovery volume with the actual recovery volume measurement value, and to locate the root cause of the problem when deviation occurs.

[0003] Existing methods for verifying oil and gas recovery typically calculate theoretical recovery based only on basic parameters such as oil and gas flow rate and inlet gas concentration, without systematically incorporating the impact of environmental parameters on oil and gas volume measurement. This leads to inherent biases in the calculation of theoretical recovery. Furthermore, these methods fail to consider the real-time operating status of the equipment as reflected by its operating parameters, making it impossible to determine whether deviations in theoretical recovery stem from equipment malfunctions. Summary of the Invention

[0004] To address the technical problems existing in the prior art, this invention provides a comprehensive verification method for oil and gas recovery based on a data model.

[0005] The technical solution adopted in this invention is: a comprehensive verification method for oil and gas recovery based on a data model, comprising the following steps:

[0006] Step 1: Collect basic parameters, environmental parameters, equipment operating parameters, and actual recovery volume measurements in real time to form raw data; among them, basic parameters include oil and gas flow rate, inlet gas concentration, exhaust gas concentration, and inlet gas temperature; environmental parameters include atmospheric pressure and ambient humidity; equipment operating parameters include recovery pump speed, oil and gas valve opening, sensor operating status information, and oil tank breather valve operating status;

[0007] Step 2: Based on the aforementioned basic parameters, determine the oil and gas processing efficiency, the cumulative oil delivery time of the day, and the recovery amount per unit time. Combine the oil and gas processing efficiency, the cumulative oil delivery time of the day, and the recovery amount per unit time to calculate the theoretical recovery amount.

[0008] Step 3: Based on environmental parameters and equipment operating parameters, generate pressure correction coefficient, humidity correction coefficient and equipment operating correction coefficient respectively. Use the pressure correction coefficient, humidity correction coefficient and equipment operating correction coefficient to correct the theoretical recovery amount and obtain the corrected recovery amount.

[0009] Step 4: Compare the calibrated recovery amount with the actual recovery amount and calculate the deviation rate; if the deviation rate is within the preset threshold range, output the calibrated recovery amount as the final recovery amount; if the deviation rate exceeds the preset threshold range, locate the cause of the deviation by combining the equipment operating parameters and generate an early warning signal.

[0010] Preferably, determining the oil and gas processing efficiency based on the aforementioned basic parameters includes the following:

[0011] Intake and exhaust concentrations are extracted from basic parameters as raw concentration data. The oil dispensing stage is identified based on the fluctuation characteristics of the raw concentration data. The oil dispensing stage includes the unloading start-up stage, the stable oil dispensing stage, and the shutdown stage. The raw concentration data of the unloading start-up stage and the shutdown stage are processed using the sliding window averaging method to obtain smoothed concentration data. The first oil and gas treatment efficiency of the unloading start-up stage and the shutdown stage is calculated based on the smoothed concentration data. The second oil and gas treatment efficiency of the stable oil dispensing stage is calculated based on the raw concentration data.

[0012] Preferably, based on the aforementioned basic parameters, determining the cumulative oiling time for the day includes the following:

[0013] Based on the characteristics of changes in oil and gas flow, the real-time oil delivery mode that exists on the day is determined. The real-time oil delivery mode includes single-pump oil delivery mode and multi-pump concurrent mode.

[0014] If only the single-pump oil dispensing mode exists on a given day, the cumulative oil dispensing volume and real-time oil and gas processing volume of the single-pump oil dispensing mode are extracted. The first dynamic correlation model between the cumulative oil dispensing volume and real-time oil and gas processing volume of the single-pump oil dispensing mode is established using the second gas-liquid ratio coefficient. The cumulative oil dispensing time of the single-pump oil dispensing mode is calculated through the first dynamic correlation model.

[0015] If only the multi-pump concurrent mode exists on a given day, the cumulative oil delivery volume and real-time oil and gas processing volume of the day under the multi-pump concurrent mode are extracted. A second dynamic correlation model between the cumulative oil delivery volume and real-time oil and gas processing volume of the day under the multi-pump concurrent mode is established using the first gas-liquid ratio coefficient. The cumulative oil delivery time of the day under the multi-pump concurrent mode is calculated through this second dynamic correlation model. The first gas-liquid ratio coefficient is higher than the second gas-liquid ratio coefficient.

[0016] If there is a switch between single-pump oil dispensing mode and multi-pump concurrent mode on the same day, the cumulative oil dispensing time of the single-pump oil dispensing mode and multi-pump concurrent mode on the same day will be added together.

[0017] Preferably, determining the amount recovered per unit time based on the basic parameters includes the following:

[0018] Oil and gas flow rate, intake gas concentration, and intake gas temperature are extracted from basic parameters. Based on the intake gas temperature fluctuation characteristics during the oil extraction stage, a staged temperature-density correction coefficient table is established. When the intake gas temperature increases, the temperature-density correction coefficient for the corresponding stage decreases proportionally. The oil and gas flow rate and intake gas concentration are multiplied to obtain the initial recovery amount per unit time.

[0019] According to the current oiling stage, consult the stage temperature-density correction coefficient table to obtain the temperature-density correction coefficient for the corresponding intake temperature. Use this temperature-density correction coefficient to compensate for the initial unit time recovery amount to obtain the stage unit time recovery amount.

[0020] If the current real-time oil dispensing mode is single-pump oil dispensing mode, then the recovery amount per unit time in the stage is the same as the recovery amount per unit time in single-pump oil dispensing mode.

[0021] If the current real-time oil delivery mode is a multi-pump concurrent mode, the flow distribution correction is performed on the unit time recovery amount of each stage based on the oil and gas flow ratio of each pump to obtain the unit time recovery amount of each pump in the multi-pump concurrent mode.

[0022] If there is a switch between single-pump oil dispensing mode and multi-pump concurrent mode on the same day, the unit time recovery amount of each corresponding oil dispensing stage under the two modes shall be calculated separately, and then the cumulative oil dispensing time of each mode on the same day shall be weighted and integrated to obtain the unit time recovery amount of the day.

[0023] Preferably, the theoretical recovery amount calculated by combining oil and gas processing efficiency, daily cumulative oil delivery time, and unit time recovery amount includes the following:

[0024] Extract the oil and gas processing efficiency corresponding to each oil dispensing stage, extract the cumulative oil dispensing time of the day under each real-time oil dispensing mode, extract the unit time recovery amount under each combination of oil dispensing stage and real-time oil dispensing mode, calculate the stage theoretical recovery amount for each combination of oil dispensing stage and real-time oil dispensing mode, and sum up the stage theoretical recovery amounts of all combinations to obtain the theoretical recovery amount for the day.

[0025] Preferably, step 3 includes the following sub-steps:

[0026] Step 3.1: Based on atmospheric pressure in the environmental parameters, and combined with the correlation characteristics of oil and gas density with atmospheric pressure, compensation is performed to generate a pressure correction coefficient to eliminate the interference of atmospheric pressure fluctuations on the calculation of theoretical recovery.

[0027] Step 3.2: Based on the environmental humidity in the environmental parameters, and combined with the interference characteristics of water vapor on the detection of inlet air concentration, a humidity correction coefficient is generated to eliminate the interference of environmental humidity fluctuations on the calculation of theoretical recovery.

[0028] Step 3.3: Based on the recovery pump speed and oil and gas valve opening in the equipment operating parameters, compensation is performed in combination with the recovery pump load characteristics and valve flow characteristics to generate equipment operation correction coefficients, so as to eliminate the interference of equipment operating state deviation on the calculation of theoretical recovery amount;

[0029] Step 3.4: Use pressure correction factor, humidity correction factor, and equipment operation correction factor to comprehensively correct the theoretical recovery amount obtained in Step 2, and obtain the corrected recovery amount.

[0030] Preferably, step 4 includes the following steps:

[0031] Step 4.1: Compare the corrected recovery amount obtained in Step 3 with the actual recovery amount measured in the original data formed in Step 1. Calculate the deviation rate by the ratio of the difference between the two to the actual recovery amount measured.

[0032] Step 4.2: Determine whether the deviation rate is within the preset threshold range. If the deviation rate is within the preset threshold range, output the corrected recovery amount as the final recovery amount.

[0033] Step 4.3: If the deviation rate exceeds the preset threshold range, retrieve the equipment operating parameters from the original data formed in Step 1, and analyze the parameter deviation between the recovery pump speed and the standard speed, the parameter deviation between the oil and gas valve opening and the standard opening, and the fluctuation trend of the operating status of the oil tank breather valve. Analyze the correlation between parameter deviation and fluctuation trend to pinpoint the cause of the deviation.

[0034] Step 4.4: Based on the cause of the deviation, generate an early warning signal that includes the faulty component identifier, the current oil dispensing stage, and emergency handling suggestions.

[0035] Preferably, the equipment operating parameters in the original data generated in step 1 are retrieved, and the parameter deviations of the recovery pump speed and standard speed, the parameter deviations of the oil and gas valve opening and standard opening, and the fluctuation trends of the operating status of the oil tank breather valve are analyzed respectively. The causes of the deviations are located by analyzing the correlation between parameter deviations and fluctuation trends, including the following:

[0036] Retrieve the recovery pump speed data from the equipment operating parameters, and combine it with the standard recovery pump speed corresponding to the current real-time oil dispensing mode to calculate the parameter deviation between the recovery pump speed and the standard speed. If the parameter deviation continues to exceed the preset deviation range and is correlated with the fluctuation trend of oil and gas flow in the basic parameters, the cause of the deviation is determined to be a recovery pump failure.

[0037] Retrieve the oil and gas valve opening data from the equipment operating parameters, and combine it with the standard opening of the oil and gas valve corresponding to the current oil dispensing stage to calculate the parameter deviation between the oil and gas valve opening and the standard opening. If the parameter deviation continues to exceed the preset deviation range and is correlated with the fluctuation trend of atmospheric pressure in the environmental parameters, the deviation is determined to be caused by oil and gas valve failure or valve sensor failure.

[0038] Retrieve the operating status data of the oil tank breather valve from the equipment operating parameters, and analyze the fluctuation trend of the oil tank breather valve's operating status in conjunction with the changing trend of atmospheric pressure in the environmental parameters. If the operating status of the oil tank breather valve shows unexpected switching fluctuations, and these fluctuations are correlated with the fluctuation trend of the intake air concentration in the basic parameters, then the cause of the deviation is determined to be a malfunction of the oil tank breather valve or a malfunction of the pressure sensor. Based on the above analysis results, determine the cause of the deviation.

[0039] The beneficial effects of this invention are: real-time collection of three types of key data—basic parameters, environmental parameters, and equipment operating parameters—to form raw data. The theoretical recovery amount is calculated based on the basic parameters, and correction coefficients are generated by combining environmental parameters and equipment operating parameters to correct the theoretical recovery amount. This can, to a certain extent, compensate for the theoretical value deviation caused by the failure of existing methods to comprehensively consider environmental interference and equipment operating status, so that the corrected recovery amount is more in line with the actual operating conditions of the oil and gas recovery system.

[0040] By combining the reasons for the positioning deviation of the equipment operating parameters, we can provide direct parameter basis for distinguishing whether the deviation is caused by fluctuations in environmental parameters, abnormal equipment operating status or other factors, and avoid the situation where existing methods cannot effectively determine the root cause of the deviation due to the lack of equipment parameter support. Attached Figure Description

[0041] Figure 1 This is a flowchart of the method of the present invention. Detailed Implementation

[0042] The embodiments of the present invention will now be described in detail with reference to the accompanying drawings.

[0043] The goal of this embodiment is to achieve accurate verification of the recovery volume and to pinpoint the cause of the fault when the deviation exceeds the limit. In this embodiment, the standard atmospheric pressure is 101.3 kPa, the standard ambient humidity is 60% RH, the gasoline vapor equivalence coefficient is 1000, the average molecular weight of the vapor is 65, and it is compatible with conventional gasoline alkane-olefin mixtures.

[0044] This embodiment provides a comprehensive verification method for oil and gas recovery based on a data model, such as... Figure 1 As shown, it includes the following steps:

[0045] Step 1: Collect basic parameters, environmental parameters, equipment operating parameters, and actual recovery volume measurements in real time to form raw data; among them, basic parameters include oil and gas flow rate, inlet gas concentration, exhaust gas concentration, and inlet gas temperature; environmental parameters include atmospheric pressure and ambient humidity; equipment operating parameters include recovery pump speed, oil and gas valve opening, sensor operating status information, and oil tank breather valve operating status.

[0046] It should be noted that basic parameters refer to parameters that directly reflect the characteristics of oil and gas, including oil and gas flow rate (unit: CFM), which represents the volume of oil and gas passing through the recovery system per unit time; inlet gas concentration (unit: g / m³), which represents the mass concentration of oil and gas entering the recovery system; exhaust gas concentration (unit: g / m³), which represents the mass concentration of oil and gas discharged after treatment by the recovery system; and inlet gas temperature (including degrees Celsius °C and absolute degrees Fahrenheit °R, with absolute degrees Fahrenheit used for oil and gas volume measurement correction). Environmental parameters refer to external environmental parameters that affect the physical properties of oil and gas, including atmospheric pressure (unit: kPa). Ambient humidity (unit: %RH, indicating the accuracy of interference intake concentration detection); Equipment operating parameters refer to parameters reflecting the working status of the oil and gas recovery device, including recovery pump speed (unit: r / min, representing the pump's oil and gas delivery capacity), oil and gas valve opening (unit: %, representing the degree of valve control over oil and gas flow), sensor operating status information (indicating whether the data acquisition equipment is working properly), and oil tank breather valve operating status (indicating whether the pressure balance inside and outside the oil tank is normal); Actual recovery volume measurement value refers to the total volume of oil and gas recovered on the same day, directly measured by a dedicated oil and gas metering instrument, unit: m³.

[0047] Among them, the basic parameters are collected by an explosion-proof vortex flow sensor to collect oil and gas flow rate, an infrared concentration sensor to collect intake and exhaust concentration, and a platinum resistance temperature sensor to collect intake temperature, and the temperature is converted from °C to absolute Fahrenheit in real time. The conversion formula is: T°R=(T℃+273.15)x9 / 5).

[0048] Step 2: Based on the aforementioned basic parameters, determine the oil and gas processing efficiency, the cumulative oil delivery time of the day, and the recovery amount per unit time. Combine the oil and gas processing efficiency, the cumulative oil delivery time of the day, and the recovery amount per unit time to calculate the theoretical recovery amount.

[0049] In one possible implementation, determining the oil and gas processing efficiency based on the aforementioned fundamental parameters includes the following:

[0050] Intake and exhaust concentrations are extracted from basic parameters as raw concentration data. The oil dispensing stage is identified based on the fluctuation characteristics of the raw concentration data. The oil dispensing stage includes the unloading start-up stage, the stable oil dispensing stage, and the shutdown stage. The raw concentration data of the unloading start-up stage and the shutdown stage are processed using the sliding window averaging method to obtain smoothed concentration data. The first oil and gas treatment efficiency of the unloading start-up stage and the shutdown stage is calculated based on the smoothed concentration data. The second oil and gas treatment efficiency of the stable oil dispensing stage is calculated based on the raw concentration data.

[0051] It should be noted that the oil unloading and start-up phase is the initial stage of system startup, characterized by large concentration fluctuations; the stable oil dispensing phase is the normal operation of the system, with stable concentrations; and the shutdown phase refers to the period before the system stops, characterized by large concentration fluctuations. The oil and gas concentration fluctuation characteristics differ significantly across different dispensing phases: during startup and shutdown, the instantaneous concentration fluctuations are large, and directly using raw data to calculate efficiency will lead to distorted results; during the stable phase, the concentration is stable, and raw data can be used directly for calculation. Therefore, efficiency needs to be calculated differently for each phase to ensure that the efficiency value accurately reflects the oil and gas processing capacity of each phase.

[0052] In the specific implementation process, the oiling stage is identified based on the fluctuation range of the original concentration data. For example, when the fluctuation range is greater than a preset threshold, it is determined to be a fluctuation stage, and when the fluctuation range is less than or equal to the preset threshold, it is determined to be a stable stage, thereby identifying the current oiling stage.

[0053] The fluctuation phase includes the oil unloading start-up phase / shutdown phase, which affects the original intake air concentration (C). m原 ), original exhaust gas concentration (C e原 The smoothed intake air concentration (C) was obtained by using the sliding window averaging method. m平 ), smooth exhaust concentration (C) e平 );

[0054] Stabilizing the oil: Use the original intake air concentration directly (C m原 ), original exhaust gas concentration (C e原 );

[0055] Oil and gas processing efficiency calculation:

[0056] First oil and gas processing efficiency: formula: ;

[0057] Second oil and gas processing efficiency: formula: .

[0058] In one possible implementation, determining the cumulative oiling time for the day based on the aforementioned basic parameters includes the following:

[0059] Based on the characteristics of changes in oil and gas flow, the real-time oil delivery mode that exists on the day is determined. The real-time oil delivery mode includes single-pump oil delivery mode and multi-pump concurrent mode.

[0060] If only the single-pump oil dispensing mode exists on a given day, the cumulative oil dispensing volume and real-time oil and gas processing volume of the single-pump oil dispensing mode are extracted. A first dynamic correlation model between the cumulative oil dispensing volume and real-time oil and gas processing volume of the single-pump oil dispensing mode is established using the second gas-liquid ratio coefficient. The cumulative oil dispensing time of the single-pump oil dispensing mode is then calculated using the first dynamic correlation model.

[0061] If only the multi-pump concurrent mode exists on a given day, the cumulative oil delivery volume and real-time oil and gas processing volume of the day under the multi-pump concurrent mode are extracted. A second dynamic correlation model between the cumulative oil delivery volume and real-time oil and gas processing volume of the day under the multi-pump concurrent mode is established using the first gas-liquid ratio coefficient. The cumulative oil delivery time of the day under the multi-pump concurrent mode is calculated through this second dynamic correlation model. The first gas-liquid ratio coefficient is higher than the second gas-liquid ratio coefficient.

[0062] If there is a switch between single-pump oil dispensing mode and multi-pump concurrent mode on the same day, the cumulative oil dispensing time of the single-pump oil dispensing mode and multi-pump concurrent mode on the same day will be added together.

[0063] It should be noted that the real-time fuel dispensing mode refers to the working mode of the fuel dispensing equipment, including single-pump dispensing mode (only one fuel dispenser works, and the amount of fuel gas produced is stable) and multi-pump concurrent mode (≥2 fuel dispensers work simultaneously, and the amount of fuel gas produced increases); the first gas-liquid ratio coefficient refers to the gas-liquid ratio coefficient used in the multi-pump concurrent mode (because the amount of fuel gas produced by multiple pumps increases, the coefficient needs to be higher, and in this embodiment it is set to 1.1); the second gas-liquid ratio coefficient refers to the gas-liquid ratio coefficient used in the single-pump dispensing mode (the amount of fuel gas produced by a single pump is stable, and the coefficient is set to 1.0), and the first gas-liquid ratio coefficient is higher than the second gas-liquid ratio coefficient; the cumulative fuel dispensing volume of the day refers to the total volume of gasoline sold through the fuel dispensers on the same day, in m³; the real-time fuel gas processing capacity refers to the volume of fuel gas that the fuel gas recovery device can process per unit time, in m³ / h; the dynamic correlation model refers to the calculation model established based on the cumulative fuel dispensing volume of the day × gas-liquid ratio coefficient = real-time fuel gas processing capacity × cumulative fuel dispensing time of the day, which is used to correlate the fuel dispensing volume and the processing capacity and derive the fuel dispensing time.

[0064] In the specific implementation process, the oil and gas flow rate change characteristics (a sudden increase in flow rate ≥50% is judged as multiple pumps operating concurrently, and a stable flow rate is judged as single pump oil delivery) are used to determine the oil delivery mode that exists on that day.

[0065] In single-pump oil dispensing mode, the second gas-liquid ratio coefficient is used. Establish the first dynamic association model: In multi-pump concurrent mode, the first gas-liquid ratio coefficient is used. Establish a second dynamic association model: .in, This represents the total amount of oil dispensed that day. This represents the real-time oil and gas processing volume.

[0066] Calculation of cumulative oil dispensing time per day: In the case of single-pump oil dispensing only: In the case of multiple pumps operating concurrently When two modes are being switched on the same day: .

[0067] In one possible implementation, determining the amount recovered per unit time based on the basic parameters includes the following:

[0068] Oil and gas flow rate, intake gas concentration, and intake gas temperature are extracted from basic parameters. Based on the intake gas temperature fluctuation characteristics during the oil extraction stage, a staged temperature-density correction coefficient table is established. When the intake gas temperature increases, the temperature-density correction coefficient for the corresponding stage decreases proportionally. The oil and gas flow rate and intake gas concentration are multiplied to obtain the initial recovery amount per unit time.

[0069] According to the current oiling stage, consult the stage temperature-density correction coefficient table to obtain the temperature-density correction coefficient for the corresponding intake temperature. Use this temperature-density correction coefficient to compensate for the initial unit time recovery amount to obtain the stage unit time recovery amount.

[0070] If the current real-time oil dispensing mode is single-pump oil dispensing mode, then the recovery amount per unit time in the stage is the same as the recovery amount per unit time in single-pump oil dispensing mode.

[0071] If the current real-time oil delivery mode is a multi-pump concurrent mode, the flow distribution correction is performed on the unit time recovery amount of each stage based on the oil and gas flow ratio of each pump to obtain the unit time recovery amount of each pump in the multi-pump concurrent mode.

[0072] If there is a switch between single-pump oil dispensing mode and multi-pump concurrent mode on the same day, the unit time recovery amount of each corresponding oil dispensing stage under the two modes shall be calculated separately, and then the cumulative oil dispensing time of each mode on the same day shall be weighted and integrated to obtain the unit time recovery amount of the day.

[0073] It should be noted that the temperature-density correction coefficient table is a coefficient table established based on the characteristics of intake air temperature fluctuation during the fuel injection stage. The coefficient decreases proportionally as the intake air temperature increases (because the increase in temperature will lead to a decrease in fuel gas density, which needs to correct for volume measurement deviation); the initial unit time recovery amount refers to the unit time recovery amount calculated only by fuel gas flow rate and intake air concentration (without considering the effect of temperature); the stage unit time recovery amount refers to the result of the initial unit time recovery amount after compensation by the temperature-density correction coefficient (adapting to the temperature characteristics of the current fuel injection stage); the flow distribution correction refers to the process of distributing the stage unit time recovery amount to a single pump according to the fuel gas flow rate ratio of each pump in the multi-pump concurrent mode.

[0074] In the specific implementation process, the rule for establishing the temperature-density correction coefficient table is to set the coefficient level according to the oil dispensing stage (the interval between the levels is small during the oil unloading start / stop stage and large during the stable stage), and the coefficient decreases by 0.02 for every 5°C increase in intake air temperature.

[0075] The formula for calculating the initial recovery amount per unit time is: ;in, This refers to the flow rate of oil and gas (CFM). The concentration of oil and gas by volume (%) The absolute temperature of the intake air is Fahrenheit. This is the gasoline vapor equivalence coefficient (taken as 1000).

[0076] The calculation process for the unit time recovery of a stage is as follows: Query the temperature-density correction coefficient table to obtain the correction coefficient for the corresponding intake temperature of the current stage. ),formula:

[0077]

[0078] in, This represents the recovery rate per unit time during the stage after temperature-density correction.

[0079] In single-pump fuel dispensing mode: ;

[0080] In multi-pump concurrent mode: calculate the oil-gas flow rate ratio of each pump ( ),formula:

[0081] ;

[0082] in, This represents the amount of water recovered per unit time by the i-th pump in a multi-pump concurrent mode; This represents the percentage of oil and gas flow in the i-th pump; This represents the total oil and gas flow rate of all pumps in a multi-pump concurrent mode; This represents the oil and gas flow rate of the i-th pump;

[0083] When switching modes, the cumulative daily oil delivery time for both modes is weighted and combined using the following formula:

[0084]

[0085] in, This indicates the amount of data collected per unit of time on the same day when the mode is switched.

[0086] In one possible implementation, the theoretical recovery amount calculated by combining oil and gas processing efficiency, cumulative daily oil delivery time, and recovery amount per unit time includes the following:

[0087] Extract the oil and gas processing efficiency corresponding to each oil dispensing stage, extract the cumulative oil dispensing time of the day under each real-time oil dispensing mode, extract the unit time recovery amount under each combination of oil dispensing stage and real-time oil dispensing mode, calculate the stage theoretical recovery amount for each combination of oil dispensing stage and real-time oil dispensing mode, and sum up the stage theoretical recovery amounts of all combinations to obtain the theoretical recovery amount for the day.

[0088] It should be noted that the theoretical recovery amount for a stage refers to the recovery amount calculated according to the combination of "oil dispensing stage - real-time oil dispensing mode" (each combination corresponds to a unique efficiency, time, and recovery amount per unit time); the theoretical recovery amount for a day refers to the cumulative result of the theoretical recovery amounts for all "stage-mode" combinations (reflecting the total amount of oil and gas that should theoretically be recovered on that day).

[0089] In the specific implementation process, the oil and gas processing efficiency of the corresponding combination is extracted according to the combination of oil dispensing stage and real-time oil dispensing mode. ), Total oil dispensing time on the day Recovery per unit time ( ;

[0090] Formula for calculating the theoretical recovery amount in a stage: ;

[0091] Formula for calculating the theoretical recovery amount on that day: ; Accumulate the theoretical recovery amount for all combinations at each stage.

[0092] Step 3: Based on environmental parameters and equipment operating parameters, generate pressure correction coefficient, humidity correction coefficient and equipment operating correction coefficient respectively. Use the pressure correction coefficient, humidity correction coefficient and equipment operating correction coefficient to correct the theoretical recovery amount and obtain the corrected recovery amount.

[0093] In one possible implementation, step 3 includes the following sub-steps:

[0094] Step 3.1: Based on atmospheric pressure in the environmental parameters, and combined with the correlation characteristics of oil and gas density with atmospheric pressure, compensation is performed to generate a pressure correction coefficient to eliminate the interference of atmospheric pressure fluctuations on the calculation of theoretical recovery.

[0095] Step 3.2: Based on the environmental humidity in the environmental parameters, and combined with the interference characteristics of water vapor on the detection of inlet air concentration, a humidity correction coefficient is generated to eliminate the interference of environmental humidity fluctuations on the calculation of theoretical recovery.

[0096] Step 3.3: Based on the recovery pump speed and oil and gas valve opening in the equipment operating parameters, compensation is performed in combination with the recovery pump load characteristics and valve flow characteristics to generate equipment operation correction coefficients, so as to eliminate the interference of equipment operating state deviation on the calculation of theoretical recovery amount;

[0097] Step 3.4: Use pressure correction coefficient, humidity correction coefficient and equipment operation correction coefficient to comprehensively correct the theoretical recovery amount obtained in step 2, and obtain the corrected recovery amount.

[0098] It should be noted that the pressure correction coefficient is a coefficient generated based on atmospheric pressure changes, used to eliminate the influence of atmospheric pressure fluctuations on oil and gas density and ensure that the recovery measurement is not affected by pressure; the humidity correction coefficient is a coefficient generated based on environmental humidity changes, used to eliminate the interference of water vapor on the intake concentration detection and ensure the accuracy of concentration parameters; the equipment operation correction coefficient is a coefficient generated based on the recovery pump speed and the opening of oil and gas valves, used to eliminate the influence of equipment operating status deviations on oil and gas transportation capacity; the corrected recovery amount refers to the theoretical recovery amount after comprehensive correction by the three types of correction coefficients.

[0099] In the specific implementation process, pressure correction coefficients are generated. It is based on the ratio of atmospheric pressure to standard pressure, formula: in Standard atmospheric pressure (101.3 kPa). This represents real-time atmospheric pressure.

[0100] Generate humidity correction factor ( () is based on the deviation between ambient humidity and standard humidity, formula: in Standard humidity (60%RH). The humidity influence coefficient is taken as 0.002.

[0101] Generate equipment operation correction coefficients ( This is based on the deviation between the recovery pump speed and the valve opening, formula: in, The standard speed of the recovery pump is 1500 r / min. This is the standard opening degree (100%) of the oil and gas valve.

[0102] The formula for calculating the corrected recovery amount is: .

[0103] Step 4: Compare the calibrated recovery amount with the actual recovery amount and calculate the deviation rate; if the deviation rate is within the preset threshold range, output the calibrated recovery amount as the final recovery amount; if the deviation rate exceeds the preset threshold range, locate the cause of the deviation by combining the equipment operating parameters and generate an early warning signal.

[0104] In one possible implementation, step 4 includes the following steps:

[0105] Step 4.1: Compare the corrected recovery amount obtained in Step 3 with the actual recovery amount measured in the original data formed in Step 1. Calculate the deviation rate by the ratio of the difference between the two to the actual recovery amount measured.

[0106] Step 4.2: Determine whether the deviation rate is within the preset threshold range. If the deviation rate is within the preset threshold range, output the corrected recovery amount as the final recovery amount.

[0107] Step 4.3: If the deviation rate exceeds the preset threshold range, retrieve the equipment operating parameters from the original data formed in Step 1, and analyze the parameter deviation between the recovery pump speed and the standard speed, the parameter deviation between the oil and gas valve opening and the standard opening, and the fluctuation trend of the operating status of the oil tank breather valve. Analyze the correlation between parameter deviation and fluctuation trend to pinpoint the cause of the deviation.

[0108] Step 4.4: Based on the cause of the deviation, generate an early warning signal that includes the faulty component identifier, the current oil dispensing stage, and emergency handling suggestions.

[0109] In one possible implementation, the equipment operating parameters in the original data generated in step 1 are retrieved, and the parameter deviations of the recovery pump speed and standard speed, the parameter deviations of the oil and gas valve opening and standard opening, and the fluctuation trends of the operating status of the oil tank breather valve are analyzed respectively. The causes of the deviations are located by analyzing the correlation between parameter deviations and fluctuation trends, including the following:

[0110] Retrieve the recovery pump speed data from the equipment operating parameters, and combine it with the standard recovery pump speed corresponding to the current real-time oil dispensing mode to calculate the parameter deviation between the recovery pump speed and the standard speed. If the parameter deviation continues to exceed the preset deviation range and is correlated with the fluctuation trend of oil and gas flow in the basic parameters, the cause of the deviation is determined to be a recovery pump failure.

[0111] Retrieve the oil and gas valve opening data from the equipment operating parameters, and combine it with the standard opening of the oil and gas valve corresponding to the current oil dispensing stage to calculate the parameter deviation between the oil and gas valve opening and the standard opening. If the parameter deviation continues to exceed the preset deviation range and is correlated with the fluctuation trend of atmospheric pressure in the environmental parameters, the deviation is determined to be caused by oil and gas valve failure or valve sensor failure.

[0112] Retrieve the operating status data of the oil tank breather valve from the equipment operating parameters, and analyze the fluctuation trend of the oil tank breather valve's operating status in conjunction with the changing trend of atmospheric pressure in the environmental parameters. If the operating status of the oil tank breather valve shows unexpected switching fluctuations, and these fluctuations are correlated with the fluctuation trend of the intake air concentration in the basic parameters, then the cause of the deviation is determined to be a malfunction of the oil tank breather valve or a malfunction of the pressure sensor. Based on the above analysis results, determine the cause of the deviation.

[0113] It should be noted that the deviation rate refers to the ratio of the difference between the corrected recovery volume and the actual recovery volume measurement value to the actual value; the preset threshold range refers to the pre-set reasonable range of the deviation rate, and exceeding it indicates a system abnormality; parameter deviation refers to the difference between the equipment operating parameters (recovery pump speed, oil and gas valve opening) and the standard parameters; fluctuation trend correlation analysis refers to analyzing the matching relationship between the equipment parameter deviation and the fluctuation trend of basic parameters / environmental parameters (used to determine whether the deviation is caused by equipment failure); and early warning signal refers to the prompt information including faulty component identification, current oil dispensing stage, and emergency handling suggestions (used to guide maintenance personnel in handling abnormalities).

[0114] In the specific implementation process, the formula for calculating the deviation rate is:

[0115] The threshold determination process is as follows: if Within a preset threshold range: the output corrected recovery amount is the final recovery amount; if Exceeding the preset threshold range: Locating the cause of the deviation.

[0116] The process for locating the cause of the deviation is as follows: Recovery pump speed analysis: Calculate the speed deviation. ,like If the speed exceeds the preset deviation range (30 r / min) and matches the trend of oil and gas flow fluctuation (speed decreases and flow decreases), the recovery pump is determined to be faulty.

[0117] Oil and gas valve opening analysis: Calculation of opening deviation ,like If the deviation exceeds the preset range (15%) and matches the trend of atmospheric pressure fluctuation (opening deviation and pressure fluctuation), the valve or valve sensor is determined to be faulty.

[0118] Analysis of breather valve in oil tank: If the breather valve exhibits unexpected opening and closing fluctuations that match the trend of inlet air concentration fluctuations (abnormal opening and closing and sudden changes in concentration), it is determined that the breather valve or pressure sensor is faulty.

[0119] Based on the cause of the deviation, an early warning signal is generated, which includes the faulty component, the current oiling stage, and emergency recommendations.

[0120] The embodiments described above are merely illustrative of specific implementations of the present invention, and while the descriptions are detailed, they should not be construed as limiting the scope of the present invention. It should be noted that those skilled in the art can make various modifications and improvements without departing from the concept of the present invention, and these modifications and improvements all fall within the scope of protection of the present invention.

Claims

1. A comprehensive verification method for oil and gas recovery based on a data model, characterized in that, Includes the following steps: Step 1: Collect basic parameters, environmental parameters, equipment operating parameters, and actual recovery volume measurements in real time to form raw data; among them, basic parameters include oil and gas flow rate, inlet gas concentration, exhaust gas concentration, and inlet gas temperature; environmental parameters include atmospheric pressure and ambient humidity; equipment operating parameters include recovery pump speed, oil and gas valve opening, sensor operating status information, and oil tank breather valve operating status; Step 2: Based on the aforementioned basic parameters, determine the oil and gas processing efficiency, the cumulative oil delivery time of the day, and the recovery amount per unit time. Combine the oil and gas processing efficiency, the cumulative oil delivery time of the day, and the recovery amount per unit time to calculate the theoretical recovery amount. Step 3: Based on environmental parameters and equipment operating parameters, generate pressure correction coefficient, humidity correction coefficient and equipment operating correction coefficient respectively. Use the pressure correction coefficient, humidity correction coefficient and equipment operating correction coefficient to correct the theoretical recovery amount and obtain the corrected recovery amount. Step 4: Compare the calibrated recovery amount with the actual recovery amount and calculate the deviation rate; if the deviation rate is within the preset threshold range, output the calibrated recovery amount as the final recovery amount; if the deviation rate exceeds the preset threshold range, locate the cause of the deviation by combining the equipment operating parameters and generate an early warning signal.

2. The comprehensive verification method for oil and gas recovery based on a data model according to claim 1, characterized in that, Based on the aforementioned fundamental parameters, determining oil and gas processing efficiency includes the following: Intake and exhaust concentrations are extracted from basic parameters as raw concentration data. The oil dispensing stage is identified based on the fluctuation characteristics of the raw concentration data. The oil dispensing stage includes the unloading start-up stage, the stable oil dispensing stage, and the shutdown stage. The raw concentration data of the unloading start-up stage and the shutdown stage are processed using the sliding window averaging method to obtain smoothed concentration data. The first oil and gas treatment efficiency of the unloading start-up stage and the shutdown stage is calculated based on the smoothed concentration data. The second oil and gas treatment efficiency of the stable oil dispensing stage is calculated based on the raw concentration data.

3. The comprehensive verification method for oil and gas recovery based on a data model according to claim 2, characterized in that, Based on the aforementioned basic parameters, the cumulative oil-dispensing time for the day is determined to include the following: Based on the characteristics of changes in oil and gas flow, the real-time oil delivery mode that exists on the day is determined. The real-time oil delivery mode includes single-pump oil delivery mode and multi-pump concurrent mode. If only the single-pump oil dispensing mode exists on a given day, the cumulative oil dispensing volume and real-time oil and gas processing volume of the single-pump oil dispensing mode are extracted. The first dynamic correlation model between the cumulative oil dispensing volume and real-time oil and gas processing volume of the single-pump oil dispensing mode is established using the second gas-liquid ratio coefficient. The cumulative oil dispensing time of the single-pump oil dispensing mode is calculated through the first dynamic correlation model. If only the multi-pump concurrent mode exists on a given day, the cumulative oil delivery volume and real-time oil and gas processing volume of the day under the multi-pump concurrent mode are extracted. A second dynamic correlation model between the cumulative oil delivery volume and real-time oil and gas processing volume of the day under the multi-pump concurrent mode is established using the first gas-liquid ratio coefficient. The cumulative oil delivery time of the day under the multi-pump concurrent mode is calculated through this second dynamic correlation model. The first gas-liquid ratio coefficient is higher than the second gas-liquid ratio coefficient. If there is a switch between single-pump oil dispensing mode and multi-pump concurrent mode on the same day, the cumulative oil dispensing time of the single-pump oil dispensing mode and multi-pump concurrent mode on the same day will be added together.

4. The comprehensive verification method for oil and gas recovery based on a data model according to claim 3, characterized in that, The determination of the amount recovered per unit time based on the aforementioned basic parameters includes the following: Oil and gas flow rate, intake gas concentration, and intake gas temperature are extracted from basic parameters. Based on the intake gas temperature fluctuation characteristics during the oil extraction stage, a staged temperature-density correction coefficient table is established. When the intake gas temperature increases, the temperature-density correction coefficient for the corresponding stage decreases proportionally. The oil and gas flow rate and intake gas concentration are multiplied to obtain the initial recovery amount per unit time. According to the current oiling stage, consult the stage temperature-density correction coefficient table to obtain the temperature-density correction coefficient for the corresponding intake temperature. Use this temperature-density correction coefficient to compensate for the initial unit time recovery amount to obtain the stage unit time recovery amount. If the current real-time oil dispensing mode is single-pump oil dispensing mode, then the recovery amount per unit time in the stage is the same as the recovery amount per unit time in single-pump oil dispensing mode. If the current real-time oil delivery mode is a multi-pump concurrent mode, the flow distribution correction is performed on the unit time recovery amount of each stage based on the oil and gas flow ratio of each pump to obtain the unit time recovery amount of each pump in the multi-pump concurrent mode. If there is a switch between single-pump oil dispensing mode and multi-pump concurrent mode on the same day, the unit time recovery amount of each corresponding oil dispensing stage under the two modes shall be calculated separately, and then the cumulative oil dispensing time of each mode on the same day shall be weighted and integrated to obtain the unit time recovery amount of the day.

5. The comprehensive verification method for oil and gas recovery based on a data model according to claim 1, characterized in that, The theoretical recovery amount, calculated by combining oil and gas processing efficiency, daily cumulative oil delivery time, and recovery amount per unit time, includes the following: Extract the oil and gas processing efficiency corresponding to each oil dispensing stage, extract the cumulative oil dispensing time of the day under each real-time oil dispensing mode, extract the unit time recovery amount under each combination of oil dispensing stage and real-time oil dispensing mode, calculate the stage theoretical recovery amount for each combination of oil dispensing stage and real-time oil dispensing mode, and sum up the stage theoretical recovery amounts of all combinations to obtain the theoretical recovery amount for the day.

6. The comprehensive verification method for oil and gas recovery based on a data model according to claim 1, characterized in that, Step 3 includes the following sub-steps: Step 3.1: Based on atmospheric pressure in the environmental parameters, and combined with the correlation characteristics of oil and gas density with atmospheric pressure, compensation is performed to generate a pressure correction coefficient to eliminate the interference of atmospheric pressure fluctuations on the calculation of theoretical recovery. Step 3.2: Based on the environmental humidity in the environmental parameters, and combined with the interference characteristics of water vapor on the detection of inlet air concentration, a humidity correction coefficient is generated to eliminate the interference of environmental humidity fluctuations on the calculation of theoretical recovery. Step 3.3: Based on the recovery pump speed and oil and gas valve opening in the equipment operating parameters, compensation is performed in combination with the recovery pump load characteristics and valve flow characteristics to generate equipment operation correction coefficients, so as to eliminate the interference of equipment operating state deviation on the calculation of theoretical recovery amount; Step 3.4: Use pressure correction coefficient, humidity correction coefficient and equipment operation correction coefficient to comprehensively correct the theoretical recovery amount obtained in step 2, and obtain the corrected recovery amount.

7. The comprehensive verification method for oil and gas recovery based on a data model according to claim 1, characterized in that, Step 4 includes the following steps: Step 4.1: Compare the corrected recovery amount obtained in Step 3 with the actual recovery amount measured in the original data formed in Step 1. Calculate the deviation rate by the ratio of the difference between the two to the actual recovery amount measured. Step 4.2: Determine whether the deviation rate is within the preset threshold range. If the deviation rate is within the preset threshold range, output the corrected recovery amount as the final recovery amount. Step 4.3: If the deviation rate exceeds the preset threshold range, retrieve the equipment operating parameters from the original data formed in Step 1, and analyze the parameter deviation between the recovery pump speed and the standard speed, the parameter deviation between the oil and gas valve opening and the standard opening, and the fluctuation trend of the operating status of the oil tank breather valve. Analyze the correlation between parameter deviation and fluctuation trend to pinpoint the cause of the deviation. Step 4.4: Based on the cause of the deviation, generate an early warning signal that includes the faulty component identifier, the current oil dispensing stage, and emergency handling suggestions.

8. The comprehensive verification method for oil and gas recovery based on a data model according to claim 7, characterized in that: Retrieve the equipment operating parameters from the raw data generated in step 1, and analyze the parameter deviations of the recovery pump speed and standard speed, the parameter deviations of the oil and gas valve opening and standard opening, and the fluctuation trends of the oil tank breather valve operating status. Through the correlation analysis of parameter deviations and fluctuation trends, the causes of the deviations are identified, including the following: Retrieve the recovery pump speed data from the equipment operating parameters, and combine it with the standard recovery pump speed corresponding to the current real-time oil dispensing mode to calculate the parameter deviation between the recovery pump speed and the standard speed. If the parameter deviation continues to exceed the preset deviation range and is correlated with the fluctuation trend of oil and gas flow in the basic parameters, the cause of the deviation is determined to be a recovery pump failure. Retrieve the oil and gas valve opening data from the equipment operating parameters, and combine it with the standard opening of the oil and gas valve corresponding to the current oil dispensing stage to calculate the parameter deviation between the oil and gas valve opening and the standard opening. If the parameter deviation continues to exceed the preset deviation range and is correlated with the fluctuation trend of atmospheric pressure in the environmental parameters, the deviation is determined to be caused by oil and gas valve failure or valve sensor failure. Retrieve the operating status data of the oil tank breather valve from the equipment operating parameters, and combine it with the changing trend of atmospheric pressure in the environmental parameters to analyze the fluctuation trend of the operating status of the oil tank breather valve. If the operating status of the tank breather valve exhibits unexpected switching fluctuations, and these fluctuations are correlated with the trend of the intake air concentration in the basic parameters, the cause of the deviation is determined to be a malfunction of the tank breather valve or a malfunction of the pressure sensor. Based on the above analysis results, the cause of the deviation is determined.

Images