Recovery metering system and method based on an oil and gas recovery installation

Abstract

The application provides a recovery metering system and method based on an oil gas recovery device, relates to the technical field of oil gas recovery, and the oil gas recovery device comprises a separation tank and an oil storage tank connected by a volatile gas pipe, wherein the volatile gas pipe is provided with a compressor and a condenser; the separation tank is connected to an oil gas feed pipe; the compressor is connected to the oil gas feed pipe through a gas supplement pipe; the system comprises a flow monitor arranged on the oil gas feed pipe; an oil gas concentration monitor group arranged on the oil gas feed pipe, the volatile gas pipe and the gas supplement pipe respectively; a temperature sensor group arranged on the oil gas feed pipe and the volatile gas pipe respectively; an adjusting valve arranged on the gas supplement pipe; a data processing module connected to the flow monitor, the oil gas concentration monitor group, the temperature sensor group and the adjusting valve; and the data processing module adjusts the opening degree of the adjusting valve to determine the mixed oil gas concentration and the oil gas recovery amount. The accuracy of recovery metering is improved.

Description

Technical Field

[0001] This invention relates to the field of oil and gas recovery technology, and more specifically to a recovery metering system and method based on an oil and gas recovery device. Background Technology

[0002] In the storage, transportation, and sales stages of the petrochemical industry, volatile organic liquids such as gasoline generate a large amount of volatile organic compounds (VOCs) during production and turnover. This not only wastes resources but also forms important precursors to ozone and PM2.5, polluting the environment.

[0003] Therefore, oil and gas recovery systems use technologies such as absorption, compression, and condensation to recover oil and gas into liquid gasoline. To evaluate the recovery effect of the system, the amount of oil and gas recovered needs to be measured. Currently, the recovery measurement method assumes an ideal state, assuming that the oil and gas concentration, flow rate, and ambient temperature are constant, and measures the recovery amount by setting a fixed equivalent coefficient. However, in reality, the oil and gas concentration in the gas phase space inside the tank fluctuates at different operating stages, and the ambient temperature also changes in real time. When the ambient temperature changes, the volume of oil and gas also changes with the temperature. Therefore, with the mass remaining constant, the flow rate of oil and gas changes. Consequently, the fixed equivalent coefficient cannot adapt to changes in concentration, temperature, and flow rate, resulting in measurement errors. Summary of the Invention

[0004] The purpose of this invention is to provide a recovery metering system and method based on an oil and gas recovery device, and the technical problem to be solved is how to improve the accuracy of recovery metering.

[0005] This invention is achieved through the following technical solution:

[0006] The first aspect provides a recovery metering system based on an oil and gas recovery device, which includes a separator and an oil storage tank connected by a vapor pipe. A compressor and a condenser are installed on the vapor pipe. The compressor compresses the oil and gas to obtain a high-concentration oil and gas mixture, which is then condensed into liquid oil by the condenser. The separator is connected to an oil and gas inlet pipe, through which the oil and gas enters. The compressor is connected to the oil and gas inlet pipe via a make-up gas pipe. The recovery metering system includes:

[0007] Flow monitor, which is installed on the oil and gas feed pipe;

[0008] The oil and gas concentration monitoring instrument group consists of oil and gas concentration monitoring instruments installed on the oil and gas feed pipe, volatile gas pipe and gas replenishment pipe respectively.

[0009] Temperature sensor group, wherein the temperature sensors in the above temperature sensor group are respectively installed on the oil and gas feed pipe and the volatile gas pipe;

[0010] The regulating valve is installed on the air supply pipe;

[0011] The data processing module is connected to the aforementioned flow monitor, oil and gas concentration monitor group, temperature sensor group and regulating valve;

[0012] The data processing module described above performs the following steps:

[0013] Based on the oil and gas concentration collected by the oil and gas concentration monitoring instrument group and the oil and gas temperature collected by the temperature sensor group, the opening of the regulating valve is adjusted.

[0014] Based on the above oil and gas concentrations and the actual concentrations of high-concentration oil and gas, the concentration of mixed oil and gas entering the separator is determined.

[0015] Based on the oil and gas flow rate, mixed oil and gas concentration, and oil and gas temperature collected by the aforementioned flow monitoring instrument, the amount of oil and gas recovered is determined.

[0016] A recovery and metering system based on an oil and gas recovery device is constructed. This system utilizes flow meters, oil and gas concentration monitoring devices, temperature sensors, regulating valves, and a data processing module installed at various locations, including the oil and gas feed pipe, volatile gas pipe, and make-up gas pipe, to achieve real-time monitoring of parameters such as oil and gas flow rate, concentration, and temperature. The data processing module performs calculations based on the collected parameters. First, it adjusts the opening of the regulating valve based on the oil and gas concentration and temperature to control the oil and gas mixing process. Next, it determines the concentration of the mixed oil and gas entering the separator. Finally, it determines the amount of oil and gas recovered based on the flow rate, mixed oil and gas concentration, and temperature. The equivalent coefficient is corrected using real-time monitoring data to make the metering more closely reflect actual conditions.

[0017] Furthermore, the aforementioned flow monitoring device is installed between the air supply pipe and the separator, and the inlet air flow rate entering the separator is collected in real time through the aforementioned flow monitoring device.

[0018] Furthermore, the aforementioned oil and gas concentration monitoring instrument group includes a first oil and gas concentration monitoring instrument, a second oil and gas concentration monitoring instrument, and a third oil and gas concentration monitoring instrument;

[0019] The aforementioned first oil and gas concentration monitor is installed at the end of the oil and gas feed pipe furthest from the separator; the first oil and gas concentration monitor is used to collect the intake gas concentration before oil and gas mixing in real time;

[0020] The aforementioned second oil and gas concentration monitor is installed on the volatile gas pipe between the condenser and the oil storage tank; the concentration of exhaust gas entering the oil storage tank is collected in real time through the aforementioned second oil and gas concentration monitor;

[0021] The aforementioned third oil and gas concentration monitor is installed on the gas supply pipe, and the actual concentration of high-concentration oil and gas fed into the oil and gas feed pipe is collected in real time through the aforementioned third oil and gas concentration monitor.

[0022] Furthermore, the aforementioned oil and gas concentration monitoring instrument group also includes a fourth oil and gas concentration monitoring instrument, which is installed on the oil and gas feed pipe between the gas replenishment pipe and the separator; the fourth oil and gas concentration monitoring instrument collects the intake gas concentration after the oil and gas mixture in real time.

[0023] Furthermore, the aforementioned temperature sensor group includes a first temperature sensor and a second temperature sensor.

[0024] The first temperature sensor is installed on the oil and gas feed pipe between the gas injection pipe and the separator, and the second temperature sensor is installed on the volatile gas pipe between the condenser and the oil storage tank. The first temperature sensor is used to collect the intake temperature of the oil and gas mixture in real time, and the second temperature sensor is used to collect the exhaust temperature of the gas entering the oil storage tank in real time.

[0025] Furthermore, the recycling metering system also includes a pressure monitoring unit, which includes a first pressure monitoring unit and a second pressure monitoring unit.

[0026] The first pressure monitoring instrument is installed on the oil and gas feed pipe, and the second pressure monitoring instrument is installed on the volatile gas pipe between the condenser and the oil storage tank. The first pressure monitoring instrument collects the first atmospheric pressure entering the separator in real time, and the second pressure monitoring instrument collects the second atmospheric pressure entering the oil storage tank in real time.

[0027] The second aspect provides a recovery metering method based on an oil and gas recovery device, which employs the aforementioned recovery metering system;

[0028] The recycling metering method includes the following steps:

[0029] Real-time acquisition of first atmospheric pressure, second atmospheric pressure, intake air flow rate, intake air concentration after oil-air mixture, intake air temperature, exhaust air concentration and exhaust air temperature;

[0030] Using the oil-gas equivalence coefficient function, based on the first atmospheric pressure, the second atmospheric pressure, the intake concentration, the exhaust concentration, the intake temperature, and the exhaust temperature, the oil-gas equivalence dynamic coefficient is determined.

[0031] The amount of oil and gas recovered is determined by using the above-mentioned intake flow rate, intake concentration, intake temperature, and oil and gas equivalent dynamic coefficient.

[0032] Furthermore, using the oil-gas equivalence coefficient function, based on the aforementioned first atmospheric pressure, second atmospheric pressure, intake concentration, exhaust concentration, intake temperature, and exhaust temperature, the dynamic coefficient of oil-gas equivalence is determined. Specific steps include:

[0033] Based on the first and second atmospheric pressures mentioned above, the function of oil and gas concentration versus oil and gas temperature is invoked respectively.

[0034] Based on the above variation function and intake temperature, the ideal intake concentration corresponding to the intake temperature at the first atmosphere pressure is determined.

[0035] Based on the above variation function and exhaust temperature, the ideal exhaust concentration corresponding to the exhaust temperature under the second atmosphere pressure is determined.

[0036] The intake air concentration deviation value is determined by comparing the ideal intake air concentration with the actual intake air concentration.

[0037] The exhaust concentration deviation value is determined by comparing the ideal exhaust concentration with the actual exhaust concentration.

[0038] The oil-gas equivalent fixed coefficient is determined by the above ideal intake concentration and ideal exhaust concentration.

[0039] The correction factor is determined based on the above intake air concentration deviation value and exhaust air concentration deviation value;

[0040] The dynamic coefficient of oil and gas equivalent is determined by using the above-mentioned fixed coefficient and correction coefficient of oil and gas equivalent.

[0041] In actual oil and gas recovery processes, the equivalence coefficient changes with atmospheric pressure, temperature, and concentration. The dynamic equivalence coefficient is determined based on multiple parameters such as the first atmospheric pressure, the second atmospheric pressure, the inlet flow rate, the inlet concentration after oil and gas mixing, the inlet temperature, the exhaust concentration, and the exhaust temperature, rather than using a fixed coefficient. Based on the parameters acquired in real time, the changes in the equivalence coefficient under different operating conditions are reflected, making the measurement results more consistent with the actual situation and thus improving the accuracy of the measurement. When determining the dynamic coefficient of oil and gas equivalent, firstly, the combined effects of atmospheric pressure and temperature on oil and gas concentration are considered, providing ideal reference values ​​for subsequent calculations. Then, by comparing the ideal intake concentration with the actual intake concentration, and the ideal exhaust concentration with the actual exhaust concentration, the intake concentration deviation and exhaust concentration deviation values ​​are determined. These deviation values ​​reflect the difference between the oil and gas concentration during actual operation and the ideal state, providing a basis for correcting the measurement results. Finally, a fixed coefficient of oil and gas equivalent is determined based on the ideal intake concentration and ideal exhaust concentration. This coefficient reflects the basic relationship of oil and gas equivalent under ideal conditions. Simultaneously, a correction coefficient is determined using the intake concentration deviation and exhaust concentration deviation values ​​to correct the fixed coefficient. Combining the basic relationship of oil and gas equivalent under ideal conditions with actual deviations not only reduces the calculation difficulty of the dynamic coefficient of oil and gas equivalent but also improves the accuracy of the coefficient, thereby improving the accuracy of oil and gas recovery calculations.

[0042] Compared with the prior art, the present invention has the following advantages and beneficial effects:

[0043] By installing flow monitors, oil and gas concentration monitors, temperature sensors, regulating valves, and data processing modules at different locations such as the oil and gas feed pipe, volatile gas pipe, and make-up gas pipe, real-time monitoring of parameters such as oil and gas flow rate, concentration, and temperature is achieved. The data processing module first adjusts the opening of the regulating valve based on the oil and gas concentration and temperature to control the oil and gas mixing process; then it determines the concentration of the mixed oil and gas entering the separator; finally, it determines the oil and gas recovery amount based on the flow rate, mixed oil and gas concentration, and temperature; and it uses real-time monitoring data to correct the equivalent coefficient, making the measurement more closely reflect actual conditions. In the actual oil and gas recovery process, the equivalent coefficient changes with atmospheric pressure, temperature, and concentration. The dynamic oil and gas equivalent coefficient is determined based on multiple parameters such as the first atmosphere pressure, the second atmosphere pressure, the inlet flow rate, the inlet concentration after oil and gas mixing, the inlet temperature, the exhaust concentration, and the exhaust temperature, rather than using a fixed coefficient. Based on the real-time acquired parameters, it reflects the changes in the oil and gas equivalent coefficient under different operating conditions, making the measurement results more closely reflect actual conditions and thus improving the accuracy of the measurement. Attached Figure Description

[0044] To more clearly illustrate the technical solutions of the exemplary embodiments of the present invention, the accompanying drawings used in the embodiments will be briefly described below. It should be understood that the following drawings only show some embodiments of the present invention and should not be considered as a limitation of the scope. For those skilled in the art, other related drawings can be obtained based on these drawings without creative effort. In the drawings:

[0045] Figure 1 A block diagram showing the connection of the recovery metering system on the oil and gas recovery unit;

[0046] Figure 2 This is a system connection diagram.

[0047] The attached diagram shows the markings and corresponding component names:

[0048] 1. Separator; 2. Oil storage tank; 3. Compressor; 4. Condenser; 5. Regulating valve; 6. Flow monitor; 7. Oil and gas concentration monitor group; 8. Temperature sensor group; 9. Pressure monitor group; 11. Oil and gas feed pipe; 12. Volatile gas pipe; 13. Gas replenishment pipe; 71. First oil and gas concentration monitor; 72. Second oil and gas concentration monitor; 73. Third oil and gas concentration monitor; 74. Fourth oil and gas concentration monitor; 81. First temperature sensor; 82. Second temperature sensor; 91. First pressure monitor; 92. Second pressure monitor. Detailed Implementation

[0049] To make the objectives, technical solutions, and advantages of the present invention clearer, the present invention will be further described in detail below with reference to the embodiments and accompanying drawings. The illustrative embodiments and descriptions of the present invention are only used to explain the present invention and are not intended to limit the present invention.

[0050] This invention relates to a recovery and metering system based on an oil and gas recovery device, primarily in the field of gasoline oil and gas recovery and metering technology. The invention includes a gas replenishment pipe 13 for supplementing the oil and gas concentration, minimizing the difference in oil and gas concentration entering the separator 1, stabilizing the oil and gas equivalence coefficient as much as possible, and thus improving the accuracy of oil and gas recovery and metering. This invention can be implemented in the following ways:

[0051] like Figure 1 and Figure 2 As shown, a recovery metering system based on an oil and gas recovery device includes a separation tank 1 and an oil storage tank 2, which are connected by a volatile gas pipe 12. A compressor 3 and a condenser 4 are installed on the volatile gas pipe 12. The compressor 3 compresses the oil and gas to obtain high-concentration oil and gas, which is then condensed into liquid oil by the condenser 4. The separation tank 1 is connected to an oil and gas inlet pipe 11, from which the oil and gas enters. The compressor 3 is connected to the oil and gas inlet pipe 11 via a make-up gas pipe 13. The recovery metering system includes:

[0052] Flow monitor 6, which is installed on the oil and gas feed pipe 11;

[0053] Oil and gas concentration monitoring instrument group 7, wherein the oil and gas concentration monitoring instruments in the oil and gas concentration monitoring instrument group 7 are respectively installed on the oil and gas feed pipe 11, the volatile gas pipe 12 and the gas replenishment pipe 13;

[0054] Temperature sensor group 8, wherein the temperature sensors in the temperature sensor group 8 are respectively installed on the oil and gas feed pipe 11 and the volatile gas pipe 12;

[0055] Regulating valve 5, the aforementioned regulating valve 5 is installed on the air supply pipe 13;

[0056] The data processing module is connected to the flow monitoring instrument 6, the oil and gas concentration monitoring instrument group 7, the temperature sensor group 8, and the regulating valve 5.

[0057] The data processing module described above performs the following steps:

[0058] Based on the oil and gas concentration collected by the oil and gas concentration monitoring instrument group 7 and the oil and gas temperature collected by the temperature sensor group 8, the opening of the regulating valve 5 is adjusted.

[0059] Based on the above oil and gas concentrations and the actual concentrations of high-concentration oil and gas, the concentration of mixed oil and gas entering separator 1 is determined.

[0060] Based on the oil and gas flow rate, mixed oil and gas concentration, and oil and gas temperature collected by the flow monitoring instrument 6, the amount of oil and gas recovered is determined.

[0061] By installing flow monitoring instruments 6, oil and gas concentration monitoring instruments 7, temperature sensors 8, regulating valves 5, and data processing modules at different locations such as the oil and gas feed pipe 11, volatile gas pipe 12, and make-up gas pipe 13, real-time monitoring of parameters such as oil and gas flow rate, concentration, and temperature is achieved. The data processing module first adjusts the opening of regulating valve 5 based on oil and gas concentration and temperature to control the oil and gas mixing process; then it determines the concentration of mixed oil and gas entering separator 1; finally, it determines the amount of oil and gas recovered based on flow rate, mixed oil and gas concentration, and temperature; and it uses real-time monitoring data to correct the equivalent coefficient, making the metering more consistent with actual conditions.

[0062] To collect the inlet air flow rate into the separator 1 in real time, the aforementioned flow monitoring instrument 6 is installed between the air supply pipe 13 and the separator 1.

[0063] Since the oil and gas concentrations vary in different parts of the oil and gas recovery unit, the oil and gas concentration monitoring instrument group 7 is set up at the following locations to collect the oil and gas concentrations in each part in real time:

[0064] The aforementioned oil and gas concentration monitoring instrument group 7 includes a first oil and gas concentration monitoring instrument 71, a second oil and gas concentration monitoring instrument 72, and a third oil and gas concentration monitoring instrument 73;

[0065] The aforementioned first oil and gas concentration monitor 71 is installed at the end of the oil and gas feed pipe 11 away from the separator 1; the first oil and gas concentration monitor 71 collects the intake gas concentration before oil and gas mixing in real time;

[0066] The aforementioned second oil and gas concentration monitor 72 is installed on the volatile gas pipe 12 between the condenser 4 and the oil storage tank 2; the exhaust gas concentration entering the oil storage tank 2 is collected in real time by the aforementioned second oil and gas concentration monitor 72.

[0067] The aforementioned third oil and gas concentration monitor 73 is installed on the gas supply pipe 13, and the actual concentration of high-concentration oil and gas fed into the oil and gas feed pipe 11 is collected in real time by the aforementioned third oil and gas concentration monitor 73.

[0068] To verify whether the concentration of the mixed oil and gas has reached the expected value, the oil and gas concentration monitoring instrument group 7 also includes a fourth oil and gas concentration monitoring instrument 74, which is installed on the oil and gas feed pipe 11 between the gas supply pipe 13 and the separator 1; the fourth oil and gas concentration monitoring instrument 74 collects the intake gas concentration after the oil and gas mixture in real time.

[0069] Since the temperature of the oil and gas affects the concentration of oil and gas at the current location, and the temperature of the oil and gas will change before and after recovery, temperature sensors are installed before and after recovery to detect the oil and gas temperature before and after recovery. Specifically, the temperature sensor group 8 includes a first temperature sensor 81 and a second temperature sensor 82;

[0070] The first temperature sensor 81 is installed on the oil and gas feed pipe 11 between the gas supply pipe 13 and the separator 1, and the second temperature sensor 82 is installed on the volatile gas pipe 12 between the condenser 4 and the oil storage tank 2. The first temperature sensor 81 is used to collect the intake temperature of the oil and gas mixture in real time, and the second temperature sensor 82 is used to collect the exhaust temperature of the oil storage tank 2 in real time.

[0071] Since atmospheric pressure also affects the concentration of oil and gas at the current location, the atmospheric pressure before and after recovery may be different. Therefore, pressure monitoring instruments are installed before and after recovery to detect the atmospheric pressure before and after recovery. The recovery metering system also includes a pressure monitoring instrument group 9, which includes a first pressure monitoring instrument 91 and a second pressure monitoring instrument 92.

[0072] The first pressure monitoring instrument 91 is installed on the oil and gas feed pipe 11, and the second pressure monitoring instrument 92 is installed on the volatile gas pipe 12 between the condenser 4 and the oil storage tank 2. The first pressure monitoring instrument 91 collects the first atmospheric pressure entering the separator 1 in real time, and the second pressure monitoring instrument 92 collects the second atmospheric pressure entering the oil storage tank 2 in real time.

[0073] The above-mentioned recovery metering system can use a recovery metering method based on an oil and gas recovery device, which includes the following steps:

[0074] Real-time acquisition of first atmospheric pressure, second atmospheric pressure, intake air flow rate, intake air concentration after oil-air mixture, intake air temperature, exhaust air concentration and exhaust air temperature;

[0075] Using the oil-gas equivalence coefficient function, based on the first atmospheric pressure, the second atmospheric pressure, the intake concentration, the exhaust concentration, the intake temperature, and the exhaust temperature, the oil-gas equivalence dynamic coefficient is determined.

[0076] The amount of oil and gas recovered is determined by using the above-mentioned intake flow rate, intake concentration, intake temperature, and oil and gas equivalent dynamic coefficient.

[0077] The oil and gas recovery rate is the amount of oil and gas recovered per unit time, calculated using the following formula: ,in, This indicates the amount of oil and gas recovered per unit time. Indicates the intake airflow; Indicates the concentration of the intake air after the oil and gas mixture; This indicates the intake air temperature after the oil and gas mixture is formed. This represents the dynamic coefficient of oil and gas equivalent.

[0078] Under ideal conditions, the amount of oil and gas recovered and the oil and gas processing efficiency are the same per unit time during the total oil delivery time of the day. The total amount of oil and gas recovered for the day can be calculated using the following formula: ,in, Indicates the total amount of oil and gas recovered; This indicates the total oil dispensing time for the day, i.e., the oil and gas recovery time. The oil and gas processing efficiency is expressed by the following formula: ,in, This indicates the concentration of exhaust gas.

[0079] Because the oil and gas equivalent coefficients are not constant under different operating conditions, dynamic coefficients of oil and gas equivalent under different operating conditions are determined based on real-time acquired parameters to make the measurement results more consistent with actual conditions. Specifically, this is achieved using an oil and gas equivalent coefficient function. ,in, This represents the correction factor. The fixed coefficient for oil and gas equivalent is represented; based on the aforementioned first atmospheric pressure, second atmospheric pressure, inlet gas concentration, exhaust gas concentration, inlet gas temperature, and exhaust gas temperature, the dynamic coefficient for oil and gas equivalent is determined, and the specific steps include:

[0080] Based on the first and second atmospheric pressures mentioned above, the function of oil and gas concentration changing with oil and gas temperature is called, and each atmospheric pressure corresponds to a unique function.

[0081] Based on the above variation function and intake temperature, the ideal intake concentration corresponding to the intake temperature at the first atmosphere pressure is determined.

[0082] Based on the above variation function and exhaust temperature, the ideal exhaust concentration corresponding to the exhaust temperature under the second atmosphere pressure is determined.

[0083] Based on the above ideal intake air concentration and actual intake air concentration, using Determine the intake air concentration deviation value, where, This indicates the intake air concentration deviation value; Indicates the ideal intake air concentration;

[0084] Based on the above ideal exhaust gas concentration and actual exhaust gas concentration, using Determine the exhaust gas concentration deviation value, where, This indicates the deviation value of exhaust gas concentration; Indicates the ideal exhaust gas concentration;

[0085] Based on the above ideal intake air concentration and ideal exhaust air concentration, using Determine the fixed coefficients for oil and gas equivalents, where, Indicates the oil and gas equivalent constant factor;

[0086] Using the above-mentioned intake air concentration deviation value and exhaust air concentration deviation value, Determine the correction factor, where, Indicates the correction factor;

[0087] Using the aforementioned oil and gas equivalent fixed coefficient and correction coefficient, Determine the dynamic coefficient of oil and gas equivalent.

[0088] In actual oil and gas recovery processes, the equivalence coefficient changes with atmospheric pressure, temperature, and concentration. The dynamic equivalence coefficient is determined based on multiple parameters such as the first atmospheric pressure, the second atmospheric pressure, the inlet flow rate, the inlet concentration after oil and gas mixing, the inlet temperature, the exhaust concentration, and the exhaust temperature, rather than using a fixed coefficient. Based on the parameters acquired in real time, the changes in the equivalence coefficient under different operating conditions are reflected, making the measurement results more consistent with the actual situation and thus improving the accuracy of the measurement. When determining the dynamic coefficient of oil and gas equivalent, firstly, the combined effects of atmospheric pressure and temperature on oil and gas concentration are considered, providing ideal reference values ​​for subsequent calculations. Then, by comparing the ideal intake concentration with the actual intake concentration, and the ideal exhaust concentration with the actual exhaust concentration, the intake concentration deviation and exhaust concentration deviation values ​​are determined. These deviation values ​​reflect the difference between the oil and gas concentration during actual operation and the ideal state, providing a basis for correcting the measurement results. Finally, a fixed coefficient of oil and gas equivalent is determined based on the ideal intake concentration and ideal exhaust concentration. This coefficient reflects the basic relationship of oil and gas equivalent under ideal conditions. Simultaneously, a correction coefficient is determined using the intake concentration deviation and exhaust concentration deviation values ​​to correct the fixed coefficient. Combining the basic relationship of oil and gas equivalent under ideal conditions with actual deviations not only reduces the calculation difficulty of the dynamic coefficient of oil and gas equivalent but also improves the accuracy of the coefficient, thereby improving the accuracy of oil and gas recovery calculations.

[0089] The specific embodiments described above further illustrate the purpose, technical solution, and beneficial effects of the present invention. It should be understood that the above description is only a specific embodiment of the present invention and is not intended to limit the scope of protection of the present invention. Any modifications, equivalent substitutions, improvements, etc., made within the spirit and principles of the present invention should be included within the scope of protection of the present invention.

Claims

1. A recovery metering system based on an oil and gas recovery device, the oil and gas recovery device comprising a separation tank (1) and an oil storage tank (2), the separation tank (1) and the oil storage tank (2) being connected by a volatile gas pipe (12), the volatile gas pipe (12) being equipped with a compressor (3) and a condenser (4), the compressor (3) compressing the oil and gas to obtain high-concentration oil and gas; the separation tank (1) being connected to an oil and gas feed pipe (11), the oil and gas entering from the oil and gas feed pipe (11); the compressor (3) being connected to the oil and gas feed pipe (11) via a gas replenishment pipe (13); characterized in that, The recycling metering system includes: A flow monitoring device (6) is installed on the oil and gas feed pipe (11); Oil and gas concentration monitoring instrument group (7), wherein the oil and gas concentration monitoring instruments in the oil and gas concentration monitoring instrument group (7) are respectively installed on the oil and gas feed pipe (11), the volatile gas pipe (12) and the gas replenishment pipe (13); Temperature sensor group (8), wherein the temperature sensors in the temperature sensor group (8) are respectively installed on the oil and gas feed pipe (11) and the volatile gas pipe (12); A regulating valve (5) is provided on the air supply pipe (13); The data processing module is connected to the flow monitor (6), the oil and gas concentration monitor group (7), the temperature sensor group (8) and the regulating valve (5); The data processing module performs the following steps: Based on the oil and gas concentration collected by the oil and gas concentration monitoring instrument group (7) and the oil and gas temperature collected by the temperature sensor group (8), the opening of the regulating valve (5) is adjusted. Based on the oil and gas concentration and the actual concentration of high-concentration oil and gas, the concentration of mixed oil and gas entering the separator (1) is determined; The amount of oil and gas recovered is determined by the intake air flow rate, intake air concentration, intake air temperature, and oil and gas equivalent dynamic coefficient, using the following formula: ， in, This indicates the amount of oil and gas recovered per unit time. Indicates the intake airflow; Indicates the concentration of the intake air after the oil and gas mixture; This indicates the intake air temperature after the oil and gas mixture is formed. Indicates the dynamic coefficient of oil and gas equivalent; The oil and gas concentration monitoring instrument group (7) includes a first oil and gas concentration monitoring instrument (71), a second oil and gas concentration monitoring instrument (72), and a third oil and gas concentration monitoring instrument (73); The first oil and gas concentration monitor (71) is set at the end of the oil and gas feed pipe (11) away from the separator (1); the first oil and gas concentration monitor (71) collects the intake gas concentration before oil and gas mixing in real time; The second oil and gas concentration monitor (72) is installed on the volatile gas pipe (12) between the condenser (4) and the oil storage tank (2); the exhaust gas concentration entering the oil storage tank (2) is collected in real time by the second oil and gas concentration monitor (72); The third oil and gas concentration monitor (73) is installed on the gas supply pipe (13), and the actual concentration of high-concentration oil and gas fed into the oil and gas feed pipe (11) is collected in real time by the third oil and gas concentration monitor (73). The oil and gas concentration monitoring instrument group (7) also includes a fourth oil and gas concentration monitoring instrument (74), which is installed on the oil and gas feed pipe (11) between the gas supply pipe (13) and the separator (1); the fourth oil and gas concentration monitoring instrument (74) collects the intake gas concentration after the oil and gas mixture in real time; The recycling metering system also includes a pressure monitoring instrument group (9), which includes a first pressure monitoring instrument (91) and a second pressure monitoring instrument (92); The first pressure monitor (91) is installed in the oil and gas feed pipe (11), and the second pressure monitor (92) is installed on the volatile gas pipe (12) between the condenser (4) and the oil storage tank (2). The first pressure monitor (91) collects the first atmospheric pressure entering the separator (1) in real time, and the second pressure monitor (92) collects the second atmospheric pressure entering the oil storage tank (2) in real time.

2. The recycling metering system according to claim 1, characterized in that, The flow monitoring instrument (6) is set between the air supply pipe (13) and the separator (1), and the flow monitoring instrument (6) collects the air flow rate entering the separator (1) in real time.

3. The recycling metering system according to claim 1, characterized in that, The temperature sensor group (8) includes a first temperature sensor (81) and a second temperature sensor (82); The first temperature sensor (81) is installed on the oil and gas feed pipe (11) between the gas supply pipe (13) and the separator (1), and the second temperature sensor (82) is installed on the volatile gas pipe (12) between the condenser (4) and the oil storage tank (2). The first temperature sensor (81) collects the intake temperature of the oil and gas mixture in real time, and the second temperature sensor (82) collects the exhaust temperature of the oil storage tank (2) in real time.

4. A recovery metering method based on an oil and gas recovery device, characterized in that, The recycling metering method employs the recycling metering system described in any one of claims 1 to 3; The recycling metering method includes the following steps: Real-time acquisition of first atmospheric pressure, second atmospheric pressure, intake air flow rate, intake air concentration after oil-air mixture, intake air temperature, exhaust air concentration and exhaust air temperature; Using the oil-gas equivalent coefficient function, the dynamic coefficient of oil-gas equivalent is determined based on the first atmospheric pressure, the second atmospheric pressure, the intake concentration, the exhaust concentration, the intake temperature, and the exhaust temperature. The amount of oil and gas recovered is determined by the intake flow rate, intake concentration, intake temperature, and oil and gas equivalent dynamic coefficient. Using the oil-gas equivalence coefficient function, based on the first atmospheric pressure, the second atmospheric pressure, the intake gas concentration, the exhaust gas concentration, the intake gas temperature, and the exhaust gas temperature, the dynamic coefficient of oil-gas equivalence is determined. The specific steps include: Based on the first atmospheric pressure and the second atmospheric pressure, respectively, call the function of oil and gas concentration changing with oil and gas temperature; Based on the aforementioned change function and the intake temperature, the ideal intake concentration corresponding to the intake temperature at the first atmosphere pressure is determined. Based on the aforementioned variation function and exhaust temperature, the ideal exhaust concentration corresponding to the exhaust temperature at the second atmosphere pressure is determined. The intake air concentration deviation value is determined by comparing the ideal intake air concentration with the actual intake air concentration. The exhaust concentration deviation value is determined by comparing the ideal exhaust concentration with the actual exhaust concentration. The oil-gas equivalent fixed coefficient is determined by the ideal intake concentration and the ideal exhaust concentration. The correction coefficient is determined based on the intake air concentration deviation value and the exhaust air concentration deviation value; The dynamic coefficient of oil and gas equivalent is determined by the fixed coefficient and correction coefficient of oil and gas equivalent.

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