Method and apparatus for measuring the flow rate of high-sulfur natural gas

Abstract

This invention discloses a method and apparatus for measuring the flow rate of high-sulfur natural gas, relating to the field of natural gas flow measurement technology. The system includes: a data acquisition device for acquiring flow detection data and sending it to a metering instrument selection device; determining a first metering pipeline to be used based on metering pipeline information sent by the metering instrument selection device; opening the first metering pipeline and acquiring first gas parameters of the natural gas in the first metering pipeline and first operating condition data of the first metering pipeline, sending them to a compressibility factor determination device; a metering instrument selection device for determining metering pipeline information based on the flow detection data and sending it to the data acquisition device; and a compressibility factor determination device for determining a first compressibility factor combination based on the first operating condition data; and determining the natural gas flow rate based on the first compressibility factor combination and the first gas parameters. This invention can improve the efficiency and accuracy of high-sulfur natural gas flow rate measurement.

Description

Technical Field

[0001] This invention relates to the field of natural gas flow measurement technology, and in particular to a method and apparatus for measuring the flow of high-sulfur natural gas. Background Technology

[0002] This section is intended to provide background or context for the embodiments of the invention set forth in the claims. The description herein is not an admission that it is prior art simply because it is included in this section.

[0003] Globally, high-sulfur natural gas reserves are vast and widely distributed. In recent years, natural gas, as a clean and environmentally friendly energy source, has been applied to all aspects of industrial production and daily life, and its development and utilization have become crucial in global energy production and consumption. The economic benefits of natural gas extraction, transportation, and sales are based on the quantitative measurement of the product. Ensuring the accuracy of measurement during natural gas trade has received increasing attention and raised higher requirements. With the rapid growth in demand for conventional natural gas and the decreasing reserves of conventional natural gas itself, the proportion of high-sulfur natural gas extraction is increasing, which also brings new challenges to the field of measurement.

[0004] Currently, there is a lack of effective methods and technologies for metering high-sulfur natural gas. In actual production processes, the metering methods and standards for conventional natural gas are directly applied. The most widely used flow meters on site are standard orifice plate flow meters and other types of flow meters. According to requirements, orifice plate flow meters need to be cleaned regularly to ensure their metering accuracy. For the production of high-sulfur natural gas, frequent cleaning and maintenance of orifice plate flow meters brings more safety risks and workload to the production site. Summary of the Invention

[0005] This invention provides a high-sulfur natural gas flow measurement system to improve the efficiency and accuracy of high-sulfur natural gas flow measurement, simplify the measurement operation process, reduce maintenance costs, and enhance measurement safety. The system includes: a data acquisition device, a metering instrument selection device, and a compressibility factor determination device. The data acquisition device includes: a verification flow meter, a first main pipeline, a second main pipeline, and a bypass pipeline.

[0006] The data acquisition device is used to send the first flow detection data collected by the verification flow meter and the second flow detection data collected by the first main pipeline to the metering instrument selection device; receive the metering pipeline information sent by the metering instrument selection device based on the first flow detection data and the second flow detection data; determine the first metering pipeline to be used from the first main pipeline, the second main pipeline, and the bypass pipeline based on the metering pipeline information; open the first metering pipeline, collect the first gas parameters of the natural gas in the first metering pipeline and the first operating condition data of the first metering pipeline; and send the first gas parameters and the first operating condition data to the compressibility factor determination device.

[0007] The metering instrument selection device is used to receive the first flow detection data and the second flow detection data sent by the data acquisition device; determine the metering pipeline information based on the first flow detection data and the second flow detection data; and send the metering pipeline information to the data acquisition device.

[0008] A compressibility factor determination device is used to receive first gas parameters and first operating condition data sent by a data acquisition device; determine a first compressibility factor combination based on the first operating condition data; and determine the natural gas flow rate based on the first compressibility factor combination and the first gas parameters.

[0009] This invention also provides a method for measuring the flow rate of high-sulfur natural gas, which improves the efficiency and accuracy of high-sulfur natural gas flow rate measurement, simplifies the measurement operation process, reduces maintenance costs, and enhances measurement safety. The method includes:

[0010] The data acquisition device sends the first flow detection data collected by the verification flow meter and the second flow detection data collected by the first main pipeline to the metering instrument selection device; receives the metering pipeline information sent by the metering instrument selection device based on the first flow detection data and the second flow detection data; determines the first metering pipeline to be used from the first main pipeline, the second main pipeline, and the bypass pipeline based on the metering pipeline information; opens the first metering pipeline, collects the first gas parameters of the natural gas in the first metering pipeline and the first operating condition data of the first metering pipeline; and sends the first gas parameters and the first operating condition data to the compressibility factor determination device.

[0011] The metering instrument selection device receives the first flow detection data and the second flow detection data sent by the data acquisition device; determines the metering pipeline information based on the first flow detection data and the second flow detection data; and sends the metering pipeline information to the data acquisition device.

[0012] The compressibility factor determination device receives first gas parameters and first operating condition data sent by the data acquisition device; determines a first compressibility factor combination based on the first operating condition data; and determines the natural gas flow rate based on the first compressibility factor combination and the first gas parameters.

[0013] This invention also provides a high-sulfur natural gas flow measurement device to improve the efficiency and accuracy of high-sulfur natural gas flow measurement, simplify the measurement operation process, reduce maintenance costs, and enhance measurement safety. The device includes:

[0014] The data acquisition module is used to send the first flow detection data collected by the verification flow meter and the second flow detection data collected by the first main pipeline to the metering instrument selection module; receive the metering pipeline information sent by the metering instrument selection module based on the first flow detection data and the second flow detection data; determine the first metering pipeline to be used from the first main pipeline, the second main pipeline, and the bypass pipeline based on the metering pipeline information; start the first metering pipeline, collect the first gas parameters of the natural gas in the first metering pipeline and the first operating condition data of the first metering pipeline; and send the first gas parameters and the first operating condition data to the compressibility factor determination module.

[0015] The metering instrument selection module is used to receive the first flow detection data and the second flow detection data sent by the data acquisition module; determine the metering pipeline information based on the first flow detection data and the second flow detection data; and send the metering pipeline information to the data acquisition module.

[0016] The compressibility factor determination module is used to receive the first gas parameters and the first operating condition data sent by the data acquisition module; determine the first compressibility factor combination based on the first operating condition data; and determine the natural gas flow rate based on the first compressibility factor combination and the first gas parameters.

[0017] This invention also provides a computer device, including a memory, a processor, and a computer program stored in the memory and executable on the processor. When the processor executes the computer program, it implements the above-described method for measuring the flow rate of high-sulfur natural gas.

[0018] This invention also provides a computer-readable storage medium storing a computer program that, when executed by a processor, implements the above-described method for measuring the flow rate of high-sulfur natural gas.

[0019] This invention also provides a computer program product, which includes a computer program that, when executed by a processor, implements the above-described high-sulfur natural gas flow measurement method.

[0020] In this embodiment of the invention, a high-sulfur natural gas flow measurement system includes: a compressibility factor determination device, a metering instrument selection device, and a data acquisition device. The data acquisition device includes: a verification flow meter, a first main pipeline, a second main pipeline, and a bypass pipeline. The data acquisition device is used to send first flow detection data collected by the verification flow meter and second flow detection data collected by the first main pipeline to the metering instrument selection device; receive metering pipeline information sent by the metering instrument selection device based on the first flow detection data and the second flow detection data; determine the first metering pipeline to be used from the first main pipeline, the second main pipeline, and the bypass pipeline based on the metering pipeline information; and open the first metering pipeline. The system collects first gas parameters and first operating condition data of the natural gas in the first metering pipeline; sends the first gas parameters and first operating condition data to a compressibility factor determination device; a metering instrument selection device receives first flow detection data and second flow detection data sent by the data acquisition device; determines the metering pipeline information based on the first flow detection data and second flow detection data; and sends the metering pipeline information to the data acquisition device; the compressibility factor determination device receives the first gas parameters and first operating condition data sent by the data acquisition device; determines a first compressibility factor combination based on the first operating condition data; and determines the natural gas flow rate based on the first compressibility factor combination and the first gas parameters. This allows for flexible adjustment and selection of the metering pipeline based on flow detection data, and then determines the natural gas flow rate based on the operating condition data of the metering pipeline and the gas parameters. This improves the efficiency and accuracy of high-sulfur natural gas flow measurement, simplifies the measurement operation process, reduces maintenance costs, and enhances measurement safety. Attached Figure Description

[0021] To more clearly illustrate the technical solutions in the embodiments of the present invention or the prior art, the drawings used in the description of the embodiments or the prior art will be briefly introduced below. Obviously, the drawings described below are only some embodiments of the present invention. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort. In the drawings:

[0022] Figure 1 This is a schematic diagram of a high-sulfur natural gas flow measurement system provided in an embodiment of the present invention;

[0023] Figure 2 This is a schematic diagram of a high-sulfur natural gas flow measurement system provided in an embodiment of the present invention;

[0024] Figure 3 This is a comprehensive structural diagram of a high-sulfur natural gas flow measurement system provided in an embodiment of the present invention;

[0025] Figure 4This is a flowchart of a method for measuring the flow rate of high-sulfur natural gas provided in an embodiment of the present invention;

[0026] Figure 5 A flowchart of a high-sulfur natural gas flow measurement device provided in an embodiment of the present invention.

[0027] Figure 6 This is a schematic diagram of a computer device provided in an embodiment of the present invention. Detailed Implementation

[0028] To make the objectives, technical solutions, and advantages of the embodiments of the present invention clearer, the embodiments of the present invention will be further described in detail below with reference to the accompanying drawings. Here, the illustrative embodiments of the present invention and their descriptions are used to explain the present invention, but are not intended to limit the present invention.

[0029] The acquisition, storage, use, and processing of data in this application comply with relevant laws and regulations.

[0030] In this document, the term "and / or" merely describes a relationship, indicating that three relationships can exist. For example, A and / or B can represent three cases: A alone, A and B simultaneously, and B alone. Furthermore, the term "at least one" in this document means any combination of at least two of any one or more elements. For example, including at least one of A, B, and C can mean including any one or more elements selected from the set consisting of A, B, and C.

[0031] In the description of this specification, the terms "comprising," "including," "having," and "containing" are open-ended terms, meaning that they include but are not limited to. The terms "an embodiment," "a specific embodiment," "some embodiments," and "for example," etc., refer to specific features, structures, or characteristics described in connection with that embodiment or example that are included in at least one embodiment or example of this application. In this specification, the illustrative expressions of the above terms do not necessarily refer to the same embodiment or example. Furthermore, the specific features, structures, or characteristics described can be combined in any suitable manner in one or more embodiments or examples. The order of steps involved in the various embodiments is used to illustrate the implementation of this application, and the order of steps is not limited and can be adjusted appropriately as needed.

[0032] Research has revealed that with the rapid increase in demand for natural gas and the decreasing reserves of conventional natural gas, the proportion of extraction and transportation of high-sulfur natural gas reservoirs is increasing. High-sulfur natural gas is generally characterized by a hydrogen sulfide (H2S) volume fraction of 2%–10% or a mass content of 30 g / m³–150 g / m³. In actual production, the metering methods and standards for high-sulfur natural gas are directly applied to those for conventional natural gas. The most widely used flow meters in the field are standard orifice plate flow meters and other types of flow meters. Orifice plate flow meters require regular cleaning to ensure accurate measurement. However, for the production of high-sulfur natural gas, frequent cleaning and maintenance of orifice plate flow meters introduces more safety risks and workload to the production site.

[0033] Currently, the compressibility factor of purified natural gas can be directly measured on-site using equipment. However, in high-sulfur natural gas, the hydrogen sulfide content increases, making it impossible for existing sensing equipment to measure accurately. For example, chromatographic analyzers commonly used in purified gas cannot detect sulfur, and sulfur measurement requires specialized equipment. Moreover, to ensure safety (hydrogen sulfide leaks pose a significant hazard to humans), equipment with higher safety standards must be used, increasing equipment costs. Therefore, how to quickly and conveniently measure the flow rate of high-sulfur natural gas under on-site working conditions has become an urgent problem to be solved.

[0034] Regarding the above research, such as Figure 1 As shown, this embodiment of the invention provides a high-sulfur natural gas flow measurement system, including: a data acquisition device 11, a metering instrument selection device 12, and a compressibility factor determination device 13. See details below. Figure 2 As shown, the data acquisition device 11 includes: a verification flow meter 11-4, a first main pipe G1, a second main pipe G2, and a bypass pipe G3;

[0035] The data acquisition device 11 is used to send the first flow detection data collected by the verification flow meter and the second flow detection data collected by the first main pipeline to the metering instrument selection device; receive the metering pipeline information sent by the metering instrument selection device based on the first flow detection data and the second flow detection data; determine the first metering pipeline to be used from the first main pipeline, the second main pipeline, and the bypass pipeline based on the metering pipeline information; open the first metering pipeline, collect the first gas parameters of the natural gas in the first metering pipeline and the first operating condition data of the first metering pipeline; and send the first gas parameters and the first operating condition data to the compressibility factor determination device.

[0036] The metering instrument selection device 12 is used to receive the first flow detection data and the second flow detection data sent by the data acquisition device; determine the metering pipeline information based on the first flow detection data and the second flow detection data; and send the metering pipeline information to the data acquisition device.

[0037] The compressibility factor determining device 13 is used to receive first gas parameters and first operating condition data sent by the data acquisition device; determine a first compressibility factor combination based on the first operating condition data; and determine the natural gas flow rate based on the first compressibility factor combination and the first gas parameters.

[0038] In this embodiment of the invention, a high-sulfur natural gas flow measurement system includes: a compressibility factor determination device, a metering instrument selection device, and a data acquisition device. The data acquisition device includes: a verification flow meter, a first main pipeline, a second main pipeline, and a bypass pipeline. The data acquisition device is used to send first flow detection data collected by the verification flow meter and second flow detection data collected by the first main pipeline to the metering instrument selection device; receive metering pipeline information sent by the metering instrument selection device based on the first flow detection data and the second flow detection data; determine the first metering pipeline to be used from the first main pipeline, the second main pipeline, and the bypass pipeline based on the metering pipeline information; and open the first metering pipeline. The system collects first gas parameters and first operating condition data of the natural gas in the first metering pipeline; sends the first gas parameters and first operating condition data to a compressibility factor determination device; a metering instrument selection device receives first flow detection data and second flow detection data sent by the data acquisition device; determines the metering pipeline information based on the first flow detection data and second flow detection data; and sends the metering pipeline information to the data acquisition device; the compressibility factor determination device receives the first gas parameters and first operating condition data sent by the data acquisition device; determines a first compressibility factor combination based on the first operating condition data; and determines the natural gas flow rate based on the first compressibility factor combination and the first gas parameters. This allows for flexible adjustment and selection of the metering pipeline based on flow detection data, and then determines the natural gas flow rate based on the operating condition data of the metering pipeline and the gas parameters. This improves the efficiency and accuracy of high-sulfur natural gas flow measurement, simplifies the measurement operation process, reduces maintenance costs, and enhances measurement safety.

[0039] The above-mentioned high-sulfur natural gas flow measurement system will be described in detail below.

[0040] like Figure 2The diagram shows a structural schematic of a high-sulfur natural gas flow measurement system according to an embodiment of the present invention. A first main pipeline G1, a second main pipeline G2, and a bypass pipeline G3 are connected in parallel. A gas component measuring instrument (not shown) is installed at the intersection of the first main pipeline, the second main pipeline, and the bypass pipeline. The gas component measuring instrument is used to measure the gas parameters of the natural gas in the first metering pipeline. The first main pipeline G1 is equipped with a first inlet valve 11-6, a first outlet valve 11-10, and a first flow meter 11-8 located between the first inlet valve 11-6 and the first outlet valve 11-10. The second main pipeline G2 is equipped with a second inlet valve 11-11, a second outlet valve 11-15, and a second flow meter 11-13 located between the second inlet valve 11-11 and the second outlet valve 11-15. The bypass pipeline G3 is equipped with a third inlet valve 11-16 and a third outlet valve 11-17. The second flow detection data is the flow data collected by the first flow meter 11-8.

[0041] In one embodiment of the present invention, the first inlet valve, the first outlet valve, the second inlet valve, the second outlet valve, the third inlet valve, and the third outlet valve are hydraulic gate valves.

[0042] In another embodiment of the present invention, the first inlet valve, the first outlet valve, the second inlet valve, the second outlet valve, the third inlet valve, and the third outlet valve are electric gate valves.

[0043] In another embodiment of the present invention, the first inlet valve, the first outlet valve, the second inlet valve, the second outlet valve, the third inlet valve, and the third outlet valve are pneumatic gate valves.

[0044] Additionally, refer to Figure 2 As shown, in one embodiment of the present invention, the first main pipeline G1 is further provided with a first pressure measuring unit 11-7 and a first temperature measuring unit 11-9; the second main pipeline G2 is further provided with a second pressure measuring unit 11-12 and a second temperature measuring unit 11-14; a third pressure measuring unit 11-3 is further provided on one side of the flow meter 11-4, and a third temperature measuring unit 11-5 is further provided on the other side of the flow meter 11-4.

[0045] Reference Figure 3The diagram shown is a comprehensive structural diagram of a high-sulfur natural gas flow measurement system provided in an embodiment of the present invention. The first inlet valve 11-6 and the first outlet valve 11-10 constitute the first control unit. The first inlet valve 11-6, the first outlet valve 11-10, the first flow meter 11-8, the first pressure measurement unit 11-7, and the first temperature measurement unit 11-9 constitute the first main pipeline G1. The second inlet valve 11-11 and the second outlet valve 11-15 constitute the second control unit. The second inlet valve 11-11, the second outlet valve 11-15, the second flow meter 11-13, the second pressure measurement unit 11-12, and the second temperature measurement unit 11-14 constitute the second main pipeline G2. The third inlet valve 11-16 and the third outlet valve 11-17 can constitute the third control unit and the bypass pipeline G3. The verification flow meter 11-4, the third pressure measurement unit 11-3, and the third temperature measurement unit 11-5 constitute the verification device.

[0046] In one embodiment of the present invention, the flow meter to be checked includes: an externally clamped ultrasonic flow meter or other flow meters with a relatively wide range. The first flow meter and the second flow meter include mass flow meters, specifically including flow meters commonly used in on-site production processes, or other types of flow meters, which are not limited in the embodiments of this specification.

[0047] In addition, refer to Figure 2 As shown, the high-sulfur natural gas flow measurement system can also be equipped with a filter 11-1 and a heater 11-2. The filter 11-1 and the heater 11-2 are used to ensure the stable transportation of high-sulfur natural gas and prevent the generation of elemental sulfur and hydrates in the pipeline.

[0048] During initial operation, the first main pipe is opened, the second main pipe and the bypass pipe are closed. The verification flow meter 11-4 in the data acquisition device 11 collects the first flow detection data, and the first flow meter 11-8 in the first main pipe G1 collects the second flow detection data. The data acquisition device 11 sends the first flow detection data and the second flow detection data to the metering instrument selection device 12.

[0049] The metering instrument selection device 12 receives the first flow detection data and the second flow detection data sent by the data acquisition device 11; and determines the metering pipeline information based on the first flow detection data and the second flow detection data.

[0050] Specifically, when the metering instrument selection device 12 determines the metering pipeline information based on the first flow detection data and the second flow detection data, there are two implementation methods: ① and ②.

[0051] ①: Metering instrument selection device 12 determines the first flow difference between the first flow detection data and the second flow detection data; when the first flow difference is less than or equal to the preset deviation value, it determines the metering pipeline information as: the first main pipeline is open, the second main pipeline is closed, and the bypass pipeline is closed; and sends the metering pipeline information to the data acquisition device 11.

[0052] In implementation method ①, the data acquisition device 11 receives metering pipeline information sent by the metering instrument selection device 12; based on the metering pipeline information, the first main pipeline G1 is identified as the first metering pipeline, the first inlet valve 11-6 and the first outlet valve 11-10 are opened, and the second inlet valve 11-11, the second outlet valve 11-15, the third inlet valve 11-16, and the third outlet valve 11-17 are closed; the first operating condition data of the first metering pipeline is collected using the first pressure measuring unit 11-7 and the first temperature measuring unit 11-9, and the first gas parameters of natural gas are collected using the gas component measuring instrument.

[0053] ②: Metering instrument selection device 12 determines the first flow difference between the first flow detection data and the second flow detection data; when the first flow difference is greater than the preset deviation value, it determines the metering pipeline information as follows: the first main pipeline is closed, the second main pipeline is open, and the bypass pipeline is closed; and sends the metering pipeline information to the data acquisition device 11.

[0054] In embodiment ②, the data acquisition device 11 receives the metering pipeline information sent by the metering instrument selection device 12; based on the metering pipeline information, the second main pipeline is identified as the first metering pipeline, the second inlet valve 11-11 and the second outlet valve 11-15 are opened, and the first inlet valve 11-6, the first outlet valve 11-10, the third inlet valve 11-16, and the third outlet valve 11-17 are closed; the first operating condition data of the first metering pipeline is collected using the second pressure measuring unit 11-12 and the second temperature measuring unit 11-14, and the first gas parameters of natural gas are collected using the gas component measuring instrument.

[0055] The data acquisition device 11 sends the acquired first operating condition data and the first gas parameters of natural gas to the compressibility factor determination device 13. The compressibility factor determination device 13 receives the first gas parameters and the first operating condition data sent by the data acquisition device 11; determines the first compressibility factor combination based on the first operating condition data; and determines the natural gas flow rate based on the first compressibility factor combination and the first gas parameters.

[0056] Specifically, when the data acquisition device 11 acquires the first gas parameters of natural gas in the first metering pipeline and the first operating condition data of the first metering pipeline, it performs multiple samplings to obtain multiple sampling combinations of the first gas parameters and the first operating condition data; and sends the multiple sampling combinations to the compressibility factor determination device 13.

[0057] Compression factor determination device 13 receives multiple sampling combinations sent by data acquisition device 11; acquires a set of compression factor formulas; determines the test curve corresponding to each compression factor formula in the set of compression factor formulas based on the multiple sampling combinations; combines the various compression factor formulas in the set of compression factor formulas to obtain multiple compression factor formula combinations and a set of test curves corresponding to each compression factor formula combination; determines the sum of similarities between any two test curves in each set of test curves based on the similarity between any two test curves in each set of test curves; and determines the compression factor formula combination corresponding to the set of test curves with the smallest sum of similarity as the first compression factor combination.

[0058] Furthermore, to further improve the accuracy of the measurement, the high-sulfur natural gas flow measurement system can also adjust the opened metering pipelines (first main pipeline, second main pipeline, and bypass pipeline) in real time based on the third flow detection data in the current first metering pipeline during the measurement process. Therefore, in another embodiment of the present invention, the data acquisition device 11 is also used to acquire the third flow detection data of the first metering pipeline; send the third flow detection data to the metering instrument selection device 12; receive the metering pipeline information updated by the metering instrument selection device 12 based on the third flow detection data and the first flow detection data; update the first metering pipeline based on the updated metering pipeline information; acquire the second gas parameters of the natural gas in the updated first metering pipeline and the second operating condition data of the updated first metering pipeline; and send the second gas parameters and the second operating condition data to the compressibility factor determination device 13.

[0059] The metering instrument selection device 12 is also used to receive the third flow detection data sent by the data acquisition device 11, update the metering pipeline information according to the first flow detection data and the third flow detection data, and send the updated metering pipeline information to the data acquisition device 11 so that the data acquisition device 11 can update the first metering pipeline according to the updated metering pipeline information.

[0060] The compressibility factor determining device 13 is also used to receive the second gas parameters and the second operating condition data sent by the data acquisition device 11, determine the second compressibility factor combination based on the second operating condition data, and determine the natural gas flow rate based on the second compressibility factor combination and the second gas parameters.

[0061] Specifically, when the first metering pipe is the first main pipe G1, the data acquisition device 11 uses the first flow meter 11-8 to collect the third flow detection data, and when the first metering pipe is the second main pipe G2, it uses the second flow meter 11-13 to collect the third flow detection data.

[0062] In this embodiment of the invention, when the metering instrument selection device 12 updates the metering pipeline information based on the first flow detection data and the third flow detection data, there may be six implementation scenarios as follows (1) to (6):

[0063] (1): When the second flow difference between the third flow detection data collected by the first flow meter 11-8 and the first flow detection data is less than or equal to the preset deviation value, the metering pipeline information is updated as follows: the first main pipeline is open G1, the second main pipeline is closed G2, and the bypass pipeline is closed G3.

[0064] In implementation method (1), the first metering pipe used before the update is the first main pipe. Therefore, the third flow detection data is the flow data collected by the first flow meter 11-8. When the second flow difference is less than or equal to the preset deviation value, the updated first metering pipe is still the first main pipe G1.

[0065] Therefore, in implementation (1), the data acquisition device 11 determines the first main pipeline G1 as the first metering pipeline according to the updated metering pipeline information, opens the first inlet valve 11-6 and the first outlet valve 11-10, and closes the second inlet valve 11-11, the second outlet valve 11-15, the third inlet valve 11-16, and the third outlet valve 11-17; it uses the first pressure measuring unit 11-7 and the first temperature measuring unit 11-9 to collect the second operating condition data of the first metering pipeline, uses the gas component measuring instrument to collect the second gas parameters of natural gas, and continues to use the first flow meter 11-8 to collect the third flow detection data.

[0066] (2): When the difference between the second flow rate and the third flow rate detection data collected by the first flow meter 11-8 is greater than the preset deviation value, the metering pipeline information is updated as follows: the first main pipeline G1 is closed, the second main pipeline G2 is open, and the bypass pipeline G3 is closed.

[0067] In implementation method (2), the first metering pipe used before the update is the first main pipe G1. Therefore, the third flow detection data is the flow data collected by the first flow meter 11-8. When the second flow difference is greater than the preset deviation value, the updated first metering pipe is the second main pipe.

[0068] Therefore, in implementation (2), the data acquisition device 11 determines the second main pipeline G2 as the first metering pipeline based on the updated metering pipeline information, opens the second inlet valve 11-11 and the second outlet valve 11-15, and closes the first inlet valve 11-6, the first outlet valve 11-10, the third inlet valve 11-16, and the third outlet valve 11-17; it uses the second pressure measuring unit 11-12 and the second temperature measuring unit 11-14 to collect the second operating condition data of the first metering pipeline, uses the gas component measuring instrument to collect the second gas parameters of natural gas, and uses the second flow meter 11-13 to collect the third flow detection data.

[0069] (3): When the difference between the third flow detection data collected by the second flow meter 11-13 and the first flow detection data is less than or equal to the preset deviation, the metering pipeline information is updated as follows: the first main pipeline G1 is closed, the second main pipeline G2 is open, and the bypass pipeline G3 is closed.

[0070] In implementation method (3), the first metering pipe used before the update is the second main pipe G2 (for example, the first metering pipe was changed from the first main pipe G1 to the second main pipe G2 after adjustment, and the first metering pipe was updated again according to the third flow detection data detected by the second main pipe G2). Therefore, the third flow detection data is the flow data collected by the second flow meter 11-13. When the second flow difference is less than or equal to the preset deviation, the updated first metering pipe continues to use the second main pipe G2.

[0071] Therefore, in implementation (3), the data acquisition device 11 determines the second main pipeline G2 as the first metering pipeline based on the updated metering pipeline information, opens the second inlet valve 11-11 and the second outlet valve 11-15, and closes the first inlet valve 11-6, the first outlet valve 11-10, the third inlet valve 11-16, and the third outlet valve 11-17; using the second operating condition data of the first metering pipeline from the second pressure measuring unit 11-12 and the second temperature measuring unit 11-14, the second gas parameters of natural gas are collected using the gas component measuring instrument, and the third flow detection data is collected using the second flow meter 11-13.

[0072] (4): When the difference between the third flow detection data collected by the second flow meter 11-13 and the first flow detection data is greater than the preset deviation, the metering pipeline information is updated as follows: the first main pipeline G1 is closed, the second main pipeline G2 is closed, and the bypass pipeline G3 is open.

[0073] In implementation method (4), the first metering pipe used before the update is the second main pipe G2 (for example, the first metering pipe was changed from the first main pipe G1 to the second main pipe G2 after adjustment, and the first metering pipe was updated again according to the third flow detection data detected by the second main pipe G2). Therefore, the third flow detection data is the flow data collected by the second flow meter 11-13. When the second flow difference is greater than the preset deviation, the updated first metering pipe is the bypass pipe G3.

[0074] Therefore, in implementation (4), the data acquisition device 11 determines the bypass pipeline G3 as the first metering pipeline based on the updated metering pipeline information, opens the third inlet valve 11-16 and the third outlet valve 11-17, and closes the first inlet valve 11-6, the first outlet valve 11-10, the second inlet valve 11-11 and the second outlet valve 11-15; it uses the third pressure measurement unit 11-3 and the third temperature measurement unit 11-5 to collect the second operating condition data of the first metering pipeline, and uses the gas component measuring instrument to collect the second gas parameters of natural gas.

[0075] The preset deviation described in this embodiment of the invention can be configured in combination with actual application scenarios. In a preferred embodiment, the preset deviation can be 1%-2%.

[0076] (5): The metering instrument selection device 12 is also used to update the metering pipeline information as follows when the bypass pipeline G3 is open and the first flow detection data is not greater than the preset flow data: the first main pipeline G1 is closed, the second main pipeline G2 is closed, and the bypass pipeline G3 is open; and send the updated metering pipeline information to the data acquisition device 11.

[0077] In implementation method (5), the first metering pipe used before the update is the bypass pipe G3 (for example, the first metering pipe was changed from the first main pipe G1 to the second main pipe G2 after adjustment, and then changed to the bypass pipe G3. The first metering pipe is updated again according to the first flow detection data detected by the flow meter). Therefore, when the first flow detection data is not greater than the preset flow data, the updated first metering pipe continues to use the bypass pipe G3.

[0078] Therefore, in implementation (5), the data acquisition device 11 receives updated metering pipeline information sent by the metering instrument selection device 12; based on the updated metering pipeline information, the bypass pipeline G3 is identified as the first metering pipeline, the third inlet valve 11-16 and the third outlet valve 11-17 are opened, and the first inlet valve 11-6, the first outlet valve 11-10, the second inlet valve 11-11, and the second outlet valve 11-15 are closed; the second operating condition data of the first metering pipeline is collected using the third pressure measurement unit 11-3 and the third temperature measurement unit 11-5, and the second gas parameters of natural gas are collected using the gas composition measuring instrument.

[0079] (6): The metering instrument selection device 12 is also used to update the metering pipeline information as follows when the bypass pipeline G3 is open and the first flow detection data is stable and greater than the preset flow data: the first main pipeline G1 is open, the second main pipeline G2 is open, and the bypass pipeline G3 is closed; and send the updated metering pipeline information to the data acquisition device 11.

[0080] In implementation method (6), the first metering pipe used before the update is the bypass pipe G3 (for example, the first metering pipe was changed from the first main pipe G1 to the second main pipe G2 after adjustment, and then changed to the bypass pipe G3. The first metering pipe is updated again according to the first flow detection data detected by the flow meter). Therefore, when the first flow detection data is stable and greater than the preset flow data, the updated first metering pipe uses both the first main pipe G1 and the second main pipe G2.

[0081] Therefore, in implementation (6), the data acquisition device 11 is also used to receive updated metering pipeline information sent by the metering instrument selection device 12; determine the first main pipeline G1 and the second main pipeline G2 as the first metering pipeline according to the updated metering pipeline information, close the third inlet valve 11-16 and the third outlet valve 11-17, and open the first inlet valve 11-6, the first outlet valve 11-10, the second inlet valve 11-11, and the second outlet valve 11-15; collect the second operating condition data of the first metering pipeline using the first pressure measuring unit 11-7, the first temperature measuring unit 11-9, the second pressure measuring unit 11-12, and the second temperature measuring unit 11-14, and collect the second gas parameters of natural gas using the gas component measuring instrument.

[0082] When updating the metering pipeline information, the updated metering pipeline information can be determined based on the consistency with the above-mentioned implementation methods (1) to (6), and the first metering pipeline can be updated based on the updated metering pipeline information.

[0083] In this embodiment of the invention, multiple flow meters, a pressure measurement unit, and a temperature measurement unit are included, and the multiple flow meters are of different types. Different types of flow meters have different measurement accuracies and measurement focus dimensions, so using different types of flow meters can further offset the measurement defects of each flow meter.

[0084] This invention also provides a method for measuring the flow rate of high-sulfur natural gas, as described in the following embodiments. Since the principle underlying this method is similar to that of the high-sulfur natural gas flow rate measurement system, the implementation of this method can refer to the implementation of the high-sulfur natural gas flow rate measurement system; repeated details will not be elaborated further.

[0085] like Figure 4 The flowchart shown is a method for measuring the flow rate of high-sulfur natural gas according to an embodiment of the present invention, including:

[0086] S401: The data acquisition device sends the first flow detection data collected by the verification flow meter and the second flow detection data collected by the first main pipeline to the metering instrument selection device; receives the metering pipeline information sent by the metering instrument selection device based on the first flow detection data and the second flow detection data; determines the first metering pipeline to be used from the first main pipeline, the second main pipeline, and the bypass pipeline based on the metering pipeline information; opens the first metering pipeline, collects the first gas parameters of the natural gas in the first metering pipeline and the first operating condition data of the first metering pipeline; and sends the first gas parameters and the first operating condition data to the compressibility factor determination device.

[0087] S402: The metering instrument selection device receives the first flow detection data and the second flow detection data sent by the data acquisition device; determines the metering pipeline information based on the first flow detection data and the second flow detection data; and sends the metering pipeline information to the data acquisition device.

[0088] S403: The compressibility factor determination device receives the first gas parameters and the first operating condition data sent by the data acquisition device; determines the first compressibility factor combination based on the first operating condition data; and determines the natural gas flow rate based on the first compressibility factor combination and the first gas parameters.

[0089] In one possible implementation, the metering instrument selection device determines the metering pipeline information based on the first flow detection data and the second flow detection data, including: the metering instrument selection device determines a first flow difference between the first flow detection data and the second flow detection data; when the first flow difference is less than or equal to a preset deviation value, the metering pipeline information is determined to be: the first main pipeline is open, the second main pipeline is closed, and the bypass pipeline is closed.

[0090] The data acquisition device determines the first metering pipeline to be used from the first main pipeline, the second main pipeline, and the bypass pipeline based on the metering pipeline information; it then opens the first metering pipeline and collects the first gas parameters of the natural gas in the first metering pipeline and the first operating condition data of the first metering pipeline, including: the data acquisition device determines the first main pipeline as the first metering pipeline based on the metering pipeline information, opens the first inlet valve and the first outlet valve, and closes the second inlet valve, the second outlet valve, the third inlet valve, and the third outlet valve; it collects the first operating condition data of the first metering pipeline using the first pressure measurement unit and the first temperature measurement unit, and collects the first gas parameters of the natural gas using a gas composition analyzer.

[0091] In one possible implementation, the metering instrument selection device determines metering pipeline information based on the first flow detection data and the second flow detection data, including: the metering instrument selection device is specifically used to determine a first flow difference between the first flow detection data and the second flow detection data; when the first flow difference is greater than a preset deviation value, the metering pipeline information is determined to be: the first main pipeline is closed, the second main pipeline is open, and the bypass pipeline is closed;

[0092] The data acquisition device determines the first metering pipeline to be used from the first main pipeline, the second main pipeline, and the bypass pipeline based on the metering pipeline information; it then opens the first metering pipeline and collects the first gas parameters of the natural gas in the first metering pipeline and the first operating condition data of the first metering pipeline, including: the data acquisition device determines the second main pipeline as the first metering pipeline based on the metering pipeline information, opens the second inlet valve and the second outlet valve, and closes the first inlet valve, the first outlet valve, the third inlet valve, and the third outlet valve; it collects the first operating condition data of the first metering pipeline using the second pressure measurement unit and the second temperature measurement unit, and collects the first gas parameters of the natural gas using a gas composition analyzer.

[0093] In one possible implementation, the method further includes: a data acquisition device acquiring third flow detection data of the first metering pipeline; sending the third flow detection data to a metering instrument selection device, receiving metering pipeline information updated by the metering instrument selection device based on the third flow detection data and the first flow detection data, and updating the first metering pipeline based on the updated metering pipeline information; acquiring second gas parameters of natural gas in the updated first metering pipeline and second operating condition data of the updated first metering pipeline; and sending the second gas parameters and second operating condition data to a compressibility factor determination device.

[0094] The metering instrument selection device receives the third flow detection data sent by the data acquisition device, updates the metering pipeline information based on the first flow detection data and the third flow detection data, and sends the updated metering pipeline information to the data acquisition device so that the data acquisition device can update the first metering pipeline based on the updated metering pipeline information.

[0095] The compressibility factor determination device receives the second gas parameters and the second operating condition data sent by the data acquisition device, determines the second compressibility factor combination based on the second operating condition data, and determines the natural gas flow rate based on the second compressibility factor combination and the second gas parameters.

[0096] In one possible implementation, the data acquisition device acquires third flow detection data of the first metering pipeline, including: when the first metering pipeline is a first main pipeline, the data acquisition device acquires third flow detection data using a first flow meter; when the first metering pipeline is a second main pipeline, the data acquisition device acquires third flow detection data using a second flow meter.

[0097] In one possible implementation, the metering instrument selection device updates the metering pipeline information based on the first flow detection data and the third flow detection data, including: when the second flow difference between the third flow detection data collected by the first flow meter and the first flow detection data is less than or equal to a preset deviation value, the metering instrument selection device updates the metering pipeline information to: the first main pipeline is open, the second main pipeline is closed, and the bypass pipeline is closed.

[0098] The data acquisition device updates the first metering pipeline according to the updated metering pipeline information; it collects the second gas parameters of natural gas in the updated first metering pipeline and the second operating condition data of the updated first metering pipeline, including: the data acquisition device identifies the first main pipeline as the first metering pipeline according to the updated metering pipeline information, opens the first inlet valve and the first outlet valve, and closes the second inlet valve, the second outlet valve, the third inlet valve, and the third outlet valve; it collects the second operating condition data of the first metering pipeline using the first pressure measurement unit and the first temperature measurement unit, collects the second gas parameters of natural gas using the gas component measuring instrument, and continues to collect the third flow detection data using the first flow meter.

[0099] In one possible implementation, the metering instrument selection device updates the metering pipeline information based on the first flow detection data and the third flow detection data, including: the metering instrument selection device is specifically used to update the metering pipeline information as follows: the first main pipeline is closed, the second main pipeline is open, and the bypass pipeline is closed when the second flow difference between the third flow detection data collected by the first flow meter and the first flow detection data is greater than a preset deviation value.

[0100] The data acquisition device updates the first metering pipeline based on the updated metering pipeline information; it collects the second gas parameters of natural gas in the updated first metering pipeline and the second operating condition data of the updated first metering pipeline, including: the data acquisition device identifies the second main pipeline as the first metering pipeline based on the updated metering pipeline information, opens the second inlet valve and the second outlet valve, and closes the first inlet valve, the first outlet valve, the third inlet valve, and the third outlet valve; it collects the second operating condition data of the first metering pipeline using the second pressure measurement unit and the second temperature measurement unit, collects the second gas parameters of natural gas using the gas component measuring instrument, and collects the third flow detection data using the second flow meter.

[0101] In one possible implementation, the metering instrument selection device updates the metering pipeline information based on the first flow detection data and the third flow detection data, including: the metering instrument selection device is specifically used to update the metering pipeline information as follows: the first main pipeline is closed, the second main pipeline is open, and the bypass pipeline is closed when the second flow difference between the third flow detection data collected by the second flow meter and the first flow detection data is less than or equal to a preset deviation.

[0102] The data acquisition device updates the first metering pipeline based on the updated metering pipeline information; it collects the second gas parameters of natural gas in the updated first metering pipeline and the second operating condition data of the updated first metering pipeline, including: the data acquisition device identifies the second main pipeline as the first metering pipeline based on the updated metering pipeline information, opens the second inlet valve and the second outlet valve, and closes the first inlet valve, the first outlet valve, the third inlet valve, and the third outlet valve; it collects the second operating condition data of the first metering pipeline using the second pressure measurement unit and the second temperature measurement unit, collects the second gas parameters of natural gas using the gas component measuring instrument, and continues to collect the third flow detection data using the second flow meter.

[0103] In one possible implementation, the metering instrument selection device updates the metering pipeline information based on the first flow detection data and the third flow detection data, including: when the second flow difference between the third flow detection data collected by the second flow meter and the first flow detection data is greater than a preset deviation, the metering instrument selection device updates the metering pipeline information to: the first main pipeline is closed, the second main pipeline is closed, and the bypass pipeline is open.

[0104] The data acquisition device updates the first metering pipeline based on the updated metering pipeline information; it collects the second gas parameters of natural gas in the updated first metering pipeline and the second operating condition data of the updated first metering pipeline, including: the data acquisition device identifies the bypass pipeline as the first metering pipeline based on the updated metering pipeline information, opens the third inlet valve and the third outlet valve, and closes the first inlet valve, the first outlet valve, the second inlet valve, and the third outlet valve; it collects the second operating condition data of the first metering pipeline using the third pressure measurement unit and the third temperature measurement unit, and collects the second gas parameters of natural gas using a gas composition analyzer.

[0105] In one possible implementation, the method further includes: when the bypass pipe is open and the first flow detection data is not greater than the preset flow data, the metering instrument selection device updates the metering pipe information to: the first main pipe is closed, the second main pipe is closed, and the bypass pipe is open; and sends the updated metering pipe information to the data acquisition device.

[0106] The data acquisition device receives updated metering pipeline information sent by the metering instrument selection device; based on the updated metering pipeline information, it identifies the bypass pipeline as the first metering pipeline, opens the third inlet valve and the third outlet valve, and closes the first inlet valve, the first outlet valve, the second inlet valve, and the third outlet valve; it uses the third pressure measurement unit and the third temperature measurement unit to collect the second operating condition data of the first metering pipeline, and uses the gas component measuring instrument to collect the second gas parameters of natural gas.

[0107] In one possible implementation, the method further includes: when the bypass pipe is open and the first flow detection data is stable and greater than the preset flow data, the metering instrument selection device updates the metering pipe information to: the first main pipe is open, the second main pipe is open, and the bypass pipe is closed; and sends the updated metering pipe information to the data acquisition device.

[0108] The data acquisition device receives updated metering pipeline information sent by the metering instrument selection device; based on the updated metering pipeline information, it identifies the first main pipeline and the second main pipeline as the first metering pipeline, closes the third inlet valve and the third outlet valve, and opens the first inlet valve, the first outlet valve, the second inlet valve, and the third outlet valve; it collects the second operating condition data of the first metering pipeline using the first pressure measurement unit, the second pressure measurement unit, the first temperature measurement unit, and the second temperature measurement unit, and collects the second gas parameters of natural gas using the gas composition measuring instrument.

[0109] In one possible implementation, the data acquisition device acquires first gas parameters of natural gas in the first metering pipeline and first operating condition data of the first metering pipeline; and sends the first gas parameters and first operating condition data to the compressibility factor determination device, including: when the data acquisition device acquires the first gas parameters of natural gas in the first metering pipeline and the first operating condition data of the first metering pipeline, it performs multiple samplings to obtain multiple sampling combinations of the first gas parameters and the first operating condition data; and sends the multiple sampling combinations to the compressibility factor determination device.

[0110] The compression factor determination device determines a first compression factor combination based on first operating condition data, comprising: a compression factor determination device specifically configured to receive multiple sampling combinations sent by a data acquisition device; acquire a set of compression factor formulas; determine the test curve corresponding to each compression factor formula in the set of compression factor formulas based on the multiple sampling combinations; combine the various compression factor formulas in the set of compression factor formulas to obtain multiple compression factor formula combinations and a set of test curves corresponding to each compression factor formula combination; determine the sum of similarities between any two test curves in each set of test curves based on the similarity between any two test curves in each set of test curves; and determine the compression factor formula combination corresponding to the set of test curves with the smallest sum of similarities as the first compression factor combination.

[0111] This invention also provides a high-sulfur natural gas flow measurement device, as described in the following embodiments. Since the principle by which this device solves the problem is similar to that of the high-sulfur natural gas flow measurement system, the implementation of this device can refer to the implementation of the high-sulfur natural gas flow measurement system; repeated details will not be elaborated further.

[0112] like Figure 5 The diagram shown is a schematic of a high-sulfur natural gas flow measurement device provided in an embodiment of the present invention, comprising:

[0113] The data acquisition module 501 is used to send the first flow detection data collected by the verification flow meter and the second flow detection data collected by the first main pipeline to the metering instrument selection module; receive the metering pipeline information sent by the metering instrument selection module based on the first flow detection data and the second flow detection data; determine the first metering pipeline to be used from the first main pipeline, the second main pipeline, and the bypass pipeline based on the metering pipeline information; start the first metering pipeline, collect the first gas parameters of the natural gas in the first metering pipeline and the first operating condition data of the first metering pipeline; and send the first gas parameters and the first operating condition data to the compressibility factor determination module.

[0114] The metering instrument selection module 502 is used to receive the first flow detection data and the second flow detection data sent by the data acquisition module; determine the metering pipeline information based on the first flow detection data and the second flow detection data; and send the metering pipeline information to the data acquisition module.

[0115] The compressibility factor determination module 503 is used to receive the first gas parameters and the first operating condition data sent by the data acquisition module; determine the first compressibility factor combination based on the first operating condition data; and determine the natural gas flow rate based on the first compressibility factor combination and the first gas parameters.

[0116] In one possible implementation, the metering instrument selection module is specifically used to determine a first flow difference between the first flow detection data and the second flow detection data; when the first flow difference is less than or equal to a preset deviation value, the metering pipeline information is determined to be: the first main pipeline is open, the second main pipeline is closed, and the bypass pipeline is closed.

[0117] The data acquisition module is specifically used to identify the first main pipeline as the first metering pipeline based on the metering pipeline information, open the first inlet valve and the first outlet valve, and close the second inlet valve, the second outlet valve, the third inlet valve, and the third outlet valve; collect the first operating condition data of the first metering pipeline using the first pressure measurement unit and the first temperature measurement unit, and collect the first gas parameters of natural gas using the gas component measuring instrument.

[0118] In one possible implementation, the metering instrument selection module is specifically used to determine a first flow difference between the first flow detection data and the second flow detection data; when the first flow difference is greater than a preset deviation value, the metering pipeline information is determined as follows: the first main pipeline is closed, the second main pipeline is open, and the bypass pipeline is closed.

[0119] The data acquisition module is specifically used to identify the second main pipeline as the first metering pipeline based on the metering pipeline information, open the second inlet valve and the second outlet valve, and close the first inlet valve, the first outlet valve, the third inlet valve, and the third outlet valve; use the second pressure measurement unit and the second temperature measurement unit to acquire the first operating condition data of the first metering pipeline, and use the gas component measuring instrument to acquire the first gas parameters of natural gas.

[0120] In one possible implementation, the data acquisition module is further configured to acquire third flow detection data of the first metering pipeline; send the third flow detection data to the metering instrument selection module; receive metering pipeline information updated by the metering instrument selection module based on the third flow detection data and the first flow detection data; update the first metering pipeline based on the updated metering pipeline information; acquire second gas parameters of natural gas in the updated first metering pipeline and second operating condition data of the updated first metering pipeline; and send the second gas parameters and second operating condition data to the compressibility factor determination module.

[0121] The metering instrument selection module is also used to receive the third flow detection data sent by the data acquisition module, update the metering pipeline information according to the first flow detection data and the third flow detection data, and send the updated metering pipeline information to the data acquisition module so that the data acquisition module can update the first metering pipeline according to the updated metering pipeline information.

[0122] The compressibility factor determination module is also used to receive the second gas parameters and the second operating condition data sent by the data acquisition module, determine the second compressibility factor combination based on the second operating condition data, and determine the natural gas flow rate based on the second compressibility factor combination and the second gas parameters.

[0123] In one possible implementation, the data acquisition module is specifically used to acquire third flow detection data using a first flow meter when the first metering pipe is a first main pipe, and to acquire third flow detection data using a second flow meter when the first metering pipe is a second main pipe.

[0124] In one possible implementation, the metering instrument selection module is specifically used to update the metering pipeline information as follows: the first main pipeline is open, the second main pipeline is closed, and the bypass pipeline is closed when the second flow difference between the third flow detection data collected by the first flow meter and the first flow detection data is less than or equal to a preset deviation value.

[0125] The data acquisition module is specifically used to identify the first main pipeline as the first metering pipeline based on the updated metering pipeline information, open the first inlet valve and the first outlet valve, and close the second inlet valve, the second outlet valve, the third inlet valve, and the third outlet valve; collect the second operating condition data of the first metering pipeline using the first pressure measurement unit and the first temperature measurement unit, collect the second gas parameters of natural gas using the gas component measuring instrument, and continue to collect the third flow detection data using the first flow meter.

[0126] In one possible implementation, the metering instrument selection module is specifically used to update the metering pipeline information as follows: the first main pipeline is closed, the second main pipeline is open, and the bypass pipeline is closed when the second flow difference between the third flow detection data collected by the first flow meter and the first flow detection data is greater than a preset deviation value.

[0127] The data acquisition module is specifically used to identify the second main pipeline as the first metering pipeline based on the updated metering pipeline information, open the second inlet valve and the second outlet valve, and close the first inlet valve, the first outlet valve, the third inlet valve, and the third outlet valve; collect the second operating condition data of the first metering pipeline using the second pressure measurement unit and the second temperature measurement unit, collect the second gas parameters of natural gas using the gas component measuring instrument, and collect the third flow detection data using the second flow meter.

[0128] In one possible implementation, the metering instrument selection module is specifically used to update the metering pipeline information as follows: the first main pipeline is closed, the second main pipeline is open, and the bypass pipeline is closed when the second flow difference between the third flow detection data collected by the second flow meter and the first flow detection data is less than or equal to a preset deviation.

[0129] The data acquisition module is specifically used to identify the second main pipeline as the first metering pipeline based on the updated metering pipeline information, open the second inlet valve and the second outlet valve, and close the first inlet valve, the first outlet valve, the third inlet valve, and the third outlet valve; use the second pressure measurement unit and the second temperature measurement unit to collect the second operating condition data of the first metering pipeline, use the gas component measuring instrument to collect the second gas parameters of natural gas, and continue to use the second flow meter to collect the third flow detection data.

[0130] In one possible implementation, the metering instrument selection module is specifically used to update the metering pipeline information as follows: the first main pipeline is closed, the second main pipeline is closed, and the bypass pipeline is open when the second flow difference between the third flow detection data collected by the second flow meter and the first flow detection data is greater than a preset deviation.

[0131] The data acquisition module is specifically used to identify the bypass pipeline as the first metering pipeline based on the updated metering pipeline information, open the third inlet valve and the third outlet valve, and close the first inlet valve, the first outlet valve, the second inlet valve, and the third outlet valve; use the third pressure measurement unit and the third temperature measurement unit to acquire the second operating condition data of the first metering pipeline, and use the gas component measuring instrument to acquire the second gas parameters of natural gas.

[0132] In one possible implementation, the metering instrument selection module is further configured to update the metering pipeline information to: first main pipeline closed, second main pipeline closed, and bypass pipeline open when the bypass pipeline is open and the first flow detection data is not greater than the preset flow data; and send the updated metering pipeline information to the data acquisition module.

[0133] The data acquisition module is also used to receive updated metering pipeline information sent by the metering instrument selection module; based on the updated metering pipeline information, the bypass pipeline is identified as the first metering pipeline, the third inlet valve and the third outlet valve are opened, and the first inlet valve, the first outlet valve, the second inlet valve, and the third outlet valve are closed; the second operating condition data of the first metering pipeline are collected using the third pressure measurement unit and the third temperature measurement unit, and the second gas parameters of natural gas are collected using the gas component measuring instrument.

[0134] In one possible implementation, the metering instrument selection module is further configured to update the metering pipeline information to: the first main pipeline is open, the second main pipeline is open, and the bypass pipeline is closed when the bypass pipeline is open and the first flow detection data is stable and greater than the preset flow data; and send the updated metering pipeline information to the data acquisition module.

[0135] The data acquisition module is also used to receive updated metering pipeline information sent by the metering instrument selection module; based on the updated metering pipeline information, it identifies the first main pipeline and the second main pipeline as the first metering pipeline, closes the third inlet valve and the third outlet valve, and opens the first inlet valve, the first outlet valve, the second inlet valve, and the third outlet valve; it uses the first pressure measurement unit, the second pressure measurement unit, the first temperature measurement unit, and the second temperature measurement unit to collect the second operating condition data of the first metering pipeline, and uses the gas component measuring instrument to collect the second gas parameters of natural gas.

[0136] In one possible implementation, the data acquisition module, specifically used to acquire the first gas parameters of natural gas in the first metering pipeline and the first operating condition data of the first metering pipeline, performs multiple samplings to obtain multiple sampling combinations of the first gas parameters and the first operating condition data; and sends the multiple sampling combinations to the compression factor determination module.

[0137] The compression factor determination module is specifically used to receive multiple sampling combinations sent by the data acquisition module; obtain a set of compression factor formulas; determine the test curve corresponding to each compression factor formula in the set of compression factor formulas based on the multiple sampling combinations; combine the various compression factor formulas in the set of compression factor formulas to obtain multiple compression factor formula combinations and a set of test curves corresponding to each compression factor formula combination; determine the sum of similarities between any two test curves in each set of test curves based on the similarity between any two test curves; and determine the compression factor formula combination corresponding to the set of test curves with the smallest sum of similarity as the first compression factor combination.

[0138] Based on the aforementioned inventive concept, such as Figure 6As shown, the present invention also proposes a computer device 600, including a memory 610, a processor 620, and a computer program 630 stored in the memory 610 and executable on the processor 620. When the processor 620 executes the computer program 630, it implements the aforementioned high-sulfur natural gas flow measurement method.

[0139] This invention also provides a computer-readable storage medium storing a computer program that, when executed by a processor, implements the above-described method for measuring the flow rate of high-sulfur natural gas.

[0140] This invention also provides a computer program product, which includes a computer program that, when executed by a processor, implements the above-described high-sulfur natural gas flow measurement method.

[0141] In this embodiment of the invention, a high-sulfur natural gas flow measurement system includes: a compressibility factor determination device, a metering instrument selection device, and a data acquisition device. The data acquisition device includes: a verification flow meter, a first main pipeline, a second main pipeline, and a bypass pipeline. The data acquisition device is used to send first flow detection data collected by the verification flow meter and second flow detection data collected by the first main pipeline to the metering instrument selection device; receive metering pipeline information sent by the metering instrument selection device based on the first flow detection data and the second flow detection data; determine the first metering pipeline to be used from the first main pipeline, the second main pipeline, and the bypass pipeline based on the metering pipeline information; and open the first metering pipeline. The system collects first gas parameters and first operating condition data of the natural gas in the first metering pipeline; sends the first gas parameters and first operating condition data to a compressibility factor determination device; a metering instrument selection device receives first flow detection data and second flow detection data sent by the data acquisition device; determines the metering pipeline information based on the first flow detection data and second flow detection data; and sends the metering pipeline information to the data acquisition device; the compressibility factor determination device receives the first gas parameters and first operating condition data sent by the data acquisition device; determines a first compressibility factor combination based on the first operating condition data; and determines the natural gas flow rate based on the first compressibility factor combination and the first gas parameters. This allows for flexible adjustment and selection of the metering pipeline based on flow detection data, and then determines the natural gas flow rate based on the operating condition data of the metering pipeline and the gas parameters. This improves the efficiency and accuracy of high-sulfur natural gas flow measurement, simplifies the measurement operation process, reduces maintenance costs, and enhances measurement safety.

[0142] Those skilled in the art will understand that embodiments of the present invention can be provided as methods, systems, or computer program products. Therefore, the present invention can take the form of a completely hardware embodiment, a completely software embodiment, or an embodiment combining software and hardware aspects. Furthermore, the present invention can take the form of a computer program product embodied on one or more computer-usable storage media (including, but not limited to, disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0143] This invention is described with reference to flowchart illustrations and / or block diagrams of methods, apparatus (systems), and computer program products according to embodiments of the invention. It will be understood that each block of the flowchart illustrations and / or block diagrams, and combinations of blocks in the flowchart illustrations and / or block diagrams, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, special-purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, generate instructions for implementing the flowchart illustrations and / or block diagrams. Figure 1 One or more processes and / or boxes Figure 1 A device that provides the functions specified in one or more boxes.

[0144] These computer program instructions may also be stored in a computer-readable storage medium that can direct a computer or other programmable data processing device to function in a particular manner, such that the instructions stored in the computer-readable storage medium produce an article of manufacture including instruction means, which are implemented in a process Figure 1 One or more processes and / or boxes Figure 1 The function specified in one or more boxes.

[0145] These computer program instructions may also be loaded onto a computer or other programmable data processing equipment to cause a series of operational steps to be performed on the computer or other programmable equipment to produce a computer-implemented process, thereby providing instructions that execute on the computer or other programmable equipment for implementing the process. Figure 1 One or more processes and / or boxes Figure 1 The steps of the function specified in one or more boxes.

[0146] 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 descriptions are merely specific embodiments of the present invention and are 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 high-sulfur natural gas flow measurement system, characterized in that, include: The data acquisition device includes a data acquisition device, a metering instrument selection device, and a compressibility factor determination device. The data acquisition device includes a verification flow meter, a first main pipeline, a second main pipeline, and a bypass pipeline. The data acquisition device is used to send the first flow detection data collected by the verification flow meter and the second flow detection data collected by the first main pipeline to the metering instrument selection device; receive the metering pipeline information sent by the metering instrument selection device based on the first flow detection data and the second flow detection data; determine the first metering pipeline to be used from the first main pipeline, the second main pipeline, and the bypass pipeline based on the metering pipeline information; open the first metering pipeline, collect the first gas parameters of the natural gas in the first metering pipeline and the first operating condition data of the first metering pipeline; and send the first gas parameters and the first operating condition data to the compressibility factor determination device. The metering instrument selection device is used to receive the first flow detection data and the second flow detection data sent by the data acquisition device; determine the metering pipeline information based on the first flow detection data and the second flow detection data; and send the metering pipeline information to the data acquisition device. A compressibility factor determination device is used to receive first gas parameters and first operating condition data sent by a data acquisition device; determine a first compressibility factor combination based on the first operating condition data; and determine the natural gas flow rate based on the first compressibility factor combination and the first gas parameters.

2. The high-sulfur natural gas flow measurement system as described in claim 1, characterized in that, The first main pipeline, the second main pipeline, and the bypass pipeline are connected in parallel. A gas component measuring instrument is installed at the intersection of the first main pipeline, the second main pipeline, and the bypass pipeline. The gas component measuring instrument is used to measure the gas parameters of natural gas in the first metering pipeline. The first main pipeline is equipped with a first inlet valve, a first outlet valve, and a first flow meter installed between the first inlet valve and the first outlet valve. The second main pipeline is equipped with a second inlet valve, a second outlet valve, and a second flow meter installed between the second inlet valve and the second outlet valve. The bypass pipeline is equipped with a third inlet valve and a third outlet valve. The second flow detection data is the flow data collected by the first flow meter.

3. The high-sulfur natural gas flow measurement system as described in claim 2, characterized in that, The first main pipeline is also equipped with a first pressure measuring unit and a first temperature measuring unit; the second main pipeline is also equipped with a second pressure measuring unit and a second temperature measuring unit; a third pressure measuring unit is also installed on one side of the flow meter, and a third temperature measuring unit is also installed on the other side of the flow meter.

4. The high-sulfur natural gas flow measurement system as described in claim 3, characterized in that, The metering instrument selection device is specifically used to determine the first flow difference between the first flow detection data and the second flow detection data; when the first flow difference is less than or equal to a preset deviation value, the metering pipeline information is determined as follows: the first main pipeline is open, the second main pipeline is closed, and the bypass pipeline is closed. The data acquisition device is specifically used to identify the first main pipeline as the first metering pipeline based on the metering pipeline information, open the first inlet valve and the first outlet valve, and close the second inlet valve, the second outlet valve, the third inlet valve, and the third outlet valve; collect the first operating condition data of the first metering pipeline using the first pressure measurement unit and the first temperature measurement unit, and collect the first gas parameters of natural gas using the gas component measuring instrument.

5. The high-sulfur natural gas flow measurement system as described in claim 3, characterized in that, The metering instrument selection device is specifically used to determine the first flow difference between the first flow detection data and the second flow detection data; when the first flow difference is greater than a preset deviation value, the metering pipeline information is determined as follows: the first main pipeline is closed, the second main pipeline is open, and the bypass pipeline is closed. The data acquisition device is specifically used to identify the second main pipeline as the first metering pipeline based on the metering pipeline information, open the second inlet valve and the second outlet valve, and close the first inlet valve, the first outlet valve, the third inlet valve, and the third outlet valve; collect the first operating condition data of the first metering pipeline using the second pressure measurement unit and the second temperature measurement unit, and collect the first gas parameters of natural gas using the gas component measuring instrument.

6. The high-sulfur natural gas flow measurement system as described in claim 3, characterized in that, The data acquisition device is also used to acquire the third flow detection data of the first metering pipeline; send the third flow detection data to the metering instrument selection device; receive the metering pipeline information updated by the metering instrument selection device based on the third flow detection data and the first flow detection data; update the first metering pipeline based on the updated metering pipeline information; acquire the second gas parameters of natural gas in the updated first metering pipeline and the second operating condition data of the updated first metering pipeline; and send the second gas parameters and the second operating condition data to the compressibility factor determination device. The metering instrument selection device is also used to receive the third flow detection data sent by the data acquisition device, update the metering pipeline information according to the first flow detection data and the third flow detection data, and send the updated metering pipeline information to the data acquisition device so that the data acquisition device can update the first metering pipeline according to the updated metering pipeline information. The compressibility factor determining device is also used to receive second gas parameters and second operating condition data sent by the data acquisition device, determine a second compressibility factor combination based on the second operating condition data, and determine the natural gas flow rate based on the second compressibility factor combination and the second gas parameters.

7. The high-sulfur natural gas flow measurement system as described in claim 6, characterized in that, The data acquisition device is specifically used to collect third flow detection data using a first flow meter when the first metering pipe is the first main pipe, and to collect third flow detection data using a second flow meter when the first metering pipe is the second main pipe.

8. The high-sulfur natural gas flow measurement system as described in claim 7, characterized in that, The metering instrument selection device is specifically used to update the metering pipeline information as follows: the first main pipeline is open, the second main pipeline is closed, and the bypass pipeline is closed when the second flow difference between the third flow detection data collected by the first flow meter and the first flow detection data is less than or equal to a preset deviation value. The data acquisition device is specifically used to identify the first main pipeline as the first metering pipeline based on the updated metering pipeline information, open the first inlet valve and the first outlet valve, and close the second inlet valve, the second outlet valve, the third inlet valve, and the third outlet valve; collect the second operating condition data of the first metering pipeline using the first pressure measurement unit and the first temperature measurement unit, collect the second gas parameters of natural gas using the gas component measuring instrument, and continue to collect the third flow detection data using the first flow meter.

9. The high-sulfur natural gas flow measurement system as described in claim 8, characterized in that, The metering instrument selection device is specifically used to update the metering pipeline information as follows: the first main pipeline is closed, the second main pipeline is open, and the bypass pipeline is closed when the second flow difference between the third flow detection data collected by the first flow meter and the first flow detection data is greater than a preset deviation value. The data acquisition device is specifically used to identify the second main pipeline as the first metering pipeline based on the updated metering pipeline information, open the second inlet valve and the second outlet valve, and close the first inlet valve, the first outlet valve, the third inlet valve, and the third outlet valve; collect the second operating condition data of the first metering pipeline using the second pressure measurement unit and the second temperature measurement unit, collect the second gas parameters of natural gas using the gas component measuring instrument, and collect the third flow detection data using the second flow meter.

10. The high-sulfur natural gas flow measurement system as described in claim 7, characterized in that, The metering instrument selection device is specifically used to update the metering pipeline information as follows: the first main pipeline is closed, the second main pipeline is open, and the bypass pipeline is closed when the second flow difference between the third flow detection data collected by the second flow meter and the first flow detection data is less than or equal to a preset deviation. The data acquisition device is specifically used to identify the second main pipeline as the first metering pipeline based on the updated metering pipeline information, open the second inlet valve and the second outlet valve, and close the first inlet valve, the first outlet valve, the third inlet valve, and the third outlet valve; use the second pressure measurement unit and the second temperature measurement unit to collect the second operating condition data of the first metering pipeline, use the gas component measuring instrument to collect the second gas parameters of natural gas, and continue to use the second flow meter to collect the third flow detection data.

11. The high-sulfur natural gas flow measurement system as described in claim 10, characterized in that, The metering instrument selection device is specifically used to update the metering pipeline information as follows: the first main pipeline is closed, the second main pipeline is closed, and the bypass pipeline is open when the second flow difference between the third flow detection data collected by the second flow meter and the first flow detection data is greater than a preset deviation. The data acquisition device is specifically used to identify the bypass pipeline as the first metering pipeline based on the updated metering pipeline information, open the third inlet valve and the third outlet valve, and close the first inlet valve, the first outlet valve, the second inlet valve, and the third outlet valve; use the third pressure measurement unit and the third temperature measurement unit to acquire the second operating condition data of the first metering pipeline, and use the gas component measuring instrument to acquire the second gas parameters of natural gas.

12. The high-sulfur natural gas flow measurement system as described in claim 11, characterized in that, The metering instrument selection device is also used to update the metering pipeline information to: first main pipeline closed, second main pipeline closed, and bypass pipeline open when the bypass pipeline is open and the first flow detection data is not greater than the preset flow data; and send the updated metering pipeline information to the data acquisition device. The data acquisition device is also used to receive updated metering pipeline information sent by the metering instrument selection device; to identify the bypass pipeline as the first metering pipeline based on the updated metering pipeline information; to open the third inlet valve and the third outlet valve; and to close the first inlet valve, the first outlet valve, the second inlet valve, and the third outlet valve; to collect the second operating condition data of the first metering pipeline using the third pressure measurement unit and the third temperature measurement unit; and to collect the second gas parameters of natural gas using the gas composition measuring instrument.

13. The high-sulfur natural gas flow measurement system as described in claim 11, characterized in that, The metering instrument selection device is also used to update the metering pipeline information to: first main pipeline open, second main pipeline open, and bypass pipeline closed when the bypass pipeline is open and the first flow detection data is stable and greater than the preset flow data; and send the updated metering pipeline information to the data acquisition device. The data acquisition device is also used to receive updated metering pipeline information sent by the metering instrument selection device; to identify the first main pipeline and the second main pipeline as the first metering pipeline based on the updated metering pipeline information; to close the third inlet valve and the third outlet valve; and to open the first inlet valve, the first outlet valve, the second inlet valve, and the third outlet valve; to collect the second operating condition data of the first metering pipeline using the first pressure measurement unit, the second pressure measurement unit, the first temperature measurement unit, and the second temperature measurement unit; and to collect the second gas parameters of natural gas using the gas component measuring instrument.

14. The high-sulfur natural gas flow measurement system as described in claim 1, characterized in that, The data acquisition device is specifically used to collect the first gas parameters of natural gas in the first metering pipeline and the first operating condition data of the first metering pipeline by performing multiple samplings to obtain multiple sampling combinations of the first gas parameters and the first operating condition data; and sending the multiple sampling combinations to the compressibility factor determination device. Compression factor determination device, specifically used to receive multiple sampling combinations sent by the data acquisition device; Obtain the set of compression factor formulas; based on multiple sampling combinations, determine the test curve corresponding to each compression factor formula in the set of compression factor formulas; The various compression factor formulas in the compression factor formula set are combined to obtain multiple compression factor formula combinations and a set of test curves corresponding to each compression factor formula combination; the sum of similarity between any two test curves in each set of test curves is determined based on the similarity between them; the compression factor formula combination corresponding to the set of test curves with the smallest sum of similarity is determined as the first compression factor combination.

15. The high-sulfur natural gas flow measurement system as described in claim 1, characterized in that, The flow meters to be checked include: clamp-on ultrasonic flow meters.

16. A method for measuring the flow rate of high-sulfur natural gas, characterized in that, include: The data acquisition device will send the first flow detection data collected by the flow meter and the second flow detection data collected by the first main pipeline to the metering instrument selection device; Receive metering pipeline information sent by the metering instrument selection device based on the first flow detection data and the second flow detection data; determine the first metering pipeline to be used from the first main pipeline, the second main pipeline, and the bypass pipeline based on the metering pipeline information; open the first metering pipeline, collect the first gas parameters of the natural gas in the first metering pipeline and the first operating condition data of the first metering pipeline; and send the first gas parameters and the first operating condition data to the compressibility factor determination device. The measuring instrument selection device receives the first flow detection data and the second flow detection data sent by the data acquisition device; Based on the first flow rate detection data and the second flow rate detection data, the metering pipeline information is determined; the metering pipeline information is then sent to the data acquisition device. The compressibility factor determination device receives the first gas parameters and the first operating condition data sent by the data acquisition device; The first compression factor combination is determined based on the first operating condition data; the natural gas flow rate is determined based on the first compression factor combination and the first gas parameters.

17. The method for measuring the flow rate of high-sulfur natural gas as described in claim 16, characterized in that, The metering instrument selection device determines the metering pipeline information based on the first flow detection data and the second flow detection data, including: The metering instrument selection device determines the first flow difference between the first flow detection data and the second flow detection data; when the first flow difference is less than or equal to a preset deviation value, the metering pipeline information is determined as follows: the first main pipeline is open, the second main pipeline is closed, and the bypass pipeline is closed. The data acquisition device determines the first metering pipeline to be used from the first main pipeline, the second main pipeline, and the bypass pipeline based on the metering pipeline information; it then opens the first metering pipeline and collects the first gas parameters of the natural gas in the first metering pipeline and the first operating condition data of the first metering pipeline, including: The data acquisition device identifies the first main pipeline as the first metering pipeline based on the metering pipeline information, opens the first inlet valve and the first outlet valve, and closes the second inlet valve, the second outlet valve, the third inlet valve, and the third outlet valve; it collects the first operating condition data of the first metering pipeline using the first pressure measurement unit and the first temperature measurement unit, and collects the first gas parameters of natural gas using the gas composition measuring instrument.

18. The method for measuring the flow rate of high-sulfur natural gas as described in claim 16, characterized in that, The metering instrument selection device determines the metering pipeline information based on the first flow detection data and the second flow detection data, including: The metering instrument selection device is specifically used to determine the first flow difference between the first flow detection data and the second flow detection data; when the first flow difference is greater than a preset deviation value, the metering pipeline information is determined as follows: the first main pipeline is closed, the second main pipeline is open, and the bypass pipeline is closed. The data acquisition device determines the first metering pipeline to be used from the first main pipeline, the second main pipeline, and the bypass pipeline based on the metering pipeline information; it then opens the first metering pipeline and collects the first gas parameters of the natural gas in the first metering pipeline and the first operating condition data of the first metering pipeline, including: The data acquisition device identifies the second main pipeline as the first metering pipeline based on the metering pipeline information, opens the second inlet valve and the second outlet valve, and closes the first inlet valve, the first outlet valve, the third inlet valve, and the third outlet valve; it uses the second pressure measurement unit and the second temperature measurement unit to collect the first operating condition data of the first metering pipeline, and uses the gas component measuring instrument to collect the first gas parameters of natural gas.

19. The method for measuring the flow rate of high-sulfur natural gas as described in claim 16, characterized in that, Also includes: The data acquisition device collects the third flow detection data from the first metering pipeline; The third flow detection data is sent to the metering instrument selection device, and the metering pipeline information updated by the metering instrument selection device based on the third flow detection data and the first flow detection data is received. The first metering pipeline is updated based on the updated metering pipeline information. The second gas parameters of natural gas in the updated first metering pipeline and the second operating condition data of the updated first metering pipeline are collected. The second gas parameters and the second operating condition data are sent to the compressibility factor determination device. The metering instrument selection device receives the third flow detection data sent by the data acquisition device, updates the metering pipeline information based on the first flow detection data and the third flow detection data, and sends the updated metering pipeline information to the data acquisition device so that the data acquisition device can update the first metering pipeline based on the updated metering pipeline information. The compressibility factor determination device receives the second gas parameters and the second operating condition data sent by the data acquisition device, determines the second compressibility factor combination based on the second operating condition data, and determines the natural gas flow rate based on the second compressibility factor combination and the second gas parameters.

20. The method for measuring the flow rate of high-sulfur natural gas as described in claim 19, characterized in that, The data acquisition device collects the third flow detection data from the first metering pipeline, including: When the first metering pipe is the first main pipe, the data acquisition device uses the first flow meter to collect the third flow detection data; when the first metering pipe is the second main pipe, it uses the second flow meter to collect the third flow detection data.

21. The method for measuring the flow rate of high-sulfur natural gas as described in claim 20, characterized in that, The metering instrument selection device updates the metering pipeline information based on the first flow rate detection data and the third flow rate detection data, including: When the second flow difference between the third flow detection data collected by the first flow meter and the first flow detection data is less than or equal to the preset deviation value, the metering instrument selection device updates the metering pipeline information to: the first main pipeline is open, the second main pipeline is closed, and the bypass pipeline is closed. The data acquisition device updates the first metering pipeline based on the updated metering pipeline information; it collects the second gas parameters of natural gas in the updated first metering pipeline and the second operating condition data of the updated first metering pipeline, including: The data acquisition device identifies the first main pipeline as the first metering pipeline based on the updated metering pipeline information, opens the first inlet valve and the first outlet valve, and closes the second inlet valve, the second outlet valve, the third inlet valve, and the third outlet valve. It then uses the first pressure measurement unit and the first temperature measurement unit to collect the second operating condition data of the first metering pipeline, uses the gas component measuring instrument to collect the second gas parameters of natural gas, and continues to use the first flow meter to collect the third flow detection data.

22. The method for measuring the flow rate of high-sulfur natural gas as described in claim 21, characterized in that, The metering instrument selection device updates the metering pipeline information based on the first flow rate detection data and the third flow rate detection data, including: The metering instrument selection device is specifically used to update the metering pipeline information as follows: the first main pipeline is closed, the second main pipeline is open, and the bypass pipeline is closed when the second flow difference between the third flow detection data collected by the first flow meter and the first flow detection data is greater than a preset deviation value. The data acquisition device updates the first metering pipeline based on the updated metering pipeline information; it collects the second gas parameters of natural gas in the updated first metering pipeline and the second operating condition data of the updated first metering pipeline, including: The data acquisition device identifies the second main pipeline as the first metering pipeline based on the updated metering pipeline information, opens the second inlet valve and the second outlet valve, and closes the first inlet valve, the first outlet valve, the third inlet valve, and the third outlet valve. It uses the second pressure measurement unit and the second temperature measurement unit to collect the second operating condition data of the first metering pipeline, uses the gas component measuring instrument to collect the second gas parameters of natural gas, and uses the second flow meter to collect the third flow detection data.

23. The method for measuring the flow rate of high-sulfur natural gas as described in claim 20, characterized in that, The metering instrument selection device updates the metering pipeline information based on the first flow rate detection data and the third flow rate detection data, including: The metering instrument selection device is specifically used to update the metering pipeline information as follows: the first main pipeline is closed, the second main pipeline is open, and the bypass pipeline is closed when the second flow difference between the third flow detection data collected by the second flow meter and the first flow detection data is less than or equal to a preset deviation. The data acquisition device updates the first metering pipeline based on the updated metering pipeline information; it collects the second gas parameters of natural gas in the updated first metering pipeline and the second operating condition data of the updated first metering pipeline, including: The data acquisition device identifies the second main pipeline as the first metering pipeline based on the updated metering pipeline information, opens the second inlet valve and the second outlet valve, and closes the first inlet valve, the first outlet valve, the third inlet valve, and the third outlet valve. It uses the second pressure measurement unit and the second temperature measurement unit to collect the second operating condition data of the first metering pipeline, uses the gas component measuring instrument to collect the second gas parameters of natural gas, and continues to use the second flow meter to collect the third flow detection data.

24. The method for measuring the flow rate of high-sulfur natural gas as described in claim 23, characterized in that, The metering instrument selection device updates the metering pipeline information based on the first flow rate detection data and the third flow rate detection data, including: When the difference between the third flow detection data collected by the second flow meter and the first flow detection data is greater than the preset deviation, the metering instrument selection device updates the metering pipeline information to: first main pipeline closed, second main pipeline closed, and bypass pipeline open. The data acquisition device updates the first metering pipeline based on the updated metering pipeline information; it collects the second gas parameters of natural gas in the updated first metering pipeline and the second operating condition data of the updated first metering pipeline, including: The data acquisition device identifies the bypass pipeline as the first metering pipeline based on the updated metering pipeline information, opens the third inlet valve and the third outlet valve, and closes the first inlet valve, the first outlet valve, the second inlet valve, and the third outlet valve; it uses the third pressure measurement unit and the third temperature measurement unit to collect the second operating condition data of the first metering pipeline, and uses the gas component measuring instrument to collect the second gas parameters of natural gas.

25. The method for measuring the flow rate of high-sulfur natural gas as described in claim 16, characterized in that, The data acquisition device collects the first gas parameters of the natural gas in the first metering pipeline and the first operating condition data of the first metering pipeline. Sending the first gas parameters and the first operating condition data to the compressibility factor determination device includes: When the data acquisition device collects the first gas parameters of natural gas in the first metering pipeline and the first operating condition data of the first metering pipeline, it performs multiple samplings to obtain multiple sampling combinations of the first gas parameters and the first operating condition data; and sends the multiple sampling combinations to the compressibility factor determination device. The compressibility factor determining device determines a first compressibility factor combination based on first operating condition data, including: The compression factor determination device is specifically used to receive multiple sampling combinations sent by the data acquisition device; obtain a set of compression factor formulas; determine the test curve corresponding to each compression factor formula in the set of compression factor formulas based on the multiple sampling combinations; combine the various compression factor formulas in the set of compression factor formulas to obtain multiple compression factor formula combinations and a set of test curves corresponding to each compression factor formula combination; determine the sum of similarities between any two test curves in each set of test curves based on the similarity between any two test curves; and determine the compression factor formula combination corresponding to the set of test curves with the smallest sum of similarity as the first compression factor combination.

26. A computer device, comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, characterized in that, When the processor executes the computer program, it implements the method of any one of claims 16 to 25.

27. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores a computer program that, when executed by a processor, implements the method of any one of claims 16 to 25.

28. A computer program product, characterized in that, The computer program product includes a computer program that, when executed by a processor, implements the method of any one of claims 16 to 25.

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