Natural gas chemical composition measurement and detection apparatus and method

Abstract

A natural gas chemical composition measurement and detection apparatus and method. The apparatus comprises: a detector tube (3), a pressure-resistant cavity (5), a color sensor (9), a pressure regulator (4), a flow detector (6), and a control device (10); an open end of the detector tube (3) is configured for connecting to a natural gas sample injection system; a first open end of the pressure-resistant cavity (5) is configured for securing the detector tube (3); a second open end of the pressure-resistant cavity (5) is in communication with an internal cavity of the pressure-resistant cavity (5), and is configured for connecting to the natural gas sample injection system and is connected to the flow detector (6) by means of the pressure regulator (4); the color sensor (9) is arranged on an outer side of the pressure-resistant cavity (5) and is configured for detecting a color change in the detector tube (3) at a sensing position; and the control device (10) is configured for turning off the flow detector (6) when the color sensor (9) detects a color change, and calculating a concentration of a component to be detected according to a color change length in the detector tube (3) and a volume of natural gas detected by the flow detector (6). The apparatus enables automatic natural gas sample injection, improves repeatability, reduces the complexity of sample injection processes, and improves detection accuracy and efficiency.

Description

A chemical metering and detection device and method for natural gas

[0001] Related applications

[0002] This application claims priority to Chinese Patent Application No. 202411630140.7, filed on November 14, 2024, and incorporates the entire contents of the aforementioned patent application as part of this application. Technical Field

[0003] This disclosure relates to the field of natural gas detection technology, and in particular to a natural gas chemical metering detection device and method. Background Technology

[0004] In related technologies, the processes of natural gas production, purification, storage, and transportation all require testing. The main testing methods in these technologies include:

[0005] Offline natural gas detection methods require the use of various analytical instruments and cumbersome chemical analysis of samples, which are time-consuming, labor-intensive, and have high labor costs, and cannot be detected online.

[0006] Existing gas detection tube technology, also known as direct-reading detection tubes, involves filling the tube with a silica or alumina carrier coated with a detection reagent. The outer surface of the tube is marked with graduations indicating gas concentration. When the gas being tested passes through the carrier, it reacts chemically with the reagent, causing a color change. In these technologies, sample introduction is achieved manually via a suction component within the tube. Inconsistencies in operation between different personnel and even repeated measurements by the same person lead to poor repeatability and reproducibility. Furthermore, environmental factors such as temperature and atmospheric pressure affect the sample volume, resulting in significant measurement uncertainty. These technologies primarily rely on manual or visual methods to determine the color change location. However, issues such as indistinct color changes and inconsistent color-changing interface lengths within the tube prevent accurate readings by manual or visual methods, leading to large errors, low accuracy, and an uncertainty of approximately 25%. Moreover, manual reading suffers from inconsistent standards, resulting in poor comparability and repeatability of test results. Summary of the Invention

[0007] This disclosure addresses the problems of complex sample introduction operations, poor repeatability, and significant environmental influence in natural gas chemometric testing, as well as the issues of large errors, low efficiency, and poor repeatability in reading test results.

[0008] To address the aforementioned technical problems, the first aspect of this disclosure provides a natural gas chemical metering and detection device, comprising: a detection tube, a pressure-resistant cavity, a color sensor, a pressure regulator, a flow detector, and a control device;

[0009] The detection tube contains natural gas component detection reagents, and the open end of the detection tube is used to connect to the natural gas injection system;

[0010] The first open end of the pressure-resistant cavity is used to fix the detection tube; the second open end of the pressure-resistant cavity is connected to the internal cavity of the pressure-resistant cavity and is used to connect to the natural gas injection system and to connect to the flow detector through the pressure regulator;

[0011] The color sensor is located on the outside of the pressure-resistant cavity and is used to detect color changes when the detection tube is located at the sensing position.

[0012] The pressure regulator is used to adjust the pressure in the pressure-resistant chamber;

[0013] The flow detector is used to detect the volume of natural gas flowing through the pressure-resistant cavity;

[0014] The control device connects a flow detector and a color sensor. When the color sensor detects a color change, it shuts off the flow detector and calculates the concentration of the component to be measured based on the length of the color change in the detection tube and the volume of natural gas detected by the flow detector.

[0015] In a further embodiment of this disclosure, the control device calculates the concentration of the analyte based on the color change length of the detection tube and the volume of natural gas detected by the flow detector, including:

[0016] The mass of the analyte is calculated based on the color change length of the detection tube and the color change chemical reaction.

[0017] The concentration of the analyte is calculated based on the mass of the analyte and the volume of natural gas detected by the flow detector.

[0018] In a further embodiment of this disclosure, the color sensor includes: a laser emitter and a laser receiver;

[0019] The laser emitter is located on one side of the pressure-resistant cavity and is used to emit laser signals;

[0020] The laser receiver is located on the other side of the pressure-resistant cavity, opposite to the laser transmitter, and is used to receive laser signals;

[0021] The laser receiver is connected to a control device, which is used to determine whether a color change occurs at the sensing location based on the laser signal received by the laser receiver.

[0022] As a further embodiment of this disclosure, the natural gas chemical metering detection also includes: a mobile device;

[0023] The color sensor is mounted on a moving device, which is used to move the color sensor to adjust its sensing position.

[0024] As a further embodiment of this disclosure, the moving device includes: a slide rail and a moving component;

[0025] The moving component is mounted on the slide rail, and the color sensor is mounted on the moving component;

[0026] The moving component is connected to the control device, which is also used to determine the sensing position based on the analyte and its concentration, and to control the moving component to move the color sensor to the sensing position.

[0027] As a further embodiment of this disclosure, the natural gas chemical metering and detection device further includes: a first control valve;

[0028] The first control valve has an input port, a first output port and a second output port. The input port of the first control valve is used to connect to the natural gas injection system. The first output port of the first control valve is connected to the open end of the detection tube through a first pipeline. The second output port of the first control valve is connected to the second open end of the pressure-resistant cavity through a second pipeline.

[0029] The first control valve is used to control the input of natural gas into the pressure-resistant chamber and the first pipeline.

[0030] As a further embodiment of this disclosure, the natural gas chemical metering and detection device further includes: a second control valve;

[0031] The second control valve connects to the first pipeline near the open end of the detection tube and is used to clean the first pipeline.

[0032] As a further embodiment of this disclosure, the natural gas chemical metering and detection device further includes: a third control valve;

[0033] One end of the third control valve is connected to the pipeline between the second output port of the first control valve and the second opening end of the pressure-resistant cavity via a three-way fitting;

[0034] The other end of the third control valve is connected to a recovery device for recovering natural gas from the pressure-resistant chamber.

[0035] As a further embodiment of this disclosure, the natural gas chemical metering and detection device further includes: a fourth control valve;

[0036] One end of the fourth control valve is connected via a tee fitting to the pipeline between the second output port of the first control valve and the second opening end of the pressure-resistant cavity;

[0037] The other end of the fourth control valve is connected to an air pumping device, which is used to pump air into the pressure-resistant chamber.

[0038] As a further embodiment of this disclosure, the natural gas chemical metering and detection device further includes: a three-way connection assembly;

[0039] The first end of the three-way connection assembly is connected to the first output port of the first control valve via a pipeline.

[0040] The second end of the tee connector is connected to the second control valve via a pipeline;

[0041] The third end of the tee connector is detachably fixed with a detection tube, which is then detachably fixed to the first opening end of the pressure-resistant cavity after being inserted into the pressure-resistant cavity.

[0042] A second aspect of this disclosure provides a method for chemical metering and detection of natural gas, applicable to the natural gas chemical metering and detection apparatus of any of the foregoing embodiments, comprising:

[0043] Connect the natural gas injection system to the second opening end of the pressure-resistant chamber and the opening end of the detection tube. After the pressure-resistant chamber is filled with natural gas, disconnect the natural gas injection system from the second opening end of the pressure-resistant chamber.

[0044] Turn on the pressure regulator and adjust the injection flow rate to the preset value;

[0045] The color sensor and flow detector are turned on, and the concentration of the component to be measured is obtained by the natural gas chemimetric detection device.

[0046] In a further embodiment of this disclosure, when the natural gas chemical metering and detection device includes a second control valve, after disconnecting the connection between the natural gas sampling system and the second opening end of the pressure-resistant chamber, the device further includes:

[0047] Open the second control valve to clean the first pipeline.

[0048] In a further embodiment of this disclosure, when the natural gas chemical metering and detection device includes a third control valve and the component to be measured is a toxic gas, after detecting the concentration of the component to be measured, the device further includes:

[0049] Open the third control valve to recover natural gas from the pressure chamber.

[0050] In a further embodiment of this disclosure, when the natural gas chemical metering and detection device includes a fourth control valve, it further includes:

[0051] Open the fourth control valve to pump air into the pressure-resistant chamber using the air pumping device. Repeatedly open and close the third and fourth control valves to complete the cleaning of the pressure-resistant chamber.

[0052] A third aspect of this disclosure provides a computer device including a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor executes the computer program to implement the method of any of the foregoing embodiments.

[0053] A fourth aspect of this disclosure provides a computer-readable storage medium storing a computer program that, when executed by a processor of a computer device, implements the methods of any of the foregoing embodiments.

[0054] The natural gas chemical metering and detection device disclosed herein comprises a detection tube, a pressure-resistant chamber, and a pressure regulator. The detection tube contains natural gas component detection reagents, and its open end is connected to a natural gas sampling system. The first open end of the pressure-resistant chamber is used to fix the detection tube. The second open end of the pressure-resistant chamber connects to its internal cavity, connecting to the natural gas sampling system and a flow detector via the pressure regulator. This enables automatic natural gas sampling, improving repeatability, reducing operational difficulty, and minimizing environmental impact. A color sensor, positioned outside the pressure-resistant chamber, detects color changes in the detection tube at the sensing position, enabling point measurement. Compared to existing visual inspection methods that rely on surface measurement, this improves detection accuracy. A flow detector and controller are also included. The flow detector detects the volume of natural gas flowing through the pressure-resistant chamber. The control device, connected to both the flow detector and color sensor, shuts off the flow detector when a color change is detected. The concentration of the analyte is calculated based on the length of the color change in the detection tube and the volume of natural gas detected by the flow detector. This enables automatic detection of natural gas concentration, improving repeatability, efficiency, and accuracy. The structure disclosed herein also enables online detection of natural gas.

[0055] To make the above and other objects, features and advantages of this disclosure more apparent and understandable, preferred embodiments are described below in detail with reference to the accompanying drawings. Attached Figure Description

[0056] To more clearly illustrate the technical solutions in the embodiments or related technologies of this disclosure, the accompanying drawings used in the description of the embodiments or related technologies will be briefly introduced below. Obviously, the accompanying drawings described below are only some embodiments of this disclosure. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0057] Figure 1 shows a first structural diagram of a natural gas chemical metering and detection device according to an embodiment of the present disclosure;

[0058] Figure 2 shows a second structural diagram of the natural gas chemical metering and detection device according to an embodiment of the present disclosure;

[0059] Figure 3 shows a third structural diagram of the natural gas chemical metering and detection device according to an embodiment of the present disclosure;

[0060] Figure 4 shows a fourth structural diagram of the natural gas chemical metering and detection device according to an embodiment of the present disclosure;

[0061] Figure 5 shows a fifth structural diagram of the natural gas chemical metering and detection device according to an embodiment of the present disclosure;

[0062] Figure 6 shows a model structural diagram of the natural gas chemical metering and detection device according to an embodiment of this disclosure;

[0063] Figure 7 shows a flowchart of the natural gas chemical metrology detection method according to an embodiment of the present disclosure;

[0064] Figure 8 shows a schematic diagram of sampling using existing detection tubes;

[0065] Figure 9 shows a structural diagram of a computer device according to an embodiment of the present disclosure.

[0066] Explanation of symbols in the attached drawings: 1. First control valve; 2. Second control valve; 3. Detection tube; 4. Pressure regulator; 5. Pressure-resistant chamber; 6. Flow detector; 7. Third control valve; 8. Fourth control valve; 9. Color sensor; 91. Laser emitter; 92. Laser receiver; 10. Control device; 11. Moving device; 12. T-junction assembly; 902. Computer equipment; 904. Processor; 906. Memory; 908. Drive mechanism; 910. Input / output module; 912. Input device; 914. Output device; 916. Presentation device; 918. Graphical user interface; 920. Network interface; 922. Communication link; 924. Communication bus. Detailed Implementation

[0067] The technical solutions of the embodiments of this disclosure will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of this disclosure, and not all embodiments. Based on the embodiments of this disclosure, all other embodiments obtained by those of ordinary skill in the art without creative effort are within the scope of protection of this disclosure.

[0068] It should be noted that the terms "first," "second," etc., in the specification, claims, and accompanying drawings of this disclosure are used to distinguish similar objects and are not necessarily used to describe a specific order or sequence. It should be understood that such data can be interchanged where appropriate so that the embodiments of this disclosure described herein can be implemented in orders other than those illustrated or described herein. Furthermore, the terms "comprising" and "having," and any variations thereof, are intended to cover non-exclusive inclusion; for example, a process, method, apparatus, product, or device that comprises a series of steps or units is not necessarily limited to those steps or units explicitly listed, but may include other steps or units not explicitly listed or inherent to such processes, methods, products, or devices.

[0069] This specification provides method operation steps as shown in the embodiments or flowcharts, but based on conventional or non-inventive labor, more or fewer operation steps may be included. The order of steps listed in the embodiments is merely one possible execution order among many and does not represent the only execution order. In actual system or device products, the methods shown in the embodiments or drawings can be executed sequentially or in parallel. The lines in Figures 1 to 6 of this specification represent connecting pipelines used for transporting natural gas.

[0070] In related technologies, the computer vision-based method of reading the scale on natural gas detection tubes suffers from large errors and low measurement accuracy due to indistinct color changes within the tube and inconsistent lengths of the color-changing interface. The manual method of reading the scale on natural gas detection tubes also suffers from large errors, low measurement accuracy, inconsistent standards, and poor comparability and repeatability of test results. Furthermore, the manual control of natural gas sample injection in these technologies leads to issues of repeatability and poor repeatability due to multiple measurements by the same personnel or different measurements by multiple personnel. Additionally, environmental factors such as temperature and atmospheric pressure affect the sample volume, resulting in significant measurement uncertainty.

[0071] To solve the above-mentioned technical problems, in some embodiments of this disclosure, a natural gas chemical metering and detection device is provided, as shown in FIG1, including: a detection tube 3, a pressure-resistant cavity 5, a color sensor 9, a pressure regulator 4, a flow detector 6, and a control device 10;

[0072] The detection tube 3 contains a natural gas component detection reagent, and its open end is connected to the natural gas injection system. Specifically, the natural gas components include, but are not limited to, hydrogen sulfide and carbon dioxide. The detection reagent is determined based on the analyte; different analytes and different detection reagents produce different color changes, which this disclosure does not limit. The natural gas in the injection system is natural gas that has undergone depressurization and / or particulate removal treatment. In specific implementations, it can also be unpressurized natural gas, i.e., natural gas maintained at the same pressure as in the natural gas transport pipeline. In specific implementations, the open end of the detection tube 3 is connected to the natural gas injection system via a silanized pipeline.

[0073] The first open end of the pressure-resistant chamber 5 is used to fix the detection tube 3; the second open end of the pressure-resistant chamber 5 connects to the internal cavity of the pressure-resistant chamber 5 and is used to connect to the natural gas injection system and the flow detector 6 through the pressure regulator 4. Specifically, to improve the applicability of the natural gas chemometrics detection device, the first open end of the pressure-resistant chamber 5 is detachably and sealingly fixed to the detection tube 3. The fixing method includes, but is not limited to, snap-fit ​​and threaded connection. Gaskets can be used to ensure sealing during implementation. The second open end of the pressure-resistant chamber 5 is sealed to the natural gas injection system and the pressure regulator 4 through a tee connection. The pressure regulator 4 is connected to the flow detector 6 through a pipeline. In the initial stage of use of this device, the pressure regulator 4 is in the closed state.

[0074] Color sensor 9 is located on the outside of pressure-resistant cavity 5 and is used to detect color changes when detection tube 3 is located at the sensing position. The detection results of color changes may include, but are not limited to, the type of color change.

[0075] The pressure regulator 4 is used to adjust the pressure of the pressure-resistant chamber 5, so that a pressure difference is generated inside the pressure-resistant chamber 5, which in turn causes the natural gas inside the pressure-resistant chamber 5 to flow out of the pressure-resistant chamber 5, and the natural gas in the sample injection system enters the inside of the detection tube 3, thereby reacting with the detection reagent inside the detection tube 3.

[0076] The flow detector 6 is used to detect the volume of natural gas flowing through the pressure-resistant cavity 5.

[0077] The control device 10 is connected to the flow detector 6 and the color sensor 9. When the color sensor 9 detects a color change, it shuts off the flow detector 6. At this time, the volume of natural gas detected by the flow detector 6 is the volume of natural gas that reacted with the detection reagent in the detection tube 3. The concentration of the analyte is calculated based on the length of the color change in the detection tube and the volume of natural gas detected by the flow detector 6.

[0078] Specifically, the control device 10 calculates the concentration of the component to be tested based on the color change length of the detection tube and the volume of natural gas detected by the flow detector 6, including: calculating the mass of the component to be tested based on the color change length of the detection tube and the color change chemical reaction; and calculating the concentration of the component to be tested based on the mass of the component to be tested and the volume of natural gas detected by the flow detector 6.

[0079] The calculation of the mass of the analyte based on the color change length and color-changing chemical reaction of the detection tube includes: calculating the mass of the reacted detection reagent based on the color change length and the length of the detection tube; and calculating the mass of the analyte based on the mass of the reacted detection reagent and the color-changing chemical reaction. Specifically, the mass of the analyte is expressed as an amount of substance or molar mass.

[0080] In practical implementation, the concentration of the analyte can be calculated based on the calibration results of the analyte (calibrated using an external standard method with a standard reference for the analyte) and the measured flow rate. The device disclosed herein also avoids the impact of differences between the factory calibration of the detection tube and on-site testing conditions on measurement accuracy and repeatability.

[0081] This disclosure, by setting up a detection tube, a pressure-resistant cavity, and a pressure regulator, includes a natural gas component detection reagent in the detection tube, with the open end of the detection tube used to connect to a natural gas injection system; the first open end of the pressure-resistant cavity is used to fix the detection tube; the second open end of the pressure-resistant cavity connects to the internal cavity of the pressure-resistant cavity, used to connect to the natural gas injection system and to connect to a flow detector through the pressure regulator, thereby enabling automatic natural gas injection, improving repeatability, reducing the operational difficulty of injection, and reducing environmental impact.

[0082] By setting a color sensor on the outside of the pressure-resistant cavity, the color sensor detects the color change of the detection tube at the sensing position. This disclosure can achieve point measurement. Specifically, point detection here refers to circular detection with a very small radius. Point detection can accurately sense whether there is a color change at the position. In contrast, existing visual detection is surface measurement, and the length of the color change interface on the detection surface is not uniform, making it impossible to accurately determine. The color sensor detection method of this disclosure can improve the accuracy of color change detection compared with the existing method.

[0083] By setting up a flow detector and a controller, the flow detector is used to detect the volume of natural gas flowing through the pressure-resistant cavity; the control device is connected to the flow detector and a color sensor, and is used to shut down the flow detector when the color sensor detects a color change. The concentration of the component to be measured is calculated based on the length of the color change in the detection tube and the volume of natural gas detected by the flow detector, which enables automatic detection of natural gas concentration, improves detection repeatability, and increases detection efficiency and accuracy. The structure of this application also enables online detection of natural gas.

[0084] In some embodiments of this disclosure, the color sensor 9 includes a laser emitter 91 and a laser receiver 92.

[0085] The laser emitter 91 is located on one side of the pressure-resistant cavity 5 and is used to emit laser signals.

[0086] The laser receiver 92 is located on the other side of the pressure-resistant cavity 5 and is opposite to the laser transmitter 91, and is used to receive laser signals.

[0087] The laser receiver 92 is connected to the control device 10, which is used to determine whether a color change has occurred at the sensing position based on the laser signal received by the laser receiver 92.

[0088] The sensing position is the location where the laser emitted by the laser emitter 91 passes through the pressure-resistant cavity 5. When the sensing position changes color, the laser signal received by the laser receiver 92 decreases or increases, depending on the color produced by the reaction between the natural gas component detection reagent and the natural gas.

[0089] In some embodiments of this disclosure, as shown in FIG6, the natural gas chemical metering and detection device further includes a mobile device 11.

[0090] Color sensor 9 is mounted on a mobile device, which moves color sensor 9 to adjust its sensing position. In practice, the laser emitter and laser receiver of color sensor 9 move synchronously.

[0091] In some implementations, the moving device is manually controlled; that is, a person determines the sensing position based on the analyte and its concentration, and manually moves the device to the sensing position. Alternatively, a camera can be installed outside the pressure-resistant chamber to capture color change images of the chamber. The control equipment determines the rate of color change based on these images and adjusts the moving device's position accordingly. Specifically, when the color change rate is high, the device moves away from the inlet of the detection tube; when the color change rate is low, the device moves closer to the inlet.

[0092] In some embodiments, the moving device includes a slide rail and a moving component. The moving component is disposed on the slide rail, and the color sensor 9 is disposed on the moving component. The moving component can be manually controlled, or it can be actuated or electrically controlled.

[0093] The moving component is connected to the control device 10. The control device 10 is also used to determine the sensing position based on the analyte and its concentration, and to control the moving component to move the color sensor 9 to the sensing position. For example, when measuring a analyte with a high concentration, the required color change position will be longer; conversely, when measuring a analyte with a low concentration, the required color change position will be shorter.

[0094] This embodiment enables the natural gas chemimetric detection device to be applied to the detection of multiple natural gas components by adjusting the position of the color sensor.

[0095] In some embodiments of this disclosure, as shown in FIG2, the natural gas chemical metering and detection device further includes: a first control valve 1.

[0096] The first control valve 1 has an inlet, a first outlet, and a second outlet. The inlet of the first control valve 1 is used to connect to the natural gas sampling system. The first outlet of the first control valve 1 is connected to the open end of the detection tube 3 through a first pipeline. The second outlet of the first control valve 1 is connected to the second open end of the pressure-resistant chamber 5 through a second pipeline. To improve the detection accuracy of the natural gas chemical metering and detection device, the first control valve, the detection pipeline, and the detection tube have undergone anti-corrosion and anti-adsorption treatment.

[0097] The first control valve 1 is used to control the input of natural gas to the pressure-resistant chamber 5 and the first pipeline. In specific implementation, the first control valve is first controlled to open the first output port and the second output port, so that natural gas is input to the pressure-resistant chamber 5 and the first pipeline; then the first control valve is controlled to close the second output port and open the pressure regulator 4. At this time, the natural gas in the pressure-resistant chamber 5 will flow out of the pressure-resistant chamber 5, and then the natural gas flowing through the first control valve 1 will enter the detection tube 3 and react chemically with the detection reagent in the detection tube 3.

[0098] This embodiment, through the setting of the first control valve, can flexibly control the natural gas injection.

[0099] In some embodiments of this disclosure, as shown in FIG3, the natural gas chemical metering and detection device further includes a second control valve 2.

[0100] The second control valve 2 is connected to the first pipeline near the opening end of the detection tube 3, and is used to clean the first pipeline.

[0101] In practice, the first pipeline and the pressure-resistant chamber 5 are filled with natural gas. Then, the first pipeline is cleaned by opening the second control valve 2. After cleaning, the pressure regulator 4 is opened so that the natural gas in the first pipeline enters the detection pipe 3 under the control of differential pressure.

[0102] In this embodiment, the second control valve 2 is used to clean the first pipeline, thereby preventing pipeline residues from affecting the test results and improving the accuracy of the test.

[0103] In some embodiments of this disclosure, as shown in FIG4, the natural gas chemical metering and detection device further includes a third control valve 7.

[0104] One end of the third control valve 7 is connected via a tee fitting to the pipeline between the second output port of the first control valve 1 and the second opening end of the pressure-resistant chamber 5. The other end of the third control valve 7 is connected to a recovery device for recovering natural gas from the pressure-resistant chamber 5.

[0105] The recovery device can recover natural gas by storing natural gas or reacting natural gas, and this disclosure does not limit the specific method of natural gas recovery.

[0106] This embodiment is applicable to detection scenarios involving natural gas components containing hazardous gases, such as natural gas containing hydrogen sulfide. Before opening the pressure-resistant chamber 5, in order to avoid the harm of the gas in the pressure-resistant chamber to the human body, the third control valve 7 is opened first to recover the natural gas in the pressure-resistant chamber 5, and then the pressure-resistant chamber 5 is opened to replace the detection tube.

[0107] In some embodiments of this disclosure, as shown in FIG5, the natural gas chemical metering and detection device further includes a fourth control valve 8.

[0108] One end of the fourth control valve 8 is connected to the pipeline between the second output port of the first control valve 1 and the second opening end of the pressure-resistant cavity 5 via a three-way fitting.

[0109] The other end of the fourth control valve 8 is connected to an air pumping device, which is used to pump air into the pressure-resistant chamber 5.

[0110] In practice, the fourth control valve 8 is opened before the pressure-resistant chamber 5 is filled with natural gas, which can clean the pressure-resistant chamber 5 and thus avoid the influence of residues in the pressure-resistant chamber 5 on the test results.

[0111] In some embodiments of this disclosure, as shown in FIG6, the natural gas chemical metering and detection device further includes a three-way connection assembly 12.

[0112] The first end of the three-way connecting assembly 12 is connected to the first output port of the first control valve 1 via a pipeline.

[0113] The second end of the tee connector 12 is connected to the second control valve 2 via a pipeline.

[0114] The third end of the three-way connector 12 is detachably fixed with a detection tube 3. After the detection tube 3 is inserted into the pressure-resistant cavity 5, it is detachably fixed to the first opening end of the pressure-resistant cavity 5.

[0115] This embodiment, through the setting of the three-way connection component, facilitates the replacement of the detection tube in the pressure-resistant cavity, thereby improving the applicability of the natural gas chemical metering and detection device.

[0116] In some embodiments of this disclosure, in relation to the natural gas chemical metering and detection device of the above embodiments, a natural gas chemical metering and detection method is also provided, as shown in FIG7, including:

[0117] Step 701: Connect the natural gas injection system to the second opening end of the pressure-resistant cavity 5 and the opening end of the detection tube 3. After the pressure-resistant cavity 5 is filled with natural gas, disconnect the connection between the natural gas injection system and the second opening end of the pressure-resistant cavity 5.

[0118] In some implementations, as shown in Figure 2, the natural gas sampling system is connected to the second opening of the pressure-resistant cavity 5 and the opening of the detection tube 3 by opening the first control valve, and the connection between the natural gas sampling system and the second opening of the pressure-resistant cavity 5 is disconnected by closing the first control valve and the valve at the second opening of the pressure-resistant cavity 5.

[0119] Step 702: Turn on pressure regulator 4 and adjust the injection flow rate to a predetermined value. The predetermined value can be set according to the analyte, and this disclosure does not limit its specific value.

[0120] Step 703: Turn on the color sensor 9 and the flow detector 6. When the color sensor 9 detects that the detection tube is in the sensing position and a color change occurs, turn off the flow detector 6. Calculate the concentration of the component to be tested based on the volume of natural gas detected by the flow detector 6 and the length of the color change in the detection tube 3.

[0121] This embodiment enables automatic sample introduction and accurate detection of color changes during natural gas component detection, as well as automatic calculation of the concentration of the component to be tested, reducing operational complexity and improving detection efficiency and accuracy.

[0122] In some embodiments, when the natural gas chemical metering and detection device includes a second control valve 2, as shown in Figure 3, after disconnecting the connection between the natural gas sampling system and the second opening end of the pressure-resistant chamber 5, it further includes:

[0123] Open the second control valve 2 to clean the first pipeline.

[0124] This embodiment avoids the impact of residual substances in the pipeline on the accuracy of the test by cleaning the first pipeline before testing.

[0125] In some embodiments, when the natural gas chemimetric detection device includes a third control valve 7 (as shown in Figure 4), and the component to be measured is a toxic gas, after detecting the concentration of the component to be measured, the device further includes:

[0126] Open the third control valve 7 to recover natural gas from the pressure chamber 5.

[0127] This embodiment improves the safety of the device and reduces harm to the human body by recovering natural gas from the pressure-resistant chamber.

[0128] In some embodiments, when the natural gas chemical metering and detection device includes a fourth control valve 8, as shown in Figure 5, the natural gas chemical metering and detection method further includes:

[0129] Open the fourth control valve 8 to pump air into the pressure-resistant chamber 5 using the air pumping device. The cleaning of the pressure-resistant chamber 5 is completed by repeatedly opening the third control valve 7 and the fourth control valve 8.

[0130] In practice, the above steps can be performed after natural gas recovery or before natural gas is filled into the pressure-resistant cavity 5.

[0131] This embodiment can avoid the impact of residual substances in the pressure-resistant cavity 5 on the detection accuracy.

[0132] To more clearly illustrate the technical solution of this disclosure, two examples are given below to describe the principles and features of this disclosure. The examples are only used to explain this disclosure and are not intended to limit the scope of this disclosure.

[0133] Example 1: Accurate and rapid chemical measurement of hydrogen sulfide in natural gas.

[0134] The chemical metering device for hydrogen sulfide in natural gas is shown in Figures 5 and 6. The device consists of a sample injection system, a pressure-resistant chamber, a Guangming Beichuan type 120U detection tube (0.1-6.0ppm), a color sensor, a pressure reducing valve (i.e., a pressure regulator), and a flow meter (i.e., a flow detector).

[0135] Samples were taken from the pressure gauge interface of the external pipeline of a natural gas purification plant for analysis. In order to compare the measurement results with the differences of existing measurement methods, the hydrogen sulfide content was determined by the technology disclosed herein, the traditional detection tube method, and the iodometric method in the same time period.

[0136] (1) In this method, a color sensor is placed at the midpoint of the detection tube (2.25 cm). At this point, the color change length of the detection tube is 2.25 cm. A silanized pipeline is used to connect the natural gas sample source (3.2 MPa) to the detection device of this method. After the pressure-resistant chamber is filled with natural gas sample, the three-way valve (i.e., the first control valve) is opened to the direction of the injection pipeline (the direction of the vent valve, i.e., the second control valve). After the vent valve is adjusted to fully flush the injection pipeline, the vent valve is closed, the pressure reducing valve is opened, and the injection flow rate is adjusted to 10 ml / min. The color sensor and flow meter are turned on, and the injection begins. After about 7 minutes, the color sensor detects the color change, the flow meter valve automatically closes, and the flow rate is recorded as 66.67 ml. Before the field test, a bottle of hydrogen sulfide gas standard material (6 ppm, relative expanded uncertainty of 2%, k=2) was used in the laboratory. The same test device and the same batch of the same model of detection tubes were used for calibration under the same test parameters, and the recorded flow rate was 33.05 ml. Therefore, the hydrogen sulfide content in the natural gas (product gas) in the external pipeline of the natural gas purification plant is 2.97 ppm.

[0137] (2) The traditional measurement method using the detection tube is as follows:

[0138] According to GB / T 11060.11-2014 "Determination of Sulfur Compounds in Natural Gas - Part 11: Determination of Hydrogen Sulfide Content by Colored Length Detection Tube Method", a Guangming Beichuan AP-20CT manual sampling pump and a Guangming Beichuan 120U detection tube (0.1-6.0ppm) were used for sampling and analysis at the pressure gauge interface of the external pipeline of the same natural gas purification plant. 50ml of sample was manually and slowly drawn. The estimated length of the detection tube changing from pale yellow to peach color was approximately 2.1ppm. The atmospheric pressure at the time of measurement was 98.6 kPa and the temperature was 21.3℃. According to the detection tube's instruction manual, the measured value = reading × 2 × 101.325 kPa / atmospheric pressure at the measurement point × temperature correction factor. The temperature correction factor corresponding to 21.3℃ was found to be 1.0. Therefore, the calculated measured value was 4.32ppm.

[0139] (3) Determination of hydrogen sulfide content by iodometric titration: According to GB / T 11060.1-2023 "Determination of sulfur compounds in natural gas - Part 1: Determination of hydrogen sulfide content by iodometric titration", the original data and calculation results for sampling and calculation are as follows:

[0140] Connect a hydrogen sulfide sampling absorber to the pressure gauge interface of the external pipeline of the same natural gas purification plant. Add 50 mL of zinc acetate solution to the absorber. Gently agitate the absorber inlet with a bulb syringe to allow some solution to enter the space below the glass orifice plate. Connect all parts tightly with a short section of tubing. Fully open the screw clamp and slowly open the sampling valve to fully displace the gas in the sampling conduit with the gas to be analyzed through the vent pipe. Record the flow meter reading as the initial reading for sampling. Adjust the screw clamp to allow the gas to pass through the absorber at a flow rate of 430 mL / min. The sampling volumes for two parallel tests were 150.000 L and 153.000 L, respectively. Record the gas temperature as 27.0℃ and the atmospheric pressure as 98.60 kPa. Remove the absorber and add 10 mL (or 20 mL) of iodine solution (2.5 g / L) and 10 mL of hydrochloric acid solution using a pipette. Attach the absorber head and gently agitate the solution at the absorber inlet with a bulb syringe to mix thoroughly. After reacting for 3 minutes, the solution was transferred to a 250 mL iodine flask and titrated with sodium thiosulfate standard solution (0.01006 mol / L). A blank test was performed following the same procedure. The titrant volumes used in the two tests were 3.0 mL and 3.05 mL, respectively. The calculated hydrogen sulfide concentrations for the two tests were 3.73 mg / mL. 3 and 3.67 mg / m 3 The average value was 3.70 mg / m³. 3 This translates to a volume fraction of 2.62 ppm.

[0141] A comparison of the three measurement methods shows that the hydrogen sulfide measurement result using the method disclosed herein is 2.97 ppm, with a deviation of 0.35 ppm from the result determined by the iodometric method (2.62 ppm). The hydrogen sulfide measurement value using the traditional detection tube method is 4.32 ppm, with a deviation of 1.7 ppm from the result determined by the iodometric method (2.62 ppm). It is evident that at the 2.62 ppm measurement point, the deviation has been reduced from 1.7 ppm to 0.35 ppm. Therefore, the measurement accuracy of the method disclosed herein is significantly improved compared to the traditional detection tube method.

[0142] Example 2: Accurate and rapid chemometric detection of carbon dioxide in natural gas.

[0143] The chemical metering device for detecting hydrogen sulfide in natural gas is shown in Figures 5 and 6. The device consists of a sample injection system, a pressure-resistant chamber, a Guangming Beichuan type 126SA detection tube (0.1-5.2%), a color sensor, a pressure reducing valve, and a flow meter.

[0144] Samples were taken from the pressure gauge interface of the external pipeline of a natural gas purification plant for analysis. In order to compare the measurement results with the differences of existing measurement methods, carbon dioxide content was determined by the technology disclosed herein, the traditional detection tube method, and gas chromatography in the same time period.

[0145] (1) In this detection method, the color sensor is positioned at the midpoint of the detection tube (4.0 cm). At this point, the color change length of the detection tube is 4.0 cm. The natural gas sample source (3.2 MPa) is connected to the detection device of this disclosure. After the pressure-resistant chamber is filled with the natural gas sample, the three-way valve is opened to the direction of the injection pipeline (vent valve direction). After the vent valve is adjusted to fully flush the injection pipeline, the vent valve is closed, the pressure-reducing valve is opened, and the injection flow rate is adjusted to 10 ml / min. The color sensor and flow meter are turned on, and the injection begins. After approximately 10 minutes, the color sensor detects a color change, the flow meter valve automatically closes, and the flow rate is recorded as 100.12 ml. Before the field test, a calibration gas mixture GBW(E)061322 with the components listed in Table 1 was used in the laboratory. The same test device and the same batch of the same model of detection tubes were used for calibration testing under the same test parameters, and the recorded flow rate was 44.56 ml. Therefore, the carbon dioxide content in the natural gas exported from the purification plant (product gas) is 1.30%.

[0146] Table 1. Composition of Standard Gas

[0147] (2) The traditional measurement method using the detection tube is as follows:

[0148] According to ASTM D4984–2020, "Test Method for Carbon Dioxide in Natural Gas Using Colored Length Test Tubes," a Guangming Beichuan AP-20CT manual sampling pump and a Guangming Beichuan 126SA test tube (0.1-5.2%) were used for sampling and analysis at the pressure gauge interface of the external pipeline of the same natural gas purification plant. 100 ml of sample was manually and slowly drawn. The estimated length of the test tube changing from bluish-purple to light peach was approximately 0.91%. The atmospheric pressure at the time of measurement was 98.6 kPa and the temperature was 21.3 °C. According to the test tube's instruction manual, the measured value = reading × 101.325 kPa / atmospheric pressure at the measurement point; therefore, the calculated measured value was 0.93%.

[0149] (3) Carbon dioxide content was determined by gas chromatography. Samples were taken according to GB / T 13609-2017 "Guidelines for Natural Gas Sampling" and brought back to the laboratory for chromatographic analysis according to GB / T 13610-2020. The result was 1.34%.

[0150] A comparison of the three measurement methods shows that the carbon dioxide measurement result using the method disclosed herein is 1.30%, with a deviation of 0.04% from the chromatographic result (1.34%). The carbon dioxide measurement value using the traditional detection tube method is 0.93%, with a deviation of 0.41% from the chromatographic result (1.34%). It is evident that at the 1.34% measurement point, the deviation has been improved from 0.41% to 0.04%. Therefore, the measurement accuracy of this disclosed method is significantly improved compared to the traditional detection tube method.

[0151] The natural gas chemical metering and detection device and method disclosed herein can achieve the following technical effects:

[0152] (1) By setting up a detection tube, a pressure-resistant cavity and a pressure regulator, the detection tube is equipped with natural gas component detection reagents, and the open end of the detection tube is used to connect to the natural gas injection system; the first open end of the pressure-resistant cavity is used to fix the detection tube; the second open end of the pressure-resistant cavity is connected to the internal cavity of the pressure-resistant cavity, and is used to connect to the natural gas injection system and to connect to the flow detector through the pressure regulator. This enables automatic natural gas injection, improves repeatability, reduces the difficulty of injection operation and reduces environmental impact, and avoids the problem of large human operation errors.

[0153] (2) By setting a color sensor, the color sensor is placed on the outside of the pressure-resistant cavity. The color sensor detects the color change of the detection tube at the sensing position, which can realize point measurement. Compared with the existing visual detection surface measurement (which has the problem of interface overlap and unclear interface), it can improve the accuracy of automatic detection and avoid the error of manual reading.

[0154] (3) By setting up a flow detector and a controller, the flow detector is used to detect the volume of natural gas flowing through the pressure-resistant cavity; the control device is connected to the flow detector and the color sensor, which is used to turn off the flow detector when the color sensor detects a color change, and calculate the concentration of the component to be tested based on the length of the color change of the detection tube and the volume of natural gas detected by the flow detector, so as to realize the automatic detection of natural gas concentration, improve detection repeatability, and improve detection efficiency and accuracy.

[0155] (4) Through the structure disclosed herein, online detection of natural gas can also be achieved.

[0156] In some embodiments of this disclosure, a computer device 902 is also provided, as shown in FIG. 9. The computer device 902 may include one or more processors 904, such as one or more central processing units (CPUs), each CPU implementing one or more hardware threads. The computer device 902 may also include any memory 906 for storing information of any kind, such as code, settings, data, etc. Non-limitingly, for example, the memory 906 may include any type of RAM, any type of ROM, flash memory, hard disk, optical disk, etc. More generally, any memory can use any technology to store information. Further, any memory may provide volatile or non-volatile retention of information. Further, any memory may represent a fixed or removable component of the computer device 902. In one case, when the processor 904 executes associated instructions stored in any memory or combination of memories, the computer device 902 may perform any operation of the associated instructions. The computer device 902 also includes one or more drive mechanisms 908 for interacting with any memory, such as hard disk drive mechanisms, optical disk drive mechanisms, etc.

[0157] Computer device 902 may also include an input / output module 910 (I / O) for receiving various inputs (via input device 912) and providing various outputs (via output device 914). A specific output mechanism may include a presentation device 916 and an associated graphical user interface 918 (GUI). In other embodiments, the input / output module 910 (I / O), input device 912, and output device 914 may be omitted, and the device may function solely as a computer device within a network. Computer device 902 may also include one or more network interfaces 920 for exchanging data with other devices via one or more communication links 922. One or more communication buses 924 couple the components described above together.

[0158] Communication link 922 can be implemented in any way, such as via a local area network (LAN), a wide area network (WAN) (e.g., the Internet), a point-to-point connection, or any combination thereof. Communication link 922 may include any combination of hardwired links, wireless links, routers, gateway functions, name servers, etc., governed by any protocol or combination of protocols.

[0159] This disclosure also provides a computer-readable storage medium storing a computer program that, when executed by a processor, performs the steps of the above-described method.

[0160] This disclosure also provides computer-readable instructions, wherein when a processor executes the instructions, the program therein causes the processor to perform the methods of any of the foregoing embodiments.

[0161] It should be understood that in the various embodiments of this disclosure, the sequence number of each process does not imply the order of execution. The execution order of each process should be determined by its function and internal logic, and should not constitute any limitation on the implementation process of the embodiments of this disclosure.

[0162] It should also be understood that, in the embodiments of this disclosure, the term "and / or" is merely a description of the relationship between related objects, indicating that three relationships can exist. For example, A and / or B can represent: A existing alone, A and B existing simultaneously, and B existing alone. Furthermore, the character " / " in this disclosure generally indicates that the preceding and following related objects have an "or" relationship.

[0163] Those skilled in the art will recognize that the units and algorithm steps of the various examples described in conjunction with the embodiments disclosed in this disclosure can be implemented in electronic hardware, computer software, or a combination of both. To clearly illustrate the interchangeability of hardware and software, the components and steps of the various examples have been generally described in terms of functionality in the foregoing description. Whether these functions are implemented in hardware or software depends on the specific application and design constraints of the technical solution. Those skilled in the art can use different methods to implement the described functions for each specific application, but such implementation should not be considered beyond the scope of this disclosure.

[0164] Those skilled in the art will clearly understand that, for the sake of convenience and brevity, the specific working processes of the systems, devices, and units described above can be referred to the corresponding processes in the foregoing method embodiments, and will not be repeated here.

[0165] In the embodiments provided in this disclosure, it should be understood that the disclosed systems, apparatuses, and methods can be implemented in other ways. For example, the apparatus embodiments described above are merely illustrative; for instance, the division of units is only a logical functional division, and in actual implementation, there may be other division methods. For example, multiple units or components may be combined or integrated into another system, or some features may be ignored or not executed. Furthermore, the couplings or direct couplings or communication connections shown or discussed may be indirect couplings or communication connections through some interfaces, apparatuses, or units, or they may be electrical, mechanical, or other forms of connection.

[0166] The units described as separate components may or may not be physically separate. The components shown as units may or may not be physical units; that is, they may be located in one place or distributed across multiple network units. Some or all of the units can be selected to achieve the purpose of the embodiments of this disclosure, depending on actual needs.

[0167] Furthermore, the functional units in the various embodiments of this disclosure can be integrated into one processing unit, or each unit can exist physically separately, or two or more units can be integrated into one unit. The integrated unit can be implemented in hardware or as a software functional unit.

[0168] If the integrated unit is implemented as a software functional unit and sold or used as an independent product, it can be stored in a computer-readable storage medium. Based on this understanding, the technical solution of this disclosure, in essence, or the part that contributes to related technologies, or all or part of the technical solution, can be embodied in the form of a software product. This computer software product is stored in a storage medium and includes several instructions to cause a computer device (which may be a personal computer, server, or network device, etc.) to execute all or part of the steps of the methods of the various embodiments of this disclosure. The aforementioned storage medium includes various media capable of storing program code, such as USB flash drives, portable hard drives, read-only memory (ROM), random access memory (RAM), magnetic disks, or optical disks.

[0169] This disclosure uses specific embodiments to illustrate the principles and implementation methods of this disclosure. The description of the above embodiments is only for the purpose of helping to understand the methods and core ideas of this disclosure. At the same time, for those skilled in the art, there will be changes in the specific implementation methods and application scope based on the ideas of this disclosure. Therefore, the content of this specification should not be construed as a limitation of this disclosure.

Claims

1. A natural gas stoichiometry detection device, characterized by, include: The detector tube (3), the pressure-resistant chamber (5), the color sensor (9), the pressure regulator (4), the flow detector (6), and the control device (10) are included. The detection tube (3) is equipped with a natural gas component detection reagent, and the open end of the detection tube (3) is used to connect to the natural gas sampling system; The first opening of the pressure-resistant cavity (5) is used to fix the detection tube (3); the second opening of the pressure-resistant cavity (5) is connected to the internal cavity of the pressure-resistant cavity (5) and is used to connect to the natural gas injection system and to connect to the flow detector (6) through the pressure regulator (4); The color sensor (9) is located on the outside of the pressure-resistant cavity (5) and is used to detect the color change of the detection tube (3) at the sensing position; The pressure regulator (4) is used to adjust the pressure of the pressure-resistant cavity (5); The flow detector (6) is used to detect the volume of natural gas flowing through the pressure-resistant cavity (5); The control device (10) is connected to the flow detector (6) and the color sensor (9) and is used to turn off the flow detector (6) when the color sensor (9) detects a color change, and to calculate the concentration of the component to be tested based on the length of the color change in the detection tube and the volume of natural gas detected by the flow detector (6).

2. The apparatus of claim 1, wherein, The control device (10) calculates the concentration of the component to be tested based on the color change length of the detection tube and the volume of natural gas detected by the flow detector (6), including: The mass of the analyte is calculated based on the color change length and color change chemical reaction of the detection tube. The concentration of the component to be tested is calculated based on the mass of the component to be tested and the volume of natural gas detected by the flow detector (6).

3. The apparatus of claim 1, wherein, The color sensor (9) includes: a laser emitter (91) and a laser receiver (92); The laser emitter (91) is disposed on one side of the pressure-resistant cavity (5) and is used to emit laser signals; The laser receiver (92) is located on the other side of the pressure-resistant cavity (5) and opposite to the laser emitter (91) for receiving the laser signal; The laser receiver (92) is connected to the control device (10), and the control device (10) is used to determine whether a color change occurs at the sensing position based on the laser signal received by the laser receiver (92).

4. The apparatus of claim 1, wherein, Also includes: Mobile devices; The color sensor (9) is mounted on the mobile device, which is used to move the color sensor (9) to adjust the sensing position.

5. The apparatus of claim 4, wherein, The moving device includes: a slide rail and a moving component; The moving component is disposed on the slide rail, and the color sensor (9) is disposed on the moving component; The moving component is connected to the control device (10), and the control device (10) is also used to determine the sensing position according to the component to be measured and the concentration of the component to be measured, and to control the moving component to drive the color sensor (9) to move to the sensing position.

6. The apparatus of claim 1, wherein, Also includes: First control valve (1); The first control valve (1) has an input port, a first output port and a second output port. The input port of the first control valve (1) is used to connect to the natural gas injection system. The first output port of the first control valve (1) is connected to the opening end of the detection tube (3) through a first pipeline. The second output port of the first control valve (1) is connected to the second opening end of the pressure-resistant cavity (5) through a second pipeline. The first control valve (1) is used to control the input of natural gas to the pressure-resistant cavity (5) and the first pipeline.

7. The apparatus of claim 6, wherein, Also includes: Second control valve (2); The second control valve (2) is connected to a first pipeline near the opening end of the detection tube (3) for cleaning the first pipeline.

8. The apparatus of claim 6, wherein, Also includes: Third control valve (7); One end of the third control valve (7) is connected to the pipeline between the second output port of the first control valve (1) and the second opening end of the pressure-resistant cavity (5) through a three-way fitting; The other end of the third control valve (7) is connected to a recovery device for recovering natural gas in the pressure-resistant cavity (5).

9. The apparatus of claim 8, wherein, Also includes: Fourth control valve (8); One end of the fourth control valve (8) is connected to the pipeline between the second output port of the first control valve (1) and the second opening end of the pressure-resistant cavity (5) through a three-way fitting; The other end of the fourth control valve (8) is connected to an air pumping device for pumping air into the pressure-resistant cavity (5).

10. The apparatus of claim 7, wherein, Also includes: Three-way Connection components; The first end of the three-way connection assembly is connected to the first output port of the first control valve (1) via a pipeline; The second end of the three-way connector is connected to the second control valve (2) via a pipeline; The detection tube (3) is detachably fixed at the third end of the three-way connector assembly. After the detection tube (3) is inserted into the pressure-resistant cavity (5), it is detachably fixed at the first opening end of the pressure-resistant cavity (5).

11. A method of stoichiometric detection of natural gas, characterized by, The natural gas chemical metering and detection device according to any one of claims 1 to 10 includes: Connect the natural gas injection system to the second opening end of the pressure-resistant cavity (5) and the opening end of the detection tube (3). After the pressure-resistant cavity (5) is filled with natural gas, disconnect the connection between the natural gas injection system and the second opening end of the pressure-resistant cavity (5). Turn on the pressure regulator (4) and adjust the injection flow rate to a predetermined value; The color sensor (9) and the flow detector (6) are turned on, and the concentration of the component to be measured is detected by the natural gas chemical metering detection device.

12. The method of claim 11, wherein, When the natural gas chemical metering and detection device includes a second control valve (2), after disconnecting the connection between the natural gas injection system and the second opening end of the pressure-resistant cavity (5), it further includes: Open the second control valve (2) to clean the first pipeline.

13. The method of claim 11, wherein, When the natural gas chemical metering and detection device includes a third control valve (7), and the component to be tested is a toxic gas, after detecting the concentration of the component to be tested, it further includes: Open the third control valve (7) to recover natural gas from the pressure chamber (5).

14. The method of claim 13, wherein, When the natural gas chemical metering and detection device includes a fourth control valve (8), it also includes: Opening the fourth control valve (8), the pressure chamber (5) is inflated by the inflator. The pressure chamber (5) is cleaned by repeatedly opening the third control valve (7) and the fourth control valve (8).

15. A computer device comprising a memory, a processor, and a computer program stored on the memory and executable on the processor, characterized in that, The computer program is executed by the processor to implement the method of any one of claims 11-14.

16. A computer-readable storage medium, the computer-readable storage medium storing a computer program, characterized in that, The computer program is executed by the processor of the computer device to implement the method of any one of claims 11-14.

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