A method, system, apparatus and device for performance calibration of a high-sulfur flowmeter

Abstract

The present application belongs to the technical field of oil and gas measurement, and particularly relates to a performance calibration method, system, device and equipment for a high-sulfur flowmeter, the system comprising a main pipeline and a bypass pipeline, the main pipeline being provided with a flowmeter to be calibrated, and the bypass pipeline being provided with a plurality of flow measurement devices, the method comprising: determining a compression factor combination of the flowmeter to be calibrated according to working condition data of the main pipeline; obtaining measurement data of the plurality of flow measurement devices and gas parameters of natural gas; calculating a corrected compression factor of the flowmeter to be calibrated according to the gas parameters and the compression factor combination; calculating a measurement relative deviation value according to the measurement data of the plurality of flow measurement devices, the corrected compression factor and a measurement value of the flowmeter to be calibrated; and calibrating the measurement value of the flowmeter to be calibrated by using the measurement relative deviation value. The present application uses a plurality of flow measurement devices as a standard for performance evaluation, and improves the accuracy of calibration of measurement results of flowmeters used in the field in combination with working conditions of field production.

Description

Technical Field

[0001] This article belongs to the field of oil and gas measurement technology, specifically involving a high sulfur content flow meter performance calibration method, system, device and equipment. Background Technology

[0002] 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 transactions has received increasing attention. However, 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 reservoir extraction is increasing, which also brings new challenges to the field of measurement.

[0003] 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. Orifice plate flow meters require regular cleaning to ensure accuracy. However, for high-sulfur natural gas production, frequent cleaning and maintenance of orifice plate flow meters introduces more safety risks and workload to the production site. Meanwhile, how to accurately calibrate the flow meters used on-site has become a pressing technical problem that needs to be solved. Summary of the Invention

[0004] To address the aforementioned problems in the prior art, the purpose of this paper is to provide a method, system, apparatus, and equipment for calibrating the performance of high sulfur content flow meters, so as to improve the accuracy of calibration of flow meter measurement results used in the field.

[0005] To solve the above-mentioned technical problems, the specific technical solution presented in this paper is as follows:

[0006] On the one hand, this paper provides a performance calibration method for a high sulfur content flow meter, applied to a high sulfur content flow meter performance calibration system. The system includes a main pipeline and a bypass pipeline, the bypass pipeline being connected to the side wall of the main pipeline. The main pipeline is equipped with the flow meter to be calibrated, and the bypass pipeline is equipped with multiple flow measurement devices. The method includes:

[0007] Based on the operating data of the main pipeline, determine the compressibility factor combination of the flow meter to be calibrated;

[0008] Acquire measurement data from multiple flow measurement devices and gas parameters of high-sulfur natural gas in the bypass pipeline;

[0009] The calibration compression factor of the flow meter to be calibrated is calculated based on the combination of the gas parameters and the compressibility factor.

[0010] Based on the measurement data from multiple flow measurement devices, the correction compressibility factor, and the measurement value of the flow meter to be calibrated, the relative deviation value of the flow meter to be calibrated is calculated, and the measurement value of the flow meter to be calibrated is calibrated using the relative deviation value.

[0011] Further, determining the compressibility factor combination of the flow meter to be calibrated based on the operating data of the main pipeline includes:

[0012] Multiple sampling data points were obtained from the high-sulfur natural gas in the main pipeline. Each sampling data point included gas parameters and sulfur content.

[0013] Obtain a set of compressibility factor formulas, and calculate the test curve corresponding to each compressibility factor formula in the set of compressibility factor formulas based on multiple sampling data of high-sulfur natural gas in the main pipeline.

[0014] Determine whether there are empirical values ​​for the natural gas compressibility factor corresponding to the multiple sampled data;

[0015] If it exists, then the empirical values ​​of the natural gas compressibility factor corresponding to multiple sampled data will be plotted to generate an empirical curve;

[0016] Calculate the similarity between each test curve and the empirical curve in turn;

[0017] The compression factor formula combination corresponding to the test curves with similarity higher than a preset threshold is determined as the compression factor combination of the flow meter to be calibrated;

[0018] If it does not exist, the test curves will be aggregated, and the combination of compression factor formulas corresponding to the test curve combination with the best aggregation effect will be determined as the compression factor combination of the flow meter to be calibrated.

[0019] Further, if the condition does not exist, the test curves will be aggregated, and the compressibility factor formula combination corresponding to the test curve combination with the best aggregation effect will be determined as the compressibility factor combination of the flowmeter to be calibrated, including:

[0020] Based on the number of test curves, generate multiple test curve sets, each containing the same number of test curves;

[0021] Based on the similarity between any two test curves in each test curve set, calculate the sum of the similarities between any two test curves in each test curve set;

[0022] The combination of compression factor formulas corresponding to the set of test curves with the smallest sum of similarity is determined as the compression factor combination of the flowmeter to be calibrated.

[0023] Furthermore, each flow measurement device includes a flow meter, a pressure measurement unit, and a temperature measurement unit, and different flow measurement devices include different types of flow meters.

[0024] Further, the step of calculating the correction compressibility factor of the flow meter to be calibrated based on the combination of the gas parameters and the compressibility factor includes:

[0025] Determine the calculation formula for each compression factor in the compression factor combination;

[0026] Based on the gas parameters and the calculation formula for each compressibility factor, the calculated value corresponding to each compressibility factor is obtained;

[0027] The calibration compression factor of the flow meter to be calibrated is calculated based on the calculated value corresponding to each compression factor.

[0028] Furthermore, the relative deviation value of the flow meter to be calibrated is obtained by the following formula:

[0029]

[0030] in, To measure the relative deviation value; V x P represents the measured value of the flow meter to be calibrated. i V represents the pressure measurement value in the i-th flow measurement device. i T represents the measured value of the flow meter in the i-th flow measurement device; i Z represents the temperature measurement value in the i-th flow measurement device; s To correct the compression factor; n is the number of flow measurement devices.

[0031] On the other hand, this paper also provides a high sulfur content flow meter performance calibration system, the system comprising: a data acquisition device, a compressibility factor combination determination device, and a calibration device;

[0032] The acquisition device includes a main pipeline and a bypass pipeline. The main pipeline is used to transport high-sulfur natural gas. A flow meter to be calibrated is installed on the main pipeline. The bypass pipeline is connected to the side wall of the main pipeline and is located upstream of the flow meter to be calibrated. Multiple flow measurement devices are installed on the bypass pipeline to obtain measurement data of high-sulfur natural gas entering the bypass pipeline.

[0033] The compressibility factor combination determining device is used to determine the compressibility factor combination of the flow meter to be calibrated based on the operating condition data of the main pipeline.

[0034] The calibration device is connected to the flow meter to be calibrated, multiple flow measurement devices, and a compressibility factor combination determination device. It is used to acquire measurement data from the multiple flow measurement devices and gas parameters of high-sulfur natural gas in the bypass pipeline; calculate the correction compressibility factor of the flow meter to be calibrated based on the gas parameters and the compressibility factor combination; calculate the relative deviation value of the flow meter to be calibrated based on the measurement data from the multiple flow measurement devices, the correction compressibility factor, and the measured value of the flow meter to be calibrated; and calibrate the measured value of the flow meter to be calibrated using the relative deviation value.

[0035] On the other hand, this paper also provides a high sulfur content flow meter performance calibration device, applied to a high sulfur content flow meter performance calibration system. The system includes a main pipeline and a bypass pipeline. The main pipeline is equipped with a flow meter to be calibrated, and the bypass pipeline is equipped with multiple flow measurement devices. The device includes:

[0036] The compressibility factor combination determination module is used to determine the compressibility factor combination of the flow meter to be calibrated based on the operating condition data of the main pipeline.

[0037] The information acquisition module is used to acquire measurement data from multiple flow measurement devices and gas parameters of high-sulfur natural gas in the bypass pipeline;

[0038] The calibration compressibility factor calculation module is used to calculate the calibration compressibility factor of the flow meter to be calibrated based on the gas parameters and the compressibility factor combination.

[0039] The calibration module is used to calculate the relative deviation value of the flow meter to be calibrated based on the measurement data of the multiple flow measurement devices, the correction compression factor, and the measurement value of the flow meter to be calibrated, and to calibrate the measurement value of the flow meter to be calibrated using the relative deviation value.

[0040] On the other hand, this document also 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, when executing the computer program, implements the method described above.

[0041] Finally, this document also provides a computer-readable storage medium storing a computer program that, when executed by a processor, implements the method described above.

[0042] Using the above technical solution, the high-sulfur flow meter performance calibration method, system, device, and equipment described in this paper involve connecting a bypass pipe to the side wall of a main pipeline. The main pipeline is equipped with a flow meter to be calibrated, and the bypass pipe is equipped with multiple flow measurement devices. First, the compressibility factor combination of the flow meter to be calibrated is determined based on the operating data of the main pipeline. Then, the relative deviation value of the flow meter to be calibrated is calculated using the measurement data of multiple flow measurement devices and the correction compressibility factor calculated from the gas parameters of high-sulfur natural gas. The relative deviation value is then used to calibrate the measured value of the flow meter to be calibrated. This paper uses multiple flow measurement devices as the standard for performance evaluation and combines them with the operating conditions of on-site production to improve the accuracy of the calibration of the measurement results of the flow meter used in the field.

[0043] To make the above and other objects, features and advantages of this document more apparent and understandable, preferred embodiments are described below in detail with reference to the accompanying drawings. Attached Figure Description

[0044] To more clearly illustrate the technical solutions in the embodiments or prior art described herein, the accompanying drawings used in the description of the embodiments or prior art will be briefly introduced below. Obviously, the accompanying drawings described below are only some embodiments of this article. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0045] Figure 1 This document shows a schematic diagram of a high sulfur content flow meter performance calibration system provided in an embodiment.

[0046] Figure 2 A schematic diagram of the acquisition device in the embodiments of this article is shown;

[0047] Figure 3 This document illustrates a step-by-step diagram of a high-sulfur flow meter performance calibration method provided in an embodiment of the invention.

[0048] Figure 4 A schematic diagram of the steps for determining the combination of compression factors in the embodiments of this paper is shown;

[0049] Figure 5 A schematic diagram of the steps for determining the combination of compression factors is shown in another embodiment of this paper;

[0050] Figure 6 This document shows a schematic diagram of a high sulfur content flow meter performance calibration device provided in an embodiment of the invention.

[0051] Figure 7 A schematic diagram of the structure of the computer device provided in the embodiments of this article is shown.

[0052] Explanation of symbols in the attached drawings:

[0053] 01. Data acquisition device;

[0054] 02. Compression factor combination determination device;

[0055] 03. Calibration device;

[0056] 10. Main pipeline;

[0057] 20. Bypass pipe;

[0058] 11. Flow meter to be calibrated;

[0059] 12. First control unit;

[0060] 13. Filter;

[0061] 14. Heater;

[0062] 21. First flow measurement device;

[0063] 22. Second flow measurement device;

[0064] 23. Second control unit;

[0065] 211. First measuring flow meter;

[0066] 212. First pressure measurement unit;

[0067] 213. First temperature measurement unit;

[0068] 221. Second measuring flow meter;

[0069] 222. Second pressure measurement unit;

[0070] 223. Second temperature measurement unit;

[0071] 100. Compression factor combination determination module;

[0072] 200. Information Acquisition Module;

[0073] 300. Correction compression factor calculation module;

[0074] 400. Calibration module;

[0075] 702. Computer equipment;

[0076] 704, Processor;

[0077] 706. Memory;

[0078] 708. Drive mechanism;

[0079] 710. Input / Output Module;

[0080] 712. Input devices;

[0081] 714. Output devices;

[0082] 716. Presentation equipment;

[0083] 718. Graphical User Interface;

[0084] 720. Network interface;

[0085] 722. Communication link;

[0086] 724. Communication bus. Detailed Implementation

[0087] The technical solutions in the embodiments described below will be clearly and completely described with reference to the accompanying drawings. Obviously, the described embodiments are only a part of the embodiments described herein, and not all of the embodiments. Based on the embodiments described herein, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of this document.

[0088] It should be noted that the terms "first," "second," etc., used in the specification, claims, and accompanying drawings herein 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 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 a 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.

[0089] 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 generally has a hydrogen sulfide (H2S) volume fraction of 2% to 10% or a mass content of 30 g / m³. 3 ~150g / m 3 The metering of high-sulfur natural gas in actual production processes directly adopts the metering methods and standards of conventional natural gas. The most widely used flow meters on site are standard orifice plate flow meters and other types of flow meters. According to the 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.

[0090] 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.

[0091] To address the aforementioned issues, this specification provides a high-sulfur flow meter performance calibration system, which can improve the accuracy of performance evaluation of high-sulfur flow meters, thereby enhancing the accuracy and reliability of their measurement performance calibration.

[0092] In the embodiments described in this specification, such as Figure 1 As shown, the system may include a data acquisition device 01, a compression factor combination determination device 02, and a calibration device 03, wherein further reference is made to... Figure 2 The acquisition device 01 includes a main pipeline 10 and a bypass pipeline 20. The main pipeline 10 is used to transport high-sulfur natural gas. A flow meter 11 to be calibrated is installed on the main pipeline 10. The bypass pipeline 20 is connected to the side wall of the main pipeline 10 and is located upstream of the flow meter 11 to be calibrated. Multiple flow measurement devices are installed on the bypass pipeline 20 to obtain measurement data of the high-sulfur natural gas entering the bypass pipeline 20. The compressibility factor combination determination device 02 is used to determine the compressibility factor combination of the flow meter 11 to be calibrated based on the operating data of the main pipeline 10.

[0093] The calibration device 03 is connected to the flow meter 11 to be calibrated, multiple flow measuring devices, and the compressibility factor combination determination device 02. It is used to acquire the measurement data of the multiple flow measuring devices and the gas parameters of the high-sulfur natural gas in the bypass pipe 20; calculate the correction compressibility factor of the flow meter 11 to be calibrated based on the gas parameters and the compressibility factor combination; calculate the relative deviation value of the flow meter 11 to be calibrated based on the measurement data of the multiple flow measuring devices, the correction compressibility factor, and the measurement value of the flow meter 11 to be calibrated; and calibrate the measurement value of the flow meter 11 to be calibrated using the relative deviation value.

[0094] In this embodiment of the specification, a bypass pipe 20 is connected to the side wall of the on-site production transportation pipeline (i.e., the main pipeline 10), and the flow measurement device on the bypass pipe 20 is used to measure the flow rate of natural gas in the pipeline. The measurement result is then combined with the compressibility factor combination determined according to the on-site production conditions to calibrate the measurement result of the flow meter 11 to be calibrated. This avoids the need to set up corresponding calibration equipment on the main pipeline 10, improves the efficiency and accuracy of calibration, reduces calibration costs, and improves convenience.

[0095] The flow meter 11 to be calibrated can be an orifice plate flow meter, which is a commonly used flow meter in the field production process, or it can be other types of flow meters, which are not limited in the embodiments of this specification.

[0096] By installing multiple flow measurement devices on the bypass pipe 20 and evaluating and calibrating the multiple measurement results in a unified manner, the measurement error caused by a single flow measurement device can be reduced, thereby improving the reliability of the measurement.

[0097] In the embodiments described in this specification, each flow measurement device includes a flow meter, a pressure measurement unit, and a temperature measurement unit. Different flow measurement devices include different types of flow meters. Different types of flow meters have different measurement accuracy and measurement focus dimensions. Therefore, by using different types of flow meters, the measurement defects of each flow meter can be further offset, thereby improving the accuracy of the measurement performance evaluation and calibration of the flow meter 11 to be calibrated on the main pipeline 10.

[0098] In some optional embodiments, there are two flow measurement devices: a first flow measurement device 21 and a second flow measurement device 22. The first flow measurement device 21 includes a first flow meter 211, a first pressure measurement unit 212, and a first temperature measurement unit 213. The second flow measurement device 22 includes a second flow meter 221, a second pressure measurement unit 222, and a second temperature measurement unit 223. The first flow measurement device 21 and the second flow measurement device 22 are used to calibrate the flow meter 11 to be calibrated. Optionally, the first flow measurement device 21 is an external clamp-on ultrasonic flow meter, and the second flow measurement device 22 is a contact type. Ultrasonic flow meters, especially clamp-on ultrasonic flow meters, can measure volumetric flow rate without contacting the gas inside the pipe, making them easier to install and debug on-site. Contact ultrasonic flow meters need to be installed on the bypass pipe 20, and their measurement accuracy is relatively more accurate. The measuring range of clamp-on ultrasonic flow meters should be 1.5 to 2 times that of contact ultrasonic flow meters to achieve a wider measurement range. In addition, the accuracy class of ultrasonic flow meters reaches 1.0, which can ensure the accuracy of measurement to a certain extent. Therefore, using these two types of flow meters can reduce the complexity and difficulty of assembly while ensuring the accuracy of measurement. In some other embodiments, the number and type of flow measuring devices may be set differently, which are not limited in the embodiments of this specification.

[0099] The ultrasonic flow meter works by using an ultrasonic transducer to detect the flow velocity with ultrasonic waves, thus obtaining the operating flow rate of the gas in the pipeline. The final actual flow rate is then calculated based on the compressibility factor. However, due to the compressibility factor, the measurement results from the ultrasonic flow meter will deviate somewhat from the actual value. To further ensure the reliability of the flow measurement results, a mass flow meter can be installed in the system. This mass flow meter is installed on the bypass pipe 20. Since the mass flow meter is not affected by the compressibility factor, it can directly obtain the mass flow rate. Therefore, the mass flow rate of the mass flow meter can be used to verify the measurement results of the flow measurement device.

[0100] For example, during specific verification, the deviation between the measurement results of the mass flow meter and the measurement results of the flow meter in each flow measurement device can be calculated. When the deviation is within a preset range, the reliability of the flow measurement device can be determined, and it can be used to evaluate and calibrate the measurement results of the flow meter 11 to be calibrated. Of course, other verification methods are also possible, and are not limited in the embodiments of this specification.

[0101] In this embodiment of the specification, the data acquisition device 01 may further include a first control unit 12 and a second control unit 23. The first control unit 12 is disposed in the main pipeline 10 and connected in parallel with the bypass pipeline 20, and is used to control the interruption of the flow of high-sulfur natural gas in the main pipeline 10, thereby allowing the gas flow to enter the bypass pipeline 20, and then enter the main pipeline 10 and finally enter the flow meter 11 to be calibrated. The second control unit 23 is disposed in the bypass pipeline 20 and is used to control the connection and disconnection of the bypass pipeline 20.

[0102] In some embodiments of this specification, the first control unit 12 and the second control unit 23 may be pipeline control valves.

[0103] In this embodiment of the specification, the collection device 01 is further provided with a filter 13 and a heater 14. The filter 13 and the heater 14 are disposed at the input end of the main pipeline 10. The filter 13 can filter impurities in the high-sulfur natural gas entering the main pipeline 10, improving the purity of the transmitted gas, avoiding damage to the pipeline by impurities during transmission, and improving the efficiency of natural gas transmission. The heater 14 can increase the activity of the natural gas in the main pipeline 10, thereby reducing transmission resistance and further improving the speed and efficiency of natural gas transmission.

[0104] The specific working logic of the compression factor combination determination device 02 and the calibration device 03 will be described later. Optionally, the compression factor combination determination device 02 and the calibration device 03 can be backend servers. The servers can interact with each other, for example, by establishing a communication connection through wired or wireless means. By configuring the corresponding computing logic of the server, the corresponding functions can be realized. The server can be an independent physical server, or a server cluster or distributed system composed of multiple physical servers. It can also be a cloud server that provides basic cloud computing services such as cloud services, cloud databases, cloud computing, cloud functions, cloud storage, network services, cloud communication, middleware services, domain name services, security services, content delivery networks (CDN), and big data and artificial intelligence platforms.

[0105] The embodiments of this specification provide a high sulfur content flow meter performance calibration system, which can quickly assemble a device for evaluating and calibrating the flow meter measurement performance in the main pipeline 10 during on-site generation, thereby improving the accuracy and reliability of high sulfur content natural gas flow measurement during on-site generation.

[0106] Based on the high sulfur content flow meter performance calibration system provided above, this specification provides a high sulfur content flow meter performance calibration method, which can improve the accuracy of calibration of flow meter measurement results used in the field. Figure 3 This is a schematic diagram illustrating the steps of a high-sulfur flow meter performance calibration method provided in this embodiment. This specification provides the operational steps of the method described in the embodiments or flowcharts, but based on conventional or non-inventive labor, more or fewer operational 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 possible execution order. In actual system or device products, the methods shown in the embodiments or accompanying drawings can be executed sequentially or in parallel. Specifically, as shown... Figure 3 As shown, the method may include:

[0107] S101: Determine the compressibility factor combination of the flow meter to be calibrated based on the operating data of the main pipeline;

[0108] S102: Acquire measurement data from multiple flow measurement devices and gas parameters of high-sulfur natural gas in the bypass pipeline;

[0109] S103: Calculate the correction compression factor of the flow meter to be calibrated based on the combination of the gas parameters and the compressibility factor;

[0110] S104: Based on the measurement data of the multiple flow measurement devices, the correction compressibility factor, and the measurement value of the flow meter to be calibrated, calculate the relative deviation value of the flow meter to be calibrated, and use the relative deviation value to calibrate the measurement value of the flow meter to be calibrated.

[0111] This specification can be understood as follows: the embodiments determine the appropriate combination of compression factors by using the operating condition data of high sulfur natural gas during transmission, and then calculate the relative deviation value of the flow meter 11 to be calibrated by obtaining the measurement data of multiple flow measurement devices in the bypass pipeline 20 and the gas parameters in the pipeline. The measurement value of the flow meter 11 to be calibrated can then be calibrated using the relative deviation value. This specification can quickly and accurately calibrate the flow meter in the field generation process.

[0112] As gas flows, its volume changes with the environment. For example, under different temperature and pressure conditions, the volume of gas during flow will deviate from the volume under ideal conditions. Therefore, the natural gas compressibility factor can be used to represent the degree of deviation between the natural gas measurement results and the ideal gas. By calculating the compressibility factor and combining it with the measurement results, a true and reliable measurement result can be obtained.

[0113] In the existing technology, there are many methods for calculating the compressibility factor, which correspond to different calculation formulas. However, different compressibility factor calculation formulas are designed under different conditions (such as temperature, pressure, physical properties and other working conditions). For example, GB / T 17747 recommends the use of the AGA8-92DC calculation method, and ISO20765 recommends the use of the GERG-2008 equation of state calculation method and the CPA equation of state. Therefore, how to select a suitable compressibility factor is also a necessary prerequisite for improving the accuracy of measurement results.

[0114] As an option, such as Figure 4 As shown, determining the compressibility factor combination of the flow meter to be calibrated based on the operating data of the main pipeline includes:

[0115] S201: Obtain multiple sampling data points of high-sulfur natural gas in the main pipeline. Each sampling data point includes gas parameters and sulfur content.

[0116] S202: Obtain the set of compressibility factor formulas, and calculate the test curve corresponding to each compressibility factor formula in the set of compressibility factor formulas based on multiple sampling data of high-sulfur natural gas in the main pipeline;

[0117] S203: Determine whether there are empirical values ​​for the natural gas compressibility factor corresponding to the multiple sampled data;

[0118] S204: If it exists, then plot the empirical values ​​of the natural gas compressibility factor corresponding to multiple sampled data to generate an empirical curve;

[0119] S205: Calculate the similarity between each test curve and the empirical curve in sequence;

[0120] S206: The combination of compression factor formulas corresponding to test curves with similarity higher than a preset threshold is determined as the compression factor combination of the flow meter to be calibrated;

[0121] S207: If it does not exist, the test curves will be aggregated, and the compression factor formula combination corresponding to the test curve combination with the best aggregation effect will be determined as the compression factor combination of the flow meter 11 to be calibrated.

[0122] This can be understood as a combination of compressibility factor calculation methods, with different methods corresponding to different formulas. The sampled data can be operating condition data, such as temperature, pressure, and gas parameters, or other parameters related to compressibility factor calculation. Empirical values ​​of the compressibility factor corresponding to the sampled data are found in historically published data (e.g., experimental data from relevant historical documents). These empirical values ​​can be considered the true values ​​of the natural gas compressibility factor under the current sampled data. If such empirical values ​​exist, empirical curves can be generated, and the compressibility factor combination for the flow meter 11 to be calibrated (i.e., under the current operating conditions) can be determined based on the similarity of the curves. If not, the test curves are aggregated, and the compressibility factor formula combination corresponding to the test curve combination with the best aggregation effect is determined as the compressibility factor combination for the flow meter 11 to be calibrated. This ensures that each compressibility factor calculation method in the aggregated combination has stable and similar calculation results. These stable and similar calculation results also reflect that the results corresponding to each compressibility factor calculation method in the compressibility factor combination are close to the true compressibility factor.

[0123] For example, the compression factor formula set contains 10 formulas. Eight sampled data points are obtained, and these eight data points are substituted into the 10 formulas to obtain 80 calculation results. Each formula corresponds to eight calculation results, and these eight results are plotted as test curves. Correspondingly, by checking if the eight sampled data points have corresponding empirical values ​​for compression factors, if so, an empirical curve is plotted, and the distance between each test curve and the empirical curve is calculated. This distance represents the similarity between the test curve and the empirical curve, and can be Euclidean distance, Mahalanobis distance, Manhattan distance, etc. Different similarity calculation methods correspond to different preset thresholds. The combination of compression factor formulas corresponding to test curves with similarity higher than the preset threshold is determined as the compression factor combination of the flowmeter 11 to be calibrated. For example, if two similarities are higher than the preset threshold, the combination of compression factor formulas corresponding to these two similarity test curves is determined as the compression factor combination of the flowmeter 11 to be calibrated.

[0124] In a further embodiment, during the process of finding empirical values, when it is determined that only a portion of the sampled data has corresponding empirical values, interpolation can be used to determine that the number of data points in the empirical curve matches the number of sampled data. Optionally, the following steps can be taken:

[0125] Step 1.1: Determine the order of the sampled data according to the sampling time sequence;

[0126] Step 1.2: Determine the location of the sampled data without an empirical value for the compression factor, where the location can be the sequence number of the sampled data;

[0127] Step 1.3: Determine whether the sampled data corresponding to the preceding and following serial numbers have empirical values ​​for compression factors;

[0128] Step 1.4: If not, take the empirical value corresponding to the sampled data with the nearest empirical value of compression factor to the sequence number as the empirical value of the sequence number;

[0129] Step 1.5: If so, the mean of the empirical values ​​corresponding to the sampled data with compression factor empirical values ​​before and after the serial number is taken as the empirical value of the serial number.

[0130] For example, given five sampled data points, numbered A1, A2, A3, A4, and A5, by searching experimental data in historical literature, we can find that A2, A3, and A5 have empirical values, while A1 and A4 are null values. Following the steps above, we can first analyze whether the numbers before and after A1 have empirical values. We find that the numbers before A1 have no numbers, and correspondingly, there are no empirical values ​​for the compression factor. The numbers after A1, A2, A3, and A5, all have corresponding empirical values ​​for the compression factor. Therefore, we can take the empirical value of A2, which is closest to A1, as the empirical value of A1. Similarly, we can take the average of the empirical values ​​of A3 and A5 as the empirical value of A4.

[0131] It should be noted that the above is only one way to determine the empirical value. There are other ways to determine it, such as determining it by the trend of data change, or finding the empirical value corresponding to the experimental data in the historical literature with the highest similarity to the sampled data as the empirical value of the sampled data, etc. The specific determination method is not limited in the embodiments of this specification.

[0132] It should be noted again that the collection and processing of experimental data from historical documents requires the authorization of the authors of those documents.

[0133] In the embodiments described in this specification, such as Figure 5 As shown, if the condition is not met, the test curves will be aggregated, and the compressibility factor formula combination corresponding to the test curve combination with the best aggregation effect will be determined as the compressibility factor combination of the flowmeter to be calibrated, including:

[0134] S301: Generate multiple test curve sets based on the number of test curves, with each test curve set containing the same number of test curves;

[0135] S302: Calculate the sum of similarities between any two test curves in each test curve set based on their similarity.

[0136] S303: The combination of compression factor formulas corresponding to the set of test curves with the smallest sum of similarity is determined as the compression factor combination of the flowmeter to be calibrated.

[0137] This can be understood as follows: because different compressibility factor calculation formulas have different adaptability to the current field working conditions, the calculation result of a compressibility factor calculation formula with higher adaptability has a lower difference from the true value of the compressibility factor. That is, the test curve obtained by the compressibility factor calculation formula is very close to the curve formed by the true value. On the other hand, the test curve corresponding to the compressibility factor calculation formula with poor adaptability will have a larger deviation from the curve formed by the true value. Therefore, a high similarity of the test curve combination means that the test curves in the combination are very close and the deviation is very small. This reflects that each test curve in the combination is close to the curve formed by the true value. Therefore, it is reliable to determine the compressibility factor combination of the test curve set with the smallest sum of similarity as the compressibility factor combination of the flowmeter 11 to be calibrated.

[0138] In practice, the number of test curves in each trend curve set can be set according to the actual situation, such as 2, 3, 4, etc. This number is the number of compression factor formulas in the final determined compression factor combination. For example, if there are M test curves in total, and each test curve set contains N test curves, where N < M, and M and N are both positive integers, then the number of test curve sets can be determined as follows: Then, the combination of compression factors is determined through the above steps.

[0139] In some other embodiments, there may be other aggregation processing methods, and the specific processing methods are not limited in the embodiments of this specification.

[0140] Based on determining the compressibility factor combination of the flow meter 11 to be calibrated, optionally, the step of calculating the correction compressibility factor of the flow meter 11 to be calibrated according to the gas parameters and the compressibility factor combination includes:

[0141] Determine the calculation formula for each compression factor in the compression factor combination;

[0142] Based on the gas parameters and the calculation formula for each compressibility factor, the calculated value corresponding to each compressibility factor is obtained;

[0143] The calibration compression factor of the flow meter 11 to be calibrated is calculated based on the calculated value corresponding to each compression factor.

[0144] The calculation formulas and processes for different compression factors are conventional methods in this field and will not be elaborated here. Optionally, the corrected compression factor can be calculated using the following formula (1):

[0145]

[0146] Among them, Z s To correct the compression factor, Z i is the calculated value of the i-th compression factor in the compression factor combination, and m is the total number of compression factors in the compression factor combination.

[0147] In the embodiments described in this specification, the relative deviation value of the flow meter to be calibrated is obtained by the following formula (2):

[0148]

[0149] in, To measure the relative deviation value; V x P represents the measured value of the flow meter to be calibrated. i V represents the pressure measurement value in the i-th flow measurement device. i T represents the measured value of the flow meter in the i-th flow measurement device; i Z represents the temperature measurement value in the i-th flow measurement device; s To correct the compression factor; n is the number of flow measurement devices.

[0150] The relative deviation value can be the relative indication error between the flow meter to be calibrated and the flow measurement device. Therefore, the measurement result of the flow meter to be calibrated can be calibrated using this relative deviation value. The calibration result is shown in the following formula (3):

[0151]

[0152] in, Calibration value for the measurement result of the flow rate to be calibrated; V x The measured value of the flow meter to be calibrated; To measure the relative deviation value.

[0153] This specification provides a method for calibrating the performance of a high-sulfur flow meter. A bypass pipe is connected to the side wall of a main pipeline. The main pipeline is equipped with a flow meter to be calibrated, and the bypass pipe is equipped with multiple flow measurement devices. First, the compressibility factor combination of the flow meter to be calibrated is determined based on the operating data of the main pipeline. Then, using the measurement data from the multiple flow measurement devices and the correction compressibility factor calculated from the gas parameters of high-sulfur natural gas, the relative deviation value of the flow meter to be calibrated is calculated. This relative deviation value is then used to calibrate the measured value of the flow meter. This method uses multiple flow measurement devices as a standard for performance evaluation and combines this with the operating conditions of on-site production to improve the accuracy of calibration of the measurement results of flow meters used in the field.

[0154] Based on the same inventive concept, embodiments of this specification also provide a high-sulfur flow meter performance calibration device, applied to a high-sulfur flow meter performance calibration system. The system includes a main pipeline and a bypass pipeline. The main pipeline is equipped with the flow meter to be calibrated, and the bypass pipeline is equipped with multiple flow measurement devices, such as... Figure 6 As shown, the high sulfur content flow meter performance calibration device includes:

[0155] The compressibility factor combination determination module 100 is used to determine the compressibility factor combination of the flow meter to be calibrated based on the operating condition data of the main pipeline.

[0156] The information acquisition module 200 is used to acquire measurement data from multiple flow measurement devices and gas parameters of high-sulfur natural gas in the bypass pipeline;

[0157] The calibration compressibility factor calculation module 300 is used to calculate the calibration compressibility factor of the flow meter to be calibrated based on the gas parameters and the compressibility factor combination.

[0158] The calibration module 400 is used to calculate the relative deviation value of the flow meter to be calibrated based on the measurement data of the multiple flow measurement devices, the correction compression factor and the measurement value of the flow meter to be calibrated, and to calibrate the measurement value of the flow meter to be calibrated using the relative deviation value.

[0159] The beneficial effects obtained by the above-described device are the same as those obtained by the above-described method, and will not be described in detail in the embodiments of this specification.

[0160] like Figure 7As shown, a computer device provided in this embodiment is described. The apparatus described herein can be the computer device in this embodiment, performing the methods described above. The computer device 702 may include one or more processors 704, such as one or more central processing units (CPUs), each of which can implement one or more hardware threads. The computer device 702 may also include any memory 706 for storing information of any kind, such as code, settings, data, etc. Without limitation, for example, memory 706 may include any type of RAM, any type of ROM, flash memory device, hard disk, optical disk, etc. More generally, any memory can use any technology to store information. Further, any memory can provide volatile or non-volatile retention of information. Further, any memory may represent a fixed or removable component of the computer device 702. In one case, when processor 704 executes associated instructions stored in any memory or combination of memories, the computer device 702 can perform any operation of the associated instructions. The computer device 702 also includes one or more drive mechanisms 708 for interacting with any memory, such as hard disk drive mechanisms, optical disk drive mechanisms, etc.

[0161] Computer device 702 may also include an input / output module 710 (I / O) for receiving various inputs (via input device 712) and providing various outputs (via output device 714). A specific output mechanism may include a presentation device 716 and an associated graphical user interface (GUI) 718. In other embodiments, the input / output module 710 (I / O), input device 712, and output device 714 may be omitted, and the device may function solely as a computer device within a network. Computer device 702 may also include one or more network interfaces 720 for exchanging data with other devices via one or more communication links 722. One or more communication buses 724 couple the components described above together.

[0162] Communication link 722 can be implemented in any way, such as via a local area network, a wide area network (e.g., the Internet), a point-to-point connection, or any combination thereof. Communication link 722 may include any combination of hardwired links, wireless links, routers, gateway functions, name servers, etc., governed by any protocol or combination of protocols.

[0163] Corresponding to Figures 3-5 In addition to the methods described above, this embodiment also provides a computer-readable storage medium storing a computer program that, when executed by a processor, performs the steps of the above-described methods.

[0164] This embodiment also provides a computer-readable instruction, wherein when a processor executes the instruction, the program therein causes the processor to perform the following: Figures 3 to 5 The method shown.

[0165] It should be understood that in the various embodiments of this document, 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 document.

[0166] It should also be understood that, in the embodiments herein, the term "and / or" is merely a description of the relationship between associated 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. Additionally, the character " / " in this document generally indicates that the preceding and following associated objects have an "or" relationship.

[0167] Those skilled in the art will recognize that the units and algorithm steps of the various examples described in conjunction with the embodiments disclosed herein 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 document.

[0168] 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.

[0169] In the embodiments provided herein, 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, devices, or units, or they may be electrical, mechanical, or other forms of connection.

[0170] 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 described herein, depending on actual needs.

[0171] Furthermore, the functional units in the various embodiments of this document 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.

[0172] 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 paper, in essence, or the part that contributes to the prior art, 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 described in the various embodiments of this paper. 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.

[0173] This document uses specific embodiments to illustrate the principles and implementation methods of this document. The descriptions of the embodiments above are only for the purpose of helping to understand the methods and core ideas of this document. 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 document. Therefore, the content of this specification should not be construed as a limitation of this document.

Claims

1. A method of performance calibration of a high-sulfur flowmeter, comprising: A method for calibrating the performance of a high-sulfur flow meter is provided. The system includes a main pipeline and a bypass pipeline, the bypass pipeline being connected to the side wall of the main pipeline. The main pipeline houses the flow meter to be calibrated, and the bypass pipeline houses multiple flow measurement devices. Based on the operating data of the main pipeline, the compressibility factor combination of the flow meter to be calibrated is determined; the compressibility factor combination represents a combination of compressibility factor formulas. Acquire measurement data from multiple flow measurement devices and gas parameters of high-sulfur natural gas in the bypass pipeline; The calibration compression factor of the flow meter to be calibrated is calculated based on the combination of the gas parameters and the compressibility factor. Based on the measurement data from multiple flow measurement devices, the correction compressibility factor, and the measurement value of the flow meter to be calibrated, the relative deviation value of the flow meter to be calibrated is calculated, and the measurement value of the flow meter to be calibrated is calibrated using the relative deviation value. The step of determining the compressibility factor combination of the flow meter to be calibrated based on the operating data of the main pipeline includes: Multiple sampling data points were obtained from the high-sulfur natural gas in the main pipeline. Each sampling data point included gas parameters and sulfur content. Obtain a set of compressibility factor formulas, and calculate the test curve corresponding to each compressibility factor formula in the set of compressibility factor formulas based on multiple sampling data of high-sulfur natural gas in the main pipeline. Determine whether there are empirical values ​​for the natural gas compressibility factor corresponding to the multiple sampled data; If it exists, then the empirical values ​​of the natural gas compressibility factor corresponding to multiple sampled data will be plotted to generate an empirical curve; Calculate the similarity between each test curve and the empirical curve in turn; The compression factor formula combination corresponding to the test curves with similarity higher than a preset threshold is determined as the compression factor combination of the flow meter to be calibrated; If it does not exist, the test curves will be aggregated, and the combination of compression factor formulas corresponding to the test curve combination with the best aggregation effect will be determined as the compression factor combination of the flow meter to be calibrated.

2. The method according to claim 1, characterized in that, If the condition is not met, the test curves will be aggregated, and the compressibility factor formula combination corresponding to the test curve combination with the best aggregation effect will be determined as the compressibility factor combination of the flowmeter to be calibrated, including: Based on the number of test curves, generate multiple test curve sets, each containing the same number of test curves; Based on the similarity between any two test curves in each test curve set, calculate the sum of the similarities between any two test curves in each test curve set; The combination of compression factor formulas corresponding to the set of test curves with the highest sum of similarity is determined as the compression factor combination of the flowmeter to be calibrated.

3. The method according to claim 1, characterized in that, Each flow measurement device includes a flow meter, a pressure measurement unit, and a temperature measurement unit. Different flow measurement devices include different types of flow meters.

4. The method according to claim 1, characterized in that, The step of calculating the correction compressibility factor of the flow meter to be calibrated based on the combination of the gas parameters and the compressibility factor includes: Determine the calculation formula for each compression factor in the compression factor combination; Based on the gas parameters and the calculation formula for each compressibility factor, the calculated value corresponding to each compressibility factor is obtained; The calibration compression factor of the flow meter to be calibrated is calculated based on the calculated value corresponding to each compression factor.

5. The method according to claim 1, characterized in that, The relative deviation of the flow meter to be calibrated is obtained by the following formula: , in, To measure the relative deviation value; The measured value of the flow meter to be calibrated; For the first i Pressure measurement value in a flow measurement device; For the first i The measured value of the flow meter in a flow measurement device; For the first i Temperature measurement value in a flow measurement device; To correct the compression factor; n This represents the number of flow measurement devices.

6. A performance calibration system for a high sulfur content flow meter, characterized in that, The system includes: a data acquisition device, a compression factor combination determination device, and a calibration device; The acquisition device includes a main pipeline and a bypass pipeline. The main pipeline is used to transport high-sulfur natural gas. A flow meter to be calibrated is installed on the main pipeline. The bypass pipeline is connected to the side wall of the main pipeline and is located upstream of the flow meter to be calibrated. Multiple flow measurement devices are installed on the bypass pipeline to obtain measurement data of high-sulfur natural gas entering the bypass pipeline. The compressibility factor combination determining device is used to determine the compressibility factor combination of the flow meter to be calibrated based on the operating condition data of the main pipeline. The calibration device is connected to the flow meter to be calibrated, multiple flow measuring devices, and a compressibility factor combination determination device. It is used to acquire measurement data from the multiple flow measuring devices and gas parameters of high-sulfur natural gas in the bypass pipeline; calculate the correction compressibility factor of the flow meter to be calibrated based on the gas parameters and the compressibility factor combination; calculate the relative deviation value of the flow meter to be calibrated based on the measurement data from the multiple flow measuring devices, the correction compressibility factor, and the measured value of the flow meter to be calibrated; and calibrate the measured value of the flow meter to be calibrated using the relative deviation value. The compressibility factor combination determination device is specifically used for: acquiring multiple sampling data of high-sulfur natural gas in the main pipeline, each sampling data including gas parameters and sulfur content; acquiring a set of compressibility factor formulas, and calculating the test curve corresponding to each compressibility factor formula in the set of compressibility factor formulas based on the multiple sampling data of high-sulfur natural gas in the main pipeline; determining whether there are empirical values ​​of natural gas compressibility factors corresponding to the multiple sampling data; if so, plotting the empirical values ​​of natural gas compressibility factors corresponding to the multiple sampling data to generate an empirical curve; sequentially calculating the similarity between each test curve and the empirical curve; determining the compressibility factor formula combination corresponding to the test curve with a similarity higher than a preset threshold as the compressibility factor combination of the flow meter to be calibrated; if not, performing aggregation processing on the test curves, and determining the compressibility factor formula combination corresponding to the test curve combination with the best aggregation effect as the compressibility factor combination of the flow meter to be calibrated.

7. A performance calibration device for a high sulfur content flow meter, characterized in that, An application is made in a high-sulfur flow meter performance calibration system. The system includes a main pipeline and a bypass pipeline. The main pipeline is equipped with the flow meter to be calibrated, and the bypass pipeline is equipped with multiple flow measurement devices, the devices including: The compressibility factor combination determination module is used to determine the compressibility factor combination of the flow meter to be calibrated based on the operating condition data of the main pipeline. The information acquisition module is used to acquire measurement data from multiple flow measurement devices and gas parameters of high-sulfur natural gas in the bypass pipeline; The calibration compressibility factor calculation module is used to calculate the calibration compressibility factor of the flow meter to be calibrated based on the gas parameters and the compressibility factor combination. The calibration module is used to calculate the relative deviation value of the flow meter to be calibrated based on the measurement data of the multiple flow measurement devices, the correction compression factor and the measurement value of the flow meter to be calibrated, and to calibrate the measurement value of the flow meter to be calibrated using the relative deviation value. The compression factor combination determination module is specifically used for: Multiple sampling data points were obtained from the high-sulfur natural gas in the main pipeline. Each sampling data point included gas parameters and sulfur content. Obtain a set of compressibility factor formulas, and calculate the test curve corresponding to each compressibility factor formula in the set of compressibility factor formulas based on multiple sampling data of high-sulfur natural gas in the main pipeline. Determine whether there are empirical values ​​for the natural gas compressibility factor corresponding to the multiple sampled data; If it exists, then the empirical values ​​of the natural gas compressibility factor corresponding to multiple sampled data will be plotted to generate an empirical curve; Calculate the similarity between each test curve and the empirical curve in turn; The compression factor formula combination corresponding to the test curves with similarity higher than a preset threshold is determined as the compression factor combination of the flow meter to be calibrated; If it does not exist, the test curves will be aggregated, and the combination of compression factor formulas corresponding to the test curve combination with the best aggregation effect will be determined as the compression factor combination of the flow meter to be calibrated.

8. 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 as described in any one of claims 1 to 5.

9. 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 as described in any one of claims 1 to 5.

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