Experimental method and device for obtaining compression factor of natural gas with high sulfur content

Abstract

The invention belongs to the technical field of oil and gas measurement, and discloses an experimental method and device for obtaining a compression factor of high-sulfur-content natural gas, and the method comprises the following steps: mixing purified natural gas and hydrogen sulfide through a checking system according to gas component parameters of a high-sulfur-content natural gas site to obtain sulfur-containing natural gas; determining the molar mass, the mass flow rate and the volume flow rate of the sulfur-containing natural gas through a standard measurement system; according to the flow value and the pressure value of the purified natural gas measured by the checking system and the volume flow of the hydrogen sulfide, whether the mass flow of the sulfur-containing natural gas measured by the standard measurement system is accurate is determined; and if so, determining the compression factor of the sulfur-containing natural gas according to the gas molar mass, mass flow and volume flow of the sulfur-containing natural gas. The device can simulate working conditions of a high-sulfur-content field, configure gas components consistent with the field conditions and determine the compression factor of gas at a standard detection system, and is clear in overall measurement principle, simple in system and easy to maintain.

Description

Technical Field

[0001] The present invention belongs to the technical field of oil and gas measurement, and in particular relates to an experimental method and device for obtaining the compression factor of high-sulfur natural gas. Background Art

[0002] Globally, high-sulfur natural gas reserves are huge and widely distributed, and high-sulfur natural gas reserves account for a large proportion of natural gas resources.

[0003] During the extraction, transportation, and sales of natural gas, the basis for calculating its economic benefits is the quantitative measurement of the product. This also puts forward higher requirements for how to ensure the measurement accuracy during the natural gas trade handover process.

[0004] With the rapid growth of conventional natural gas demand and the decreasing reserves of conventional natural gas, the proportion of high-sulfur natural gas reservoirs is increasing, which also brings new challenges to the measurement field. According to GB / T 26979-2011 "Natural Gas Reservoir Classification", H2S volume fraction is 2% to 10% or mass content is 30g / m 3 ~150g / m 3 Natural gas with a sulfur content is called high-sulfur natural gas.

[0005] Physical properties are a key focus of natural gas research, with compressibility being a crucial parameter, closely related to changes in other parameters. Methods for determining compressibility primarily include experimental methods, empirical formulas, equations of state, and graphical methods. However, most of these methods are applied to conventional natural gas. The presence of H2S causes deviations in critical parameters for high-sulfur natural gas, requiring calibration of commonly used methods for calculating natural gas compressibility to achieve relatively accurate results.

[0006] The empirical formula method is simpler than the state equation, but it is often only effective within a specific pressure and temperature range. Analysis of commonly used empirical formulas shows that the model will have large deviations, which brings inconvenience to the calculation of the high-pressure natural gas compression factor.

[0007] The equation of state method offers high accuracy, but it involves numerous parameters, is complex, and is difficult to calculate. Currently, when the H2S molar content measured by the component analyzer in the sampled data is less than 0.02%, the compressibility factor at the flowmeter is calculated using the AGA8-92DC natural gas physical property calculation method or the method in the GB / T17747.2-2011 natural gas compressibility factor calculation standard. This standard has significant drawbacks for high-sulfur natural gas. Experimental measurement of the compressibility factor is the most accurate, but it is costly, time-consuming, and labor-intensive.

[0008] In the actual production process, the measurement of high-sulfur natural gas is directly applied to the measurement methods and standards of conventional natural gas. The most widely used on-site are standard orifice flowmeters and other types of flowmeters. The orifice flowmeters need to be cleaned regularly as required to ensure their accurate measurement. For the production of high-sulfur natural gas, frequent cleaning and maintenance of the orifice flowmeters bring more safety risks and workload to the production site.

[0009] For high-sulfur natural gas, once the hydrogen sulfide content increases, the sensing equipment used in existing working conditions cannot perform accurate measurements. For example, the chromatograph analyzer generally used for purified gas cannot detect sulfur. Sulfur measurement requires specialized equipment, and to ensure safety (hydrogen sulfide leaks are very harmful to people), equipment with higher safety standards has to be used, which increases the cost of the equipment.

[0010] In summary, existing methods for obtaining the compression factor of high-sulfur natural gas are costly, time-consuming, labor-intensive, and involve high safety risks, and are unable to efficiently and accurately determine the compression factor of high-sulfur natural gas. Summary of the Invention

[0011] To address the above issues, the present invention provides an experimental method and device for obtaining the compressibility factor of high-sulfur natural gas, which adopts the following technical solutions:

[0012] An experimental method for obtaining the compressibility factor of high-sulfur natural gas comprises the following steps:

[0013] Based on the gas component parameters of high-sulfur natural gas on site, the purified natural gas and hydrogen sulfide are mixed through the verification system to obtain sour natural gas;

[0014] Determine the molar mass, mass flow rate, and volume flow rate of sour natural gas using standard measuring systems;

[0015] Based on the flow and pressure values ​​of the purified natural gas and the volume flow of hydrogen sulfide measured by the verification system, determine whether the mass flow rate of the sour natural gas measured by the standard measurement system is accurate;

[0016] If accurate, the compressibility factor of sour natural gas can be determined based on the gas molar mass, mass flow rate and volume flow rate of sour natural gas.

[0017] Furthermore, according to the gas component parameters, the purified natural gas and hydrogen sulfide are mixed by the verification system to obtain sour natural gas, which includes the following steps:

[0018] Determine the volume flow rate of natural gas added by the purified gas metering unit to the sour gas mixer, and the volume flow rate of hydrogen sulfide added by the hydrogen sulfide filling unit to the sour gas mixer, based on the gas component parameters;

[0019] Natural gas and hydrogen sulfide are mixed in a sour gas mixer to form sour natural gas.

[0020] Furthermore, the molar mass, mass flow rate, and volume flow rate of the sour natural gas are determined by a standard measurement system, including the following steps:

[0021] Determine the components of the mixed sour natural gas using a gas component analysis device, and determine the molar mass of the sour natural gas based on the components of the sour natural gas, the molar mass of hydrogen sulfide, and the molar mass of the natural gas;

[0022] The mass flow rate of the sour natural gas is measured by the mass measuring unit, and the volume flow rate of the sour natural gas is measured by the volume measuring unit.

[0023] Furthermore, determining whether the mass flow rate of the sour natural gas measured by the standard measurement system is accurate based on the flow rate and pressure values ​​of the purified natural gas and the volume flow rate of hydrogen sulfide measured by the verification system includes the following steps:

[0024] determining a deviation of the mass flow rate of the sour gas measured by the standard measurement system based on the volume flow rate of hydrogen sulfide added by the hydrogen sulfide filling unit to the sour gas mixer, the pressure value of the purified natural gas measured by the first pressure measuring unit, the volume flow value of the purified natural gas measured by the first flowmeter, and the temperature of the purified natural gas measured by the first temperature measuring unit;

[0025] When the deviation of the mass flow rate of the sour natural gas measured by the standard measurement system is a fixed value, it is determined that the mass flow rate of the sour natural gas measured by the standard measurement system is accurate.

[0026] Furthermore, the gas component parameters at the high-sulfur natural gas site include the volume fraction content of hydrogen sulfide in the high-sulfur natural gas and the volume fraction content of natural gas.

[0027] Furthermore, the compressibility factor of the sour natural gas is determined based on the gas molar mass, mass flow rate, and volume flow rate of the sour natural gas, as follows:

[0028]

[0029] Wherein, Z is the compressibility factor of sour natural gas; V2 is the volume flow rate of sour natural gas measured by the volume flowmeter; P2 is the pressure value of sour natural gas measured by the third pressure measurement unit; T2 is the temperature value of sour natural gas measured by the third temperature measurement unit; m1 is the mass flow rate of sour natural gas measured by the mass flowmeter; M is the molar mass of sour natural gas; and R is the ideal gas constant.

[0030] The present invention also provides an experimental device for obtaining the compression factor of high-sulfur natural gas, which is used to perform the experimental method for obtaining the compression factor of high-sulfur natural gas, and includes a verification system and a standard measurement system;

[0031] The verification system includes a purified gas metering unit, a hydrogen sulfide filling unit and a sulfur-containing gas mixer, and the standard measurement system includes a gas component analysis device, a mass measurement unit and a volume measurement unit;

[0032] One end of the purified gas metering unit is connected to the upstream purified natural gas pipeline, the other end of the purified gas metering unit is connected to the first inlet of the sulfur-containing gas mixer, the hydrogen sulfide filling unit is connected to the second inlet of the sulfur-containing gas mixer, and the outlet of the sulfur-containing gas mixer is connected to the gas component analysis equipment, the mass measurement unit, and the volume measurement unit in sequence.

[0033] Furthermore, the purified gas metering unit includes a first pipeline, the two ends of which are respectively connected to the upstream purified natural gas pipeline and the first inlet of the sulfur-containing gas mixer, and the first pipeline is provided with a first valve, a first pressure measuring unit, a first flow meter, a first temperature measuring unit and a first one-way valve in sequence between the upstream purified natural gas pipeline and the sulfur-containing gas mixer.

[0034] Furthermore, the hydrogen sulfide filling unit includes a high-pressure hydrogen sulfide gas storage tank and a second pipeline, the two ends of the second pipeline are respectively connected to the high-pressure hydrogen sulfide gas storage tank and the second inlet of the sulfur-containing gas mixer, and a pressure regulating valve and a second one-way valve are provided on the second pipeline, wherein the pressure regulating valve is arranged close to the high-pressure hydrogen sulfide gas storage tank, and the second one-way valve is arranged close to the sulfur-containing gas mixer.

[0035] Furthermore, the mass measurement unit includes a third pipeline, the two ends of which are respectively connected to the outlet of the gas component analysis equipment and the volume measurement unit, and the third pipeline is provided with a second valve, a second pressure measurement unit, a mass flow meter and a second temperature measurement unit in sequence between the gas component analysis equipment and the volume measurement unit.

[0036] Furthermore, the volume measuring unit includes a fourth pipeline, one end of which is connected to the third pipeline, and a third pressure measuring unit, a volume flow meter, a third temperature measuring unit and a third valve are sequentially arranged on the fourth pipeline.

[0037] Furthermore, it also includes a hydrogen sulfide recovery system, and both ends of the hydrogen sulfide recovery system are respectively connected to the volume measurement unit and the downstream purified natural gas pipeline.

[0038] Beneficial effects of the present invention:

[0039] The present invention can simulate the working conditions of a high-sulfur site, configure gas quality components consistent with the site conditions, and determine the compressibility factor of the gas at the standard detection system based on the mass measurement unit and the volume measurement unit. The overall measurement principle is clear, the system is simple, and it is easy to maintain.

[0040] Other features and advantages of the present invention will be described in the following description, and in part will become apparent from the description, or will be understood by practicing the present invention. The purpose and other advantages of the present invention can be realized and obtained by the structures pointed out in the description and the drawings. BRIEF DESCRIPTION OF THE DRAWINGS

[0041] In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the following is a brief introduction to the drawings required for use in the embodiments or the description of the prior art. Obviously, the drawings described below are some embodiments of the present invention. For ordinary technicians in this field, other drawings can be obtained based on these drawings without paying any creative work.

[0042] Figure 1 A structural block diagram of an experimental device for obtaining the compression factor of high-sulfur natural gas according to an embodiment of the present invention is shown;

[0043] Figure 2 A detailed structural diagram of an experimental device for obtaining the compression factor of high-sulfur natural gas according to an embodiment of the present invention is shown;

[0044] Figure 3 A schematic flow chart of an experimental method for obtaining the compression factor of high-sulfur natural gas according to an embodiment of the present invention is shown;

[0045] Figure 4 A schematic diagram of obtaining gas parameters through an experimental device according to an embodiment of the present invention is shown.

[0046] In the figure: 1. Sulfur-containing gas mixer; 2. Gas component analysis equipment; 3. First pipeline; 4. First valve; 5. First pressure measuring unit; 6. First flowmeter; 7. First temperature measuring unit; 8. First one-way valve; 9. High-pressure hydrogen sulfide storage tank; 10. Second pipeline; 11. Pressure regulating valve; 12. Second one-way valve; 13. Third pipeline; 14. Second valve; 15. Second pressure measuring unit; 16. Mass flowmeter; 17. Second temperature measuring unit; 18. Fourth pipeline; 19. Third pressure measuring unit; 20. Volume flowmeter; 21. Third temperature measuring unit; 22. Third valve; 23. Hydrogen sulfide recovery system. DETAILED DESCRIPTION

[0047] To make the objectives, technical solutions, and advantages of the embodiments of the present invention more clear, the technical solutions in the embodiments of the present invention will be clearly and completely described below in conjunction with the accompanying drawings in the embodiments of the present invention. Obviously, the described embodiments are only part of the embodiments of the present invention, not all of the embodiments. Based on the embodiments of the present invention, all other embodiments obtained by ordinary technicians in this field without making creative efforts shall fall within the scope of protection of the present invention.

[0048] It should be noted that the terms "first," "second," etc., in this application are used to distinguish similar objects, and are not necessarily used to describe a specific order or precedence. It should be understood that the terms used in this manner are interchangeable where appropriate, so as to facilitate the embodiments of the present application described herein.

[0049] The present invention provides an experimental method and device for obtaining the compression factor of high-sulfur natural gas, which can be used at the high-sulfur natural gas trade transfer site and can quickly, efficiently and accurately obtain the compression factor of the sour natural gas.

[0050] like Figure 1 and Figure 2 As shown, an experimental device for obtaining the compression factor of high-sulfur natural gas includes a verification system, a standard measurement system and a hydrogen sulfide recovery system 23.

[0051] The verification system includes a purified gas metering unit, a hydrogen sulfide filling unit and a sulfur-containing gas mixer 1, and the standard measurement system includes a gas component analysis device 2, a mass measurement unit and a volume measurement unit.

[0052] Among them, one end of the purified gas metering unit is connected to the upstream purified natural gas pipeline, the other end of the purified gas metering unit is connected to the first inlet of the sulfur-containing gas mixer 1, the hydrogen sulfide filling unit is connected to the second inlet of the sulfur-containing gas mixer 1, and the outlet of the sulfur-containing gas mixer 1 is connected to the gas component analysis equipment 2, the mass measurement unit, the volume measurement unit, and the hydrogen sulfide recovery system 23 in sequence. The hydrogen sulfide recovery system 23 is also connected to the downstream purified natural gas pipeline.

[0053] For example, the hydrogen sulfide recovery system 23 may adopt a desulfurization tower to recover hydrogen sulfide gas in the sour natural gas detected by the standard measurement system through the hydrogen sulfide recovery system 23, thereby reducing the impact on downstream natural gas.

[0054] like Figure 2 As shown, for example, the purified gas metering unit includes a first pipeline 3, the two ends of which are respectively connected to the upstream purified natural gas pipeline and the first inlet of the sulfur-containing gas mixer 1, and the first pipeline 3 is provided with a first valve 4, a first pressure measuring unit 5, a first flow meter 6, a first temperature measuring unit 7 and a first one-way valve 8 in sequence between the upstream purified natural gas pipeline and the sulfur-containing gas mixer 1.

[0055] The first one-way valve 8 prevents the gas in the sulfur-containing gas mixer 1 from returning to the upstream purified natural gas pipeline.

[0056] like Figure 2 As shown, for example, the hydrogen sulfide filling unit includes a high-pressure hydrogen sulfide gas storage tank 9 and a second pipeline 10, the two ends of the second pipeline 10 are respectively connected to the high-pressure hydrogen sulfide gas storage tank 9 and the second inlet of the sulfur-containing gas mixer 1, and a pressure regulating valve 11 and a second one-way valve 12 are provided on the second pipeline 10, wherein the pressure regulating valve 11 is arranged close to the high-pressure hydrogen sulfide gas storage tank 9, and the second one-way valve 12 is arranged close to the sulfur-containing gas mixer 1.

[0057] The high-pressure hydrogen sulfide storage tank 9 can adjust the volume flow of the output hydrogen sulfide, and the second one-way valve 12 prevents the gas in the sulfur-containing gas mixer 1 from returning to the high-pressure hydrogen sulfide storage tank 9 .

[0058] like Figure 2 As shown, for example, the mass measurement unit includes a third pipeline 13, both ends of which are connected to the outlet of the gas component analysis device 2 and the volume measurement unit respectively, and the third pipeline 13 is provided with a second valve 14, a second pressure measurement unit 15, a mass flow meter 16 and a second temperature measurement unit 17 in sequence between the gas component analysis device 2 and the volume measurement unit.

[0059] like Figure 2 As shown, for example, the volume measurement unit includes a fourth pipeline 18, both ends of which are connected to the third pipeline 13 and the hydrogen sulfide recovery system 23 respectively. The fourth pipeline 18 is provided with a third pressure measurement unit 19, a volume flow meter 20, a third temperature measurement unit 21 and a third valve 22 in sequence between the mass measurement unit and the hydrogen sulfide recovery system 23.

[0060] For example, the first valve 4 , the second valve 14 and the third valve 22 may be any one of hydraulic, electric and pneumatic ball valves.

[0061] It should be noted that both the mass measurement unit and the volume measurement unit are provided with temperature and pressure measurement units. The mass measurement unit and the volume measurement unit include different types of measuring flow meters. Different types of measuring flow meters have different measurement accuracy and measurement focus dimensions. Therefore, different types of measuring flow meters can further offset the measurement defects of each measuring flow meter.

[0062] like Figure 2As shown, the working process of the experimental device for the compression factor of high-sulfur natural gas is as follows: the first valve 4 is opened, the first pipeline 3 transports the purified natural gas in the upstream purified natural gas pipeline to the sulfur-containing gas mixer 1, the first pressure measuring unit 5 measures the pressure value of the purified natural gas, the first flowmeter 6 measures the volume flow rate of the purified natural gas, and the first temperature measuring unit 7 measures the temperature value of the purified natural gas.

[0063] Open the pressure regulating valve 11, and the second pipeline 10 transports the hydrogen sulfide in the high-pressure hydrogen sulfide storage tank 9 to the sulfur-containing gas mixer 1. The purified natural gas and hydrogen sulfide are mixed in the sulfur-containing gas mixer 1, and the sulfur-containing gas mixer 1 transports the mixed sulfur-containing natural gas to the third pipeline 13.

[0064] The second valve 14 and the third valve 22 are opened, and the gas component analysis device 2 analyzes the components of the sour natural gas to determine the molar mass of the sour natural gas. The mass flowmeter 16 measures the mass flow rate of the sour natural gas. The second pressure measuring unit 15 measures the pressure of the sour natural gas in the third pipeline 13. The second temperature measuring unit 17 measures the temperature of the sour natural gas in the third pipeline 13.

[0065] The volume flowmeter 20 measures the volume flow of the sour natural gas, the third pressure measuring unit 19 measures the pressure of the sour natural gas in the fourth pipeline 18 , and the third temperature measuring unit 21 measures the temperature of the sour natural gas in the fourth pipeline 18 .

[0066] The hydrogen sulfide recovery system 23 recovers hydrogen sulfide from the sour natural gas transported by the fourth pipeline 18 and transports the purified natural gas to a downstream purified natural gas pipeline.

[0067] Based on the above experimental device for obtaining the compression factor of high-sulfur natural gas, Figure 3 and Figure 4 As shown, the present invention also provides an experimental method for obtaining the compression factor of high-sulfur natural gas, comprising the following steps:

[0068] S1. Obtain gas component parameters of high-sulfur natural gas on site, wherein the gas component parameters include the volume fraction content of hydrogen sulfide and the volume fraction content of natural gas in the high-sulfur natural gas.

[0069] The purpose of this step is to obtain the gas component parameters of high-sulfur natural gas on site, configure the gas quality components consistent with the on-site conditions, and make the gas measured by the standard measurement system consistent with the on-site conditions.

[0070] S2. Based on the gas component parameters, the purified natural gas and hydrogen sulfide are mixed by the verification system to obtain sour natural gas, including the following steps:

[0071] S21. Determine the volume flow rate of natural gas added by the purified gas metering unit to the sulfur-containing gas mixer 1 and the volume flow rate of hydrogen sulfide added by the hydrogen sulfide filling unit to the sulfur-containing gas mixer 1 according to the gas component parameters.

[0072] S22, mixing natural gas and hydrogen sulfide by the sulfur-containing gas mixer 1 to form sulfur-containing natural gas, comprising the following steps:

[0073] Open the first valve 4, the first pipeline 3 transports the purified natural gas from the upstream purified natural gas pipeline to the sour gas mixer 1, open the pressure regulating valve 11, and the second pipeline 10 transports the hydrogen sulfide in the high-pressure hydrogen sulfide storage tank 9 to the sour gas mixer 1. The purified natural gas and hydrogen sulfide are mixed in the sour gas mixer 1 to form sour natural gas.

[0074] S3. Determining the molar mass, mass flow rate, and volume flow rate of the sour natural gas using a standard measurement system, including the following steps:

[0075] S31. Determine the components of the mixed sour natural gas using the gas component analysis device 2, and determine the molar mass of the sour natural gas based on the components of the sour natural gas, the molar mass of hydrogen sulfide, and the molar mass of the natural gas.

[0076] S32, measuring the mass flow rate of the sour natural gas by the mass measurement unit, and measuring the volume flow rate of the sour natural gas by the volume measurement unit, comprising the following steps:

[0077] The mass flow rate of the sour natural gas in the third pipeline 13 is measured by the mass flow meter 16 , and the volume flow rate of the sour natural gas in the fourth pipeline 18 is measured by the volume flow meter 20 .

[0078] S4. Determining whether the mass flow rate of sour natural gas measured by the standard measurement system is accurate based on the flow rate and pressure values ​​of the purified natural gas and the volume flow rate of hydrogen sulfide measured by the verification system, including the following steps:

[0079] S41. Determine a deviation of the mass flow rate of the sour gas measured by the standard measurement system based on the volume flow rate of hydrogen sulfide added by the hydrogen sulfide filling unit to the sour gas mixer 1, the pressure value of the purified natural gas measured by the first pressure measurement unit 5 of the purified gas metering unit, the volume flow value of the purified natural gas measured by the first flowmeter 6 of the purified gas metering unit, and the temperature of the purified natural gas measured by the first temperature measurement unit 7 of the purified gas metering unit, as follows:

[0080]

[0081] in, is the deviation of the mass flow rate of the sour natural gas measured by the standard measurement system, that is, the deviation of the mass flow rate of the sour natural gas in the third pipeline 13 measured by the mass flowmeter 16; m1 is the mass flow rate of the sour natural gas measured by the mass flowmeter 16; V0 is the volume flow value of the purified natural gas measured by the first flowmeter 6; m0 is the mass flow rate of the hydrogen sulfide filling unit to the sour gas mixer 1, which is determined according to the volume flow rate of hydrogen sulfide filled by the hydrogen sulfide filling unit to the sour gas mixer 1 and the density of hydrogen sulfide; P0 is the pressure value of the purified natural gas measured by the first pressure measuring unit 5, T0 is the temperature of the purified natural gas measured by the first temperature measuring unit 7, and Z0 is the gas compressibility factor of the purified natural gas.

[0082] S42. When the deviation 1 of the mass flow rate of the sour natural gas measured by the standard measurement system is a fixed value, it is determined that the performance of the mass flow meter 16 in the mass measurement unit is stable and the mass flow rate of the sour natural gas measured by the standard measurement system is accurate. Otherwise, it is necessary to perform a performance evaluation on the mass flow meter 16 in the mass measurement unit.

[0083] S5. When determining whether the mass flow rate of the sour natural gas measured by the standard measurement system is accurate, determine the compressibility factor of the sour natural gas based on the gas molar mass, mass flow rate, and volume flow rate of the sour natural gas.

[0084] The gas compressibility factor of sour natural gas is obtained by the following formula:

[0085]

[0086] Wherein, Z is the compressibility factor of the sour natural gas; V2 is the volume flow rate of the sour natural gas measured by the volume flowmeter 20 in the volume measurement unit; P2 is the pressure value of the sour natural gas measured by the third pressure measurement unit 19 in the volume measurement unit; T2 is the temperature value of the sour natural gas measured by the third temperature measurement unit 21 in the volume measurement unit; M is the molar mass of the sour natural gas; R is the ideal gas constant. At a temperature of 273.15K, the value of each mole of any gas is 22.414L. Therefore, in the legal measurement unit, R = 8.314J / ·mol·K.

[0087] The present invention solves the problem of difficulty in obtaining sour natural gas using existing metering devices. It can simulate the working conditions of a high-sulfur site, configure gas quality components consistent with the site conditions, and determine the compressibility factor of the gas at the standard detection system based on the mass measurement unit and the volume measurement unit. The overall measurement principle is clear, the system is simple, and it is easy to maintain.

[0088] Although the present invention has been described in detail with reference to the aforementioned embodiments, those skilled in the art should understand that they can still modify the technical solutions described in the aforementioned embodiments, or make equivalent replacements for some of the technical features therein; and these modifications or replacements do not cause the essence of the corresponding technical solutions to deviate from the spirit and scope of the technical solutions of the embodiments of the present invention.

Claims

1. An experimental method for obtaining the compressibility factor of high-sulfur natural gas, characterized in that: The following steps are involved: Based on the gas component parameters of high-sulfur natural gas on site, the purified natural gas and hydrogen sulfide are mixed through the verification system to obtain sour natural gas; Determine the molar mass, mass flow rate, and volume flow rate of sour natural gas using standard measuring systems; Based on the flow and pressure values ​​of the purified natural gas and the volume flow of hydrogen sulfide measured by the verification system, determine whether the mass flow rate of the sour natural gas measured by the standard measurement system is accurate; If accurate, the compressibility factor of sour natural gas can be determined based on the gas molar mass, mass flow rate and volume flow rate of sour natural gas.

2. The experimental method for obtaining the compressibility factor of high-sulfur natural gas according to claim 1, characterized in that: According to the gas component parameters, the purified natural gas and hydrogen sulfide are mixed through the verification system to obtain sour natural gas, including the following steps: Determine the volume flow rate of natural gas added by the purified gas metering unit to the sour gas mixer, and the volume flow rate of hydrogen sulfide added by the hydrogen sulfide filling unit to the sour gas mixer, based on the gas component parameters; Natural gas and hydrogen sulfide are mixed in a sour gas mixer to form sour natural gas.

3. The experimental method for obtaining the compressibility factor of high-sulfur natural gas according to claim 1, characterized in that: Determining the molar mass, mass flow rate, and volume flow rate of sour natural gas using a standard measuring system involves the following steps: Determine the components of the mixed sour natural gas using a gas component analysis device, and determine the molar mass of the sour natural gas based on the components of the sour natural gas, the molar mass of hydrogen sulfide, and the molar mass of the natural gas; The mass flow rate of the sour natural gas is measured by the mass measuring unit, and the volume flow rate of the sour natural gas is measured by the volume measuring unit.

4. The experimental method for obtaining the compressibility factor of high-sulfur natural gas according to claim 1, characterized in that: Based on the flow and pressure values ​​of the purified natural gas and the volume flow of hydrogen sulfide measured by the verification system, determining whether the mass flow of the sour natural gas measured by the standard measurement system is accurate includes the following steps: determining a deviation of the mass flow rate of the sour gas measured by the standard measurement system based on the volume flow rate of hydrogen sulfide added by the hydrogen sulfide filling unit to the sour gas mixer, the pressure value of the purified natural gas measured by the first pressure measuring unit, the volume flow value of the purified natural gas measured by the first flowmeter, and the temperature of the purified natural gas measured by the first temperature measuring unit; When the deviation of the mass flow rate of the sour natural gas measured by the standard measurement system is a fixed value, it is determined that the mass flow rate of the sour natural gas measured by the standard measurement system is accurate.

5. The experimental method for obtaining the compressibility factor of high-sulfur natural gas according to claim 1, characterized in that: The gas composition parameters at the high-sulfur natural gas site include the volume fraction content of hydrogen sulfide and the volume fraction content of natural gas in the high-sulfur natural gas.

6. The experimental method for obtaining the compressibility factor of high-sulfur natural gas according to any one of claims 1 to 5, characterized in that: The compressibility factor of sour natural gas is determined based on its gas molar mass, mass flow rate, and volume flow rate, as follows: Wherein, Z is the compressibility factor of sour natural gas; V2 is the volume flow rate of sour natural gas measured by the volume flowmeter; P2 is the pressure value of sour natural gas measured by the third pressure measurement unit; T2 is the temperature value of sour natural gas measured by the third temperature measurement unit; m1 is the mass flow rate of sour natural gas measured by the mass flowmeter; M is the molar mass of sour natural gas; and R is the ideal gas constant.

7. An experimental device for obtaining the compressibility factor of high-sulfur natural gas, used to perform the experimental method for obtaining the compressibility factor of high-sulfur natural gas according to any one of claims 1 to 6, characterized in that: Includes verification systems and standard measurement systems; The verification system includes a purified gas metering unit, a hydrogen sulfide filling unit and a sulfur-containing gas mixer, and the standard measurement system includes a gas component analysis device, a mass measurement unit and a volume measurement unit; One end of the purified gas metering unit is connected to the upstream purified natural gas pipeline, the other end of the purified gas metering unit is connected to the first inlet of the sulfur-containing gas mixer, the hydrogen sulfide filling unit is connected to the second inlet of the sulfur-containing gas mixer, and the outlet of the sulfur-containing gas mixer is connected to the gas component analysis equipment, the mass measurement unit, and the volume measurement unit in sequence.

8. The experimental device for obtaining the compression factor of high-sulfur natural gas according to claim 7, characterized in that: The purified gas metering unit includes a first pipeline, the two ends of which are respectively connected to the upstream purified natural gas pipeline and the first inlet of the sulfur-containing gas mixer. The first pipeline is provided with a first valve, a first pressure measuring unit, a first flow meter, a first temperature measuring unit and a first one-way valve in sequence between the upstream purified natural gas pipeline and the sulfur-containing gas mixer.

9. The experimental device for obtaining the compression factor of high-sulfur natural gas according to claim 7, characterized in that: The hydrogen sulfide filling unit includes a high-pressure hydrogen sulfide gas storage tank and a second pipeline, the two ends of the second pipeline are respectively connected to the high-pressure hydrogen sulfide gas storage tank and the second inlet of the sulfur-containing gas mixer, and a pressure regulating valve and a second one-way valve are provided on the second pipeline, wherein the pressure regulating valve is arranged close to the high-pressure hydrogen sulfide gas storage tank, and the second one-way valve is arranged close to the sulfur-containing gas mixer.

10. The experimental device for obtaining the compression factor of high-sulfur natural gas according to claim 7, characterized in that: The mass measurement unit includes a third pipeline, the two ends of which are respectively connected to the outlet of the gas component analysis equipment and the volume measurement unit. The third pipeline is provided with a second valve, a second pressure measurement unit, a mass flowmeter and a second temperature measurement unit in sequence between the gas component analysis equipment and the volume measurement unit.

11. The experimental device for obtaining the compression factor of high-sulfur natural gas according to claim 10, characterized in that: The volume measuring unit includes a fourth pipeline, one end of which is connected to the third pipeline. A third pressure measuring unit, a volume flow meter, a third temperature measuring unit and a third valve are sequentially arranged on the fourth pipeline.

12. The experimental device for obtaining the compressibility factor of high-sulfur natural gas according to any one of claims 7 to 11, characterized in that: It also includes a hydrogen sulfide recovery system, both ends of which are connected to a volume measurement unit and a downstream purified natural gas pipeline respectively.

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