Evaluation device and evaluation method for desulfurization effect of desulfurizing agent

Abstract

The invention discloses an evaluation device and an evaluation method for the desulfurization effect of a desulfurizer. The evaluation device for the desulfurization effect of the desulfurizer comprises an absorption tower treatment structure and a pipeline direct filling structure, wherein the absorption tower treatment structure and the pipeline direct filling structure are connected in parallel on a raw material gas pipeline; one hydrogen sulfide detection mechanism is connected to the raw gas pipeline, and the other hydrogen sulfide detection mechanism is used for detecting the content of hydrogen sulfide in any gas outlet pipeline in the absorption tower treatment structure and the pipeline direct filling structure; when the absorption tower treatment structure and the pipeline direct filling structure operate at the same time, any structure serves as an experimental branch, the other structure serves as a working branch, and the influence of corresponding structure parameters and desulfurizer filling parameters in the two treatment processes on the sulfur capacity is obtained. The method has the beneficial effects that the influence factors on the sulfur capacity under two treatment process conditions are obtained.

Description

Technical Field

[0001] This invention relates to the field of natural gas desulfurization technology, specifically to an evaluation device and method for the desulfurization effect of a desulfurizing agent. Background Technology

[0002] In recent years, a non-regenerative liquid desulfurization process, namely triazine solution desulfurization, has been adopted both domestically and internationally for the desulfurization of natural gas with low latent sulfur content. Triazine solution, as a novel desulfurization agent, removes hydrogen sulfide through an irreversible chemical reaction upon contact with natural gas. Its desulfurization products are non-toxic and harmless and can be directly reinjected into the formation, offering significant economic and technical advantages. Currently, triazine desulfurization can be achieved through direct pipeline injection or absorption tower treatment.

[0003] Since the equipment cost of direct pipeline injection is lower than that of absorption tower treatment, the industry chooses between absorption tower treatment and direct pipeline injection for desulfurization based on the length of the raw gas pipeline. If the length of the raw gas pipeline meets the requirements for direct pipeline injection, it will be given priority. However, the price of various types of triazine desulfurizing agents is also very high, and the cost of using desulfurizing agents should also be considered when reducing the cost of natural gas desulfurization. Summary of the Invention

[0004] The technical problem this invention aims to solve is that when selecting a triazine desulfurizer injection process, only the equipment cost of the natural gas desulfurization process is considered, without taking into account the cost of the desulfurizer. This results in an incomplete understanding of the factors affecting the natural gas desulfurization effect. The purpose is to provide an evaluation device and method for the desulfurization effect of the desulfurizer, so as to obtain the influence of the equipment structure parameters and desulfurizer injection parameters of the two treatment processes on the sulfur capacity. This facilitates the formulation of the optimal process equipment structure parameters and desulfurizer injection parameters based on the actual on-site working conditions, thereby reducing the production cost of natural gas desulfurization.

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

[0006] An evaluation device for the desulfurization effect of a desulfurizing agent includes an absorption tower treatment structure and a direct pipeline injection structure, which are connected in parallel to a raw gas pipeline. At least two hydrogen sulfide detection mechanisms are included: one connected to the raw gas pipeline, and the other used to detect the hydrogen sulfide content in the outlet pipeline of either the absorption tower treatment structure or the direct pipeline injection structure. When the absorption tower treatment structure and the direct pipeline injection structure operate simultaneously, one structure serves as the experimental branch, and the other as the working branch, to obtain the influence of corresponding structural parameters and desulfurizing agent injection parameters on sulfur capacity in the absorption tower treatment process and the direct pipeline injection process.

[0007] The present invention, employing the above-described scheme, connects the absorption tower treatment structure and the direct pipeline injection structure in parallel to the raw gas pipeline. A hydrogen sulfide detection device is installed to detect the hydrogen sulfide content in the raw gas pipeline before it enters the absorption tower treatment structure or the direct pipeline injection structure, while another hydrogen sulfide detection device detects the hydrogen sulfide content after treatment by either the absorption tower treatment structure or the direct pipeline injection structure. This facilitates on-site measurement of desulfurization data under both treatment process conditions at the raw gas pipeline, objectively and accurately reflecting the actual on-site conditions and obtaining corresponding desulfurization data. Furthermore, by changing the equipment structure parameters and desulfurizer injection parameters of the two treatment processes, the impact of these parameters on sulfur capacity can be obtained. This allows for the development of optimal process equipment structure parameters and desulfurizer injection parameters tailored to the actual on-site conditions, thereby reducing the production cost of natural gas desulfurization.

[0008] In some embodiments, a desulfurizing agent dosing module is further included. This module is connected to the absorption tower treatment structure via a first dosing pipeline, on which a first metering pump is installed. The module is also connected to the direct pipeline dosing structure via a second dosing pipeline, on which a third metering pump is installed. The first and third metering pumps control the flow rate and dosage of the desulfurizing agent on the corresponding experimental branch, and can also change the type of desulfurizing agent, thereby obtaining the sulfur capacity under different dosing parameters and thus identifying the dosing parameters affecting the sulfur capacity.

[0009] In some embodiments, the absorption tower treatment structure includes an absorption tower treatment module, a first inlet pipeline, and a first outlet pipeline. The inlet end of the absorption tower treatment module is connected to the first inlet pipeline, and the outlet end of the absorption tower treatment module is connected to the first outlet pipeline. The first inlet pipeline is connected to the raw material gas pipeline, and a regulating valve A is installed on the first inlet pipeline. The first outlet pipeline is connected to the exhaust pipeline. This facilitates connecting the absorption tower treatment module to the raw material gas pipeline, allowing direct treatment of the raw material gas and obtaining the hydrogen sulfide content after treatment. It also functions as a normal operating treatment structure, directly inputting the treated gas into the exhaust pipeline. The regulating valve A on the first inlet pipeline adjusts the flow rate of the raw material gas entering the absorption tower treatment module, thus obtaining the effect of different raw material gas flow rates on the desulfurization effect.

[0010] In some embodiments, the absorption tower processing module includes an absorption tower, desulfurizing agent nozzles, a mist eliminator, and a packing layer. The packing layer, desulfurizing agent nozzles, and mist eliminator are all located within the absorption tower. Both the packing layer and the desulfurizing agent nozzles are detachably connected within the absorption tower. The mist eliminator is connected to the top outlet of the absorption tower, and the desulfurizing agent nozzles are connected to a first injection pipeline. This detachable connection of the packing layer and desulfurizing agent nozzles within the absorption tower facilitates the replacement of different types of desulfurizing agent nozzles, different types of packing layers, and packing layers of different heights, allowing for the acquisition of the effects of different types of desulfurizing agent nozzles, different types of packing layers, and different packing layer heights on sulfur capacity.

[0011] In some embodiments, three sampling ports are provided on the side wall of the absorption tower. These three sampling ports are sequentially arranged along the height direction of the packing layer. The hydrogen sulfide detection mechanism includes an inlet online hydrogen sulfide detector and an outlet online hydrogen sulfide detector. The inlet online hydrogen sulfide detector is connected to the raw gas pipeline, and the three sampling ports are connected to the outlet online hydrogen sulfide detector via corresponding first instrument pipelines to obtain the hydrogen sulfide content of the output gas at any sampling port. Thus, by providing three sampling ports on the side wall of the absorption tower and contacting the detection points of the online hydrogen sulfide detectors with the corresponding packing layer heights at the three sampling ports, the influence of different packing layer heights on the desulfurization effect (sulfur capacity) can be experimentally studied, facilitating the investigation of factors affecting the desulfurization effect based on different packing layer heights.

[0012] In some embodiments, a desulfurizing agent circulation pipeline is connected to the absorption tower. The two ends of the circulation pipeline are connected to the bottom of the absorption tower and the desulfurizing agent nozzle, respectively. A second metering pump and a pressure gauge C are installed along the circulation pipeline. By connecting the desulfurizing agent circulation pipeline to the absorption tower, the desulfurizing agent within the absorption tower can be recycled, reducing production costs. Furthermore, the second metering pump and pressure gauge C on the circulation pipeline facilitate the recycling of the desulfurizing agent, thereby reducing the amount of desulfurizing agent used and saving costs.

[0013] In some embodiments, the absorption tower processing module further includes a level gauge, a differential pressure gauge, and a level transmitter. The level gauge and level transmitter are respectively installed on the absorption tower, and the level transmitter and the regulating valve C are linked for control. Thus, by installing a level gauge and a level transmitter on the absorption tower, observing the liquid level on-site through the level gauge, and interlocking control through the level transmitter and the regulating valve, automatic liquid drainage is achieved.

[0014] In some embodiments, the direct pipeline injection structure includes a pipeline injection module, a second inlet pipeline, and a second outlet pipeline. The inlet end of the pipeline injection module is connected to the second inlet pipeline, and the outlet end of the pipeline injection module is connected to the second outlet pipeline. The second inlet pipeline is connected to the raw material gas pipeline. A regulating valve B is provided on the second inlet pipeline. The second outlet pipeline is connected to the exhaust pipeline. The pipeline injection module and the desulfurizer injection module are connected through the second injection pipeline.

[0015] This allows for the direct connection of the pipeline injection structure to the raw gas pipeline, facilitating the direct processing of the raw gas and obtaining the hydrogen sulfide content after processing. It also enables the study of the impact of the direct pipeline injection structure on sulfur capacity. Furthermore, it can function as a normal operating processing structure, directly inputting the processed gas into the exhaust pipeline. A regulating valve B is installed on the second inlet pipeline to adjust the flow rate of the raw gas entering the pipeline injection module, thereby obtaining the impact of different raw gas flow rates on the desulfurization effect.

[0016] In some embodiments, the pipeline filling module includes a pipe section, the inlet of which is connected to an air inlet pipeline, and the outlet of which is connected to a serpentine pipe module. The pipe section may have a filling port at its front end, or a filling port and an atomizing nozzle connected to the filling port at its front end, or a filling port and a static mixer on the pipe section, or a filling port, an atomizing nozzle, and a static mixer on the pipe section, to facilitate the study of the impact of different pipeline filling processes on sulfur capacity. This facilitates experimental research on the impact of various filling processes (without any treatment device, with an atomizing nozzle, with a static mixer, and with an atomizing nozzle and a static mixer) on desulfurization efficiency, and allows for the study of the effects of the above four filling processes on desulfurization efficiency, in order to obtain the optimal filling scheme and reduce desulfurization costs.

[0017] In some embodiments, a serpentine tube module is also included. The serpentine tube module comprises a serpentine pipe and several sampling lines. The inlet of the serpentine tube is connected to a pipe filling module, and the outlet is connected to a second outlet line. Several sampling ports are provided on the serpentine pipe. The hydrogen sulfide detection mechanism includes an online hydrogen sulfide detector at the outlet. One end of each sampling line is connected to a corresponding sampling port, and the other end is connected to the online hydrogen sulfide detector at the outlet via a second instrument line. Thus, by setting up a serpentine pipe and sampling ports connected at different locations on the serpentine pipe, it is convenient to experimentally study the impact of different reaction pipe lengths on the desulfurization effect, and to investigate the influencing factors of different reaction pipe lengths on the desulfurization effect, thereby finding the optimal reaction pipe length.

[0018] This invention also provides a method for evaluating the desulfurization effect of a desulfurizing agent, implemented using the aforementioned device for evaluating the desulfurization effect of a desulfurizing agent, comprising the following steps:

[0019] The system operates with a direct pipeline injection structure. By changing the injection parameters of the desulfurizing agent injection module and the structural parameters of the pipeline injection module, the hydrogen sulfide content in the raw gas pipeline and the gas in the second instrument pipeline is detected for at least one injection parameter of the desulfurizing agent injection module, or the hydrogen sulfide content in the raw gas pipeline and the gas in the second instrument pipeline is detected for at least one structural parameter of the pipeline injection module, or the hydrogen sulfide content in the raw gas pipeline and the gas in the second instrument pipeline is detected for at least one injection parameter of the desulfurizing agent injection module and at least one structural parameter of the pipeline injection module, respectively. The corresponding sulfur capacity is obtained through calculation formulas to verify the influence factors of the structural parameters of the pipeline injection module and the desulfurizing agent injection parameters of the desulfurizing agent injection module on the sulfur capacity. The absorption tower treatment structure involves changing the charging parameters of the desulfurizing agent charging module and the structural parameters of the absorption tower treatment module. The hydrogen sulfide content in the raw gas pipeline and the gas in the first instrument pipeline is detected corresponding to at least one charging parameter of the desulfurizing agent charging module, or the hydrogen sulfide content in the raw gas pipeline and the gas in the first instrument pipeline is detected corresponding to at least one structural parameter of the absorption tower treatment module, or the hydrogen sulfide content in the raw gas pipeline and the gas in the first instrument pipeline is detected corresponding to at least one charging parameter of the desulfurizing agent charging module and at least one structural parameter of the absorption tower treatment module. The corresponding sulfur capacity is obtained through calculation, verifying the influence of the structural parameters of the absorption tower treatment module and the desulfurizing agent charging parameters of the desulfurizing agent charging module on the sulfur capacity. The present invention, employing the above-described scheme, utilizes a pipeline direct injection structure or an absorption tower treatment structure operating on the same raw gas pipeline to detect the hydrogen sulfide content of the natural gas in the raw gas pipeline (untreated) and the hydrogen sulfide content in the instrument pipeline (treated). It studies the influence of at least one structural parameter on sulfur capacity, or at least one injection parameter on sulfur capacity, or the influence of a combination of at least one structural parameter and at least one injection parameter on sulfur capacity. This allows for the acquisition of the influencing factors of each injection parameter and structural parameter on sulfur capacity under two treatment process conditions. This facilitates the development of the optimal treatment scheme based on the actual on-site conditions, thereby reducing the production cost of natural gas desulfurization.

[0020] In some embodiments, the calculation formula is: Sulfur capacity = (Hydrogen sulfide content monitored online before desulfurization - Hydrogen sulfide content monitored online after desulfurization) * Natural gas flow rate / Desulfurizing agent mass; where, desulfurizing agent mass = desulfurizing agent density * desulfurizing agent volume, and desulfurizing agent volume = metering pump reading * time t. Based on the above calculation formula, the sulfur capacity under corresponding parameters is obtained, and the influencing factors of each injection parameter and structural parameter on the sulfur capacity under two treatment process conditions are obtained.

[0021] In some embodiments, the dispensing parameters of the desulfurizing agent dispensing module include desulfurizing agent type, desulfurizing agent concentration, and desulfurizing agent dispensing amount. By adjusting at least one of the desulfurizing agent type, desulfurizing agent concentration, and desulfurizing agent dispensing amount, the sulfur capacity under the corresponding parameters can be obtained, thereby identifying the factors affecting the sulfur capacity.

[0022] In some embodiments, the parameters of the absorption tower include the packing layer height, the desulfurizing agent nozzle type, and the packing layer type. By adjusting at least one of the packing layer height, the desulfurizing agent nozzle type, or the packing layer type, the sulfur capacity under the corresponding parameters can be obtained, thereby identifying the factors affecting the sulfur capacity.

[0023] In some embodiments, the structural parameters of the pipeline filling module include different filling process structures and reaction pipes of different lengths. The filling process structure includes pipe sections with a filling port at the front end, or pipe sections with a filling port and an atomizing nozzle connected to the filling port at the front end, or pipe sections with a filling port at the front end and a static mixer installed on the pipe section, or pipe sections with a filling port, an atomizing nozzle, and a static mixer installed on the pipe section. By adjusting at least one of the above structural parameters or filling processes, the sulfur capacity under corresponding parameters can be obtained, thereby identifying the factors affecting the sulfur capacity.

[0024] Compared with the prior art, the present invention has the following advantages and beneficial effects:

[0025] 1. By simultaneously designing two branches, each equipped with an absorption tower and a direct pipeline injection treatment device, the experiment allows for easy replacement of different influencing factors (including different process structure parameters and injection parameters) to objectively and accurately reflect the actual on-site conditions. By changing the equipment structure parameters and desulfurizer injection parameters of the two treatment processes, the influence of these parameters on sulfur capacity can be obtained. This facilitates the development of optimal process equipment structure parameters and desulfurizer injection parameters for specific on-site conditions, thereby reducing the production cost of natural gas desulfurization.

[0026] 2. Design two branches to conduct experiments on the influencing factors of desulfurization effect under two treatment processes: absorption tower treatment and direct pipeline injection. Taking into account the injection parameters, select the optimal treatment process equipment to reduce production costs.

[0027] 3. By adjusting the flow rate of the test branch using regulating valves, the influence of different flow rates on the desulfurization effect can be studied. By comprehensively considering the treatment process and equipment, the equipment structure and charging parameters with good desulfurization effect and low production cost can be obtained.

[0028] 4. Design a desulfurizer dosing module to study the influence of desulfurizer dosing amount, different concentrations of the same type of desulfurizer, and different types of desulfurizer on sulfur capacity. By comprehensively considering the treatment process and equipment, we can obtain equipment structure and dosing parameters with good desulfurization effect and low production cost.

[0029] 5. The design of the absorption tower treatment module allows for experimental research on the influence of nozzle type and different height packing layers on the desulfurization effect. By comprehensively considering the injection parameters, an equipment structure and injection parameters with excellent desulfurization effect and low production cost can be obtained.

[0030] 6. The pipeline filling module is designed to test and study the influence of four different pipeline filling processes (without any treatment device, with atomizing nozzle, with static mixer, and with atomizing nozzle + static mixer) on the desulfurization effect. By comprehensively considering the filling parameters, the equipment structure and filling parameters with good desulfurization effect and low production cost can be obtained.

[0031] 7. The design of the serpentine pipe module allows for experimental research on the impact of different downstream pipeline reaction lengths on desulfurization efficiency. By comprehensively considering the injection parameters, an equipment structure and injection parameters with excellent desulfurization effect and low production cost can be obtained. Attached Figure Description

[0032] To more clearly illustrate the technical solutions of the exemplary embodiments of the present invention, the accompanying drawings used in the embodiments will be briefly described below. It should be understood that the following drawings only show some embodiments of the present invention and should not be regarded as a limitation of the scope. For those skilled in the art, other related drawings can be obtained based on these drawings without creative effort.

[0033] In the picture:

[0034] Figure 1 This is a schematic diagram of the process principle of the testing and evaluation device in this invention;

[0035] Figure 2 This is a schematic diagram of the absorption tower treatment module in this invention;

[0036] Figure 3 This is a schematic diagram of the desulfurizing agent injection module in this invention;

[0037] Figure 4 This is a schematic diagram of the structure of a pipeline filling module according to the present invention;

[0038] Figure 5 This is a schematic diagram of the structure of a pipeline filling module according to the present invention;

[0039] Figure 6 This is a schematic diagram of the structure of a pipeline filling module according to the present invention;

[0040] Figure 7 This is a schematic diagram of the structure of a pipeline filling module according to the present invention;

[0041] Figure 8 This is a schematic diagram of the serpentine tube module in this invention.

[0042] The attached diagram shows the markings and corresponding component names:

[0043] Raw material gas pipeline 1, ball valve A102, ball valve B104, ball valve C107, ball valve D301, ball valve E303, ball valve F306, ball valve G403, ball valve H502, ball valve I506, ball valve J601, ball valve K1201, ball valve L222, ball valve M901, ball valve N905, ball valve P1001, ball valve R225, inlet online hydrogen sulfide detector 103, outlet online hydrogen sulfide detector 304, absorption tower processing module 2, absorption tower 201, desulfurizing agent nozzle 202, mist eliminator 203. Packing layer 204, sampling port A205, sampling port B207, sampling port C209, level transmitter 219, level gauge A213, level gauge B410, differential pressure gauge 216, drain valve 220, desulfurizing agent circulation pipeline 221, exhaust pipeline 3, stop valve A206, stop valve B208, stop valve C210, stop valve D302, stop valve E305, stop valve F406, stop valve G1102, stop valve H1104, stop valve I1106, stop valve K1110, Desulfurizing agent filling module 4, Desulfurizing agent storage tank 401, Desulfurizing agent filling pipeline 402, Centrifugal pump 404, Check valve 405, Breather valve 407, Drain valve 411, Pipeline filling module 8, Filling port 801, Atomizing nozzle 802, Static mixer 803, Serpentine pipe module 11, Regulating valve A105, Regulating valve B108, Regulating valve C602, First flow meter 106, Second metering pump 223, First filling pipeline 501, First metering pump 503, Pressure... Force gauge A504, pressure gauge B903, pressure gauge C224, check valve A505, check valve B904, sewage pipeline 6, first instrument pipeline 7, pipeline filling module 8, third metering pump 902, second flow meter 109, serpentine pipe module 11, second filling pipeline 9, serpentine pipe opening A1101, serpentine pipe opening B1103, serpentine pipe opening C1105, serpentine pipe opening D1107, serpentine pipe opening E1109, second instrument pipeline 13, manhole 226. Detailed Implementation

[0044] To make the objectives, technical solutions, and advantages of the present invention clearer, the present invention will be further described in detail below with reference to the embodiments and accompanying drawings. The illustrative embodiments and descriptions of the present invention are only used to explain the present invention and are not intended to limit the present invention.

[0045] In the following description, numerous specific details are set forth in order to provide a thorough understanding of the invention. However, it will be apparent to those skilled in the art that these specific details are not necessary to practice the invention. In other embodiments, well-known structures, circuits, materials, or methods have not been specifically described in order to avoid obscuring the invention.

[0046] Throughout this specification, references to "an embodiment," "an example," or "an example" mean that a particular feature, structure, or characteristic described in connection with that embodiment or example is included in at least one embodiment of the present invention. Therefore, the phrases "an embodiment," "an example," "an example," or "an example" appearing in various places throughout the specification do not necessarily refer to the same embodiment or example. Furthermore, specific features, structures, or characteristics can be combined in one or more embodiments or examples in any suitable combination and / or sub-combination. Moreover, those skilled in the art will understand that the illustrations provided herein are for illustrative purposes and are not necessarily drawn to scale. The term "and / or" as used herein includes any and all combinations of one or more of the associated listed items.

[0047] In the description of this invention, the terms "front," "rear," "left," "right," "up," "down," "vertical," "horizontal," "high," "low," "inner," and "outer," etc., indicate the orientation or positional relationship based on the orientation or positional relationship shown in the accompanying drawings. They are only for the convenience of describing this invention and simplifying the description, and do not indicate or imply that the device or element referred to must have a specific orientation, or be constructed and operated in a specific orientation. Therefore, they should not be construed as limiting the scope of protection of this invention.

[0048] The terms "first," "second," etc., used in this invention are merely for clarity of description and are not intended to limit any order or emphasize importance. Furthermore, the term "connection" as used herein, unless otherwise specified, can refer to a direct connection or an indirect connection via other components.

[0049] Existing triazine desulfurization processes and equipment are costly to produce, and various types of triazine desulfurizers are also expensive. Studies have shown significant discrepancies between data obtained from laboratory desulfurization treatments and data directly detected in actual field production. Furthermore, different factors (including different processes, structures within different processes, and different desulfurizers) affect the desulfurization effect. Therefore, by setting up a process structure for on-site desulfurization treatment and conducting tests, it was found that for absorption tower treatment processes, factors influencing desulfurization effectiveness may include: natural gas quality conditions, temperature, pressure, gas flow rate, desulfurizer dosage, packing layer height, nozzle type, and desulfurizer type / concentration. Therefore, this invention, through the following embodiments, studies the influence of the above-mentioned factors on the desulfurization effect in absorption tower treatment processes, thereby enabling the selection of the most appropriate desulfurizer type / concentration, absorption tower equipment selection and manufacturing, and desulfurizer dosage when formulating process structures and dosage schemes.

[0050] Factors affecting the desulfurization effect of direct pipeline injection may include: natural gas quality conditions, temperature, pressure, gas flow rate, desulfurizer injection volume, pipeline injection module type, desulfurizer type / concentration, and downstream pipeline length. Therefore, this invention, through the following embodiments, studies the influence of these factors on the desulfurization effect in the direct pipeline injection process, thereby enabling the selection of the most appropriate desulfurizer type / concentration, pipeline injection module type, desulfurizer injection volume, and required downstream pipeline length when formulating process structures and injection schemes.

[0051] In order to accurately obtain the factors affecting the desulfurization effect, this application provides the following embodiments.

[0052] Example 1

[0053] This embodiment provides a device for evaluating the desulfurization effect of a desulfurizing agent, see [link to relevant documentation]. Figures 1 to 8 The system includes an absorption tower treatment structure and a direct pipeline injection structure, which are connected in parallel to the raw gas pipeline. It includes at least two hydrogen sulfide detection mechanisms: one connected to the raw gas pipeline 1, and the other used to detect the hydrogen sulfide content in the outlet pipeline of either the absorption tower treatment structure or the direct pipeline injection structure. When the absorption tower treatment structure and the direct pipeline injection structure operate simultaneously, one structure serves as the experimental branch, and the other as the working branch, to obtain the influence of the corresponding structural parameters and desulfurizer injection parameters on the sulfur capacity in both treatment processes.

[0054] See Figure 1 and Figure 3The device also includes a desulfurizing agent injection module 4, which is connected to the absorption tower treatment structure via a first injection pipeline 501. The desulfurizing agent injection module 4 is also connected to the direct pipeline injection structure via a second injection pipeline 9. The inlet of the experimental device is connected to the raw material gas pipeline 1, which is equipped with an inlet ball valve 101, a ball valve A102, and an inlet online hydrogen sulfide detector 103. The outlet of the experimental device is equipped with an exhaust pipeline 3, which is equipped with a shut-off valve D302, a connecting ball valve E303, and an outlet online hydrogen sulfide detector 304. A shut-off valve E305 and an outlet ball valve F306 are installed on the pipeline connecting the exhaust pipeline 3 to the raw material gas pipeline. The device includes two branches. The first branch supplies sulfur-containing natural gas to the downstream (outlet) after desulfurization treatment via the absorption tower processing module 2. The second branch supplies sulfur-containing natural gas to the downstream (outlet) after desulfurization treatment via the pipeline injection module 8 and the serpentine pipe module 11. Both branches are equipped with ball valves, regulating valves, and flow meters (106, 109). The flow rate of the test branch can be adjusted via the regulating valves. Under normal testing conditions, both branches are used simultaneously, one as the test branch and the other for normal processing of sulfur-containing natural gas. When parts replacement or maintenance is required, a single branch can also be used independently.

[0055] The specific process of the first branch: Sulfur-containing natural gas passes through the inlet ball valve 101, and the hydrogen sulfide content of the incoming gas (untreated natural gas) can be detected in real time by the inlet online hydrogen sulfide detector 103. Then, it enters the absorption tower treatment module 2 through the first inlet pipeline. The first inlet pipeline is connected in sequence to the ball valve B104, the regulating valve A105, and the first flow meter 106. After the gas comes into contact with the added triazine solution in the absorption tower 201, the hydrogen sulfide is removed. Then, it enters the exhaust pipeline 3 from the top of the tower through the ball valve D301. Detection branch: Any one of the three sampling ports of the absorption tower 201 is connected to the first instrument pipeline 7. The first instrument pipeline 7 is connected to the outlet online hydrogen sulfide detector 304 to monitor the hydrogen sulfide content after desulfurization in real time.

[0056] See Figure 1 and Figure 2 The absorption tower processing module 2 is connected to the desulfurizing agent injection module 4 via a first injection pipeline 501. Ball valve H502, first metering pump 503, pressure gauge A504, check valve A505, and ball valve I506 are connected in series on the first injection pipeline 501. The desulfurizing agent is injected into the absorption tower 201 through the first metering pump 503. The bottom of the absorption tower 201 is connected to a drain pipeline 6, on which ball valve J601 and regulating valve C602 are connected in series, subsequently flowing into the exhaust pipeline 3. Regulating valve C602 is interlocked with the level transmitter 219; when the absorption tower level reaches the high limit, regulating valve C602 automatically opens, achieving automatic drainage. The absorption tower processing module 2 is also connected to a first instrument pipeline 7, which can be connected to the online hydrogen sulfide detector 304 at the outlet via ball valve E303.

[0057] See Figure 1 and Figure 2 The absorption tower processing module 2 includes an absorption tower 201, a desulfurizing agent nozzle 202, a mist eliminator 203, and a packing layer 204. The inlet end of the sulfur-containing natural gas pipeline enters from the bottom of the tower through an inlet pipeline 1. Three sampling ports A205, B207, and C209 are installed at three heights on the side wall of the absorption tower 201, and are respectively connected to the packing layer at the corresponding heights. The three sampling ports A205, B207, and C209 can be respectively controlled by shut-off valves A206, B208, and C209. 210 is connected to the first instrument pipeline 7, and finally connected to the outlet online hydrogen sulfide detector 304 via ball valve E303. The effect of different height packing layers on the desulfurization effect is studied experimentally. The desulfurizing agent nozzle 202 can be replaced by opening the absorber tower cover. The effect of different types of nozzles on the desulfurization effect is studied experimentally. A manhole 226 is provided on the side wall of the absorber tower. The packing layer 204 can be replaced through the manhole 226. The effect of different types of packing layers on the desulfurization effect is studied experimentally.

[0058] Meanwhile, the absorber tower 201 is designed with a desulfurizing agent circulation pipeline 221. The desulfurizing agent circulation pipeline 221 is connected in series with ball valve L222, second metering pump 223, pressure gauge C224, and ball valve R225. The desulfurizing agent may not react completely in the tower. By recycling, the amount of desulfurizing agent used can be reduced, saving costs. The absorber tower treatment module also includes an opening to the bottom sewage discharge pipeline 6, and a sewage discharge valve 220 on the sewage discharge pipeline. The absorber tower treatment module also includes a level gauge A213, a differential pressure gauge 216, and a level transmitter 219. The level transmitter 219 is interlocked with the regulating valve C602 to realize automatic liquid discharge.

[0059] See Figure 1 and Figure 3 The system includes a desulfurizing agent filling module 4, which comprises a desulfurizing agent storage tank 401, a desulfurizing agent filling pipeline 402, a ball valve G403, a centrifugal pump 404, a check valve 405, a shut-off valve F406, a breather valve 407, a level gauge B410, and a drain valve 411. One branch of the desulfurizing agent filling module 4 can supply desulfurizing agent to the absorption tower 201 via a first filling pipeline 501 and a first metering pump 503, while another branch can supply desulfurizing agent to the pipeline filling module 8 via a second filling pipeline 9 and a third metering pump 902. See also... Figure 1The specific process of the second branch is as follows: Sulfur-containing natural gas passes through the inlet ball valve 101, where the hydrogen sulfide content is detected in real-time by the inlet online hydrogen sulfide detector 103. It then passes through the second inlet pipeline, which is equipped with a ball valve C107, a regulating valve B108, and a second flow meter 109 before entering the pipeline filling module 8. In the pipeline filling module 8, the gas comes into contact with the added triazine solution to remove hydrogen sulfide. It then enters the serpentine tube module 11 and finally passes through the bottom of the serpentine tube to the natural gas exhaust pipeline 3 via the second outlet pipeline, which is equipped with a ball valve K1201.

[0060] See Figure 1 The pipeline filling module 8 is connected to the desulfurizing agent filling module 4 through the second filling pipeline 9. The second filling pipeline 9 is connected in series with ball valve M901, third metering pump 902, pressure gauge B903, check valve B904, and ball valve N905. The desulfurizing agent is injected into the filling port 801 of the pipeline filling module 8 through the third metering pump 902.

[0061] See Figures 5 to 8 Specifically, the pipeline filling module 8 is a 1-meter pipe section with flanges at both ends for easy replacement with different types of pipe sections. The inlet of the pipe section is connected to the gas inlet pipeline 1, and the outlet flows to the serpentine pipe module 11. The pipe section is designed in four types according to different processing technologies: 1) a pipe section without any processing technology, with a filling port 801 at the front end; 2) a pipe section with an atomizing nozzle 802 connected to the filling port 801, thereby increasing the contact area between the desulfurizing agent and the sulfur-containing natural gas; 3) a pipe section with a static mixer 803, with a filling port 801 at the front end, where the desulfurizing agent and gas pass together through the static mixer 803, thereby increasing the mixing intensity of the desulfurizing solvent and the sulfur-containing natural gas; 4) a pipe section with both an atomizing nozzle 802 and a static mixer 803, with a filling port 801 at the front end. This module allows for easy replacement of different types of pipe sections, enabling experimental research on the impact of different pipeline filling processes (without any treatment device, with atomizing nozzles, with static mixer 803, with atomizing nozzle 802, and with static mixer 803) on desulfurization efficiency.

[0062] See Figure 1 and Figure 4The air inlet of the serpentine tube module 11 is connected to the pipeline filling module 8 via ball valve P1001 and pipeline, and the outlet enters the exhaust pipeline 3 via ball valve K1201. The serpentine tube module 11 is arranged in a stacked manner, with the pipeline being 5 meters long and 1-1.6 meters high, folded into 10 layers, thereby saving device space. A sampling port is set up every 10 meters, with a total of serpentine tube openings A1101, B1103, C1105, D1107, and E1109. These openings are connected to the online hydrogen sulfide detector 304 at the outlet via sampling pipelines. Each sampling pipeline is equipped with a corresponding shut-off valve G1102, H1104, I1106, J1108, and K1110, which are connected to the second instrument pipeline 13 and the online hydrogen sulfide detector 304 at the outlet. The valve is then connected to the online hydrogen sulfide detector 304 at the outlet via ball valve E303. This allows for experimental research on the effect of different reaction lengths on the desulfurization effect.

[0063] Example 2

[0064] This embodiment provides a method for evaluating the desulfurization effect of a desulfurizing agent, including the following steps:

[0065] The system operates with a direct pipeline injection structure. By changing the injection parameters of the desulfurizing agent injection module 4 and the structural parameters of the pipeline injection module, the hydrogen sulfide content in the raw gas pipeline 1 and the second instrument pipeline corresponding to at least one injection parameter of the desulfurizing agent injection module 4 is detected; or the hydrogen sulfide content in the raw gas pipeline 1 and the second instrument pipeline 13 corresponding to at least one structural parameter of the pipeline injection module 4 is detected; or the hydrogen sulfide content in the raw gas pipeline 1 and the second instrument pipeline 13 corresponding to at least one injection parameter of the desulfurizing agent injection module 4 and at least one structural parameter of the pipeline injection module 8 is detected. The corresponding sulfur capacity is obtained through calculation formulas to verify the influence factors of the structural parameters of the pipeline injection module 8 and the desulfurizing agent injection parameters of the desulfurizing agent injection module 4 on the sulfur capacity. The absorption tower treatment structure, by changing the injection parameters of the desulfurizing agent injection module 4 and the structural parameters of the absorption tower treatment module 2, detects the hydrogen sulfide content in the raw gas pipeline 1 and the gas in the first instrument pipeline 7 corresponding to at least one injection parameter of the desulfurizing agent injection module 4, or detects the hydrogen sulfide content in the raw gas pipeline 1 and the gas in the first instrument pipeline 7 corresponding to at least one structural parameter of the absorption tower treatment module 2, or detects the hydrogen sulfide content in the raw gas pipeline 1 and the gas in the first instrument pipeline 7 corresponding to at least one injection parameter of the desulfurizing agent injection module 4 and at least one structural parameter of the absorption tower treatment module 2, and obtains the corresponding sulfur capacity through calculation formula, verifying the influence factors of the structural parameters of the absorption tower treatment module 2 and the desulfurizing agent injection parameters of the desulfurizing agent injection module 4 on the sulfur capacity. By operating a direct injection structure on the same natural gas pipeline, the hydrogen sulfide content of the raw gas pipeline (untreated) and the outlet pipeline (treated) is detected. The influence of at least one structural parameter, or at least one injection parameter, or a combination of at least one structural parameter and at least one injection parameter on sulfur capacity is studied. This allows for the identification of the influencing factors of each injection parameter and structural parameter on sulfur capacity under two treatment process conditions. This facilitates the development of the optimal injection scheme based on the actual on-site conditions, thereby reducing the production cost of natural gas desulfurization.

[0066] See Figure 1 The calculation formula is: Sulfur capacity = (Hydrogen sulfide content monitored online before desulfurization - Hydrogen sulfide content monitored online after desulfurization) * Natural gas flow rate / Desulfurizing agent mass; where, desulfurizing agent mass = desulfurizing agent density * desulfurizing agent volume, and desulfurizing agent volume = metering pump reading * time t. Based on the above calculation formula, the sulfur capacity under corresponding parameters is obtained, and the influencing factors of various injection parameters and structural parameters on the sulfur capacity under the two treatment process conditions are obtained.

[0067] See Figure 1The desulfurizing agent dosing module's dosing parameters include desulfurizing agent type, desulfurizing agent concentration, and desulfurizing agent dosing amount. By adjusting at least one of the desulfurizing agent type, concentration, and dosing amount, the sulfur capacity under the corresponding parameters can be obtained, thereby identifying the factors affecting sulfur capacity.

[0068] See Figure 1 The parameters of the absorption tower include the packing layer height, the desulfurizing agent nozzle type, and the packing layer type. By adjusting at least one of the packing layer height, the desulfurizing agent nozzle type, or the packing layer type, the sulfur capacity under the corresponding parameters can be obtained, thereby identifying the factors affecting the sulfur capacity.

[0069] See Figure 1 The structural parameters of the pipeline filling module include different filling process structures and reaction pipes (serpentine pipes) of different lengths. The filling process structures include pipe sections with a filling port 801 at the front end, or a filling port 801 and an atomizing nozzle 802 connected to the filling port at the front end, or a filling port 801 at the front end and a static mixer 803 on the pipe section, or a filling port 801, an atomizing nozzle 802, and a static mixer 803 on the pipe section. By adjusting at least one of the above structural parameters or filling processes, the sulfur capacity under corresponding parameters can be obtained, thereby identifying the factors affecting the sulfur capacity.

[0070] In specific operations

[0071] By default, all valves are in the closed state.

[0072] S1: Open ball valve G403 and stop valve F406, and inject No. 1 triazine desulfurizer (original solution: water ratio of 1:1) into desulfurizer storage tank 401 through desulfurizer injection pipeline 402 using centrifugal pump 404. Open ball valve 408 and ball valve 409, observe the reading of level gauge B410, and stop injection when the level reaches the appropriate position. Close ball valve G403, stop valve F406 and centrifugal pump 404.

[0073] S2: Open ball valves H502 and I506, and inject the desulfurizing agent from the desulfurizing agent storage tank 401 into the absorption tower 201 via the first metering pump 503 through the injection pipeline 501. Open ball valves 211, 212, 214, 215, 217, and 218. Open ball valves L222 and R225, so that the desulfurizing agent in the tower flows into the injection pipeline 501 via the second metering pump 223 through the circulation pipeline 221.

[0074] S3: Open ball valve D301, shut-off valve E305, and ball valve F306 on the exhaust pipeline, and open ball valve J601 on the sewage pipeline 6.

[0075] S4: Open ball valve P1001 and ball valve K1201, then open ball valve M901 and ball valve N905. The desulfurizing agent in the desulfurizing agent storage tank 401 is injected into the pipeline filling module 8 through the filling pipeline 9 using the third metering pump 902. The desulfurizing agent passes through the serpentine pipe module 11 and flows into the exhaust pipeline 3.

[0076] S5: Open ball valves 101, A102, B104, and A105 on the inlet pipeline. Sulfur-containing natural gas enters the absorption tower 201 through the first branch to remove hydrogen sulfide. The gas phase flows downstream through the exhaust pipeline 3, and the liquid phase enters the circulation pipeline 221. Open the shut-off valve D302 and ball valve E303, observe the reading on the online hydrogen sulfide detector 304 at the outlet, and adjust the first metering pump 503 according to actual requirements to control the desulfurizing agent injection amount.

[0077] S6: Open ball valve C107 and regulating valve B108. A portion of the sulfur-containing natural gas enters pipeline injection module 8 through the second branch to remove hydrogen sulfide, then enters serpentine module 11, and finally enters exhaust pipeline 3 from the bottom of serpentine through ball valve K1201.

[0078] S7: Using the first branch as the test branch, the influencing factors of desulfurization effect under the absorption tower treatment process conditions are studied.

[0079] S701: Stabilize the flow rate of sulfur-containing natural gas and the amount of desulfurizing agent injected for a certain period of time t, and record the relevant readings for the corresponding operating conditions at this time, including the readings of the first flow meter 106, the first metering pump 503, the inlet online hydrogen sulfide detector 103, and the outlet online hydrogen sulfide detector 304. Then, calculate the sulfur capacity using the formula: Sulfur capacity = (hydrogen sulfide content monitored online before desulfurization - hydrogen sulfide content monitored online after desulfurization) * flow rate / desulfurizing agent mass, where, desulfurizing agent mass = desulfurizing agent density * desulfurizing agent volume, and desulfurizing agent volume = metering pump reading * time t.

[0080] Assuming time t is 0.5h, the flow rate of sulfur-containing natural gas—read by the first flow meter 106—is 0.0833 × 10⁴ m³ / h; the desulfurizing agent injection rate—read by the first metering pump 504—is 2 L / h; and the hydrogen sulfide content before desulfurization—read by the inlet online hydrogen sulfide detector 103—is 300 mg / m³, and by the outlet online hydrogen sulfide detector—is 3041 mg / m³. Flow rate = 0.0833 × 10⁴ m³ / h * 0.5h = 416.5 m³, desulfurizing agent volume = 2 L / h * 0.5h = 1 L, desulfurizing agent mass = 1.08 g / cm³ * 1 L = 1.08 kg. Sulfur capacity = (300 - 1) mg / m³ * 416.5 m³ / 1.08 kg = 11.53%.

[0081] S702: Conduct multiple sets of tests, adjust the flow rate of the test branch by regulating valve A105, and study the effect of different flow rates of sulfur-containing natural gas on the desulfurization effect.

[0082] S703: Conduct multiple sets of experiments to study the desulfurization effect of different desulfurizing agent dosages by controlling the first metering pump 503.

[0083] S704: Close the shut-off valve D302, switch the sampling port and conduct 3 more sets of tests, opening the absorber shut-off valves A206, B208 and C210 respectively, to test the effect of different height packing layers on the desulfurization effect.

[0084] S705: Close ball valve B104 and regulating valve A105 on the first branch (test branch), then close ball valve H502, first metering pump 503, ball valve I506, ball valve L222, second metering pump 223, ball valve R225, ball valve D301, and shut-off valve E305 to release the remaining gas inside the absorption tower. Open drain valve 220 to drain the residual liquid.

[0085] S706: Open the absorber cover, replace the absorber nozzle 202, and repeat S1-S705 to conduct multiple sets of tests to test the effect of different types of nozzles on the desulfurization effect.

[0086] S707: Open manhole 226, replace absorber tower packing layer 204, repeat S1-S706, conduct multiple sets of tests, and test the effect of different types of packing layers on desulfurization effect.

[0087] S7': Using the second branch as the test branch, the influencing factors of desulfurization effect under the direct pipeline injection process are studied.

[0088] S701': Close shut-off valve D302, open shut-off valve G1102, stabilize the sulfur-containing natural gas flow rate and desulfurizing agent injection amount for a certain time t, and record the relevant readings for the corresponding operating conditions at this time, including the readings of the second flow meter 109, the third metering pump 902, the inlet online hydrogen sulfide detector 103, and the outlet online hydrogen sulfide detector 304. Then, calculate the sulfur capacity using the formula: Sulfur capacity = (online monitoring hydrogen sulfide content before desulfurization - online monitoring hydrogen sulfide content after desulfurization) * flow rate / desulfurizing agent mass, where, desulfurizing agent mass = desulfurizing agent density * desulfurizing agent volume, and desulfurizing agent volume = metering pump reading * time t.

[0089] S702': Conduct multiple sets of tests, adjust the flow rate of the test branch by regulating valve B108, and study the effect of different flow rates of sulfur-containing natural gas on the desulfurization effect.

[0090] S703': Conduct multiple sets of experiments to study the desulfurization effect of different desulfurizing agent injection amounts by controlling the third metering pump 902.

[0091] S704': Close the shut-off valve G1102, switch the sampling port and conduct 4 more sets of tests, opening the shut-off valves (1104, 1106, 1108, 1110) respectively, and test the effect of different reaction lengths on the desulfurization effect.

[0092] S705': Close ball valve C107 and regulating valve B108 on the second branch (test branch), then close ball valve M901, third metering pump 902, ball valve N905, and ball valve P1001 to vent the remaining gas inside the pipe section. Replace the pipe section with a different type in the pipeline filling module 8 and repeat S1-S704' to test and study the effects of different pipeline filling processes (without any treatment device, with atomizing nozzle, with static mixer, and with atomizing nozzle + static mixer) on the desulfurization effect.

[0093] S8: Close the ball valve 101 on the inlet pipeline. After the remaining sulfur-containing natural gas in the unit has been processed, slowly open the vent valve to reduce the internal pressure of the unit to atmospheric pressure. Close all other valves and open the drain valve 220 of the absorption tower and the drain valve 412 of the desulfurizing agent storage tank to drain the residual liquid.

[0094] S9: Change the proportions of No. 1 triazine desulfurizer and the proportions of No. 2 / No. 3 triazine desulfurizer, repeat S1-S8, and conduct multiple sets of experiments to study the effects of different concentrations and types of the same type of desulfurizer on the desulfurization effect.

[0095] The specific embodiments described above further illustrate the purpose, technical solution, and beneficial effects of the present invention. It should be understood that the above description is only a specific embodiment of the present invention and is not intended to limit the scope of protection of the present invention. Any modifications, equivalent substitutions, improvements, etc., made within the spirit and principles of the present invention should be included within the scope of protection of the present invention.

Claims

1. A device for evaluating the desulfurization effect of a desulfurizing agent, characterized in that, It includes an absorption tower treatment structure and a direct pipeline injection structure, wherein the absorption tower treatment structure and the direct pipeline injection structure are connected in parallel to the raw gas pipeline; It also includes at least two hydrogen sulfide detection devices, one of which is connected to the raw gas pipeline, and the other is used to detect the hydrogen sulfide content of natural gas in the outlet pipeline of either the absorption tower treatment structure or the direct pipeline injection structure. When the absorption tower treatment structure and the pipeline direct injection structure are running simultaneously, one structure serves as the experimental branch and the other as the working branch, in order to obtain the influence of the corresponding structural parameters and desulfurizer injection parameters on the sulfur capacity in the absorption tower treatment process and the pipeline direct injection treatment process.

2. The device for evaluating the desulfurization effect of the desulfurizing agent according to claim 1, characterized in that, It also includes a desulfurizing agent injection module, which is connected to the absorption tower treatment structure via a first injection pipeline, and a first metering pump is installed on the first injection pipeline; the desulfurizing agent injection module is connected to the direct pipeline injection structure via a second injection pipeline, and a third metering pump is installed on the second injection pipeline.

3. The device for evaluating the desulfurization effect of the desulfurizing agent according to claim 1, characterized in that, The absorption tower processing structure includes an absorption tower processing module, a first inlet pipeline, and a first outlet pipeline. The inlet end of the absorption tower processing module is connected to the first inlet pipeline, and the outlet end of the absorption tower processing module is connected to the first outlet pipeline. The first inlet pipeline is connected to the raw material gas pipeline. A regulating valve A is installed on the first inlet pipeline, and the first outlet pipeline is connected to the exhaust pipeline.

4. The device for evaluating the desulfurization effect of the desulfurizing agent according to claim 3, characterized in that, The absorption tower processing module includes an absorption tower, a desulfurizing agent nozzle, a mist eliminator, and a packing layer. The packing layer, desulfurizing agent nozzle, and mist eliminator are all installed inside the absorption tower. The packing layer and desulfurizing agent nozzle are detachably connected to the absorption tower. The mist eliminator is connected to the top outlet of the absorption tower, and the desulfurizing agent nozzle is connected to the first injection pipeline.

5. The device for evaluating the desulfurization effect of the desulfurizing agent according to claim 4, characterized in that, The absorption tower has three sampling ports on its side wall, which are arranged at intervals along the height of the packing layer. The hydrogen sulfide detection mechanism includes an inlet online hydrogen sulfide detector and an outlet online hydrogen sulfide detector. The inlet online hydrogen sulfide detector is connected to the raw material gas pipeline, and the three sampling ports are connected to the outlet online hydrogen sulfide detector through corresponding first instrument pipelines to obtain the hydrogen sulfide content of the output gas at any sampling port.

6. The device for evaluating the desulfurization effect of the desulfurizing agent according to claim 4, characterized in that, The absorption tower is connected to a desulfurizing agent circulation pipeline. The two ends of the desulfurizing agent circulation pipeline are connected to the bottom of the absorption tower and the desulfurizing agent nozzle, respectively. A second metering pump and a pressure gauge C are installed along the desulfurizing agent circulation pipeline.

7. The device for evaluating the desulfurization effect of the desulfurizing agent according to claim 3, characterized in that, The absorption tower processing module also includes a level gauge, a differential pressure gauge, and a level transmitter. The level gauge and the level transmitter are respectively installed on the absorption tower, and the level transmitter is linked to the regulating valve C for control.

8. The device for evaluating the desulfurization effect of the desulfurizing agent according to claim 2, characterized in that, The direct pipeline injection structure includes a pipeline injection module, a second air inlet pipeline, and a second air outlet pipeline. The inlet end of the pipeline injection module is connected to the second air inlet pipeline, and the outlet end of the pipeline injection module is connected to the second air outlet pipeline. The second air inlet pipeline is connected to the raw material gas pipeline. A regulating valve B is installed on the second air inlet pipeline. The second air outlet pipeline is connected to the exhaust pipeline. The pipeline injection module and the desulfurizer injection module are connected through the second injection pipeline.

9. The device for evaluating the desulfurization effect of the desulfurizing agent according to claim 8, characterized in that, The pipeline filling module includes a pipe section. The inlet of the pipe section is connected to the second air inlet pipeline, and the outlet is connected to the serpentine pipe module. The pipe section has a filling port at the front end, or a filling port and an atomizing nozzle connected to the filling port at the front end of the pipe section, or a filling port and a static mixer on the pipe section, or a filling port, an atomizing nozzle and a static mixer on the pipe section, so as to study the influence of different pipeline filling processes on sulfur capacity.

10. The device for evaluating the desulfurization effect of the desulfurizing agent according to claim 8, characterized in that, The serpentine tube module includes a serpentine pipe and several parallel sampling lines. The air inlet of the serpentine tube is connected to the pipeline filling module, and the air outlet is connected to the second air outlet line. Several sampling ports are provided on the serpentine pipe. One end of the sampling line is connected to the corresponding sampling port, and the other end is connected to the online hydrogen sulfide detector at the outlet through the second instrument line.

11. A method for evaluating the desulfurization effect of a desulfurizing agent, characterized in that, The device for evaluating the desulfurization effect of the desulfurizing agent according to any one of claims 1 to 10 is implemented, including: The system operates with a direct pipeline injection structure. The injection parameters of the desulfurizing agent injection module and the structural parameters of the pipeline injection module are changed. The hydrogen sulfide content in the raw gas pipeline and the gas in the second instrument pipeline is detected for at least one injection parameter of the desulfurizing agent injection module. Alternatively, the hydrogen sulfide content in the raw gas pipeline and the gas in the second instrument pipeline are detected for at least one structural parameter of the pipeline injection module. Or, the hydrogen sulfide content in the raw gas pipeline and the gas in the second instrument pipeline are detected for at least one injection parameter of the desulfurizing agent injection module and at least one structural parameter of the pipeline injection module. The corresponding sulfur capacity is obtained through calculation, verifying the influence of the structural parameters of the pipeline injection module and the desulfurizing agent injection parameters of the desulfurizing agent injection module on the sulfur capacity. The absorption tower processing structure is operated, and the hydrogen sulfide content in the raw gas pipeline and the gas in the first instrument pipeline is detected by changing the charging parameters of the desulfurizing agent charging module and the structural parameters of the absorption tower processing module, respectively. Alternatively, the hydrogen sulfide content in the raw gas pipeline and the gas in the first instrument pipeline are detected by detecting the hydrogen sulfide content in the raw gas pipeline and the gas in the first instrument pipeline, respectively, or the hydrogen sulfide content in the raw gas pipeline and the gas in the first instrument pipeline are detected by detecting the hydrogen sulfide content in the raw gas pipeline and the gas in the first instrument pipeline, respectively, corresponding to the charging parameters of the desulfurizing agent charging module and the structural parameters of the absorption tower processing module. The corresponding sulfur capacity is obtained by calculation formula, and the influence factors of the structural parameters of the absorption tower processing module and the desulfurizing agent charging parameters of the desulfurizing agent charging module on the sulfur capacity are verified.

12. The method for evaluating the desulfurization effect of the desulfurizing agent according to claim 11, characterized in that, The calculation formula is: Sulfur capacity = (Hydrogen sulfide content monitored online before desulfurization - Hydrogen sulfide content monitored online after desulfurization) * Natural gas flow rate / Desulfurizing agent mass; Wherein, the mass of desulfurizing agent = density of desulfurizing agent * volume of desulfurizing agent, and the volume of desulfurizing agent = metering pump reading * time t.

13. The method for evaluating the desulfurization effect of the desulfurizing agent according to claim 11, characterized in that, The parameters for the desulfurizing agent dosing module include the type of desulfurizing agent, the concentration of desulfurizing agent, and the amount of desulfurizing agent added.

14. The method for evaluating the desulfurization effect of the desulfurizing agent according to claim 11, characterized in that, The structural parameters of the absorption tower include the height of the packing layer, the type of desulfurizing agent nozzle, and the type of packing layer.

15. The method for evaluating the desulfurization effect of the desulfurizing agent according to claim 11, characterized in that, The structural parameters of the pipeline filling module include different filling process structures and reaction tubes of different lengths. The filling process structure includes pipe sections with a filling port at the front end of the pipe section, or pipe sections with a filling port at the front end of the pipe section and an atomizing nozzle connected to the filling port, or pipe sections with a filling port at the front end of the pipe section and a static mixer installed on the pipe section, or pipe sections with a filling port, an atomizing nozzle, and a static mixer installed on the pipe section.

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