Evaluation device and evaluation method for influence factors of desulfurization effect of direct injection of pipeline

Abstract

The invention discloses a device and a method for evaluating influence factors of a desulfurization effect during direct injection of a pipeline. The device for evaluating the influence factors of the direct pipeline filling desulfurization effect comprises a direct pipeline filling structure, a desulfurizing agent filling module and a hydrogen sulfide detection mechanism, wherein an inlet of the direct pipeline filling structure is connected with a feed gas pipeline; the desulfurizing agent filling module is used for filling a desulfurizing agent into the pipeline direct filling structure; and one hydrogen sulfide detection mechanism is used for detecting the hydrogen sulfide content of the raw material gas from the raw material gas pipeline, and the other hydrogen sulfide detection mechanism is used for detecting the hydrogen sulfide content of the gas treated by the pipeline direct filling structure. The method has the beneficial effects that the influence of different structural characteristics and filling parameters on the sulfur capacity is obtained under the actual site condition, and the structural characteristics and the filling parameters which are influence factors of the desulfurization effect of the pipeline direct filling structure are determined, so that a scheme is prevented from being formulated by artificial experience, and the economical efficiency of the process is improved.

Description

Technical Field

[0001] This invention relates to the field of natural gas desulfurization technology, specifically to an evaluation device and method for evaluating the influencing factors of desulfurization effect by direct pipeline injection. Background Technology

[0002] For desulfurization of natural gas with low latent sulfur content, a non-regenerative liquid desulfurization process, namely triazine solution desulfurization, is adopted. 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. The triazine solution desulfurization process mainly includes two methods: absorption tower treatment and direct pipeline injection. Direct pipeline injection is suitable for desulfurization at stations with gas collection pipelines.

[0003] Currently, there is very little research on the factors affecting the desulfurization effect of direct pipeline injection. Most studies on the factors affecting the desulfurization effect are limited to simple laboratory simulation analysis, which involves placing desulfurizing agent samples into experimental vessels for experiments. The study only investigates the effect of the desulfurizing agent on the desulfurization effect, and the conclusions are mostly predicted by theoretical calculations, which cannot objectively and comprehensively evaluate the factors affecting the desulfurization effect. Summary of the Invention

[0004] The technical problem to be solved by this invention is that the influence of desulfurizing agents on desulfurization effect is currently only studied in the laboratory. The purpose is to provide an evaluation device and method for evaluating the influencing factors of desulfurization effect by direct pipeline injection, which can obtain the influence of equipment structural characteristics and desulfurizing agent injection parameters on sulfur capacity under objective and real field conditions, and thus clarify which structural characteristics and injection parameters are the influencing factors of desulfurization effect of direct pipeline injection process.

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

[0006] A device for evaluating the influencing factors of direct pipeline desulfurization effect includes a direct pipeline injection structure, a desulfurizing agent injection module, and two hydrogen sulfide detection mechanisms. The inlet of the direct pipeline injection structure is connected to a raw material gas pipeline. The desulfurizing agent injection module is used to inject desulfurizing agent into the direct pipeline injection structure. The two hydrogen sulfide detection mechanisms are used to detect the hydrogen sulfide content of the raw material gas from the raw material gas pipeline and to detect the hydrogen sulfide content of the gas treated by the direct pipeline injection structure.

[0007] The present invention, employing the above-described scheme, sets up a pipeline injection module connected to the raw gas pipeline. It also includes two hydrogen sulfide detection mechanisms: one to detect the hydrogen sulfide content of the raw gas before treatment by the pipeline direct injection structure, and the other to detect the hydrogen sulfide content of the gas after treatment by the pipeline direct injection structure. Since the raw gas pipeline is directly connected to the wellhead, and the raw gas in the well is transported through the pipeline, connecting the pipeline direct injection structure to the raw gas pipeline allows for the acquisition of corresponding desulfurization data under objective and realistic on-site conditions. Furthermore, by modifying the equipment structure characteristics and desulfurizer injection parameters of the pipeline direct injection structure, it obtains the structural characteristics and desulfurizer injection parameters that affect sulfur capacity, clarifying which structural characteristics and injection parameters influence the desulfurization effect of the pipeline direct injection structure. This facilitates the development of optimal process schemes for the equipment structure characteristics and desulfurizer injection parameters based on actual on-site conditions, thereby reducing the production cost of natural gas desulfurization.

[0008] In some embodiments, 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 a regulating valve A and a flow meter are connected to the raw material gas pipeline to regulate the flow rate of the raw material gas. By installing an inlet online hydrogen sulfide detector on the raw material gas pipeline, the hydrogen sulfide content of the raw material gas in the pipeline when it passes through the online hydrogen sulfide detector is obtained. Regulating valve A is installed on the raw material gas pipeline to regulate the flow rate of the raw material gas entering the direct injection structure from the raw material gas pipeline, facilitating the testing of the impact of the raw material gas flow rate on the desulfurization effect.

[0009] In some embodiments, the direct pipeline injection structure includes a pipeline injection module and a serpentine pipe module. The pipeline injection module includes a pipe section, the inlet of which is connected to the raw material gas pipeline, and the outlet of which is connected to the serpentine pipe module. An injection structure is provided on the pipe section, and the injection structure is connected to the desulfurizing agent injection module via an injection pipeline. This facilitates the desulfurizing agent from the desulfurizing agent injection module to pass through the injection structure and enter the pipe section to react with the raw material gas from the raw material gas pipeline for desulfurization.

[0010] In some embodiments, the injection structure includes an injection port located at the front end of the pipe section, or an injection port located at the front end of the pipe section and an atomizing nozzle connected to the injection port, or an injection port located at the front end of the pipe section and a static mixer located within the pipe section, or an injection port located at the front end of the pipe section, an atomizing nozzle connected to the injection port, and a static mixer located within the pipe section, to study the impact of different pipeline injection processes on sulfur capacity. This facilitates experimental research on the impact of various injection processes (including injection ports only without any processing equipment, injection ports with atomizing nozzles, injection ports with static mixers, and injection ports with both atomizing nozzles and static mixers) on desulfurization efficiency. It also facilitates research on the impact of the above four injection processes on desulfurization efficiency to obtain the optimal injection scheme and reduce desulfurization costs.

[0011] In some embodiments, the serpentine tube module includes a serpentine tube and several parallel sampling lines. The inlet of the serpentine tube is connected to the raw material gas line, and the outlet is connected to the exhaust gas line. Several sampling ports are provided on the serpentine tube. One end of each sampling line is connected to a corresponding sampling port, and the other end is connected to an online hydrogen sulfide detector at the outlet via an instrument line. Each sampling line is equipped with a corresponding shut-off valve. Thus, by setting up the serpentine tube and sampling ports connected at different locations on the serpentine tube, the influence of different reaction pipe (serpentine tube) lengths on the desulfurization effect can be experimentally studied, thereby finding the optimal reaction pipe length.

[0012] In some embodiments, the desulfurizing agent dosing module includes a desulfurizing agent storage tank, a desulfurizing agent dosing pipeline, and a centrifugal pump. The inlet of the desulfurizing agent storage tank is connected to the desulfurizing agent dosing pipeline, and the outlet is connected to the dosing pipeline. The centrifugal pump is connected to the desulfurizing agent dosing pipeline, and a metering pump and a filter screen are installed on the dosing pipeline, with the filter screen located upstream of the metering pump. A desulfurizing agent storage tank is installed and connected to the desulfurizing agent dosing pipeline. The centrifugal pump delivers desulfurizing agent through the desulfurizing agent dosing pipeline into the desulfurizing agent storage tank. By preparing desulfurizing agents of different concentrations, it is possible to study the impact of different concentrations on the desulfurization effect, or to change the type of desulfurizing agent used to study the impact of different types of desulfurizing agents on the desulfurization effect. The outlet of the desulfurizing agent storage tank is connected to the pipeline filling module through a filling pipeline, which facilitates the filling of the desulfurizing agent in the storage tank into the pipeline section through the filling pipeline. The dosage of desulfurizing agent is also controlled by a metering pump, which facilitates the study of the impact of different amounts of desulfurizing agent on the desulfurization effect.

[0013] This invention also provides a method for evaluating the influencing factors of direct pipeline desulfurization effect, implemented based on the aforementioned desulfurizing agent desulfurization effect evaluation device, comprising the following steps: operating the direct pipeline injection structure, changing the injection parameters of the desulfurizing agent injection module and the structural features of the direct pipeline injection structure, detecting the hydrogen sulfide content before desulfurization in the raw gas pipeline and the hydrogen sulfide content after desulfurization in the gas in the instrument pipeline corresponding to at least one injection parameter of the desulfurizing agent injection module, and / or detecting the hydrogen sulfide content before desulfurization in the raw gas pipeline and the hydrogen sulfide content after desulfurization in the instrument pipeline corresponding to at least one structural feature, obtaining the corresponding sulfur capacity through calculation formula, and verifying the influence factors of the structural features of the direct pipeline injection structure and the desulfurizing agent injection parameters of the desulfurizing agent injection module on the sulfur capacity.

[0014] The present invention, employing the above-described scheme, utilizes a direct pipeline injection structure connected to the raw gas pipeline to detect the hydrogen sulfide content (untreated) in the raw gas pipeline and the hydrogen sulfide content (treated raw gas) in the outlet pipeline. It studies the influence of at least one structural feature on sulfur capacity, or the influence of at least one injection parameter on sulfur capacity, or the influence of a combination of at least one structural feature and at least one injection parameter on sulfur capacity. This allows for the determination of the influence of each injection parameter and structural feature on sulfur capacity under the direct pipeline injection process conditions. This facilitates the development of the optimal direct pipeline injection process scheme based on the influencing factors and actual on-site conditions, thereby reducing the production cost of natural gas desulfurization.

[0015] 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 various injection parameters and structural characteristics on sulfur capacity under the direct pipeline injection treatment process are obtained.

[0016] 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.

[0017] In some embodiments, the structural features of the direct pipeline injection structure include an injection structure and serpentine pipes of different lengths. The injection structure includes an injection port located at the front end of the pipe section, or an injection port located at the front end of the pipe section and an atomizing nozzle connected to the injection port, or an injection port located at the front end of the pipe section and a static mixer located within the pipe section, or an injection port located at the front end of the pipe section, an atomizing nozzle connected to the injection port, and a static mixer located within the pipe section. By adjusting at least one injection structure and the reaction pipe length, the adjusted sulfur capacity is calculated, thereby obtaining the factors affecting the sulfur capacity.

[0018] Compared with the prior art, the present invention has the following advantages and beneficial effects:

[0019] 1. By directly installing a pipeline injection structure on the raw gas pipeline, different influencing factors (including different structural features and injection parameters) can be easily replaced under actual site conditions. This allows for obtaining the impact of different structural features and injection parameters on sulfur capacity, thereby clarifying which structural features and injection parameters are the influencing factors of the desulfurization effect of the pipeline direct injection structure. The optimal injection plan can be formulated for the actual site conditions, avoiding the need for manual experience-based plan formulation and improving the economic efficiency of the process.

[0020] 2. Experimentally study the factors affecting the desulfurization effect under the direct pipeline injection treatment process, and comprehensively consider the injection parameters to select the optimal treatment process equipment and reduce production costs.

[0021] 3. By setting regulating valves to adjust the flow rate of raw gas, the influence of different flow rates on the desulfurization effect can be experimentally studied. Taking into account the structure of the pipeline direct injection process equipment, an equipment structure and injection parameters with good desulfurization effect and low production cost can be obtained.

[0022] 4. Design a desulfurizer injection module to study the influence of desulfurizer injection amount, different concentrations of the same type of desulfurizer, and different types of desulfurizer on sulfur capacity. Take into account the direct injection process equipment in pipelines to obtain equipment structure and injection parameters with good desulfurization effect and low production cost.

[0023] 5. Design a pipeline filling module to test and study the impact 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. By comprehensively considering the filling parameters, the equipment structure and filling parameters with good desulfurization effect and low production cost can be obtained.

[0024] 6. 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

[0025] 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.

[0026] In the picture:

[0027] Figure 1 This is a flowchart illustrating the process principle of the present invention;

[0028] Figure 2 This is a schematic diagram of the desulfurizing agent injection module in this invention;

[0029] Figure 3 This is a schematic diagram of the serpentine tube module in this invention;

[0030] Figure 4 This is a schematic diagram of the structure of a pipeline filling module according to the present invention;

[0031] Figure 5 This is a schematic diagram of the structure of a pipeline filling module according to the present invention;

[0032] Figure 6 This is a schematic diagram of the structure of a pipeline filling module according to the present invention;

[0033] Figure 7 This is a schematic diagram of the structure of a pipeline filling module according to the present invention.

[0034] The attached diagram shows the markings and corresponding component names:

[0035] Raw material gas pipeline 1, inlet ball valve 101, ball valve A102, inlet online hydrogen sulfide detector 103, ball valve B 104, regulating valve A105, flow meter 106, pipeline filling module 2, filling port 201, atomizing nozzle 202, static mixer 203, ball valve C1001, serpentine pipe module 3, serpentine pipe opening A301, serpentine pipe opening B303, serpentine pipe opening C305, serpentine pipe opening D307, serpentine pipe opening E309, stop valve A302, stop valve B304, stop valve C306, stop valve D308, stop valve E310, desulfurizing agent filling module 4, desulfurizing agent storage tank 401 1. Desulfurizer filling pipeline 402, filter screen 404, ball valve C403, centrifugal pump 405, check valve 406, shut-off valve F407, breather valve 408, ball valve J409, ball valve K410, level gauge D411, drain valve 412, exhaust pipeline 5, ball valve I501, shut-off valve G502, ball valve H503, outlet ball valve 505, filling pipeline 6, ball valve D601, filter screen 602, metering pump 603, ball valve E606, pressure gauge 604, check valve 605, instrument pipeline 7. Detailed Implementation

[0036] 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.

[0037] 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.

[0038] 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.

[0039] 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.

[0040] 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.

[0041] Existing triazine desulfurizers are expensive, and significant discrepancies have been found between data obtained from laboratory desulfurization treatments and data directly detected in actual field production. Furthermore, various factors (including process structure and different desulfurizers) affect desulfurization efficiency. Therefore, this invention involves setting up a process structure for on-site desulfurization treatment for testing. It was also found that factors influencing 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.

[0042] In order to accurately obtain the factors affecting the desulfurization effect, this application provides the following embodiments.

[0043] Example 1

[0044] This implementation provides a device for evaluating the influencing factors of direct pipeline desulfurization effect. (See also...) Figures 1-7The system includes a direct pipeline injection structure, a desulfurizer injection module 4, and two hydrogen sulfide detection mechanisms. The inlet of the direct pipeline injection structure is connected to the raw gas pipeline 1. The desulfurizer injection module 4 is used to inject desulfurizer into the direct pipeline injection structure. One hydrogen sulfide detection mechanism detects the hydrogen sulfide content of the raw gas from the raw gas pipeline 1, and the other detects the hydrogen sulfide content of the gas treated by the direct pipeline injection structure. Connecting the direct pipeline injection structure to the raw gas pipeline 1 allows for the acquisition of corresponding desulfurization data under objective and realistic on-site conditions. Furthermore, by changing the equipment structure characteristics and desulfurizer injection parameters of the direct pipeline injection structure, the system can identify the structural characteristics and injection parameters affecting sulfur capacity, clarifying which structural characteristics and injection parameters influence the desulfurization effect of the direct pipeline injection structure. This facilitates the development of optimal process schemes for specific on-site conditions, reducing the production cost of natural gas desulfurization.

[0045] Specifically, see Figures 1-7 The inlet of the direct injection structure is connected to the raw gas pipeline 1. An inlet ball valve 101 is connected to the raw gas pipeline 1. A ball valve A102 is connected to the pipeline that connects the raw gas pipeline 1 to the inlet online hydrogen sulfide detector 103. The outlet of the direct injection structure is equipped with an exhaust pipeline 5. The exhaust pipeline 5 is provided with a branch pipe that is connected to the outlet online hydrogen sulfide detector 504. A shut-off valve G502 and a ball valve H503 are connected to the branch pipe. An outlet ball valve 505 is provided on the exhaust pipeline 5.

[0046] See Figures 1-7 The sulfur-containing natural gas (raw material gas) passes through the inlet ball valve 101. The hydrogen sulfide content of the raw material gas is detected in real time by the online hydrogen sulfide detector 103. The raw material gas then passes sequentially through ball valve B 104, regulating valve A 105, and flow meter 106 before entering the pipeline filling module 2. In the pipeline filling module 2, the raw material gas comes into contact with the triazine solution from the desulfurizing agent filling module 4 to remove hydrogen sulfide. It then enters the serpentine pipe module 3 and finally enters the exhaust pipeline 5 from the bottom of the serpentine pipe.

[0047] See Figure 1 and Figure 2The desulfurizing agent filling module 4 includes a desulfurizing agent storage tank 401, a desulfurizing agent filling pipeline 402, a filter screen 404, a ball valve C403, a centrifugal pump 405, a check valve 406, a shut-off valve F407, a breather valve 408, a level gauge D411, and a drain valve 412. The filter screen 404, ball valve C403, centrifugal pump 405, check valve 406, and shut-off valve F407 are sequentially installed on the desulfurizing agent filling pipeline 402 along the airflow direction. The desulfurizing agent filling module 4 supplies desulfurizing agent to the pipeline filling module 2 through the filling pipeline 6, and uses a metering pump 603 to pump the desulfurizing agent into the filling port 201 of the pipeline filling module 2.

[0048] See Figures 4-7 Taking a 1-meter pipe section as an example, the influence of different injection structures on the desulfurization effect was tested: flanges were installed at both ends to facilitate the replacement of different types of pipe sections. The inlet of the pipe section was the raw gas pipeline, and the outlet flowed to the serpentine pipe module 3. The pipe section was designed with four types according to different treatment processes: 1) Pipe section without any treatment process, with an injection port 201 at the front end; 2) Pipe section with atomizing nozzle 202, which is connected to the injection port 201 to increase the contact area between the desulfurizing agent and the sulfur-containing natural gas; 3) Pipe section with static mixer 203, with an injection port 201 at the front end, through which the desulfurizing agent and gas pass together, thereby increasing the mixing intensity of the desulfurizing solvent and the sulfur-containing natural gas; 4) Pipe section with both atomizing nozzle 202 and static mixer 203, with an injection port 201 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 mixers, and with atomizing nozzles + static mixers) on desulfurization efficiency.

[0049] See Figure 1 and Figure 3 The air inlet of the serpentine tube module 3 is connected to the pipeline filling module 2 via ball valve C1001 and pipeline, and the outlet enters the exhaust pipeline 5 after passing through ball valve I501. The serpentine tube module 3 is arranged in a stacked manner.

[0050] Taking a pipeline with a length of 5 meters and a height of 1-1.6 meters, folded into 10 layers as an example, the effect of different reaction tube lengths on desulfurization efficiency was tested. A sampling port was set up every 10 meters, for a total of five sampling ports (301, 303, 305, 307, and 309). These ports were connected to instrument pipeline 7 via shut-off valves A302, B304, C306, D308, and E310, respectively, and then connected to the online hydrogen sulfide detector 504 at the outlet via ball valve H503. This allowed for the experimental study of the effect of different reaction lengths on desulfurization efficiency.

[0051] Implementation 2

[0052] This embodiment provides a method for evaluating the influencing factors of direct pipeline desulfurization effect, implemented based on the desulfurization effect evaluation device of the desulfurizing agent described in Embodiment 1, including the following steps: operating the direct pipeline injection structure, changing the injection parameters of the desulfurizing agent injection module 4 and the structural features of the direct pipeline injection structure, detecting the hydrogen sulfide content before desulfurization in the raw gas pipeline 1 and the hydrogen sulfide content after desulfurization in the gas in the instrument pipeline 7 corresponding to at least one injection parameter of the desulfurizing agent injection module 4, and / or detecting the hydrogen sulfide content before desulfurization in the raw gas pipeline 1 and the hydrogen sulfide content after desulfurization in the instrument pipeline 7 corresponding to at least one structural feature, obtaining the corresponding sulfur capacity through calculation formula, and verifying the influence factors of the structural features of the direct pipeline injection structure and the desulfurizing agent injection parameters of the desulfurizing agent injection module 4 on the sulfur capacity.

[0053] See Figures 1-7 The specific steps are as follows:

[0054] By default, all valves are in the closed state.

[0055] S1: Open ball valve C403 and shut-off valve F407. 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 405. Open ball valve J409 and ball valve K410. Observe the reading of level gauge D411. Stop injection when the level is appropriate. Close ball valve C403, shut-off valve F407 and centrifugal pump 405.

[0056] S2: Open ball valve C1001, ball valve I501 and outlet ball valve 505.

[0057] S3: Open ball valves D601 and E606, and inject the desulfurizing agent in the desulfurizing agent storage tank 401 into the pipeline injection module 2 through the injection pipeline 6 using the metering pump 603. The desulfurizing agent passes through the serpentine pipe module 3 and flows into the exhaust pipeline 5.

[0058] S4: Open the inlet ball valve 101, ball valve A102, ball valve B104, and regulating valve A105 on the inlet pipeline. Sulfur-containing natural gas enters the pipeline filling module 2 to remove hydrogen sulfide, then enters the serpentine pipe module 3, and finally enters the exhaust pipeline 5 from the bottom of the serpentine pipe through ball valve I501. Open the shut-off valve G502 and ball valve H503, observe the reading on the online hydrogen sulfide detector 504 at the outlet, and adjust the metering pump 603 according to actual requirements to control the desulfurizing agent injection amount.

[0059] S5: Stabilize the sulfur-containing natural gas flow rate and desulfurizer injection amount for a certain time t, and record the relevant readings for the corresponding operating conditions, including the readings of flow meter 106, metering pump 603, inlet online hydrogen sulfide detector 103, and outlet online hydrogen sulfide detector 504. 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 / desulfurizer mass, where, desulfurizer mass = desulfurizer density * desulfurizer volume, and desulfurizer volume = metering pump reading * time t.

[0060] Assuming t is 0.5h, the flow rate of the sulfur-containing natural gas—as displayed by the first flow meter 106—is 0.0833 × 10⁻⁶. 4 m 3 / h, desulfurizing agent injection rate—the first metering pump 504 shows 2L / h; hydrogen sulfide content before desulfurization—the imported online hydrogen sulfide detector 103 shows 300mg / m³. 3 Export online hydrogen sulfide detector 3041 mg / m³ 3 Flow rate = 0.0833 × 10 4 m 3 / h*0.5h=416.5m 3 Desulfurizer volume = 2L / h * 0.5h = 1L, desulfurizer mass = 1.08g / cm³ 3 *1L = 1.08kg. Sulfur capacity = (300-1)mg / m³ 3 *416.5m 3 / 1.08kg=11.53%.

[0061] S6: Conduct multiple sets of experiments, adjust the gas flow rate by regulating valve A105, and study the effect of different flow rates of sulfur-containing natural gas (raw gas) on the desulfurization effect.

[0062] S7: Conduct multiple sets of experiments to study the desulfurization effect of different desulfurizing agent dosages by controlling metering pump 603.

[0063] S8: Close the shut-off valve G502, switch the sampling port and conduct 5 more sets of tests, opening shut-off valves A302, B304, C306, D308 and E310 respectively, to test the effect of different reaction lengths on desulfurization effect.

[0064] S9: Close inlet ball valve 101, ball valve B 104, and regulating valve A105, then close ball valve D601, metering pump 603, and ball valve E606. Close ball valve C1001 to vent the remaining gas inside the pipeline filling module 2 section. Replace different types of pipeline sections in pipeline filling module 2 and repeat S1-S8 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.

[0065] S10: Close the inlet 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 412 of the desulfurizing agent storage tank to drain the residual liquid.

[0066] S11: Change the proportion of No. 1 triazine desulfurizer to other proportions, and repeat S1-S10 with different proportions of No. 2 / No. 3 triazine desulfurizer. Conduct multiple sets of experiments to study the effects of different concentrations and types of the same type of desulfurizer on the desulfurization effect.

[0067] 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 influencing factors of direct pipeline desulfurization effect, characterized in that, include: A direct pipeline injection structure, wherein the inlet of the direct pipeline injection structure is connected to the raw material gas pipeline; A desulfurizing agent injection module, which is used to inject desulfurizing agent into a pipeline direct injection structure; Two hydrogen sulfide detection devices are provided. One of the hydrogen sulfide detection devices is used to detect the hydrogen sulfide content of the raw gas from the raw gas pipeline, and the other of the hydrogen sulfide detection device is used to detect the hydrogen sulfide content of the gas after the pipeline is directly injected with structural treatment.

2. The device for evaluating the influencing factors of direct pipeline desulfurization effect according to claim 1, characterized in that, The hydrogen sulfide detection system 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 raw material gas pipeline is connected to a regulating valve A and a flow meter to regulate the flow rate of the raw material gas.

3. The device for evaluating the influencing factors of direct pipeline desulfurization effect according to claim 2, characterized in that, The direct pipeline injection structure includes a pipeline injection module and a serpentine pipe module. The pipeline injection module includes a pipe section, the inlet of which is connected to the raw material gas pipeline and the outlet of which is connected to the serpentine pipe module. An injection structure is provided on the pipe section, and the injection structure is connected to the desulfurizer injection module through an injection pipeline.

4. The device for evaluating the influencing factors of direct pipeline desulfurization effect according to claim 3, characterized in that, The injection structure includes an injection port at the front end of the pipe section, or an injection port at the front end of the pipe section and an atomizing nozzle connected to the injection port, or an injection port at the front end of the pipe section and a static mixer inside the pipe section, or an injection port at the front end of the pipe section, an atomizing nozzle connected to the injection port, and a static mixer inside the pipe section, in order to study the influence of different pipeline injection processes on sulfur capacity.

5. The device for evaluating the influencing factors of direct pipeline desulfurization effect according to claim 3, characterized in that, The serpentine tube module includes a serpentine tube and several parallel sampling lines. The inlet of the serpentine tube is connected to the raw material gas line, and the outlet is connected to the exhaust gas line. Several sampling ports are provided on the serpentine tube. One end of each sampling line is connected to the corresponding sampling port, and the other end is connected to the online hydrogen sulfide detector at the outlet via an instrument line. Each sampling line is equipped with a corresponding shut-off valve.

6. The device for evaluating the influencing factors of direct pipeline desulfurization effect according to claim 3, characterized in that, The desulfurizing agent filling module includes a desulfurizing agent storage tank, a desulfurizing agent filling pipeline, and a centrifugal pump. The inlet of the desulfurizing agent storage tank is connected to the desulfurizing agent filling pipeline, and the outlet is connected to the filling pipeline. The centrifugal pump is connected to the desulfurizing agent filling pipeline. A metering pump and a filter screen are installed on the filling pipeline, and the filter screen is located upstream of the metering pump.

7. A method for evaluating the influencing factors of direct pipeline desulfurization effect, characterized in that, The evaluation device for evaluating the influencing factors of direct pipeline desulfurization effect according to any one of claims 1 to 6 includes the following steps: The system operates with a direct pipeline injection structure. By changing the injection parameters of the desulfurizing agent injection module and the structural features of the direct pipeline injection structure, the system detects the hydrogen sulfide content before desulfurization in the raw gas pipeline and the hydrogen sulfide content after desulfurization in the gas in the instrument pipeline corresponding to at least one injection parameter of the desulfurizing agent injection module, and / or detects the hydrogen sulfide content before desulfurization in the raw gas pipeline and the hydrogen sulfide content after desulfurization in the instrument pipeline corresponding to at least one structural feature. The corresponding sulfur capacity is obtained through calculation formulas to verify the influence of the structural features of the direct pipeline injection structure and the desulfurizing agent injection parameters of the desulfurizing agent injection module on the sulfur capacity.

8. The method for evaluating the influencing factors of direct pipeline desulfurization effect according to claim 7, 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.

9. The method for evaluating the influencing factors of direct pipeline desulfurization effect according to claim 7, characterized in that, The desulfurizing agent dosing module's dosing parameters include desulfurizing agent type, desulfurizing agent concentration, and desulfurizing agent dosing amount.

10. The method for evaluating the influencing factors of direct pipeline desulfurization effect according to claim 7, characterized in that, The structural features of the direct pipeline injection structure include an injection structure and serpentine pipes of different lengths. The injection structure includes an injection port at the front end of the pipe section, or an injection port at the front end of the pipe section and an atomizing nozzle connected to the injection port, or an injection port at the front end of the pipe section and a static mixer installed inside the pipe section, or an injection port at the front end of the pipe section, an atomizing nozzle connected to the injection port, and a static mixer installed inside the pipe section.

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