A device for monitoring hydrogen sulphide production from an oil well

Abstract

The utility model discloses an oil well output hydrogen sulfide monitoring devices, including gas -liquid separation part, gas detection part, clear liquid recovery part, gas -liquid separation part includes import pipe, gas -liquid separation subassembly, and gas detection part includes gas pre -treatment subassembly, gas -liquid separation subassembly's gas outlet communicates with gas pre -treatment subassembly, and gas pre -treatment subassembly connects detection chamber, and detection chamber connects hydrogen sulfide detector, and detection chamber connects gas harmless component, clear liquid recovery part includes jet pump, and the liquid inlet of jet pump is communicated with the liquid outlet of gas -liquid separation subassembly through the liquid suction pipe, and the gas -liquid import of gas -liquid separation subassembly is used for connecting wellhead flow, and the air inlet of jet pump is used for connecting sleeve gas pipe, and the liquid outlet gas port of jet pump is used for connecting oil gathering pipeline, through jet pump makes the oil liquid of entering device with the oil liquid in wellhead flow, and the same pressure parallel operation, effectively drive oil -gas mixture flow in system, has improved the efficiency and stability of entire processing flow.

Description

Technical Field

[0001] This utility model relates to the field of petroleum monitoring technology, specifically to a device for monitoring hydrogen sulfide production from oil wells. Background Technology

[0002] In oilfield development, detecting the hydrogen sulfide content in oil wells has become an important routine management task. Currently, the hydrogen sulfide content in oil wells is mainly detected through manual sampling, which has several drawbacks: First, the number of oil wells containing hydrogen sulfide has increased, accounting for about one-third of the total number of oil wells. The detection and recording procedures are complex, the workload has increased significantly, and the requirements for personal protection are high. The manual sampling method involves extracting natural gas from the wellhead using an oil-gas separator, then using a syringe to extract 100 ml of gas from the oil-gas separator and injecting it into a hazardous gas detection tube. The data is read from the scale indicated by the brown column. According to the requirement for monthly quantitative testing of hydrogen sulfide-containing wells, the oilfield conducts nearly 8,000 well tests per month. After the implementation of remediation measures, the testing frequency is even higher. The testing process requires two people wearing breathing apparatus, with an average testing time of 30 minutes, resulting in high labor intensity. Secondly, the gas sampling process is cumbersome, time-consuming, and the standards are unstable. Periodic sampling results in low testing frequency, discontinuous data, large numerical fluctuations, low accuracy, and large errors, making it impossible to monitor the changes in hydrogen sulfide in real time and hindering the tracking and adjustment of the treatment effect. Thirdly, during the sampling and testing process, the sampling is not sealed, which may lead to hydrogen sulfide overflow and leakage. The gas is emitted into the air during testing, which is extremely harmful and increases the occupational health and safety risks for operators.

[0003] Announcement No. CN111579317B discloses an auxiliary device for rapid detection of associated hydrogen sulfide in oil wells, comprising a trailer, an upper cavity, an intermediate cavity, a lower cavity, and a level gauge. The trailer includes an axle, a main beam, a pin, and support legs. The main beam is fixed above the axle, and the support legs are fixed below the axle. From top to bottom, the main beam is fixed with an upper hanging pipe, a middle hanging pipe, a lower hanging pipe, and a limiting pipe. The pin passes through the upper hanging pipe, the middle hanging pipe, and the lower hanging pipe from top to bottom, and the end of the pin is threaded to the limiting pipe. The upper cavity, the intermediate cavity, and the lower cavity are connected to the trailer from top to bottom via the pin. The upper cavity is connected to the intermediate cavity, and the intermediate cavity is connected to the lower cavity. The level gauge is connected to the upper cavity and the lower cavity via a connecting device.

[0004] Announcement No. CN108487906B discloses a closed-loop sampling and detection device and method for hydrogen sulfide at the wellhead of an oil well. The device consists of two parts: a sampling assembly and a detection assembly. The detection assembly is installed on the upper part of the sampling assembly. The sampling assembly includes a flow section, a sampling guide pipe, a sampling valve, a sampling tube, a lower connector of the sampler, a spring, a cone valve cone, and a cone valve seat. The detection assembly includes a quick connector, a cone valve top rod, a colorimetric tube connector, a rubber hose, a colorimetric tube, a sampling pump barrel, a piston, a rubber stopper, a piston guide rod, and a handwheel.

[0005] Announcement No. CN208380564U discloses a sealed hydrogen sulfide sampling and testing device for oil wellheads, including a sealed separation sampler and a sealed sampling tester. The sealed separation sampler includes a sampler cylinder, a first piston, and a first piston screw. The first piston is disposed inside the sampler cylinder and has a built-in thrust bearing. The lower end of the first piston screw is connected to the thrust bearing. The sampler cylinder has an upper port and a lower port. An end cap is provided at the upper port of the sampler cylinder, and an internally threaded hole is formed in the center of the end cap. The first piston screw is installed in conjunction with the internally threaded hole. A handle is installed after the upper end of the first piston screw extends out of the internally threaded hole. The upper side wall of the sampler cylinder is connected to the sampler outlet connector, and the lower port of the sampler cylinder is connected to the gas outlet valve on the wellhead oil pipeline. The sampler outlet connector of the sealed sampling tester is connected to the tester inlet connector.

[0006] The aforementioned existing technologies are all temporary connections and require manual operation, which pose occupational health and safety risks to operators.

[0007] In summary, the technical solutions, technical problems to be solved, and beneficial effects of the above-disclosed technologies are all different from those of this utility model. For more technical features, technical problems to be solved, and beneficial effects of this utility model, the above-disclosed technical documents do not provide any technical inspiration. Utility Model Content

[0008] In order to overcome the shortcomings of the prior art and solve at least one of the technical problems mentioned in the background art, this utility model provides a monitoring device for hydrogen sulfide production in oil wells.

[0009] To achieve the above objectives, the present invention adopts the following technical solution:

[0010] A hydrogen sulfide production monitoring device for oil wells includes a gas-liquid separation section, a gas detection section, and a clean liquid recovery section. The gas-liquid separation section includes an inlet pipe and a gas-liquid separation assembly. The gas detection section includes a gas pretreatment assembly. The gas outlet of the gas-liquid separation assembly is connected to the gas pretreatment assembly. The gas pretreatment assembly is connected to a detection chamber, which is connected to a hydrogen sulfide detector and a gas detoxification assembly. The clean liquid recovery section includes a jet pump. The inlet of the jet pump is connected to the outlet of the gas-liquid separation assembly via a pumping pipe. The gas-liquid inlet of the gas-liquid separation assembly is used to connect to the wellhead process, the gas inlet of the jet pump is used to connect to the casing pipe, and the gas outlet of the jet pump is used to connect to the oil gathering pipeline.

[0011] Furthermore, the gas-liquid separation assembly includes a primary cyclone separator, a secondary cyclone separator, and a tertiary cyclone separator;

[0012] The first inlet of the primary hydrocyclone is connected to the wellhead via an inlet pipe, and a sampling valve is installed on the inlet pipe.

[0013] The first liquid outlet of the primary hydrocyclone is connected to the second liquid inlet of the secondary hydrocyclone through a primary connecting pipe.

[0014] The second liquid outlet of the secondary hydrocyclone is connected to the third liquid inlet of the tertiary hydrocyclone through a secondary connecting pipe;

[0015] The third outlet of the three-stage hydrocyclone is connected to the clear liquid recovery section;

[0016] The upper ends of the first-stage cyclone separator, the second-stage cyclone separator, and the third-stage cyclone separator are connected to gas collecting pipes, which are connected to the gas detection section.

[0017] Furthermore, the gas pretreatment assembly includes a solenoid valve, a solenoid valve outlet pipe, a pressure reducing valve, a pressure reducing purge pipe, a filter, and a filter outlet pipe connected in sequence.

[0018] The end of the solenoid valve away from the solenoid valve outlet pipe is connected to the gas collecting pipe, the end of the filter outlet pipe away from the filter is connected to the filter, and the pressure reducing purge pipe is connected to the purge pump.

[0019] Furthermore, the gas desulfurization component includes a desulfurization tank, which contains a desulfurizing agent. The detection chamber is connected to the desulfurization tank via an outlet pipe, which is inserted into the desulfurization tank into the desulfurizing agent. A venting pipe is installed at the upper end of the desulfurization tank, and a vent valve is installed on the venting pipe.

[0020] Furthermore, the inlet of the jet pump is connected to the third outlet of the three-stage cyclone separator through a pumping pipe, the air inlet of the jet pump is connected to the well casing valve at the wellhead through a casing pipe, the jet outlet of the jet pump is connected to the inlet of a single-flow valve through a pumping liquid-gas pipe, and the outlet of the single-flow valve is connected to the oil gathering pipeline.

[0021] Furthermore, a liquid level monitoring tube is installed next to the primary hydrocyclone separator. The upper end of the primary hydrocyclone separator is connected to the upper end of the liquid level monitoring tube through a pressure balance tube, and the lower end of the primary hydrocyclone separator is connected to the lower end of the liquid level monitoring tube through a liquid level connecting tube. The liquid level monitoring tube is equipped with a magnetic coupling liquid level gauge.

[0022] Furthermore, the data acquisition and control section includes a PLC logic controller;

[0023] The PLC logic controller is connected to the magnetically coupled level gauge via a level acquisition line.

[0024] The PLC logic controller is connected to the solenoid valve via a solenoid valve control line.

[0025] The PLC logic controller is connected to the hydrogen sulfide detector via an H2S acquisition line.

[0026] The PLC logic controller is connected to the purge pump via the air pump control line.

[0027] The PLC logic controller is connected to the industrial control network switch via a network cable.

[0028] The PLC logic controller is wirelessly connected to the remote control switch via its own wireless module.

[0029] Furthermore, the wellhead process is connected to the production valve at the wellhead of the oil well, and the wellhead process is connected to a back pressure valve and a sampling valve, with the back pressure valve connected to the oil gathering pipeline.

[0030] Furthermore, the release and retraction tube is connected to the gas sleeve tube.

[0031] Furthermore, the first liquid inlet is higher than the second liquid inlet, the second liquid inlet is higher than the third liquid inlet, the third liquid inlet is higher than the third liquid outlet, the first liquid outlet is at the same height as the second liquid inlet, and the second liquid outlet is at the same height as the third liquid inlet.

[0032] Compared with the prior art, the present invention has the following advantages:

[0033] 1. This utility model uses a jet pump to make the oil entering the device and the oil in the wellhead process run in parallel at the same pressure, effectively driving the flow of the oil-gas mixture in the system and improving the efficiency and stability of the entire processing process.

[0034] 2. This utility model achieves closed measurement, eliminates the need for workers to conduct tests in hazardous environments, eliminates the emission of hydrogen sulfide gas into the air, and ensures that the emitted oil and gas meet relevant national standards.

[0035] 3. This utility model realizes automatic measurement, timed and quantitative data acquisition and transmission, unmanned operation, saving time, effort and cost, reducing labor costs and improving detection efficiency; it meets the requirements for monitoring hydrogen sulfide in low-gas-content oil wells, reducing nearly 10,000 manual inspections for oil fields, and reducing the workload and labor intensity of inspection.

[0036] 4. This utility model reduces occupational health risks, promotes green and clean production, and has significant economic, compliance, practicality, and scalability benefits, generating comprehensive benefits of over ten million yuan annually. Attached Figure Description

[0037] Figure 1 This is a schematic diagram of the structure of a hydrogen sulfide production monitoring device for oil wells according to this utility model.

[0038] In the diagram: 1. Wellhead; 2. Production Valve; 3. Wellhead Flow Chart; 4. Back Pressure Valve; 5. Sampling Valve; 6. Inlet Pipe; 7. Liquid Level Connecting Pipe; 8. First-Stage Cyclone Separator; 9. First-Stage Connecting Pipe; 10. Second-Stage Cyclone Separator; 11. Second-Stage Connecting Pipe; 12. Tertiary Cyclone Separator; 13. Gas Gathering Pipe; 14. Solenoid Valve; 15. Solenoid Valve Outlet Pipe; 16. Pressure Reducing Valve; 17. Purge Pump; 18. Pressure Reducing Purge Pipe; 19. Filter; 20. Filter Outlet Pipe; 21. Detection Chamber; 22. Hydrogen Sulfide Detector; 23. Gas Outlet Pipe; 24. Desulfurization Tank; 25. Desulfurizing Agent; 26. Exhaust Pipe; 27. Venting. 27. Valve, 28. Receiving / Receiving Pipe, 29. Pump Inlet Valve, 30. Jet Pump, 31. Oil Well Casing Valve, 32. Casing Pipe, 33. Pump Outlet Gas Pipe, 34. Check Valve, 35. Inlet Gas Pipe, 36. Oil Gathering Pipe, 37. Liquid Level Monitoring Pipe, 38. Magnetic Coupler Liquid Level Gauge, 39. Pressure Balancing Pipe, 40. Power Line, 41. Liquid Level Acquisition Line, 42. Explosion-proof Control Box, 43. PLC Logic Controller, 44. Power Supply, 45. Network Cable, 46. Industrial Control Network Switch, 47. Solenoid Valve Control Line, 48. Air Pump Control Line, 49. H2S Acquisition Line, 50. Remote Control Switch, 51. Detailed Implementation

[0039] The technical solutions of the present utility model will be clearly and completely described below with reference to the accompanying drawings of the embodiments. Obviously, the described embodiments are only some embodiments of the present utility model, and not all embodiments. Based on the embodiments of the present utility model, all other embodiments obtained by those of ordinary skill in the art without creative effort are within the protection scope of the present utility model.

[0040] Example 1:

[0041] Please see Figure 1 This utility model provides an oil well hydrogen sulfide production monitoring device that draws on the technical principle of hydrogen sulfide detectors in atmospheric environments. It separates oil and gas in the oil well, reduces the pressure of the separated gas to below 0.1 MPa, and forms a medium environment that meets the detection requirements of the probe during detection. Using an electrochemical principle, the concentration of hydrogen sulfide gas in the medium environment is detected by the probe, and the hydrogen sulfide content is displayed on the LCD screen.

[0042] A device for monitoring hydrogen sulfide production from oil wells includes a gas-liquid separation section, a gas detection section, a clear liquid recovery section, and a data acquisition and control section.

[0043] Furthermore, the gas-liquid separation section includes an inlet pipe 6 and a gas-liquid separation assembly. The gas-liquid separation assembly includes a primary cyclone separator 8, a secondary cyclone separator 10, and a tertiary cyclone separator 12. The first inlet of the primary cyclone separator 8 is connected to the wellhead process 3 through the inlet pipe 6. A sampling valve 5 is installed on the inlet pipe 6. The first outlet of the primary cyclone separator 8 is connected to the second inlet of the secondary cyclone separator 10 through a primary connecting pipe 9. The second outlet of the secondary cyclone separator 10 is connected to the third inlet of the tertiary cyclone separator 12 through a secondary connecting pipe 11. The third outlet of the tertiary cyclone separator 12 is connected to the clear liquid recovery section. The upper ends of the primary cyclone separator 8, the secondary cyclone separator 10, and the tertiary cyclone separator 12 are connected to a gas collecting pipe 13, which is connected to a gas detection section. The gas detection section is connected to the acquisition and control section.

[0044] Among them, the wellhead process 3 is connected to the production valve 2 of the wellhead 1, and the wellhead process 3 is connected to the back pressure valve 4 and the sampling valve 5 respectively. The back pressure valve 4 is connected to the oil gathering pipeline 37.

[0045] In use, close the back pressure valve 4. Gas and liquid are drawn from the wellhead 1 and flow sequentially through the production valve 2, wellhead flow path 3, sampling valve 5, and inlet pipe 6, entering the first-stage cyclone separator 8. The separated gas enters the gas collecting pipe 13. The separated liquid enters the second-stage cyclone separator 10 through the first-stage connecting pipe 9. The separated gas enters the gas collecting pipe 13. The separated liquid enters the third-stage cyclone separator 12 through the second-stage connecting pipe 11. The separated gas enters the gas collecting pipe 13. The separated liquid enters the clean liquid recovery section. The gas in the gas collecting pipe 13 enters the gas detection section.

[0046] Specifically, the cyclone separator is the key to achieving gas-liquid separation. The three-stage cyclone process uses three small cyclone separators with a diameter of DN50 connected in series to achieve oil-gas separation. The miniaturized design has a total volume of 20L and is not classified as a pressure vessel, thus eliminating the safety risks associated with pressure vessels.

[0047] Specifically, the first inlet is higher than the second inlet, the second inlet is higher than the third inlet, the third inlet is higher than the third outlet, the first outlet is at the same height as the second inlet, and the second outlet is at the same height as the third inlet; the elevation difference forms a natural flow gradient, which compensates for flow rate loss, enhances separation stability, and ensures separation effect.

[0048] Specifically, the inlet pipe 6 is threadedly connected to the sampling valve 5. When the sampling valve 5 is opened, the gas and liquid extracted from the wellhead 1 enter the inlet pipe 6.

[0049] Specifically, a liquid level monitoring tube 38 is installed next to the primary hydrocyclone separator 8. The upper end of the primary hydrocyclone separator 8 is connected to the upper end of the liquid level monitoring tube 38 through a pressure balance tube 40, and the lower end of the primary hydrocyclone separator 8 is connected to the lower end of the liquid level monitoring tube 38 through a liquid level connecting tube 7. The liquid level monitoring tube 38 is equipped with a magnetic coupling liquid level gauge 39, which adopts a magnetic coupling protection design. The liquid separated by the primary hydrocyclone separator 8 enters the liquid level monitoring tube 38 through the liquid level connecting tube 7, and the gas separated by the primary hydrocyclone separator 8 enters the liquid level monitoring tube 38 through the pressure balance tube 40, keeping the liquid level inside the tube level with that of the primary hydrocyclone separator 8. The magnetic coupling liquid level gauge 39 monitors the liquid level inside the primary hydrocyclone separator 8.

[0050] Furthermore, the gas detection section includes a gas pretreatment component, which is connected to the gas collection pipe 13, the gas pretreatment component is connected to the detection chamber 21, the detection chamber 21 is connected to the hydrogen sulfide detector 22, and the detection chamber 21 is connected to the gas detoxification component.

[0051] Specifically, the gas pretreatment assembly includes a solenoid valve 14, a solenoid valve outlet pipe 15, a pressure reducing valve 16, a pressure reducing purge pipe 18, a filter 19, and a filter outlet pipe 20, connected sequentially by threads. The end of the solenoid valve 14 furthest from the solenoid valve outlet pipe 15 is connected to a gas collecting pipe 13. The end of the filter outlet pipe 20 furthest from the filter 19 is connected to the filter 19. The pressure reducing purge pipe 18 is connected to a purge pump 17. The solenoid valve 14 controls the gas flow rate, ensuring the stability and accuracy of the gas concentration in the detection chamber and preventing oil-liquid cross-flow during oil-gas separation. The pressure reducing valve 16 reduces the high-pressure gas to a suitable detection pressure range, protecting the detection equipment and improving detection accuracy.

[0052] In operation, the gas separated by the primary cyclone separator 8, the secondary cyclone separator 10, and the tertiary cyclone separator 12 enters the gas collecting pipe 13. It then flows sequentially through the solenoid valve 14, the solenoid valve outlet pipe 15, the pressure reducing valve 16, the pressure reducing purge pipe 18, the filter 19, and the filter outlet pipe 20 before entering the detection chamber 21. There, it comes into contact with the detection probe of the hydrogen sulfide detector 22 in a gaseous medium environment, and the hydrogen sulfide detector 22 displays the hydrogen sulfide concentration value. Combined with the monitoring data from the magnetic coupling level gauge 39, the opening and closing time of the solenoid valve 14 is adjusted to ensure the liquid level remains below 2 / 3 of the cyclone separator capacity, preventing oil and water from entering the gas phase detection chamber.

[0053] Specifically, the gas desulfurization assembly includes a desulfurization tank 24, which contains a desulfurizing agent 25. The detection chamber 21 is connected to the desulfurization tank 24 via an outlet pipe 23, which is inserted into the desulfurization tank 24 and into the desulfurizing agent 25. A vent pipe 28 is installed at the upper end of the desulfurization tank 24, and a vent valve 27 is installed on the vent pipe 28. The desulfurization tank 24 desulfurizes the hydrogen sulfide-containing gas, ensuring that the emitted gas meets national environmental protection standards.

[0054] In use, the solenoid valve 14 is closed, the purge pump 17 is started, and the pumped pressurized air passes through the pressure reducing purge pipe 18, filter 19, filter outlet pipe 20, detection chamber 21, and exhaust pipe 23, and enters the desulfurization tank 24. The pressurized air mixes with the gas remaining in the filter 19, filter outlet pipe 20, and detection chamber 21, and enters the desulfurization tank 24 together to react chemically with the desulfurizing agent 25 to remove hydrogen sulfide gas. The desulfurized non-toxic gas enters the exhaust pipe 26, passes through the vent valve 27, and enters the vent pipe 28 to be discharged into the atmosphere.

[0055] Furthermore, the clarified fluid recovery section includes a jet pump 31. The fourth inlet of the jet pump 31 is connected to the third outlet of the three-stage cyclone separator 12 via a pumping pipe 29. The air inlet of the jet pump 31 is connected to the well casing valve 32 of the wellhead 1 via a casing pipe 33. The jet outlet of the jet pump 31 is connected to the inlet of a one-way valve 35 via a pumping liquid-gas pipe 34. The outlet of the one-way valve 35 is connected to the oil gathering pipeline 37. By generating negative pressure through high-speed fluid injection by the jet pump 31, the pressure difference of the incoming fluid is overcome, allowing the oil entering the device to run in parallel with the oil in the wellhead process at the same pressure. This effectively drives the flow of the oil-gas mixture in the system, improving the efficiency and stability of the entire processing flow.

[0056] When in use, the solenoid valve 14 is closed, and the gas and liquid continue to flow and remain in the first-stage cyclone separator 8, the first-stage connecting pipe 9, the second-stage cyclone separator 10, the second-stage connecting pipe 11, and the third-stage cyclone separator 12. On the other hand, the casing gas produced from the wellhead 1 enters the jet pump 31 through the casing valve 32 and the casing gas pipe 33. A negative pressure is formed in the section between the pump inlet valve 30 and the jet pump 31. Under the action of the negative pressure, the gas and liquid flowing inside are sucked into the jet pump 31 through the pumping pipe 29 and the pump inlet valve 30. After the casing gas mixes with the gas and liquid, it enters the oil collection pipeline 37 through the pump outlet gas pipe 34, the check valve 35, and the inlet gas pipe 36 in sequence and is recovered.

[0057] Specifically, when the casing gas pressure is lower than or equal to the back pressure of the oil collecting line 37, the check valve 35 prevents the backflow of gas and liquid in the oil collecting line 37.

[0058] In one embodiment, the release pipe 28 is connected to the gas casing 33, and the desulfurized non-toxic gas is recovered by the jet pump 31.

[0059] Furthermore, the data acquisition and control section includes a PLC logic controller 44. The PLC logic controller 44 is connected to a magnetically coupled level gauge 39 via a level acquisition line 42, a solenoid valve 14 via a solenoid valve control line 48, a hydrogen sulfide detector 22 via an H2S acquisition line 50, a purge pump 17 via a purge pump control line 49, and an industrial control network switch 47 via a network cable 46. The PLC logic controller 44 is also wirelessly connected to a remote control switch 51 via its own wireless module. By integrating control algorithms and logical judgment functions, the PLC logic controller 44 achieves intelligent control of the entire processing flow. The industrial control network switch 47 uploads real-time information such as operating status and detection data to a remote monitoring center, enabling remote monitoring and management.

[0060] Specifically, an explosion-proof control box 43 is provided, and a PLC logic controller 44 and a power supply 51 are installed inside the explosion-proof control box 43.

[0061] Among them, the liquid level acquisition line 42, the H2S acquisition line 50, and the remote control switch 51 are used as inputs; the solenoid valve control line 48, the air pump control line 49, and the network cable 46 are used as outputs.

[0062] The power supply 45 draws power through the power line 41 and supplies power to the PLC logic controller 44, the purge pump 17, the solenoid valve 14, and the magnetic coupler level gauge 39.

[0063] In use, the PLC logic controller 44 opens the solenoid valve 14 via the solenoid valve control line 48 according to the set monitoring time interval. The gas in the first-stage cyclone separator 8, the second-stage cyclone separator 10, the second-stage connecting pipe 11, and the third-stage cyclone separator 12 enters the detection chamber 21. The hydrogen sulfide concentration value measured by the hydrogen sulfide detector 22 is transmitted to the PLC logic controller 44. The data is sent to the monitoring terminal via the network cable 46 and the industrial control network switch 47. The system automatically generates reports, or receives instructions from the monitoring terminal, or sends instructions to the PLC logic controller 44 via the remote control switch 51 to reset the monitoring time interval.

[0064] In use, the PLC logic controller 44 closes the solenoid valve 14 through the solenoid valve control line 48 and starts the purge pump 17 through the air pump control line 49 according to the set monitoring time interval, so as to realize the exit of the purge detection chamber 21.

[0065] In operation, when the solenoid valve 14 is open, if the magnetic coupling level gauge 39 detects that the liquid level in the level monitoring tube 38 is higher than 2 / 3 of its height, it transmits the liquid level signal to the PLC logic controller 44 via the level acquisition line 42. The solenoid valve 14 is then closed via the solenoid valve control line 48, allowing stored gas to press down the liquid level. Before the solenoid valve 14 opens, if the magnetic coupling level gauge 39 detects that the liquid level in the level monitoring tube 38 is higher than 2 / 3 of its height, the PLC logic controller 44 controls the solenoid valve 14 to remain inactive, continuing to collect gas to press down the liquid level, and the liquid is discharged through the suction pipe 29. Once the liquid level has been lowered, the PLC logic controller 44 opens the solenoid valve 14 via the level acquisition line 42.

[0066] It should be noted that the valves, cyclone separators, purge pumps 17, filters 19, hydrogen sulfide detectors 22, desulfurizing agents 25, jet pumps 31, magnetic coupler level gauges 39, PLC logic controllers 44, industrial control network switches 47, and remote control switches 51 used are all existing technologies and can be obtained by purchase. Those skilled in the art are clear about their structure and usage, so they will not be described in detail.

[0067] Example 2:

[0068] Based on Example 1, this example provides a method for using an oil well hydrogen sulfide production monitoring device, including the following steps:

[0069] When the back pressure valve 4 is closed, the gas and liquid are drawn out from the wellhead 1 and flow sequentially through the production valve 2, wellhead flow path 3, sampling valve 5, and inlet pipe 6, entering the first-stage cyclone separator 8. The separated gas enters the gas gathering pipe 13; the separated liquid enters the second-stage cyclone separator 10 through the first-stage connecting pipe 9, and the separated gas enters the gas gathering pipe 13. The separated liquid enters the third-stage cyclone separator 12 through the second-stage connecting pipe 11, and the separated gas enters the gas gathering pipe 13. The separated liquid enters the jet pump 31 through the liquid extraction pipe 29.

[0070] The liquid separated by the first-stage cyclone separator 8 enters the liquid level monitoring tube 38 via the liquid level connecting pipe 7, while the gas separated by the first-stage cyclone separator 8 enters the liquid level monitoring tube 38 via the pressure balancing pipe 40, maintaining the liquid level inside the monitoring tube 38 at the same level as the first-stage cyclone separator 8. A magnetic coupling liquid level gauge 39 monitors the liquid level inside the cyclone separator and, by adjusting the opening and closing time of the solenoid valve 14, ensures that the liquid level is always below 2 / 3 of the cyclone separator's capacity, preventing oil and water from entering the gas phase detection chamber.

[0071] Among them, jet pump 31 extracts the stagnant liquid in the three-stage cyclone separator 12 for recovery.

[0072] The gas enters the gas collection pipe 13 and is detected by the hydrogen sulfide detector 22. The hydrogen sulfide in the desulfurization tank 24 is removed by the desulfurizing agent 25. The hydrogen sulfide in the residual gas swept out by the purge pump 17 from the filter 19 and the detection chamber 21 is either discharged through the discharge pipe 28 or recovered by the jet pump 31.

[0073] After closing the back pressure valve 4, the gas-liquid flow becomes: inlet pipe 6, primary cyclone separator 8, primary connecting pipe 9, secondary cyclone separator 10, secondary connecting pipe 11, and tertiary cyclone separator 12. Gas flows through solenoid valve 14, solenoid valve outlet pipe 15, pressure reducing valve 16, purge pump 17, pressure reducing purge pipe 18, filter 19, filter outlet pipe 20, detection chamber 21, gas outlet pipe 23, desulfurization tank 24, and discharge / receive pipe 28 to the atmosphere, or through gas casing pipe 33, jet pump 31, pumped liquid-gas pipe 34, liquid-gas inlet pipe 36, and oil collection line 37. Liquid flows through suction pipe 29, jet pump 31, pumped liquid-gas pipe 34, liquid-gas inlet pipe 36, and oil collection line 37. During this process, the amount of gas retained in the cyclone separator is changed by opening and closing solenoid valve 14, thereby adjusting the liquid level in the cyclone separator.

[0074] Achieve stable detection of hydrogen sulfide concentration:

[0075] The pressure reducing valve 16 is set to reduce the pressure to 0.05 MPa and the gas intake time to 10 seconds to achieve quantitative gas sampling and monitoring. Three types of hydrogen sulfide detector probes 22 are selected based on different hydrogen sulfide concentrations. The hydrogen sulfide concentration values ​​are saved after measurement, with a test interval of 30 minutes. The liquid level status is set with an upper limit of red and a normal display of green. Data is collected through a PLC logic controller 44, a remote control program is written, and the system is connected to the oilfield PCS system, establishing a connection channel for PCS storage and enabling PCS storage and real-time monitoring. According to the time interval set by the PLC logic controller 44, the solenoid valve 14 is switched on and off. When the solenoid valve 14 is closed, the purge pump 17 is started. The pumped pressurized air passes through the pressure reducing purge pipe 18, filter 19, filter outlet pipe 20, detection chamber 21, and exhaust pipe 23, and enters the desulfurization tank 24. The pressurized air mixes with the gas remaining in the filter 19, filter outlet pipe 20, and detection chamber 21, and enters the desulfurization tank 24 together to react chemically with the desulfurizing agent 25 to remove hydrogen sulfide gas. The desulfurized non-toxic gas enters the exhaust pipe 26, passes through the vent valve 27 and enters the vent pipe 28, or is discharged into the atmosphere, or the vent pipe 28 is connected to the casing pipe 33 and recovered by the jet pump 31.

[0076] All components not discussed in detail in this application, as well as the connection methods of these components, are well-known technologies in this field. They can be directly applied and will not be elaborated further.

[0077] In this utility model, the term "multiple" refers to two or more unless otherwise explicitly defined. The terms "installation," "connection," "linking," and "fixing," etc., should be interpreted broadly. For example, "connection" can be a fixed connection, a detachable connection, or an integral connection; "linking" can be a direct connection or an indirect connection through an intermediate medium. Those skilled in the art can understand the specific meaning of the above terms in this utility model according to the specific circumstances.

[0078] In the description of this utility model, it should be understood that the terms "upper", "lower", "left", "right", "front", "rear", 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 utility model and simplifying the description, and do not indicate or imply that the device or unit referred to must have a specific orientation or be constructed and operated in a specific orientation. Therefore, they should not be construed as limitations on this utility model.

[0079] In the description of this specification, the terms "one embodiment," "some embodiments," "specific embodiment," etc., refer to a specific feature, structure, material, or characteristic described in connection with that embodiment or example, which is included in at least one embodiment or example of the present invention. In this specification, the illustrative expressions of the above terms do not necessarily refer to the same embodiment or example. Furthermore, the specific features, structures, materials, or characteristics described may be combined in any suitable manner in one or more embodiments or examples.

[0080] The above description is merely a preferred embodiment of this utility model and is not intended to limit the utility model. Various modifications and variations can be made to this utility model by those skilled in the art. Any modifications, equivalent substitutions, improvements, etc., made within the spirit and principles of this utility model should be included within the protection scope of this utility model.

Claims

1. A device for monitoring hydrogen sulfide production from oil wells, characterized in that, It includes a gas-liquid separation section, a gas detection section, and a clear liquid recovery section; The gas-liquid separation section includes an inlet pipe and a gas-liquid separation assembly, and the gas detection section includes a gas pretreatment assembly. The outlet of the gas-liquid separation component is connected to the gas pretreatment component, the gas pretreatment component is connected to the detection chamber, the detection chamber is connected to the hydrogen sulfide detector, and the detection chamber is connected to the gas harmlessness component. The clear liquid recovery section includes a jet pump, and the inlet of the jet pump is connected to the outlet of the gas-liquid separation component through a liquid extraction pipe. The gas-liquid inlet of the gas-liquid separation component is used to connect to the wellhead process, the air inlet of the jet pump is used to connect to the casing, and the liquid-gas outlet of the jet pump is used to connect to the oil gathering pipeline.

2. The oil well hydrogen sulfide production monitoring device according to claim 1, characterized in that, The gas-liquid separation assembly includes a primary cyclone separator, a secondary cyclone separator, and a tertiary cyclone separator; The first inlet of the primary hydrocyclone is connected to the wellhead via an inlet pipe, and a sampling valve is installed on the inlet pipe. The first liquid outlet of the primary hydrocyclone is connected to the second liquid inlet of the secondary hydrocyclone through a primary connecting pipe. The second liquid outlet of the secondary hydrocyclone is connected to the third liquid inlet of the tertiary hydrocyclone through a secondary connecting pipe; The third outlet of the three-stage hydrocyclone is connected to the clear liquid recovery section; The upper ends of the first-stage cyclone separator, the second-stage cyclone separator, and the third-stage cyclone separator are connected to gas collecting pipes, which are connected to the gas detection section.

3. The oil well hydrogen sulfide production monitoring device according to claim 2, characterized in that, The gas pretreatment assembly includes a solenoid valve, a solenoid valve outlet pipe, a pressure reducing valve, a pressure reducing purge pipe, a filter, and a filter outlet pipe connected in sequence. The end of the solenoid valve away from the solenoid valve outlet pipe is connected to the gas collecting pipe, the end of the filter outlet pipe away from the filter is connected to the filter, and the pressure reducing purge pipe is connected to the purge pump.

4. The oil well hydrogen sulfide production monitoring device according to claim 3, characterized in that, The gas desulfurization component includes a desulfurization tank, which contains a desulfurizing agent. The detection chamber is connected to the desulfurization tank via an outlet pipe, which is inserted into the desulfurization tank into the desulfurizing agent. A venting pipe is installed at the upper end of the desulfurization tank, and a vent valve is installed on the venting pipe.

5. The oil well hydrogen sulfide production monitoring device according to claim 4, characterized in that, The inlet of the jet pump is connected to the third outlet of the three-stage cyclone separator through the pumping pipe. The inlet of the jet pump is connected to the well casing valve at the wellhead through the casing pipe. The jet outlet of the jet pump is connected to the inlet of the single-flow valve through the pumping liquid-gas pipe. The outlet of the single-flow valve is connected to the oil gathering pipeline.

6. The oil well hydrogen sulfide production monitoring device according to claim 5, characterized in that, A liquid level monitoring tube is installed next to the primary hydrocyclone separator. The upper end of the primary hydrocyclone separator is connected to the upper end of the liquid level monitoring tube through a pressure balance tube, and the lower end of the primary hydrocyclone separator is connected to the lower end of the liquid level monitoring tube through a liquid level connecting tube. A magnetically coupled liquid level gauge is installed in the liquid level monitoring tube.

7. The oil well hydrogen sulfide production monitoring device according to claim 6, characterized in that, The data acquisition and control section includes a PLC logic controller; The PLC logic controller is connected to the magnetically coupled level gauge via a level acquisition line. The PLC logic controller is connected to the solenoid valve via a solenoid valve control line. The PLC logic controller is connected to the hydrogen sulfide detector via an H2S acquisition line. The PLC logic controller is connected to the purge pump via the air pump control line. The PLC logic controller is connected to the industrial control network switch via a network cable. The PLC logic controller is wirelessly connected to the remote control switch via its own wireless module.

8. The oil well hydrogen sulfide production monitoring device according to claim 5, characterized in that, The wellhead process is connected to the production valve at the wellhead of the oil well. The wellhead process is connected to the back pressure valve and the sampling valve, and the back pressure valve is connected to the oil gathering pipeline.

9. The oil well hydrogen sulfide production monitoring device according to claim 5, characterized in that, The release and retraction tube is connected to the air jacket tube.

10. The oil well hydrogen sulfide production monitoring device according to claim 2, characterized in that, The first liquid inlet is higher than the second liquid inlet, the second liquid inlet is higher than the third liquid inlet, the third liquid inlet is higher than the third liquid outlet, the first liquid outlet is at the same height as the second liquid inlet, and the second liquid outlet is at the same height as the third liquid inlet.

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