Intelligent oil well pipeline oil hydrogen sulfide detection treatment management and control system

Abstract

The invention relates to the technical field of oil field equipment, in particular to an intelligent oil well pipeline oil hydrogen sulfide detection treatment management and control system which comprises a wellhead control device, the wellhead control device is connected with a wellhead pipeline, an oil-gas separator, a hydrogen sulfide detector and an oil pipeline, and the oil-gas separator is connected with a desulfurization device. The device has the functions of fluid and scene conversion in a non-stop closed-loop manner, a small multi-stage oil-gas separation structure, a chemical combination and adsorption combined desulfurizer and multi-point automatic gas collection and detection. The system has the characteristics of small size, optimized structure, full-closed-loop scene conversion, safety and reliability, and intelligent ordered operation of each work flow.

Description

Technical Field

[0001] The present invention relates to the technical field of oilfield equipment, and specifically to an intelligent oil well pipeline oil hydrogen sulfide detection, treatment and control system. Background Art

[0002] The oil and gas well pipelines in oilfields contain toxic H2S gas. Due to the long conveying pipelines and many working conditions in the process. If there is a leak in a certain link of the pipeline or process, it will endanger personal safety and even cause harm. Hydrogen sulfide exists in the mixed medium of crude oil and natural gas in the oil well pipeline, and the pressure in the pipeline is relatively high. For the detection and treatment of hydrogen sulfide, oil and gas separation needs to be carried out first, and then the hydrogen sulfide in the gas is treated. After the detected and treated gas meets the emission standards, it is then safely discharged or processed.

[0003] At present, there is no small oil and gas separator for oil well pipelines in China, nor is there a sensor for detecting hydrogen sulfide in pressurized pipelines. Due to the relatively high pressure and fast flow rate in oil well pipelines, there are also great difficulties in the treatment of hydrogen sulfide gas. At present, the oilfield industry is unable to make the production process operate in a fully closed loop. Therefore, the existence of toxic hydrogen sulfide gas has become the main factor affecting the safe production of enterprises. Summary of the Invention

[0004] The technical problem to be solved by the present invention is to overcome the defects of the prior art and provide an intelligent oil well pipeline oil hydrogen sulfide detection, treatment and control system.

[0005] To solve the above technical problems, the present invention provides the following technical solutions: An intelligent oil well pipeline oil hydrogen sulfide detection, treatment and control system includes a wellhead control device. The wellhead control device is respectively connected to a wellhead pipeline, an oil and gas separator, a hydrogen sulfide detector and an oil pipeline. The oil and gas separator is connected to a desulfurization device; The wellhead control device includes a main body. The main body includes an inner pipe and an outer pipe. The inner pipe is sleeved inside the outer pipe. The first interface of the inner pipe penetrates to the outside of the outer pipe. The second interface of the inner pipe is arranged inside the outer pipe. The main body is connected with a first control valve. The first control valve is a three-way valve. The second interface of the inner pipe is connected to the first control valve and is connected to the first port of the first control valve. The second port of the first control valve is connected to an outer outlet pipeline. The outer outlet pipeline is connected to the inlet pipeline of the oil and gas separator. An outer inlet is arranged on the outer pipe. The outer inlet is connected to the liquid outlet of the oil and gas separator. The first control valve is used to control the fluid to flow into the inside of the outer pipe through the inner pipe, or to control the fluid to flow into the inside of the outer pipe through the outer outlet pipeline and the outer inlet; The outer pipe is respectively provided with a first connection port and a second connection port. The first interface of the inner pipe and the first connection port of the outer pipe are connected to a second unit. The second unit includes a second control valve. The second control valve is provided with at least three valve ports. The first valve port of the second control valve is connected to the first interface of the inner pipe. The second valve port of the second control valve is connected to an intermediate pipe and is connected to a conversion cavity through the intermediate pipe. The conversion cavity is connected to the first connection port of the outer pipe. The third valve port of the second control valve is connected to a main inlet. The main inlet is connected to a wellhead pipe. The conversion cavity is connected to a main outlet. The main outlet is connected to an oil transportation pipe.

[0006] The first control valve is arranged inside the outer pipe. The second connection port of the outer pipe is connected to a blind plate. The outer outlet pipe penetrates through the blind plate. The third through port of the first control valve is communicated with the inner cavity of the outer pipe. The hydrogen sulfide detector is connected to the inner cavity at the top of the outer pipe through a collection pipe.

[0007] The first connection port of the outer pipe is connected to a check valve assembly. And the first connection port of the outer pipe is connected to the conversion cavity through the check valve assembly to ensure unidirectional flow from the outer pipe to the conversion cavity. The check valve assembly includes a first check valve and a maintenance valve. A second check valve is arranged at the outer inlet.

[0008] The oil-gas separator includes a pre-stage separator and a post-stage separator. The pre-stage separator includes a separation chamber b. A separation chamber a is arranged inside the separation chamber b. The top of the separation chamber a is connected to an inlet pipe. The inlet pipe passes through the separation chamber b and extends to the outside. The inlet pipe is connected to the outer outlet pipe of the wellhead control device. A spiral channel is arranged inside the separation chamber a. A gas channel a is fixedly connected inside the separation chamber a. The bottom opening of the gas channel a is arranged close to the bottom of the separation chamber a. The top of the gas channel a sequentially penetrates out of the separation chamber a and the separation chamber b and is communicated with the upper end of the post-stage separator. The bottom opening of the separation chamber a allows the fluid to flow into the separation chamber b. The bottom of the separation chamber b is communicated with the bottom of the post-stage separator through a fluid pipe. A fixed disk is installed at the bottom opening of the separation chamber a. A fluid channel is opened in the middle of the fixed disk. A protruding ring is arranged at the upper edge of the fluid channel. The protruding ring protrudes from the top surface of the fixed disk. A plurality of anti-rotation baffles distributed in an annular array are arranged on the fixed disk. The anti-rotation baffles are arranged close to the outer edge of the fixed disk.

[0009] The post-stage separator includes a separation chamber c. A plurality of stages of flow-blocking rings are horizontally arranged on the inner wall of the separation chamber c. A plurality of stages of reflection plates are arranged in the middle of the separation chamber c. The reflection plates are fixedly connected to each other by connecting rods. The reflection plates are frustum structures with a narrower upper part and a wider lower part. Through holes are formed in the middle of the reflection plates. The reflection plates and the flow-blocking rings are arranged in a vertical dislocation manner. The bottom of the separation chamber c is a liquid outlet, and the liquid outlet is connected to the outer inlet of the wellhead control device; The fluid pipeline extends from the bottom of the separation chamber c into the interior of the separation chamber c and the outlet faces upward. The outlet of the fluid pipeline is set as a necking pipe, and an umbrella-shaped nozzle is arranged at the outlet.

[0010] The topmost reflection plate is connected with a flow-blocking plate through a connecting rod. A flow-blocking valve is connected to the top of the flow-blocking plate. The flow-blocking valve is fixedly arranged at the top of the separation chamber c. The flow-blocking valve is connected to the gas passage c. The gas passage c is arranged outside the top of the separation chamber c. The gas passage c is connected to the desulfurization device.

[0011] A cross-shaped plate is fixedly arranged in the fluid passage. The bottom of the cross-shaped plate is connected with an overflow plate through an intermediate rod. The overflow plate is a plate structure with a concave middle and a convex edge; An overflow port is formed at the bottom of the separation chamber b. The overflow port is correspondingly arranged below the overflow plate. The overflow port is communicated with the fluid pipeline; A gas passage b is arranged in the process that the gas passage a penetrates out of the separation chamber b. The gas passage b is communicated with the separation chamber b; A demisting net is arranged at the connection part of the gas passage a and the separation chamber c; A gas collection port is arranged at the bottom end of the gas passage a. The gas collection port is umbrella-shaped; The spiral passage is arranged outside the gas passage a; A flow-blocking net is arranged inside the gas passage a.

[0012] The desulfurization device includes at least two stages of chemical desulfurizers. Each chemical desulfurizer includes at least one stage of reaction tank. A speed-up pipe is connected to the top of the reaction tank. One end of the speed-up pipe is arranged outside the reaction tank. The other end of the speed-up pipe has an opening facing downward and the opening is connected to a nozzle. A third check valve is connected to the speed-up pipe. The reaction tank is respectively connected with an inlet pipe and a drain pipe. An inlet valve is arranged on the inlet pipe. A drain valve is arranged on the drain pipe. The inlet pipe feeds desulfurizing agent into the reaction tank. The reaction tank is connected with an outlet gas pipeline. The reaction tank is connected to the speed-up pipe of the next-stage reaction tank through the outlet gas pipeline; A collection chamber is connected to the outlet gas pipeline of the last-stage reaction tank of the chemical desulfurizer. The collection chamber is connected to a hydrogen sulfide detector through a pipeline. A collection valve is arranged on this pipeline.

[0013] The outlet gas pipeline of the last-stage reaction tank of the chemical desulfurizer is also connected with an adsorber. An exhaust valve is arranged on this outlet gas pipeline; The output end of the adsorber is connected to the conversion cavity of the wellhead control device through a pipeline.

[0014] A gas collector is arranged between the hydrogen sulfide detector and the collection chamber, and the gas collector is connected to multiple collection chambers through multiple pipelines respectively.

[0015] The beneficial effects achieved by the present invention are as follows: The present invention is applied to the pipeline of the oil well wellhead in the oilfield, and is an intelligent multi-functional integrated instrument and equipment for remotely and online automatically detecting and treating sulfide gas. The present invention is respectively composed of an integrated scenario closed-loop control device, a composite oil-gas separator, a combined multi-item hydrogen sulfide desulfurizer, and a hydrogen sulfide automatic detector, which together constitute a management and control system for detecting and treating sulfide gas.

[0016] The present invention has the functions of continuously producing and closing the loop to perform fluid and scenario conversion, a small multi-stage oil-gas separation structure, a combined chemical and adsorption desulfurizer, and multi-point automatic gas collection and detection. It has the characteristics of small volume, optimized structure, full closed-loop scenario conversion, safety and reliability, and intelligent and orderly operation of various work processes. BRIEF DESCRIPTION OF THE DRAWINGS

[0017] The drawings are used to provide a further understanding of the present invention, and constitute a part of the specification. Together with the embodiments of the present invention, they are used to explain the present invention, and do not constitute a limitation to the present invention. In the drawings: Figure 1 is a schematic structural diagram of the present invention; Figure 2 is a schematic structural diagram of the wellhead control device of the present invention (internal and external circulation mode); Figure 3 is a schematic structural diagram of the wellhead control device of the present invention (internal circulation mode); Figure 4 is a schematic structural diagram of the oil-gas separator of the present invention; Figure 5 is a schematic structural diagram of the fixed disc of the oil-gas separator of the present invention (top view perspective); Figure 6 is a schematic structural diagram of the fixed disc of the oil-gas separator of the present invention (three-dimensional perspective); Figure 7 is a schematic structural diagram of the reflection disc and the flow blocking disc of the oil-gas separator of the present invention; Figure 8 is a schematic diagram of the oil-gas separation state when the oil-gas separator of the present invention is applied to the pipeline of the oil well wellhead; Figure 9 is a schematic structural diagram of the desulfurization device of the present invention; Figure 10 is a schematic structural diagram of the hydrogen sulfide detector of the present invention.

[0018] In the figure: 11. Outer pipe; 12. First control valve; 13. Inner pipe; 14. Main inlet; 15. Second control valve; 16. Outer outlet pipe; 17. Outer inlet; 18. Check valve assembly; 19. Intermediate pipe; 110. Conversion cavity; 111. Main outlet; 112. Second check valve; 113. Blind plate; 21. Inlet pipe; 22. Gas passage a; 23. Separation chamber b; 24. Choke net; 25. Separation chamber a; 26. Anti-rotation baffle; 27. Overflow tray; 28. Overflow port; 29. Spiral passage; 210. Gas passage b; 211. Demisting net; 212. Choke valve; 213. Gas passage c; 214. Choke disc; 215. Connecting rod; 216. Separation chamber c; 217. Reflecting disc; 218. Choke ring; 219. Umbrella-shaped nozzle; 220. Liquid outlet; 221. Fluid pipe; 222. Protruding ring; 223. Fixed disc; 224. Cross-shaped plate; 225. Fluid passage; 226. Through hole; 31. Speed-up pipe; 32. Reaction tank; 33. Third check valve; 34. Inflow pipe; 35. Drain pipe; 36. Outlet gas pipe; 37. Collection chamber; 38. Collection valve; 39. Exhaust valve; 310. Adsorber; 41. Solenoid valve a; 42. First pipe; 43. Check valve a; 44. Flow-limiting valve; 45. Gas mixing chamber; 46. Solenoid valve c; 47. Third pipe; 48. Solenoid valve b; 49. Gas pressure reduction chamber; 410. Circulation pipe; 411. Solenoid valve d; 412. H2S sensor; 413. Air pump; 414. Check valve d; 415. Pressure sensor b; 416. Pressure sensor a; 417. Check valve b; 418. Fourth pipe; 419. Second pipe; 420. Fifth pipe; 421. Check valve c; 422. Piston chamber; 423. Push-pull electromagnet; 5. Gas collector; 6. Oil pipeline; 7. Wellhead pipeline; 8. Collection pipeline. Specific embodiments

[0019] The preferred embodiments of the present invention will be described below with reference to the accompanying drawings. It should be understood that the preferred embodiments described herein are only used to illustrate and explain the present invention, and are not used to limit the present invention.

[0020] Embodiment: As Figures 1 - 10 shown, an intelligent oil well pipeline oil hydrogen sulfide detection, treatment and control system includes a wellhead control device, the wellhead control device is respectively connected to the wellhead pipeline 7, the oil-gas separator, the hydrogen sulfide detector and the oil pipeline 6, and the oil-gas separator is connected to the desulfurization device.

[0021] As Figures 1 - 3As shown in the figure, the wellhead control device includes a main body, which includes an inner pipe 13 and an outer pipe 11. The inner pipe 13 is sleeved inside the outer pipe 11. The first interface of the inner pipe 13 penetrates to the outside of the outer pipe 11, and the second interface of the inner pipe 13 is arranged inside the outer pipe 11 (in the attached drawing, the first interface is located at the lower position of the inner pipe 13, and the second interface is located at the top position of the inner pipe 13). Regarding the structures and connection relationships of the above-mentioned inner pipe 13 and outer pipe 11, the applicant has disclosed an integrated fluid control device for multi-scenario applications and obtained an invention patent authorization. The authorization announcement number is CN117948075B. The structures of the inner pipe 13 and outer pipe 11 in this application are similar to the inner and outer pipe structures in this patent. The inner pipe 13 and the outer pipe 11 are concentrically arranged. The second interface of the inner pipe 13 is located inside the outer pipe 11 and lower than the second connection port of the outer pipe 11. The volume of the outer pipe 11 is twice or more than twice the volume of the inner pipe 13.

[0022] The main body is connected with a first control valve 12. The first control valve 12 is a three-way valve. The second interface of the inner pipe 13 is connected with the first control valve 12 and is connected with the first port of the first control valve 12. The second port of the first control valve 12 is connected with an outer outlet pipeline 16. The outer outlet pipeline 16 is connected with the inlet pipeline 21 of the oil-gas separator. An outer inlet 17 is arranged on the outer pipe 11. The outer inlet 17 is connected with the liquid outlet 220 of the oil-gas separator. The first control valve 12 is used to control the fluid to directly flow into the inside of the outer pipe 11 through the inner pipe 13, or control the fluid to flow into the inside of the outer pipe 11 through the outer outlet pipeline 16 and the outer inlet 17, so as to provide multiple flow directions for the fluid to meet the requirements of multi-scenario applications at the oilfield wellhead.

[0023] The outer pipe 11 is respectively provided with a first connection port and a second connection port (in the attached drawing, the first connection port is located at the lower position of the outer pipe 11, and the second connection port is located at the top position of the outer pipe 11). The first interface of the inner pipe 13 and the first connection port of the outer pipe 11 are connected with a second unit. The second unit includes a second control valve 15. The second control valve 15 is provided with at least three valve ports. The first valve port of the second control valve 15 is connected with the first interface of the inner pipe 13. The second valve port of the second control valve 15 is connected with an intermediate pipeline 19 and is connected with a conversion cavity 110 through the intermediate pipeline 19. The conversion cavity 110 is connected with the first connection port of the outer pipe 11. The above-mentioned second unit provides more flow directions for the fluid.

[0024] The third valve port of the second control valve 15 is connected with a main inlet 14. The main inlet 14 is connected with a wellhead pipeline 7. The conversion cavity 110 is connected with a main outlet 111. The main outlet 111 is connected with an oil transmission pipeline 6.

[0025] The first control valve 12 is arranged inside the outer pipe 11. The second connection port of the outer pipe 11 is connected to the blind plate 113. The outer outlet pipe 16 penetrates through the blind plate 113. The third port of the first control valve 12 is communicated with the inner cavity of the outer pipe 11. The hydrogen sulfide detector is connected to the inner cavity at the top of the outer pipe 11 through the collection pipe 8.

[0026] The first connection port of the outer pipe 11 is connected to the check valve assembly 18. And the first connection port of the outer pipe 11 is connected to the conversion cavity 110 through the check valve assembly 18, ensuring one-way flow from the outer pipe 11 to the conversion cavity 110 and preventing the fluid from flowing back reversely to the oil well wellhead.

[0027] The check valve assembly 18 includes a first check valve and a maintenance valve.

[0028] A second check valve 112 is arranged at the outer inlet 17.

[0029] In the above structure, both the first control valve 12 and the second control valve 15 are selected as three-way valves. Both the first control valve 12 and the second control valve 15 are of T type.

[0030] As Figure 1 、 Figures 4 - 8 shown, the oil and gas separator includes a pre-stage separator and a post-stage separator. The pre-stage separator includes a separation chamber b23. A separation chamber a25 is arranged inside the separation chamber b23. The top of the separation chamber a25 is connected to the inlet pipe 21. The inlet pipe 21 passes through the separation chamber b23 and extends to the outside. The inlet pipe 21 is connected to the outer outlet pipe 16 of the wellhead control device. A spiral channel 29 is arranged inside the separation chamber a25. A gas channel a22 is fixedly connected inside the separation chamber a25. The bottom opening of the gas channel a22 is arranged near the bottom of the separation chamber a25. The top of the gas channel a22 sequentially penetrates out of the separation chamber a25 and the separation chamber b23 and is communicated with the upper end of the post-stage separator. The bottom opening of the separation chamber a25 allows the fluid to flow into the separation chamber b23. The bottom of the separation chamber b23 is communicated with the bottom of the post-stage separator through the fluid pipe 221.

[0031] The mixed gas enters the separation chamber a25 of the pre-stage separator through the inlet pipe 21. Due to the structural characteristics of the spiral channel 29 inside the separation chamber a25, when the pressurized oil and gas pass through quickly, a centrifugal force is generated. Due to the different densities, the oil and gas are separated under the action of the centrifugal force. After the oil and gas enter the separation chamber a25, due to the increased space, the separated gas enters the gas channel a22 and is sent to the post-stage separator. The crude oil flows out through the bottoms of the separation chamber a25 and the separation chamber b23 to the fluid pipe 221 and then enters the post-stage separator.

[0032] A fixed disk 223 is installed at the bottom opening of the separation chamber a25. A fluid passage 225 is provided in the middle of the fixed disk 223. A protruding ring 222 is provided at the upper edge of the fluid passage 225. The protruding ring 222 protrudes from the top surface of the fixed disk 223. A number of anti-rotation baffles 26 are arranged on the fixed disk 223 in an annular array, and the anti-rotation baffles 26 are arranged close to the outer edge of the fixed disk 223.

[0033] The post-stage separator includes a separation chamber c216. A multi-stage flow blocking ring 218 is horizontally arranged on the inner wall of the separation chamber c216. A multi-stage reflection disk 217 is arranged in the middle of the separation chamber c216. The two reflection disks 217 are fixedly connected by a connecting rod 215. The reflection disk 217 is a frustum structure with a narrow upper part and a wide lower part. A through hole 226 is provided in the middle of the reflection disk 217. The reflection disk 217 and the flow blocking ring 218 are arranged in a vertical offset. The bottom of the separation chamber c216 is a liquid outlet 220, and the liquid outlet 220 is connected to the outer inlet 17 of the wellhead control device through a pipeline. The fluid pipeline 221 extends from the bottom of the separation chamber c216 into the interior of the separation chamber c216 and the outlet faces upward. The outlet of the fluid pipeline 221 is provided as a necking pipe, and an umbrella-shaped nozzle 219 is provided at the outlet.

[0034] The crude oil separated by the pre-stage separator enters the post-stage separator through the fluid pipeline 221 and is quickly ejected by the umbrella-shaped nozzle 219 through the necking pipe. The function of the necking pipe structure is to reduce the diameter of the fluid passage 225 to increase the flow rate. The function of the umbrella-shaped nozzle 219 structure is to eject the fluid outward through the small holes distributed on the nozzle (similar to the principle of a shower head). The purpose of using the umbrella-shaped nozzle 219 to eject is to evenly eject the fluid onto the multi-layer reflection disks 217, and the remaining gas in the crude oil is released through the blocking and reflection of the reflection disks 217.

[0035] In addition, the crude oil separated by the pre-stage separator enters the post-stage separator through the fluid pipeline 221. The post-stage separator uses the volume difference to separate oil and gas. When the reflection disk 217 reflects the crude oil, due to the inner diameter and capacity of the top of the separation chamber c216 being much larger than the crude oil flow rate per unit time entering, the increase in space causes the chamber pressure to drop, and the remaining gas in the crude oil will be completely separated. The separated gas rises and enters the gas passage c213 through the flow blocking valve 212, and the crude oil flows out through the liquid outlet 220 through the overflow pipe at the bottom of the separation chamber c216 under the action of gravity.

[0036] The topmost reflection disc 217 is connected to a flow blocking disc 214 through a connecting rod 215. The top of the flow blocking disc 214 is connected to a flow blocking valve 212. The flow blocking valve 212 is fixedly arranged at the top of the separation chamber c216. The flow blocking valve 212 is connected to a gas channel c213. The gas channel c213 is arranged outside the top of the separation chamber c216. The gas channel c213 is connected to a desulfurization device. A floating valve core is arranged inside the flow blocking valve 212. If the crude oil outlet pipeline is blocked and the crude oil in the separation chamber c216 rises, when it rises to a certain height, the floating valve core of the flow blocking valve 212 will be floated by the crude oil and the valve orifice will be closed.

[0037] A cross-shaped plate 224 is fixedly arranged inside the fluid channel 225. The bottom of the cross-shaped plate 224 is connected to an overflow disc 27 through an intermediate rod. The overflow disc 27 is a disc structure with a concave middle and a convex edge. An overflow port 28 is opened at the bottom of the separation chamber b23. The overflow port 28 is correspondingly arranged below the overflow disc 27. The overflow port 28 is communicated with a fluid pipeline 221. A gas channel b210 is arranged in the process that the gas channel a22 penetrates out of the separation chamber b23. The gas channel b210 is communicated with the separation chamber b23. A demisting net 211 is arranged at the connection of the gas channel a22 and the separation chamber c216. A gas collection port is arranged at the bottom end of the gas channel a22. The gas collection port is in an umbrella shape. The spiral channel 29 is arranged outside the gas channel a22. A flow blocking net 24 is arranged inside the gas channel a22.

[0038] As Figure 8 shown, the working principle for oil-gas separation is as follows: Crude oil and gas under pressure enter from the inlet pipeline 21 of the pre-stage separator. When quickly passing through the spiral channel 29, a centrifugal force will be generated. Due to different specific gravities, oil and gas are separated under the action of the centrifugal force. The separated oil and gas enter the separation chamber a25 from the outlet of the spiral channel 29. The gas enters the gas channel a22 from the gas collection port inside the separation chamber a25. The crude oil that quickly rotates and enters the separation chamber a25 is blocked by the anti-rotation baffle 26 and impacts, and the remaining part of the gas in the crude oil is released again. The released gas enters the gas channel a22 from the gas collection port, and the crude oil flows out through the fluid channel 225. Since the space of the separation chamber b23 is relatively large, after the crude oil flowing out of the fluid channel 225 overflows through the overflow disc 27, the remaining gas is released again and enters the gas channel b210, and the crude oil enters the fluid pipeline 221 through the overflow port 28.

[0039] The crude oil separated by the pre-stage separator enters the post-stage separator through the fluid pipeline 221. When passing through the reduced-diameter pipe, the flow rate of the crude oil passing through increases due to the decrease in the pipe diameter. Multiple through-holes 226 with smaller apertures are distributed on the umbrella-shaped nozzle 219 at the end of the reduced-diameter pipe. The crude oil is ejected upward rapidly through the through-holes 226 and impacts the multi-layer reflection disks 217 at the same time. Since the volume of the separation chamber c216 is relatively large, the pressure of the ejected crude oil drops due to the increased space, and the remaining gas will be released from the crude oil. In addition, if there is still gas after the ejected crude oil impacts the reflection disk 217, the gas will be released. The reflected crude oil scatters and splashes onto the chamber wall, and then slowly flows downward along the flow-blocking ring 218 and flows out through the liquid outlet 220 under the action of gravity. The gas continuously released from the crude oil gradually passes upward through the outlet of the flow-blocking valve 212 and enters the gas passage c213 and flows out through the gas outlet.

[0040] As Figure 1 、 Figure 9 shown, the desulfurization device includes at least two-stage chemical desulfurizers. The chemical desulfurizer includes at least one-stage reaction tank 32. A speed-up pipe 31 is connected to the top of the reaction tank 32. One end of the speed-up pipe 31 is arranged outside the reaction tank 32. The opening at the other end of the speed-up pipe 31 faces downward and is connected to a spray nozzle. A third check valve 33 is connected to the speed-up pipe 31. The reaction tank 32 is respectively connected with an inlet pipe 34 and a drain pipe 35. An inlet valve is arranged on the inlet pipe 34, and a drain valve is arranged on the drain pipe 35. The reaction tank 32 is connected with an air outlet pipeline 36. The reaction tank 32 is connected to the speed-up pipe 31 of the next-stage reaction tank 32 through the air outlet pipeline 36.

[0041] A collection chamber 37 is connected to the air outlet pipeline 36 of the last-stage reaction tank 32 of the chemical desulfurizer. The collection chamber 37 is connected to a hydrogen sulfide detector through a pipeline, and a collection valve 38 is arranged on this pipeline. The structures and functions of each collection chamber 37 and collection valve 38 are the same, and their functions are to transport the collected gas to the gas collector 5 of the hydrogen sulfide detector.

[0042] The speed-up pipe 31 is a reduced-neck pipe, and the pipe diameter gradually decreases from top to bottom, increasing the gas flow rate. The accelerated gas is ejected from the spray nozzle through the third check valve 33. The shape of the spray nozzle is umbrella-shaped and is composed of an orifice plate with smaller air holes, which is similar to the structure of a shower head.

[0043] The reaction tank 32 is filled with desulfurizing agent. The dispersed gas ejected from the small air holes of the spray nozzle of the speed-up pipe 31 enters the desulfurizing agent liquid for a neutralization reaction. Due to the different specific gravities of the gas and the liquid medium, while undergoing a chemical reaction, the gas separates from the liquid medium and rises to the upper part of the reaction tank 32. When the air pressure in the pipe gradually increases, the gas passes through the air outlet pipeline 36 at the top of the reaction tank 32 and enters the speed-up pipe 31 of the next reaction tank 32 for the next chemical reaction, and so on.

[0044] The inlet pipe 34 feeds desulfurizer into the reaction tank 32. The saturation of the desulfurizer is periodically detected through the drain valve on the drain pipe 35, and the desulfurizer that has reached the reaction saturation is discharged through this valve.

[0045] The gas outlet pipe 36 of the last-stage reaction tank 32 of the chemical desulfurizer is also connected to the adsorber 310. An exhaust valve 39 is provided on the gas outlet pipe 36. Each exhaust valve 39 has the same function, which is to control the discharge of gas to the adsorber 310. When the hydrogen sulfide detector detects that the hydrogen sulfide content is lower than the set value, the desulfurized gas flows from the exhaust valve 39 to the adsorber 310 for treatment and then is discharged subsequently. If the hydrogen sulfide content does not reach the set value, it flows into the next-stage chemical desulfurizer for desulfurization treatment again. The adsorber 310 is a physical adsorption structure for adsorbing impurities.

[0046] The output end of the adsorber 310 is connected to the conversion cavity 110 of the wellhead control device through a pipeline, so that the gas is finally transported out together with the crude oil. A booster pump is provided at the output end of the adsorber 310.

[0047] A gas sampler 5 is provided between the hydrogen sulfide detector and the sampling chamber 37. The gas sampler 5 is connected to a plurality of sampling chambers 37 through a plurality of pipelines respectively.

[0048] The hydrogen sulfide detector can be a conventional hydrogen sulfide sensor structure.

[0049] A more preferable choice for the hydrogen sulfide detector is as Figure 1 、 Figure 10 shown. The hydrogen sulfide detector includes a gas mixing chamber 45. The gas mixing chamber 45 is respectively connected to a first pipeline 42, a second pipeline 419 and a third pipeline 47. Control components are respectively provided on the first pipeline 42, the second pipeline 419 and the third pipeline 47. The gas mixing chamber 45 is connected to the gas sampler 5 through the first pipeline 42. The gas mixing chamber 45 is connected to an oxygen-containing gas through the second pipeline 419. The gas mixing chamber 45 is connected to a gas pressure reduction chamber 49 through the third pipeline 47. The gas mixing chamber 45 is also connected to a vacuum pumping component. The gas pressure reduction chamber 49 is connected to a circulation pipeline 410. An air pump 413 and an H2S sensor 412 are provided on the circulation pipeline 410. Pressure detection components are provided in both the gas mixing chamber 45 and the gas pressure reduction chamber 49. The pressure detection components detect the air pressure in the gas mixing chamber 45 and the gas pressure reduction chamber 49.

[0050] Since the pipeline gas is extracted from the oil well and contains no oxygen, and in the prior art, the vast majority of electrochemical sensors require oxygen to participate in the reaction, and the H2S sensor 412 also requires oxygen to participate in the detection. Therefore, when detecting hydrogen sulfide, more than 3% of oxygen needs to be incorporated. In the above structure, the gas mixing chamber 45 mixes the pipeline gas introduced into it with the oxygen-containing gas (preferably air) to meet the detection conditions of the H2S sensor 412; The control component on the third pipeline 47 controls the mixed gas entering the gas decompression chamber 49. When the inside of the gas decompression chamber 49 reaches normal pressure, the control component on the third pipeline 47 closes, so that the gas in the gas decompression chamber 49 meets the detection conditions of the H2S sensor 412; In addition, the vacuum pumping component can evacuate and reduce the negative pressure of the gas mixing chamber 45 and the gas decompression chamber 49. The purpose of vacuum pumping is to evacuate and clean the residual gas in the gas mixing chamber 45 and the gas decompression chamber 49 to ensure accurate real-time gas detection data; there are two purposes for reducing the negative pressure: one is to reduce the negative pressure of the gas mixing chamber 45: the pipeline gas contains no oxygen, and the H2S sensor 412 cannot detect normally. The oxygen content in the air is about 21%. It can be solved by injecting external air into the gas mixing chamber 45. Since the external air is at normal pressure, it is necessary to reduce the gas mixing chamber 45 to negative pressure in advance to allow air to enter; the other is to reduce the negative pressure of the gas decompression chamber 49: the H2S sensor 412 is not pressure-resistant and needs to work in an environment of normal pressure. After the gas decompression chamber 49 is reduced to negative pressure, the pressure of the detected gas sent by the gas mixing chamber 45 will drop after entering, and the air pressure will gradually rise to normal pressure as the gas continuously enters, which is convenient for detection.

[0051] The vacuum pumping component includes a fourth pipeline 418. One end of the fourth pipeline 418 is connected to the gas mixing chamber 45, and the other end is connected to the pumping component. A check valve b417 is connected to the fourth pipeline 418. The output end of the pumping component is connected to a fifth pipeline 420. The vacuum pumping component can evacuate and reduce the negative pressure of the gas mixing chamber 45 and the gas decompression chamber 49.

[0052] A check valve c421 is connected to the fifth pipeline 420, and the output end of the fifth pipeline 420 is connected to the gas passage c213 of the oil-gas separator. The above structure can send the extracted gas back to avoid polluting the external air.

[0053] The pumping component includes a piston chamber 422. A piston is slidably arranged in the piston chamber 422, and the piston is connected to a push-pull power mechanism.

[0054] The push-pull power mechanism includes a push-pull electromagnet 423, which is arranged outside the piston chamber 422. The push rod of the push-pull electromagnet 423 penetrates through the piston chamber 422 and is fixedly connected to the piston. The push-pull electromagnet 423 selects the commonly used push-pull electromagnet structure in the prior art. It adjusts the magnetic strength by using different electromagnetic coils and power supplies, and becomes a reciprocating push-pull motion to realize the linear reciprocating motion of the push rod. The above structure is small in size and convenient for installation and use.

[0055] The push-pull power mechanism can also adopt other reciprocating linear power structures such as an electric cylinder.

[0056] The control component on the first pipeline 42 is a solenoid valve a41, and a check valve a43 is also arranged on the first pipeline 42. The solenoid valve a41 controls the pipeline gas entering the gas mixing chamber 45, and the check valve a43 controls the one-way flow of gas and prevents backflow under special circumstances.

[0057] A flow limiting valve 44 is arranged on the first pipeline 42. The flow limiting valve 44 not only controls the size of the gas flow, but also can be preset to prevent the gas flow from being too large, so as to avoid the gas pressure entering the mixing chamber exceeding the specified value.

[0058] The control component on the second pipeline 419 is a solenoid valve b48, and the solenoid valve b48 controls the external air entering the gas mixing chamber 45.

[0059] The control component on the third pipeline 47 is a solenoid valve c46, and the solenoid valve c46 controls the mixed gas entering the gas decompression chamber 49.

[0060] A check valve d414 and a solenoid valve d411 are arranged on the circulation pipeline 410. The solenoid valve d411 and the check valve d414 prevent the H2S sensor 412 from being underpressure or overpressure during the processes of waste gas cleaning, negative pressure reduction, and gas entering the gas decompression chamber 49.

[0061] The pressure detection component on the gas mixing chamber 45 is a pressure sensor a416, and the pressure detection component on the gas decompression chamber 49 is a pressure sensor b415.

[0062] To ensure accurate detection data and real-time gas, and at the same time make the functions of each structural unit work properly, before the collection and detection of hydrogen sulfide gas, it is necessary to empty the residual waste gas in the gas mixing chamber 45 and the gas decompression chamber 49. Therefore, this work process is divided into two parts: (1) Exhaust gas cleaning and negative pressure reduction: According to the settings of the intelligent control program, the control circuit first opens the solenoid valve c46, and repeatedly energizes and de-energizes the push-pull electromagnet 423. The piston reciprocates under the drive of the push-pull electromagnet 423, that is, inhales and exhales. When the piston inhales, the one-way valve c421 closes and the one-way valve b417 opens. The gas in the gas decompression chamber 49 and the gas mixing chamber 45 is inhaled into the piston chamber 422 by the piston through the one-way valve b417. When the piston exhales, the one-way valve b417 closes and the one-way valve c421 opens. The gas in the piston chamber 422 is pushed into the oil-gas separator through the one-way valve c421. The piston makes repeated movements under the drive of the push-pull electromagnet 423. When the values of the pressure sensors a416 and b415 in the gas decompression chamber 49 and the gas mixing chamber 45 drop to the specified negative pressure, the push-pull electromagnet 423 stops working, and at the same time the solenoid valve c46 closes; (2) Gas collection, mixing and detection: To make the pipeline gas contain oxygen for the H2S sensor 412 to detect, air needs to be mixed in. Since the pipeline gas pressure is greater than that of air, external air needs to be introduced into the gas mixing chamber 45 in advance. Therefore, the control circuit first opens the solenoid valve b48, and the external air enters the gas mixing chamber 45 in a negative pressure state through the solenoid valve b48. When the value of the pressure sensor a416 rises to atmospheric pressure, the control circuit closes the solenoid valve b48. Then, the solenoid valve a41 is opened, and the pressurized pipeline gas enters the gas mixing chamber 45 through the solenoid valve a41, the check valve a43 and the flow limiting valve 44. The flow rate of the flow limiting valve 44 has been preset according to the air pressure of the gas pipeline pressure gauge, so the airflow entering the gas mixing chamber 45 is small. Since the diameter and volume of the gas mixing chamber 45 are large, the pressure of the entering gas gradually rises. When the air pressure in the gas mixing chamber 45 reaches the specified value, the solenoid valve a41 is closed. At this time, the air in the gas mixing chamber 45 is also mixed with the pipeline gas. At the same time, the control circuit opens the solenoid valve c46, and the gas in the gas mixing chamber 45 enters the gas decompression chamber 49 through the solenoid valve c46. The structural principle of the gas decompression chamber 49 is the same as that of the gas mixing chamber 45 and is also in a negative pressure state. The air pressure also gradually rises after the gas enters. When it reaches atmospheric pressure, the solenoid valve c46 is closed. At this time, the control circuit opens the solenoid valve d411, and at the same time, the air pump 413 and the H2S sensor 412 are turned on. The air pump 413 pumps out the gas in the gas decompression chamber 49 through the check valve d414 and transports it to the H2S sensor 412. The H2S sensor 412 continuously detects hydrogen sulfide while the gas is circulating, and uploads the data through the remote transmission circuit; after the detection process is completed, the control circuit turns off the air pump 413, the H2S sensor 412 and the solenoid valve d411 in sequence, and at the same time opens the solenoid valve c46, and the push-pull electromagnet 423 is energized and de-energized multiple times. The piston inhales or exhales under the drive of the push-pull electromagnet 423 to inject the waste gas in the gas mixing chamber 45 and the gas decompression chamber 49 back; when the pressure sensors a416 and b415 of the two chambers respectively drop to the specified pressure values, the control circuit turns off the push-pull electromagnet 423 and the solenoid valve c46 in sequence, and thus the hydrogen sulfide gas detection work is completed.

[0063] The detection process conducts two similar waste gas cleanings before and after hydrogen sulfide detection respectively, aiming to ensure the normal operation of the structural unit and the accuracy of hydrogen sulfide detection without residual gas.

[0064] To sum up, the working principle and process of the present invention are as follows: When there is no hydrogen sulfide in the wellhead pipeline 7, the wellhead control device is in the internal circulation mode ( Figure 3As shown). In the internal circulation mode, the oil and gas enter the inner pipe 13 through the second control valve 15 from the main inlet 14, and enter the outer pipe 11 through the inner outlet of the first control valve 12 and flow out from the main outlet 111 at the lower part. Since the inner diameter and volume of the outer pipe 11 are much larger than those of the inner pipe 13, the increased space allows some gas to separate from the crude oil and rise to the upper part of the outer pipe 11. A collection pipeline 8 and a gas valve (in a normally open state) are installed at the upper part of the outer pipe 11, and the collection pipeline 8 is connected to an input port of the gas collector 5 of the hydrogen sulfide detector. When the wellhead control device is in the internal circulation mode, the gas at the upper part of the outer pipe 11 of the device is in a state of being detected.

[0065] When it is detected that the hydrogen sulfide content in the gas in the outer pipe 11 exceeds the specified value, the control circuit remotely switches the wellhead control device from the internal circulation mode to the internal and external circulation mode ( Figure 2 As shown), and at the same time, the hydrogen sulfide detector also switches the gas collector 5 to the state of detecting the desulfurization device.

[0066] After the wellhead control device is switched from the internal circulation mode to the internal and external circulation mode, the oil and gas entering the outer pipe 11 through the inner outlet of the first control valve 12 will be converted into a closed loop and flow out through the outer outlet pipeline 16, and enter the inlet pipeline 21 of the oil and gas separator connected to the outer outlet pipeline 16. After the oil and gas enter the oil and gas separator, they are separated. The crude oil flows out from the liquid outlet 220 of the separator and is reinjected into the outer pipe 11 through the outer inlet 17 of the wellhead control device. The separated gas containing hydrogen sulfide flows out through the gas channel c213 of the oil and gas separator and enters the desulfurization device. The hydrogen sulfide gas first enters from the inlet of the first group of chemical desulfurizers, undergoes desulfurization through the multi-stage reaction tank 32, and then passes through the collection chamber 37 of the first group. Since the multi-point gas collector 5 has been switched to the state of detecting the collection valve 38 (which has been opened), the gas passes through the collection chamber 37 and the collection valve 38, and then the gas is transported to the hydrogen sulfide detector through the gas collector 5. After being detected by this detector, if the hydrogen sulfide content has dropped to a safe value, the control circuit will open the exhaust valve 39 corresponding to this group of chemical desulfurizers. The adsorber 310 desulfurizes and processes the gas again, and after being pressurized by the booster pump, it is discharged through the gas outlet.

[0067] The safe gas discharged through the gas outlet after being pressurized by the booster pump is reinjected into the wellhead control device through the check valve, and is secondarily combined with the crude oil and enters the oil pipeline 6 through the main outlet 111. The function of the check valve is to prevent the crude oil from entering the gas pipeline.

[0068] If the detected hydrogen sulfide content has not dropped to a safe value, the gas will be sent to the next group or multiple groups of chemical desulfurizers for secondary desulfurization or multiple desulfurizations.

Claims

1. An intelligent oil well pipeline hydrogen sulfide detection, treatment and control system, characterized in that, It includes a wellhead control device, which is respectively connected to a wellhead pipeline (7), an oil-gas separator, a hydrogen sulfide detector and an oil pipeline (6), and the oil-gas separator is connected to a desulfurization device; The wellhead control device includes a main body, which includes an inner pipe (13) and an outer pipe (11). The inner pipe (13) is sleeved inside the outer pipe (11). The first interface of the inner pipe (13) penetrates to the outside of the outer pipe (11), and the second interface of the inner pipe (13) is arranged inside the outer pipe (11). The main body is connected with a first control valve (12), and the first control valve (12) is a three-way valve. The second interface of the inner pipe (13) is connected to the first control valve (12) and is connected to the first port of the first control valve (12). The second port of the first control valve (12) is connected to an outer outlet pipeline (16), and the outer outlet pipeline (16) is connected to the inlet pipeline (21) of the oil-gas separator. An outer inlet (17) is arranged on the outer pipe (11), and the outer inlet (17) is connected to the liquid outlet (220) of the oil-gas separator. The first control valve (12) is used to control the fluid to flow into the inside of the outer pipe (11) through the inner pipe (13), or to control the fluid to flow into the inside of the outer pipe (11) through the outer outlet pipeline (16) and the outer inlet (17); The outer pipe (11) is respectively provided with a first connection port and a second connection port. The first interface of the inner pipe (13) and the first connection port of the outer pipe (11) are connected to a second unit. The second unit includes a second control valve (15). The second control valve (15) has at least three valve ports. The first valve port of the second control valve (15) is connected to the first interface of the inner pipe (13). The second valve port of the second control valve (15) is connected to an intermediate pipeline (19) and is connected to a conversion cavity (110) through the intermediate pipeline (19). The conversion cavity (110) is connected to the first connection port of the outer pipe (11); The third valve port of the second control valve (15) is connected to a main inlet (14), the main inlet (14) is connected to the wellhead pipeline (7), and the conversion cavity (110) is connected to a main outlet (111), and the main outlet (111) is connected to the oil pipeline (6).

2. The intelligent oil well pipeline hydrogen sulfide detection, treatment and control system according to claim 1, wherein The first control valve (12) is arranged inside the outer pipe (11). The second connection port of the outer pipe (11) is connected to a blind plate (113). The outer outlet pipeline (16) penetrates through the blind plate (113). The third port of the first control valve (12) is communicated with the inner cavity of the outer pipe (11); The hydrogen sulfide detector is connected to the inner cavity at the top of the outer pipe (11) through a collection pipeline (8).

3. The intelligent oil well pipeline hydrogen sulfide detection, treatment and control system according to claim 1, characterized in that, The first connection port of the outer pipe (11) is connected to a check valve assembly (18), and the first connection port of the outer pipe (11) is connected to the conversion cavity (110) through the check valve assembly (18) to ensure one-way flow from the outer pipe (11) to the conversion cavity (110); The check valve assembly (18) includes a first check valve and a maintenance valve; A second check valve (112) is arranged at the outer inlet (17).

4. The intelligent oil well pipeline hydrogen sulfide detection, treatment and control system according to claim 1, characterized in that, The oil and gas separator includes a pre-stage separator and a post-stage separator. The pre-stage separator includes a separation chamber b (23), and a separation chamber a (25) is arranged inside the separation chamber b (23). The top of the separation chamber a (25) is connected to an inlet pipe (21). The inlet pipe (21) passes through the separation chamber b (23) and extends to the outside. The inlet pipe (21) is connected to the external outlet pipe (16) of the wellhead control device. A spiral channel (29) is arranged inside the separation chamber a (25). A gas channel a (22) is fixedly connected inside the separation chamber a (25). The bottom opening of the gas channel a (22) is arranged close to the bottom of the separation chamber a (25). The top of the gas channel a (22) successively penetrates out of the separation chamber a (25) and the separation chamber b (23) and then communicates with the upper end of the post-stage separator. The bottom opening of the separation chamber a (25) allows the fluid to flow into the separation chamber b (23). The bottom of the separation chamber b (23) is communicated with the bottom of the post-stage separator through a fluid pipe (221); A fixed disc (223) is installed at the bottom opening of the separation chamber a (25). A fluid channel (225) is opened in the middle of the fixed disc (223). A protruding ring (222) is arranged at the upper edge of the fluid channel (225). The protruding ring (222) protrudes from the top surface of the fixed disc (223). A plurality of anti-rotation baffles (26) are arranged on the fixed disc (223) in an annular array. The anti-rotation baffles (26) are arranged close to the outer edge of the fixed disc (223).

5. The intelligent oil well pipeline hydrogen sulfide detection, treatment and control system according to claim 4, characterized in that, The post-stage separator includes a separation chamber c (216). A plurality of stages of flow-blocking rings (218) are horizontally arranged on the inner wall of the separation chamber c (216). A plurality of stages of reflection discs (217) are arranged in the middle of the separation chamber c (216). The two reflection discs (217) are fixedly connected by a connecting rod (215). The reflection disc (217) is a frustum structure with a narrow upper part and a wide lower part. A through hole (226) is opened in the middle of the reflection disc (217). The reflection disc (217) and the flow-blocking ring (218) are arranged in a vertical dislocation. The bottom of the separation chamber c (216) is a liquid outlet (220). The liquid outlet (220) is connected to the external inlet (17) of the wellhead control device; The fluid pipe (221) extends from the bottom of the separation chamber c (216) into the interior of the separation chamber c (216) and the outlet faces upward. The outlet of the fluid pipe (221) is set as a necking pipe, and an umbrella-shaped nozzle (219) is arranged at the outlet.

6. The intelligent oil well pipeline hydrogen sulfide detection, treatment and control system according to claim 5, characterized in that The topmost reflection disc (217) is connected to a flow-blocking disc (214) through a connecting rod (215). The top of the flow-blocking disc (214) is connected to a flow-blocking valve (212). The flow-blocking valve (212) is fixedly arranged at the top of the separation chamber c (216). The flow-blocking valve (212) is connected to a gas channel c (213). The gas channel c (213) is arranged outside the top of the separation chamber c (216). The gas channel c (213) is connected to a desulfurization device.

7. The intelligent oil well pipeline hydrogen sulfide detection, treatment and control system according to claim 5, characterized in that A cross-shaped plate (224) is fixedly arranged in the fluid channel (225). The bottom of the cross-shaped plate (224) is connected with an overflow tray (27) through an intermediate rod. The overflow tray (27) is a tray structure with a concave middle and a convex edge. An overflow port (28) is opened at the bottom of the separation chamber b (23). The overflow port (28) is correspondingly arranged below the overflow tray (27), and the overflow port (28) is communicated with the fluid pipeline (221). A gas channel b (210) is arranged in the process that the gas channel a (22) penetrates out of the separation chamber b (23), and the gas channel b (210) is communicated with the separation chamber b (23). A demisting screen (211) is arranged at the connection part of the gas channel a (22) and the separation chamber c (216). A gas collection port is arranged at the bottom end of the gas channel a (22), and the gas collection port is in an umbrella shape. The spiral channel (29) is arranged outside the gas channel a (22). A flow blocking net (24) is arranged inside the gas channel a (22).

8. The intelligent oil well pipeline hydrogen sulfide detection, treatment and control system according to claim 1, characterized in that, The desulfurization device comprises at least two-stage chemical desulfurizers. Each chemical desulfurizer comprises at least one-stage reaction tank (32). A speed increasing pipe (31) is connected to the top of the reaction tank (32). One end of the speed increasing pipe (31) is arranged outside the reaction tank (32). The opening at the other end of the speed increasing pipe (31) faces downward and is connected with a spray nozzle. A third check valve (33) is connected to the speed increasing pipe (31). The reaction tank (32) is respectively connected with an influent pipe (34) and a drain pipe (35). An influent valve is arranged on the influent pipe (34), and a drain valve is arranged on the drain pipe (35). The influent pipe (34) feeds a desulfurizing agent into the reaction tank (32). The reaction tank (32) is connected with an outlet gas pipeline (36). The reaction tank (32) is connected with the speed increasing pipe (31) of the next-stage reaction tank (32) through the outlet gas pipeline (36). A collection chamber (37) is connected to the outlet gas pipeline (36) of the last-stage reaction tank (32) of the chemical desulfurizer. The collection chamber (37) is connected with a hydrogen sulfide detector through a pipeline, and a collection valve (38) is arranged on this pipeline.

9. The intelligent oil well pipeline hydrogen sulfide detection, treatment and control system according to claim 8, wherein The outlet gas pipeline (36) of the last-stage reaction tank (32) of the chemical desulfurizer is also connected with an adsorber (310), and an exhaust valve (39) is arranged on this outlet gas pipeline (36). The output end of the adsorber (310) is connected to the conversion cavity (110) of the wellhead control device through a pipeline.

10. The intelligent oil well pipeline hydrogen sulfide detection, treatment and control system according to claim 8, characterized in that, A gas sampler (5) is arranged between the hydrogen sulfide detector and the collection chamber (37), and the gas sampler (5) is connected with a plurality of collection chambers (37) through a plurality of pipelines respectively.

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