CN221028288U - Coalbed methane separation system - Google Patents
Coalbed methane separation system Download PDFInfo
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- CN221028288U CN221028288U CN202322560911.7U CN202322560911U CN221028288U CN 221028288 U CN221028288 U CN 221028288U CN 202322560911 U CN202322560911 U CN 202322560911U CN 221028288 U CN221028288 U CN 221028288U
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- 238000000926 separation method Methods 0.000 title claims abstract description 17
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 title claims description 44
- 238000005261 decarburization Methods 0.000 claims abstract description 34
- 229910052753 mercury Inorganic materials 0.000 claims abstract description 14
- QSHDDOUJBYECFT-UHFFFAOYSA-N mercury Chemical compound [Hg] QSHDDOUJBYECFT-UHFFFAOYSA-N 0.000 claims abstract description 13
- 238000003303 reheating Methods 0.000 claims abstract description 13
- 230000018044 dehydration Effects 0.000 claims abstract description 6
- 238000006297 dehydration reaction Methods 0.000 claims abstract description 6
- 238000006477 desulfuration reaction Methods 0.000 claims abstract description 5
- 230000023556 desulfurization Effects 0.000 claims abstract description 5
- 238000010521 absorption reaction Methods 0.000 claims description 26
- 230000008929 regeneration Effects 0.000 claims description 25
- 238000011069 regeneration method Methods 0.000 claims description 25
- 239000007788 liquid Substances 0.000 claims description 23
- 239000002253 acid Substances 0.000 claims description 21
- 238000001816 cooling Methods 0.000 claims description 10
- 238000005262 decarbonization Methods 0.000 claims description 7
- 239000003245 coal Substances 0.000 abstract description 41
- 239000007789 gas Substances 0.000 description 79
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 description 12
- PVXVWWANJIWJOO-UHFFFAOYSA-N 1-(1,3-benzodioxol-5-yl)-N-ethylpropan-2-amine Chemical compound CCNC(C)CC1=CC=C2OCOC2=C1 PVXVWWANJIWJOO-UHFFFAOYSA-N 0.000 description 6
- QMMZSJPSPRTHGB-UHFFFAOYSA-N MDEA Natural products CC(C)CCCCC=CCC=CC(O)=O QMMZSJPSPRTHGB-UHFFFAOYSA-N 0.000 description 6
- 239000001569 carbon dioxide Substances 0.000 description 6
- 229910002092 carbon dioxide Inorganic materials 0.000 description 6
- RWSOTUBLDIXVET-UHFFFAOYSA-N Dihydrogen sulfide Chemical compound S RWSOTUBLDIXVET-UHFFFAOYSA-N 0.000 description 4
- 230000000694 effects Effects 0.000 description 4
- 229910000037 hydrogen sulfide Inorganic materials 0.000 description 4
- 239000012535 impurity Substances 0.000 description 4
- 239000002245 particle Substances 0.000 description 3
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 2
- 239000004215 Carbon black (E152) Substances 0.000 description 2
- 239000000446 fuel Substances 0.000 description 2
- 229930195733 hydrocarbon Natural products 0.000 description 2
- 150000002430 hydrocarbons Chemical class 0.000 description 2
- 238000012423 maintenance Methods 0.000 description 2
- 238000004519 manufacturing process Methods 0.000 description 2
- 239000003345 natural gas Substances 0.000 description 2
- 239000003507 refrigerant Substances 0.000 description 2
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 2
- 150000004945 aromatic hydrocarbons Chemical class 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 238000009924 canning Methods 0.000 description 1
- UBAZGMLMVVQSCD-UHFFFAOYSA-N carbon dioxide;molecular oxygen Chemical compound O=O.O=C=O UBAZGMLMVVQSCD-UHFFFAOYSA-N 0.000 description 1
- 239000013064 chemical raw material Substances 0.000 description 1
- 239000003034 coal gas Substances 0.000 description 1
- 230000003009 desulfurizing effect Effects 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 239000000428 dust Substances 0.000 description 1
- 230000005611 electricity Effects 0.000 description 1
- 238000005265 energy consumption Methods 0.000 description 1
- 238000001704 evaporation Methods 0.000 description 1
- 230000008020 evaporation Effects 0.000 description 1
- 230000003090 exacerbative effect Effects 0.000 description 1
- 239000010881 fly ash Substances 0.000 description 1
- 239000002737 fuel gas Substances 0.000 description 1
- 229910052500 inorganic mineral Inorganic materials 0.000 description 1
- 239000011159 matrix material Substances 0.000 description 1
- 239000011707 mineral Substances 0.000 description 1
- 238000005065 mining Methods 0.000 description 1
- 229910052757 nitrogen Inorganic materials 0.000 description 1
- 239000011148 porous material Substances 0.000 description 1
- 238000004064 recycling Methods 0.000 description 1
- 239000002689 soil Substances 0.000 description 1
- 150000003568 thioethers Chemical class 0.000 description 1
- 238000010792 warming Methods 0.000 description 1
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- Treating Waste Gases (AREA)
Abstract
The utility model discloses a coal bed gas separation system, and relates to the technical field of coal bed gas separation. Comprises a decarburization device, a decarburization gas separator, a desulfurization device, a dehydration device, a mercury removal device, a low-temperature liquefying device, a conveying pipeline, a reheating heat exchanger, a first vortex tube and a second vortex tube which are sequentially communicated. The cold end of the reheating heat exchanger is respectively communicated with the low-temperature liquefying device and the conveying pipeline, and the hot end of the reheating heat exchanger is respectively communicated with the second vortex tube and the outside; the hot end of the first heat exchanger is respectively communicated with the decarburization device and the decarburization gas separator, and the cold end is respectively communicated with the first vortex tube and the outside. According to the utility model, the vortex tube is used for providing a cold source for the heat exchanger, and a heat source is provided for the decarburization device and the reheating heat exchanger, so that the device is more concise, and the liquefied coal bed gas is heated to be gas through the reheating heat exchanger, so that the liquefied coal bed gas is convenient to transport in a conveying pipeline, the transport cost is reduced, and the transport safety is improved.
Description
Technical Field
The utility model relates to the technical field of coal bed gas separation, in particular to a coal bed gas separation system.
Background
The coalbed methane is natural gas which is arranged in a coalbed, takes methane as a main component, takes the surface of coal matrix particles as a main component, is partially dissociated in coal pores or is dissolved in coalbed water, is a concomitant mineral resource of coal, and belongs to unconventional natural gas. The coal bed gas can be used for generating electricity and is used as industrial fuel, chemical raw material and resident living fuel. Coal bed gas leaks into the atmosphere as coal is mined, exacerbating the global warming effect. Coal bed gas is firstly extracted before coal mining, and the gas in coal mine production is reduced by 70% -85%.
The main component in the coal bed gas is methane, and the coal bed gas also contains a part of impurities such as oxygen, carbon dioxide, nitrogen, sulfides and the like, and the part of impurities need to be removed before the coal bed gas is used, so that the heat value of the coal bed gas is not reduced, and the energy consumption for preserving and conveying the coal bed gas is increased.
The patent with the publication number of CN215855952U discloses a coal bed gas purifying system, which comprises an absorption tower, an LNG high-pressure flash tank, an LNG low-pressure flash tank, a lean-rich liquid heat exchanger, a regeneration tower, a first acid-gas separator, a decarburization gas separator, a desulfurizing tower, a dryer, a mercury removal tower and a dust filter, wherein the patent can effectively deacidify, desulfurate, demercuration, dearomate and heavy hydrocarbon treatment on a coal gas layer, but a plurality of devices provide heat sources and cold sources in the treatment, which is unfavorable for the maintenance of equipment, increases the production cost, and finally produced liquefied coal bed gas is unfavorable for transportation in a pipeline, and needs to be transported away after canning, thereby increasing the transportation cost and simultaneously having potential safety hazards.
Disclosure of utility model
The main object of the present utility model is to provide a coalbed methane separation system to solve the above problems.
In order to achieve the aim, the utility model provides a coal bed gas separation system which comprises a decarburization device, a decarburization gas separator, a desulfurization device, a dehydration device, a mercury removal device and a low-temperature liquefying device which are sequentially communicated, and is characterized by further comprising a reheating heat exchanger, a first vortex tube, a second vortex tube and a conveying pipeline for conveying the coal bed gas;
The cold end inlet of the reheating heat exchanger is communicated with the outlet of the low-temperature liquefying device, the cold end outlet is communicated with the conveying pipeline, the hot end inlet is communicated with the hot gas outlet of the second vortex tube, and the hot end outlet is communicated with the outside;
The first heat exchanger is positioned between the decarburization device and the decarburization gas separator, wherein a hot end inlet of the first heat exchanger is communicated with the decarburization device, a hot end outlet of the first heat exchanger is communicated with an inlet of the decarburization gas separator, a cold end inlet of the first heat exchanger is communicated with a cold air outlet of the first vortex tube, and a cold end outlet of the first heat exchanger is communicated with the outside;
The decarbonization device is provided with a gas inlet.
Further, the device also comprises a cyclone separator, wherein a gas inlet of the cyclone separator is used for introducing coal bed gas, and a gas outlet of the cyclone separator is communicated with a gas inlet of the decarburization device.
Further, a pre-cooling heat exchanger is arranged between the mercury removal device and the low-temperature liquefying device, a hot end inlet of the pre-cooling heat exchanger is communicated with an outlet of the mercury removal device, a hot end outlet of the pre-cooling heat exchanger is communicated with an inlet of the low-temperature liquefying device, a cold end inlet of the pre-cooling heat exchanger is communicated with a cold air outlet of the second vortex tube, and a cold end outlet of the pre-cooling heat exchanger is communicated with the outside.
Further, the decarbonization device comprises an absorption tower, a flash tank, a regeneration tower, an acid-gas separator, a second heat exchanger and a reboiler for providing stripping regeneration heat for the regeneration tower;
The gas inlet is arranged at the bottom of the absorption tower, a rich liquid outlet is arranged at the other side of the bottom of the absorption tower, a lean liquid inlet is arranged at the upper part of the absorption tower, and a coal bed gas outlet communicated with the first heat exchanger is arranged at the top of the absorption tower;
the bottom of the regeneration tower is provided with a lean solution outlet, the upper part of the regeneration tower is provided with a rich solution inlet, and the top of the regeneration tower is provided with an acid gas outlet;
One end of the flash tank is communicated with the rich liquid outlet, and the other end of the flash tank is communicated with the rich liquid inlet;
The hot end inlet of the second heat exchanger is communicated with the acid gas outlet, the hot end outlet is communicated with the inlet end of the acid gas separator, the cold end inlet is communicated with the cold air outlet of the second vortex tube, and the cold end outlet is communicated with the outside;
the reboiler is in communication with the hot gas outlet of the first vortex tube.
Further, the heat exchanger also comprises a third heat exchanger; the cold end inlet of the third heat exchanger is communicated with the cold air outlet of the first vortex tube, the cold end outlet is communicated with the outside, the hot end inlet is communicated with the lean liquid outlet, and the hot end outlet is communicated with the lean liquid inlet.
Further, the acid gas separator also comprises a torch, wherein the torch is communicated with the outlet end of the acid gas separator.
The utility model has the following beneficial effects:
According to the utility model, the vortex tube provides cold sources and heat sources for each heat exchanger and reboiler, so that the number of devices for providing the cold sources is reduced, and the maintenance of equipment is facilitated; by arranging the pre-cooling heat exchanger, the coal bed gas is reduced by a certain temperature before low-temperature liquefaction, so that the consumption of the refrigerant during low-temperature liquefaction is reduced, and the subsequent low-temperature liquefaction effect is ensured; through the reheating heat exchanger, the liquid coalbed methane is changed into a gaseous state, so that the coalbed methane is convenient to transport in a pipeline, the transport cost is reduced, and the transport safety is improved.
Drawings
FIG. 1 is a schematic diagram of a coalbed methane separation system according to the present utility model;
In the figure: 1-an absorption tower; 2-a regeneration tower; 3-decarburization gas separator; 4-desulfurizing device; 5-a dehydration device; 6-mercury removal device; 7-a cryogenic liquefaction plant; 8-a reheat heat exchanger; 9-a first heat exchanger; 10-a second heat exchanger; 11-a third heat exchanger; 12-vortex tube; 13-torch; 14-precooling a heat exchanger; 15-an acid gas separator; 16-a second vortex tube; 101-flash tank.
Detailed Description
In order to achieve the above objects and effects, the present utility model adopts the technical means and structure, and the features and functions of the preferred embodiments of the present utility model will be described in detail with reference to the accompanying drawings.
As shown in fig. 1, the utility model provides a coalbed methane separation system, which comprises a decarburization device, a decarburization gas separator 3, a desulfurization device 4, a dehydration device 5, a mercury removal device 6 and a low-temperature liquefying device 7 which are sequentially communicated, and is characterized by further comprising a reheating heat exchanger 8, a first heat exchanger 9, a first vortex tube 12, a second vortex tube 16 and a conveying pipeline for conveying coalbed methane;
The cold end inlet of the reheating heat exchanger 8 is communicated with the outlet of the low-temperature liquefying device 7, the cold end outlet is communicated with a conveying pipeline, the hot end inlet is communicated with the hot gas outlet of the second vortex tube 16, and the hot end outlet is communicated with the outside;
The first heat exchanger 9 is positioned between the decarburization device and the decarburization gas separator 3, wherein a hot end inlet of the first heat exchanger 9 is communicated with the decarburization device, a hot end outlet is communicated with an inlet of the decarburization gas separator 3, a cold end inlet is communicated with a cold air outlet of the first vortex tube 12, and a cold end outlet is communicated with the outside;
the decarbonization device is provided with a gas inlet.
In actual use, air is introduced into air inlets of the first vortex tube 12 and the second vortex tube 16 by an air compressor, compressed coal bed gas enters the decarburization device from an air inlet of the decarburization device, part of carbon dioxide and hydrogen sulfide are removed, the compressed coal bed gas is discharged from a coal bed gas outlet of the decarburization device, the discharged coal bed gas exchanges heat with cold air discharged by the first vortex tube 12 through the first heat exchanger 9, the temperature is reduced to be less than or equal to 40 ℃, carbon dioxide is further removed in the decarburization gas separator 3, the carbon dioxide content in the coal bed gas after decarburization treatment is less than 50ppmV, and then the coal bed gas sequentially passes through the desulfurization device 4 for removing hydrogen sulfide, the dehydration device 5 for removing water, the mercury removal device 6 for removing mercury and the low-temperature liquefaction device 7 for removing aromatic hydrocarbon and heavy hydrocarbon from the coal bed gas through low-temperature liquefaction.
The low-temperature liquid coal bed gas leaving from the low-temperature liquefying device 7 exchanges heat with hot gas discharged by the second vortex tube 16 through the reheating heat exchanger 8, is restored to a gaseous state again, and then enters a conveying pipeline to be conveyed to a destination.
In this embodiment, in order to prevent the coal bed gas from carrying impurities such as fly ash and soil into the system, which would cause blockage and damage of the system, before the coal bed gas enters the decarburization device, the raw gas is made to pass through the filter screen first, larger particles are filtered out, then enter the cyclone separator, the impurities with smaller particles are separated out, and finally the clean raw gas enters the decarburization device to perform the subsequent separation step.
In this embodiment, a pre-cooling heat exchanger 14 is disposed between the mercury removal device 6 and the low-temperature liquefying device 7, a hot end inlet of the pre-cooling heat exchanger 14 is communicated with an outlet of the mercury removal device 6, a hot end outlet is communicated with an inlet of the low-temperature liquefying device 7, a cold end inlet is connected with a cold air outlet of the second vortex tube 16, and a cold end outlet is communicated with the outside, so as to pre-cool coalbed methane to be introduced into the low-temperature liquefying device 7, ensure the effect of subsequent low-temperature liquefaction, and reduce the consumption of refrigerant.
In this embodiment, the decarbonization device includes an absorption tower 1, a flash tank 101, a regeneration tower 2, an acid gas separator 15, a flare 13, a second heat exchanger 10, and a reboiler for supplying heat for stripping regeneration to the regeneration tower 2; the gas inlet is arranged at the bottom of the absorption tower 1, the other side of the bottom of the absorption tower 1 is provided with a rich liquid outlet, the upper part of the absorption tower is provided with a lean liquid inlet, and the top of the absorption tower is provided with a coal bed gas outlet communicated with the first heat exchanger 9; the bottom of the regeneration tower 2 is provided with a lean solution outlet, the upper part is provided with a rich solution inlet, and the top is provided with an acid gas outlet; one end of the flash tank 101 is communicated with a rich liquid outlet, and the other end is communicated with a rich liquid inlet; the hot end inlet of the second heat exchanger 10 is communicated with an acid gas outlet, the hot end outlet is communicated with an acid gas separator 15, the cold end inlet is communicated with a cold air outlet of a second vortex tube 16, and the cold end outlet is communicated with the outside; the reboiler is communicated with a hot gas outlet of the first vortex tube 12; the torch 13 is communicated with the outlet end of the acid-gas separator 15;
The coal bed gas enters the absorption tower 1 from a gas inlet at the bottom of the absorption tower 1, moves from bottom to top to a coal bed gas outlet at the top of the absorption tower 1, contacts MDEA solution (lean solution) sprayed out from a lean solution outlet at the upper part of the absorption tower 1 on the way, absorbs part of hydrogen sulfide and carbon dioxide in the gas, and the rest of the gas absorbs part of heat of the solution and is discharged from the coal bed gas outlet at the top of the absorption tower 1;
The MDEA solution (rich liquid) absorbing hydrogen sulfide and carbon dioxide in the absorption tower 1 leaves the absorption tower from a rich liquid outlet, enters a flash tank 101 for flash evaporation, flash evaporated steam is discharged to an external fuel gas system, the flash evaporated MDEA solution (rich liquid) enters a regeneration tower 2 from the upper part, the MDEA solution enters the regeneration tower 2 from a rich liquid inlet, a heat source in the regeneration tower 2 through steam stripping regeneration (the temperature in the regeneration is 105-120 ℃ in a hot gas outlet of a first vortex tube 12 communicated with a reboiler, the acid gas such as carbon dioxide is removed, the removed acid gas (the temperature is about 95-100 ℃) is discharged from an acid gas outlet at the top of the regeneration tower 2, the flash evaporated steam enters an acid gas separator 15 for removing part of the acid gas after being cooled to below 40 ℃, and the residual gas after removing part of the acid gas enters a torch 13 and is led to high-altitude discharge.
The regenerated MDEA solution (barren solution) is discharged from a barren solution outlet at the bottom of the regeneration tower 2, enters the absorption tower 1 through a barren solution inlet communicated with the barren solution outlet, and is recycled.
In this embodiment, the decarburization device further comprises a third heat exchanger 11; the cold end inlet of the third heat exchanger 11 is communicated with the cold air outlet of the first vortex tube 12, the cold end outlet is communicated with the outside, the hot end inlet is communicated with the lean solution outlet, and the hot end outlet is communicated with the lean solution inlet; so that the MDEA solution (lean solution) discharged from the lean solution outlet exchanges heat with the cold air discharged from the first vortex tube 12 through the third heat exchanger 11, and enters the absorption tower 1 after being cooled to about 45 ℃ so as to be convenient for subsequent recycling.
The foregoing description is only illustrative of the preferred embodiment, and is not intended to limit the scope of the utility model in any way.
Claims (6)
1. The coalbed methane separation system comprises a decarburization device, a decarburization gas separator (3), a desulfurization device (4), a dehydration device (5), a mercury removal device (6) and a low-temperature liquefying device (7) which are sequentially communicated, and is characterized by further comprising a reheating heat exchanger (8), a first heat exchanger (9), a first vortex tube (12), a second vortex tube (16) and a conveying pipeline for conveying coalbed methane;
The cold end inlet of the reheating heat exchanger (8) is communicated with the outlet of the low-temperature liquefying device (7), the cold end outlet is communicated with a conveying pipeline, the hot end inlet is communicated with the hot gas outlet of the second vortex tube (16), and the hot end outlet is communicated with the outside;
The first heat exchanger (9) is positioned between the decarburization device and the decarburization gas separator (3), wherein a hot end inlet of the first heat exchanger (9) is communicated with the decarburization device, a hot end outlet is communicated with an inlet of the decarburization gas separator (3), a cold end inlet is communicated with a cold air outlet of the first vortex tube (12), and a cold end outlet is communicated with the outside;
The decarbonization device is provided with a gas inlet.
2. The coalbed methane separation system of claim 1, further comprising a cyclone, a gas inlet of the cyclone for passing coalbed methane, and a gas outlet of the cyclone in communication with a gas inlet of the decarbonization device.
3. The coalbed methane separation system according to claim 1, characterized in that a pre-cooling heat exchanger (14) is arranged between the mercury removal device (6) and the low-temperature liquefying device (7), a hot end inlet of the pre-cooling heat exchanger (14) is communicated with an outlet of the mercury removal device (6), a hot end outlet is communicated with an inlet of the low-temperature liquefying device (7), a cold end inlet is communicated with a cold air outlet of the second vortex tube (16), and a cold end outlet is communicated with the outside.
4. The coalbed methane separation system of claim 1, wherein the decarbonization device comprises an absorption tower (1), a flash tank (101), a regeneration tower (2), an acid gas separator (15), a second heat exchanger (10), and a reboiler for providing stripping regeneration heat to the regeneration tower (2);
The gas inlet is arranged at the bottom of the absorption tower (1), a rich liquid outlet is arranged at the other side of the bottom of the absorption tower (1), a lean liquid inlet is arranged at the upper part of the absorption tower, and a coalbed methane outlet communicated with the first heat exchanger (9) is arranged at the top of the absorption tower;
the bottom of the regeneration tower (2) is provided with a lean solution outlet, the upper part of the regeneration tower is provided with a rich solution inlet, and the top of the regeneration tower is provided with an acid gas outlet;
one end of the flash tank (101) is communicated with the rich liquid outlet, and the other end of the flash tank is communicated with the rich liquid inlet;
The hot end inlet of the second heat exchanger (10) is communicated with the acid gas outlet, the hot end outlet is communicated with the inlet end of the acid gas separator (15), the cold end inlet is communicated with the cold air outlet of the second vortex tube (16), and the cold end outlet is communicated with the outside;
the reboiler is in communication with a hot gas outlet of the first vortex tube (12).
5. The coalbed methane separation system of claim 4, further comprising a third heat exchanger (11); the cold end inlet of the third heat exchanger (11) is communicated with the cold air outlet of the first vortex tube (12), the cold end outlet is communicated with the outside, the hot end inlet is communicated with the lean liquid outlet, and the hot end outlet is communicated with the lean liquid inlet.
6. The coal-bed gas separation system of claim 4, further comprising a flare (13), the flare (13) being in communication with an outlet end of the acid gas separator (15).
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202322560911.7U CN221028288U (en) | 2023-09-20 | 2023-09-20 | Coalbed methane separation system |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202322560911.7U CN221028288U (en) | 2023-09-20 | 2023-09-20 | Coalbed methane separation system |
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| Publication Number | Publication Date |
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| CN221028288U true CN221028288U (en) | 2024-05-28 |
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| Application Number | Title | Priority Date | Filing Date |
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| CN202322560911.7U Active CN221028288U (en) | 2023-09-20 | 2023-09-20 | Coalbed methane separation system |
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| Country | Link |
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| CN (1) | CN221028288U (en) |
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