CN219607507U - Natural gas liquefaction unit - Google Patents
Natural gas liquefaction unit Download PDFInfo
- Publication number
- CN219607507U CN219607507U CN202223575050.1U CN202223575050U CN219607507U CN 219607507 U CN219607507 U CN 219607507U CN 202223575050 U CN202223575050 U CN 202223575050U CN 219607507 U CN219607507 U CN 219607507U
- Authority
- CN
- China
- Prior art keywords
- communicated
- outlet
- heavy hydrocarbon
- separator
- inlet pipeline
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Active
Links
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 title claims abstract description 24
- 239000003345 natural gas Substances 0.000 title claims abstract description 12
- 229930195733 hydrocarbon Natural products 0.000 claims abstract description 73
- 150000002430 hydrocarbons Chemical class 0.000 claims abstract description 73
- 239000004215 Carbon black (E152) Substances 0.000 claims abstract description 72
- 239000003507 refrigerant Substances 0.000 claims abstract description 63
- 239000007789 gas Substances 0.000 claims abstract description 32
- 238000003860 storage Methods 0.000 claims abstract description 27
- 238000011084 recovery Methods 0.000 claims abstract description 15
- 238000010992 reflux Methods 0.000 claims abstract description 12
- 239000012071 phase Substances 0.000 claims description 12
- 230000008676 import Effects 0.000 claims description 8
- 239000007791 liquid phase Substances 0.000 claims description 8
- 239000007788 liquid Substances 0.000 claims description 6
- 238000004064 recycling Methods 0.000 abstract description 4
- 238000005265 energy consumption Methods 0.000 abstract description 3
- 239000003795 chemical substances by application Substances 0.000 abstract description 2
- 230000006835 compression Effects 0.000 abstract description 2
- 238000007906 compression Methods 0.000 abstract description 2
- 239000003949 liquefied natural gas Substances 0.000 description 24
- QSHDDOUJBYECFT-UHFFFAOYSA-N mercury Chemical compound [Hg] QSHDDOUJBYECFT-UHFFFAOYSA-N 0.000 description 10
- 229910052753 mercury Inorganic materials 0.000 description 10
- 238000000926 separation method Methods 0.000 description 4
- 238000001816 cooling Methods 0.000 description 3
- 239000002994 raw material Substances 0.000 description 3
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 description 2
- 239000002253 acid Substances 0.000 description 2
- 239000007792 gaseous phase Substances 0.000 description 2
- 238000004519 manufacturing process Methods 0.000 description 2
- 230000001502 supplementing effect Effects 0.000 description 2
- 230000003139 buffering effect Effects 0.000 description 1
- 229910002092 carbon dioxide Inorganic materials 0.000 description 1
- 239000001569 carbon dioxide Substances 0.000 description 1
- 238000003795 desorption Methods 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 238000010438 heat treatment Methods 0.000 description 1
- 238000000034 method Methods 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000002360 preparation method Methods 0.000 description 1
- 238000005086 pumping Methods 0.000 description 1
- 238000003303 reheating Methods 0.000 description 1
- 238000006467 substitution reaction Methods 0.000 description 1
- 239000002699 waste material Substances 0.000 description 1
Landscapes
- Separation By Low-Temperature Treatments (AREA)
Abstract
The utility model discloses a natural gas liquefaction unit, which comprises a cold box, a heavy hydrocarbon removal tower, a low-temperature separator and a heavy hydrocarbon reflux pump, and further comprises a heavy hydrocarbon heater. The advantages are that: the demercuration purifying gas exchanges heat with a heavy hydrocarbon recycling heater at the bottom of the heavy hydrocarbon removing tower before entering the cold box, so that on one hand, the heavy hydrocarbon is heated, and on the other hand, the demercuration purifying gas is precooled, thereby realizing the utilization of cold energy and reducing the consumption of cold agent; in addition, the BOG removed from the LNG storage tank is treated by the BOG separator and the low-temperature separator to recycle the LNG in the LNG storage tank, so that the income is increased; the liquefying unit carries out two-stage compression cycle on the refrigerant discharged from the cold box; the liquefaction unit realizes cold energy recovery, LNG recovery and refrigerant recycling, and has low overall energy consumption.
Description
Technical field:
the utility model relates to the technical field of liquefied natural gas preparation, in particular to a natural gas liquefaction unit.
The background technology is as follows:
the process for preparing the liquefied natural gas mainly comprises a metering pressurizing unit, an acid gas removing unit, a dewatering unit, a mercury removing unit, a liquefying unit and an LNG storage unit, wherein raw material gas enters the acid gas removing unit to remove carbon dioxide after being metered and pressurized by the metering pressurizing unit, then enters the dewatering unit to be dewatered and dried, then is subjected to mercury removal treatment by the mercury removing unit, and the raw material gas after mercury removal enters the liquefying unit to liquefy and remove heavy hydrocarbon, and finally liquefied LNG is sent to the LNG storage unit to be stored. Wherein the liquefaction unit is mainly including the cold box, get rid of heavy hydrocarbon tower and low temperature separator, the raw materials gas after the mercury removal is firstly cooled down through the cold box before reentrant heavy hydrocarbon tower desorption heavy hydrocarbon that takes off, take off heavy hydrocarbon tower exhaust gaseous phase and enter into low temperature separator again after the cold box cooling and separate in, the gaseous phase that low temperature separator top separated is sent into LNG storage unit's LNG storage tank after cooling down once more through the cold box and is stored, the heavy hydrocarbon that low temperature separator separated is got back to take off in the heavy hydrocarbon tower through the pumping of heavy hydrocarbon backward flow. The natural gas liquefaction unit has the following problems: 1. the raw gas from the mercury removal unit is directly fed into a cold box for cooling after being fed into a heavy hydrocarbon removal tower, so that heavy hydrocarbon separation is incomplete, and LNG quality is affected; 2. LNG storage tank exhaust BOG is large in quantity, and can not effectively retrieve, causes the energy waste. 3. The recovery rate of the refrigerant discharged from the cold box is low, the consumption of the refrigerant is large, and the production cost is increased.
The utility model comprises the following steps:
the utility model aims to provide a natural gas liquefaction unit capable of reducing energy consumption.
The utility model is implemented by the following technical scheme: the natural gas liquefaction unit, the cold box, the heavy hydrocarbon removal tower, the low-temperature separator and the heavy hydrocarbon reflux pump, the natural gas liquefaction unit further comprises a heavy hydrocarbon heater, a mercury removal raw gas pipeline is communicated with a first inlet of the heavy hydrocarbon heater, a first outlet of the heavy hydrocarbon heater is communicated with a first channel inlet of the cold box, and a first channel outlet of the cold box is communicated with an inlet pipeline of the heavy hydrocarbon removal tower; the underflow outlet of the heavy hydrocarbon removal tower is communicated with a second inlet pipeline of the heavy hydrocarbon heater, and the second outlet of the heavy hydrocarbon heater is communicated with an inlet pipeline of a heavy hydrocarbon storage tank; the exhaust port of the heavy hydrocarbon removal tower is communicated with the inlet pipeline of the second channel of the cold box, the outlet of the second channel of the cold box is communicated with the inlet pipeline of the low-temperature separator, the liquid outlet of the low-temperature separator is communicated with the inlet pipeline of the heavy hydrocarbon reflux pump, and the outlet of the heavy hydrocarbon reflux pump is communicated with the inlet pipeline of the heavy hydrocarbon removal tower; the exhaust port of the cryogenic separator is communicated with an inlet pipeline of a third channel of the cold box, and an outlet of the third channel of the cold box is communicated with an inlet pipeline of the LNG storage tank.
Further, it still includes BOG buffer tank, BOG compressor air cooler and BOG separator, the gas vent of LNG storage tank with the import pipeline intercommunication of the fourth passageway of cold box, the export of the fourth passageway of cold box with the import pipeline intercommunication of BOG buffer tank, the export of BOG buffer tank with the import pipeline intercommunication of BOG compressor, the export of BOG compressor with the import pipeline intercommunication of BOG compressor air cooler, the export of BOG compressor air cooler with the import pipeline intercommunication of the fifth passageway of cold box, the export of the fifth passageway of cold box with the import pipeline intercommunication of BOG separator, the underflow export of BOG separator with the import pipeline intercommunication of LNG storage tank, the top intercommunication of BOG separator has the evacuation pipe.
Further, a reverse flow refrigerant outlet of the cold box is communicated with an inlet of a refrigerant buffer tank, a refrigerant supplementing pipe is communicated with the inlet of the refrigerant buffer tank, an outlet of the refrigerant buffer tank is communicated with a primary inlet pipeline of a refrigerant compressor, a primary outlet of the refrigerant compressor is communicated with an inlet pipeline of a primary air cooler, an outlet of the primary air cooler is communicated with an inlet pipeline of the primary cooler, and an outlet of the primary cooler is communicated with an inlet pipeline of a primary separator; the liquid phase outlet of the primary separator is divided into two paths, one path is communicated with an inlet pipeline of the refrigerant recovery tank, and the other path is communicated with a refrigerant inlet pipeline of the cold box; the gas phase outlet of the primary separator is communicated with a secondary inlet pipeline of the refrigerant compressor, the secondary outlet of the refrigerant compressor is communicated with an inlet pipeline of a secondary air cooler, the outlet of the secondary air cooler is communicated with an inlet pipeline of the secondary cooler, the outlet of the secondary cooler is communicated with an inlet pipeline of the secondary separator, the gas phase outlet of the secondary separator is communicated with a refrigerant inlet pipeline of the cold box, and the liquid phase outlet of the refrigerant recovery tank is communicated with both the inlets of the primary separator and the secondary separator; and a gas phase outlet of the refrigerant recovery tank is communicated with an inlet of the refrigerant buffer tank through a pipeline.
The utility model has the advantages that: the demercuration purifying gas exchanges heat with a heavy hydrocarbon recycling heater at the bottom of the heavy hydrocarbon removing tower before entering the cold box, so that on one hand, the heavy hydrocarbon is heated, and on the other hand, the demercuration purifying gas is precooled, thereby realizing the utilization of cold energy and reducing the consumption of cold agent; in addition, the BOG removed from the LNG storage tank is treated by the BOG separator and the low-temperature separator to recycle the LNG in the LNG storage tank, so that the income is increased; the liquefying unit carries out two-stage compression cycle on the refrigerant discharged from the cold box; the liquefaction unit realizes cold energy recovery, LNG recovery and refrigerant recycling, and has low overall energy consumption.
Description of the drawings:
fig. 1 is a schematic diagram of the overall structure of the present utility model.
Cold box 1, heavy hydrocarbon removal column 2, cryogenic separator 3, heavy hydrocarbon reflux pump 4, heavy hydrocarbon heater 5, mercury removal feed gas line 6, heavy hydrocarbon storage tank 7, LNG storage tank 8, BOG buffer tank 9, BOG compressor 10, BOG compressor air cooler 11, BOG separator 12, refrigerant recovery tank 13, evacuation pipe 14, refrigerant buffer tank 15, refrigerant compressor 16, primary air cooler 17, primary cooler 18, primary separator 19, secondary air cooler 20, secondary cooler 21, secondary separator 22, refrigerant make-up pipe 23.
The specific embodiment is as follows:
as shown in fig. 1, a natural gas liquefaction unit, a cold box 1, a heavy hydrocarbon removal tower 2, a low-temperature separator 3, a heavy hydrocarbon reflux pump 4, a heavy hydrocarbon heater 5, a BOG buffer tank 9, a BOG compressor 10, a BOG compressor air cooler 11 and a BOG separator 12,
the mercury-free raw gas pipeline 6 is communicated with a first inlet of the heavy hydrocarbon heater 5, a first outlet of the heavy hydrocarbon heater 5 is communicated with a first channel inlet of the cold box 1, and a first channel outlet of the cold box 1 is communicated with an inlet pipeline of the heavy hydrocarbon removal tower 2; the underflow outlet of the heavy hydrocarbon removal tower 2 is communicated with a second inlet pipeline of the heavy hydrocarbon heater 5, and the second outlet of the heavy hydrocarbon heater 5 is communicated with an inlet pipeline of the heavy hydrocarbon storage tank 7;
the exhaust port of the heavy hydrocarbon removal tower 2 is communicated with a second channel inlet pipeline of the cold box 1, the second channel outlet of the cold box 1 is communicated with an inlet pipeline of the low-temperature separator 3, the liquid outlet of the low-temperature separator 3 is communicated with an inlet pipeline of the heavy hydrocarbon reflux pump 4, and the outlet of the heavy hydrocarbon reflux pump 4 is communicated with an inlet pipeline of the heavy hydrocarbon removal tower 2; the exhaust port of the cryogenic separator 3 is communicated with an inlet pipeline of a third channel of the cold box 1, and the outlet of the third channel of the cold box 1 is communicated with an inlet pipeline of the LNG storage tank 8.
The gas vent of LNG storage tank 8 communicates with the inlet pipeline of the fourth passageway of cold box 1, the export of the fourth passageway of cold box 1 communicates with the inlet pipeline of BOG buffer tank 9, the export of BOG buffer tank 9 communicates with the inlet pipeline of BOG compressor 10, the export of BOG compressor 10 communicates with the inlet pipeline of BOG compressor air cooler 11, the export of BOG compressor air cooler 11 communicates with the inlet pipeline of the fifth passageway of cold box 1, the export of the fifth passageway of cold box 1 communicates with the inlet pipeline of BOG separator 12, the underflow outlet of BOG separator 12 communicates with the inlet pipeline of LNG storage tank 8, the top of BOG separator 12 communicates with evacuation pipe 14.
The reverse flow refrigerant outlet of the cold box 1 is communicated with the inlet of the refrigerant buffer tank 15, a refrigerant supplementing pipe 23 is communicated with the inlet of the refrigerant buffer tank 15, the outlet of the refrigerant buffer tank 15 is communicated with a primary inlet pipeline of the refrigerant compressor 16, a primary outlet of the refrigerant compressor 16 is communicated with an inlet pipeline of the primary air cooler 17, the outlet of the primary air cooler 17 is communicated with an inlet pipeline of the primary cooler 18, and the outlet of the primary cooler 18 is communicated with an inlet pipeline of the primary separator 19;
the liquid phase outlet of the primary separator 19 is divided into two paths, one path is communicated with an inlet pipeline of the refrigerant recovery tank 13, and the other path is communicated with a refrigerant inlet pipeline of the cold box 1;
the gas phase outlet of the first separator 19 is communicated with a second-stage inlet pipeline of the refrigerant compressor 16, the second-stage outlet of the refrigerant compressor 16 is communicated with an inlet pipeline of the second-stage air cooler 20, the outlet of the second-stage air cooler 20 is communicated with an inlet pipeline of the second-stage cooler 21, the outlet of the second-stage cooler 21 is communicated with an inlet pipeline of the second-stage separator 22, the gas phase outlet of the second-stage separator 22 is communicated with a refrigerant inlet pipeline of the cold box 1, and the liquid phase outlet of the refrigerant recovery tank 13 is communicated with both pipelines between the inlets of the first-stage separator 19 and the second-stage separator 22 and between the gas phase outlet of the refrigerant recovery tank 13 and the inlet of the refrigerant buffer tank 15.
The technical process comprises the following steps:
purified gas (5.7 MPaG,35 ℃) from a mercury removal unit enters a heavy hydrocarbon heater 5 through a mercury removal raw gas pipeline 6, exchanges heat with heavy hydrocarbon from a heavy hydrocarbon removal tower 2, then enters a first passage of a cold box 1 to be cooled to minus 15 ℃, then enters the heavy hydrocarbon removal tower to remove heavy hydrocarbon, returns to a second passage of the cold box to be further cooled to minus 65 ℃, is separated by a low-temperature separator 3, then enters a third passage of the cold box 1 to be condensed so as to be supercooled, is liquefied to minus 162 ℃, and is sent to an LNG storage tank 8 to be stored to obtain an LNG product; the heavy hydrocarbons separated by the cryogenic separator 3 are returned to the heavy hydrocarbon removal column 2 via the heavy hydrocarbon reflux pump 4.
BOG (0.015 MPaG, -166 ℃) of the LNG storage tank 8 is introduced into a fourth channel of the cold box 1 for reheating to 30 ℃, then enters into the BOG buffer tank 9 for buffering, is compressed by the BOG compressor 10 and then is cooled by the BOG compressor air cooler 11, then is re-liquefied by a fifth channel of the cold box 1, the re-liquefied BOG is introduced into the BOG separator 12 for separation, the liquid phase separated by the BOG separator 12 is returned into the LNG storage tank 8, and the gas phase is emptied by the emptying pipe.
The back flow refrigerant from the cold box 1 firstly enters a refrigerant buffer tank 15, the gas from the top of the refrigerant buffer tank 15 enters a first-stage inlet of a refrigerant compressor 16 to be pressurized to 1.74MPaG, a small part of high-temperature gas is separated from a first-stage outlet of the refrigerant compressor for heating of the amateur state refrigerant, the compressed refrigerant gas is cooled to 35 ℃ through a first-stage air cooler 17 and a first-stage cooler 18, then enters a first-stage separator 19 for gas-liquid separation, the gas enters a second-stage inlet of the refrigerant compressor 16, and the liquid is removed from the refrigerant buffer tank 15. The gas-phase refrigerant is compressed to 4.37MPaG by the refrigerant compressor 16 in two stages, is cooled to 35 ℃ by the secondary air cooler 20 and the secondary cooler 21, then enters the secondary separator 22 for gas-liquid separation, and the gas-phase cryogenic refrigerant, the secondary precooling refrigerant and the liquid-phase refrigerant stored in the refrigerant storage tank enter the cold box 1 to provide cold energy.
Finally, it should be noted that: the above embodiments are only for illustrating the technical solution of the present utility model, and not for limiting the same; although the utility model has been described in detail with reference to the foregoing embodiments, it will be understood by those of ordinary skill in the art that: the technical scheme described in the foregoing embodiments can be modified or some or all of the technical features thereof can be replaced by equivalents; such modifications and substitutions do not depart from the spirit of the utility model.
Claims (3)
1. The natural gas liquefaction unit, the cold box, remove heavy hydrocarbon tower, low temperature separator and heavy hydrocarbon reflux pump, its characterized in that still includes heavy hydrocarbon heater, and demercuration raw gas pipeline and the first entry intercommunication of heavy hydrocarbon heater, the first export of heavy hydrocarbon heater with the first passageway entry intercommunication of cold box, the first passageway export of cold box with the import pipeline intercommunication of heavy hydrocarbon tower that takes off; the underflow outlet of the heavy hydrocarbon removal tower is communicated with a second inlet pipeline of the heavy hydrocarbon heater, and the second outlet of the heavy hydrocarbon heater is communicated with an inlet pipeline of a heavy hydrocarbon storage tank; the exhaust port of the heavy hydrocarbon removal tower is communicated with the inlet pipeline of the second channel of the cold box, the outlet of the second channel of the cold box is communicated with the inlet pipeline of the low-temperature separator, the liquid outlet of the low-temperature separator is communicated with the inlet pipeline of the heavy hydrocarbon reflux pump, and the outlet of the heavy hydrocarbon reflux pump is communicated with the inlet pipeline of the heavy hydrocarbon removal tower; the exhaust port of the cryogenic separator is communicated with an inlet pipeline of a third channel of the cold box, and an outlet of the third channel of the cold box is communicated with an inlet pipeline of the LNG storage tank.
2. The natural gas liquefaction unit of claim 1, further comprising a BOG buffer tank, a BOG compressor air cooler, and a BOG separator, wherein the vent of the LNG storage tank is in communication with the inlet line of the fourth channel of the cold box, the outlet of the fourth channel of the cold box is in communication with the inlet line of the BOG buffer tank, the outlet of the BOG buffer tank is in communication with the inlet line of the BOG compressor, the outlet of the BOG compressor is in communication with the inlet line of the BOG compressor air cooler, the outlet of the BOG compressor air cooler is in communication with the inlet line of the fifth channel of the cold box, the outlet of the fifth channel of the cold box is in communication with the inlet line of the BOG separator, the underflow outlet of the BOG separator is in communication with the inlet line of the LNG storage tank, and the top of the BOG separator is in communication with a vent pipe.
3. The natural gas liquefaction unit according to claim 2, wherein the reverse flow cryogen outlet of the cold box is communicated with an inlet of a cryogen buffer tank, a cryogen replenishing pipe is communicated with the inlet of the cryogen buffer tank, an outlet of the cryogen buffer tank is communicated with a primary inlet pipeline of a cryogen compressor, a primary outlet of the cryogen compressor is communicated with an inlet pipeline of a primary air cooler, an outlet of the primary air cooler is communicated with an inlet pipeline of a primary cooler, and an outlet of the primary cooler is communicated with an inlet pipeline of a primary separator; the liquid phase outlet of the primary separator is divided into two paths, one path is communicated with an inlet pipeline of the refrigerant recovery tank, and the other path is communicated with a refrigerant inlet pipeline of the cold box; the gas phase outlet of the primary separator is communicated with a secondary inlet pipeline of the refrigerant compressor, the secondary outlet of the refrigerant compressor is communicated with an inlet pipeline of a secondary air cooler, the outlet of the secondary air cooler is communicated with an inlet pipeline of the secondary cooler, the outlet of the secondary cooler is communicated with an inlet pipeline of the secondary separator, the gas phase outlet of the secondary separator is communicated with a refrigerant inlet pipeline of the cold box, and the liquid phase outlet of the refrigerant recovery tank is communicated with both the inlets of the primary separator and the secondary separator; and a gas phase outlet of the refrigerant recovery tank is communicated with an inlet of the refrigerant buffer tank through a pipeline.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202223575050.1U CN219607507U (en) | 2022-12-29 | 2022-12-29 | Natural gas liquefaction unit |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202223575050.1U CN219607507U (en) | 2022-12-29 | 2022-12-29 | Natural gas liquefaction unit |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CN219607507U true CN219607507U (en) | 2023-08-29 |
Family
ID=87743893
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN202223575050.1U Active CN219607507U (en) | 2022-12-29 | 2022-12-29 | Natural gas liquefaction unit |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN219607507U (en) |
-
2022
- 2022-12-29 CN CN202223575050.1U patent/CN219607507U/en active Active
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN109186179B (en) | Full-rectification argon extraction oxygen-enriched air separation device and process | |
| CN201265997Y (en) | Liquid air separation plant | |
| CN108458549B (en) | System and method for extracting helium from natural gas and liquefying same | |
| CN100363699C (en) | Air separation system for recycling cold energy of liquified natural gas | |
| CN109690215A (en) | Industrial gasses place produces integrated with liquid hydrogen | |
| CN208332859U (en) | Helium and liquefied system are proposed from natural gas | |
| CN108592519A (en) | Helium and liquefied apparatus and method are put forward from natural gas | |
| CN212747065U (en) | High-nitrogen and helium-containing natural gas liquefaction and crude helium and nitrogen extraction system | |
| CN110207457B (en) | Air separation equipment capable of preparing liquid nitrogen and application method thereof | |
| CN105571269A (en) | Low-temperature distillation and liquefying separation recovery system and method for coal bed gas high in nitrogen content, oxygen content and hydrogen content | |
| CN109631494A (en) | A kind of helium production system and production method | |
| CN102435045A (en) | Liquid nitrogen washing purified synthetic gas and device for cryogenically separating and recovering LNG (liquefied natural gas) thereof | |
| CN214371298U (en) | Carbon dioxide gathering liquefaction recovery device | |
| WO2019137359A1 (en) | Lng cold energy utilization system and method based on argon cycle | |
| CN214095167U (en) | Hydrogen liquefaction equipment adopting helium refrigeration cycle system | |
| CN114518016A (en) | Carbon dioxide capturing, liquefying and recycling device and method | |
| CN202382518U (en) | Device for washing and purifying synthesis gas with liquid nitrogen and cryogenically separating and recovering LNG (liquefied natural gas) | |
| CN219607507U (en) | Natural gas liquefaction unit | |
| CN219231933U (en) | Carbon dioxide capturing and storing system based on compression enthalpy increase and interstage energy utilization | |
| CN114165987B (en) | Liquid carbon dioxide production device and production method thereof | |
| CN208042611U (en) | Helium and liquefied device are carried from natural gas | |
| CN105910387A (en) | Process device and process method for recovering cold energy from LNG prepared from coke oven gas | |
| CN205209070U (en) | Low boiling gas liquefaction and low temperature container BOG retrieve device with pressure boost | |
| CN114877619A (en) | System and method for liquefying carbon dioxide | |
| CN209910277U (en) | Unpowered cryogenic separation device |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| GR01 | Patent grant | ||
| GR01 | Patent grant |