CN108048147B - Amine liquid regeneration system and process applied to floating liquefied natural gas facility - Google Patents
Amine liquid regeneration system and process applied to floating liquefied natural gas facility Download PDFInfo
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- CN108048147B CN108048147B CN201810076347.2A CN201810076347A CN108048147B CN 108048147 B CN108048147 B CN 108048147B CN 201810076347 A CN201810076347 A CN 201810076347A CN 108048147 B CN108048147 B CN 108048147B
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- 239000007788 liquid Substances 0.000 title claims abstract description 243
- 150000001412 amines Chemical class 0.000 title claims abstract description 226
- 230000008929 regeneration Effects 0.000 title claims abstract description 100
- 238000011069 regeneration method Methods 0.000 title claims abstract description 100
- 238000000034 method Methods 0.000 title claims abstract description 21
- 239000003949 liquefied natural gas Substances 0.000 title claims abstract description 12
- 239000007789 gas Substances 0.000 claims abstract description 94
- 238000010521 absorption reaction Methods 0.000 claims abstract description 28
- 239000002918 waste heat Substances 0.000 claims abstract description 28
- 238000010992 reflux Methods 0.000 claims abstract description 26
- 238000001704 evaporation Methods 0.000 claims abstract description 9
- 230000008020 evaporation Effects 0.000 claims abstract description 9
- 239000002253 acid Substances 0.000 claims description 14
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims description 14
- 239000002994 raw material Substances 0.000 claims description 13
- 239000013535 sea water Substances 0.000 claims description 9
- 239000012071 phase Substances 0.000 claims description 7
- 239000007791 liquid phase Substances 0.000 claims description 6
- 239000000126 substance Substances 0.000 claims description 6
- 238000005191 phase separation Methods 0.000 claims description 4
- 230000001174 ascending effect Effects 0.000 claims description 3
- 238000009833 condensation Methods 0.000 claims description 3
- 230000005494 condensation Effects 0.000 claims description 3
- 150000001875 compounds Chemical class 0.000 description 3
- 230000007613 environmental effect Effects 0.000 description 3
- 239000000463 material Substances 0.000 description 3
- 239000003345 natural gas Substances 0.000 description 2
- 230000003247 decreasing effect Effects 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000000746 purification Methods 0.000 description 1
- 238000011084 recovery Methods 0.000 description 1
- 230000000630 rising effect Effects 0.000 description 1
Classifications
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- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10L—FUELS NOT OTHERWISE PROVIDED FOR; NATURAL GAS; SYNTHETIC NATURAL GAS OBTAINED BY PROCESSES NOT COVERED BY SUBCLASSES C10G, C10K; LIQUEFIED PETROLEUM GAS; ADDING MATERIALS TO FUELS OR FIRES TO REDUCE SMOKE OR UNDESIRABLE DEPOSITS OR TO FACILITATE SOOT REMOVAL; FIRELIGHTERS
- C10L3/00—Gaseous fuels; Natural gas; Synthetic natural gas obtained by processes not covered by subclass C10G, C10K; Liquefied petroleum gas
- C10L3/06—Natural gas; Synthetic natural gas obtained by processes not covered by C10G, C10K3/02 or C10K3/04
- C10L3/10—Working-up natural gas or synthetic natural gas
- C10L3/101—Removal of contaminants
- C10L3/102—Removal of contaminants of acid contaminants
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
- B01D53/14—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols by absorption
- B01D53/1425—Regeneration of liquid absorbents
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
- B01D53/14—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols by absorption
- B01D53/1456—Removing acid components
- B01D53/1462—Removing mixtures of hydrogen sulfide and carbon dioxide
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
- B01D53/14—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols by absorption
- B01D53/1493—Selection of liquid materials for use as absorbents
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
- B01D53/14—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols by absorption
- B01D53/18—Absorbing units; Liquid distributors therefor
-
- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10L—FUELS NOT OTHERWISE PROVIDED FOR; NATURAL GAS; SYNTHETIC NATURAL GAS OBTAINED BY PROCESSES NOT COVERED BY SUBCLASSES C10G, C10K; LIQUEFIED PETROLEUM GAS; ADDING MATERIALS TO FUELS OR FIRES TO REDUCE SMOKE OR UNDESIRABLE DEPOSITS OR TO FACILITATE SOOT REMOVAL; FIRELIGHTERS
- C10L3/00—Gaseous fuels; Natural gas; Synthetic natural gas obtained by processes not covered by subclass C10G, C10K; Liquefied petroleum gas
- C10L3/06—Natural gas; Synthetic natural gas obtained by processes not covered by C10G, C10K3/02 or C10K3/04
- C10L3/10—Working-up natural gas or synthetic natural gas
- C10L3/101—Removal of contaminants
- C10L3/102—Removal of contaminants of acid contaminants
- C10L3/103—Sulfur containing contaminants
-
- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10L—FUELS NOT OTHERWISE PROVIDED FOR; NATURAL GAS; SYNTHETIC NATURAL GAS OBTAINED BY PROCESSES NOT COVERED BY SUBCLASSES C10G, C10K; LIQUEFIED PETROLEUM GAS; ADDING MATERIALS TO FUELS OR FIRES TO REDUCE SMOKE OR UNDESIRABLE DEPOSITS OR TO FACILITATE SOOT REMOVAL; FIRELIGHTERS
- C10L3/00—Gaseous fuels; Natural gas; Synthetic natural gas obtained by processes not covered by subclass C10G, C10K; Liquefied petroleum gas
- C10L3/06—Natural gas; Synthetic natural gas obtained by processes not covered by C10G, C10K3/02 or C10K3/04
- C10L3/10—Working-up natural gas or synthetic natural gas
- C10L3/101—Removal of contaminants
- C10L3/102—Removal of contaminants of acid contaminants
- C10L3/104—Carbon dioxide
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D2252/00—Absorbents, i.e. solvents and liquid materials for gas absorption
- B01D2252/20—Organic absorbents
- B01D2252/204—Amines
Landscapes
- Chemical & Material Sciences (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Chemical Kinetics & Catalysis (AREA)
- Engineering & Computer Science (AREA)
- General Chemical & Material Sciences (AREA)
- Analytical Chemistry (AREA)
- Organic Chemistry (AREA)
- Gas Separation By Absorption (AREA)
- Treating Waste Gases (AREA)
Abstract
The invention relates to an amine liquid regeneration system and a process applied to a floating liquefied natural gas facility, wherein the system comprises an amine liquid absorption tower, the top outlet of the amine liquid absorption tower is connected with the hot flow inlet of a treatment gas heat exchanger, the hot flow outlet of the treatment gas heat exchanger is connected with the inlet of a treatment gas buffer tank, the bottom liquid outlet of the treatment gas buffer tank is converged with the bottom outlet of the amine liquid absorption tower and then is connected to the cold flow inlet of a waste heat utilization heat exchanger, the cold flow outlet of the waste heat utilization heat exchanger is connected with the inlet of an amine liquid flash evaporation tower, the cold flow outlet of a lean amine liquid heat exchanger is connected with the inlet of the amine liquid regeneration tower, the top outlet of the amine liquid regeneration tower is connected with the hot flow inlet of the waste heat utilization heat exchanger, the hot flow outlet of the waste heat utilization heat exchanger is connected with the hot flow inlet of a regeneration tower top condenser, the hot flow outlet of the regeneration tower top condenser is connected with the inlet of a regeneration tower reflux tank, and the bottom liquid outlet of the regeneration tower reflux tank is connected with the inlet of the amine liquid regeneration tower through a reflux pump.
Description
Technical Field
The invention relates to an amine liquid regeneration system and process applied to a floating liquefied natural gas facility.
Background
In the natural gas purification process of FLNG (floating liquefied natural gas facility), the raw gas is usually deacidified by an amine method in a chemical absorption method, namely, a weak alkaline amine liquidWith acid gases (mainly H) in natural gas 2 S and CO 2 ) And reacting to form a compound. Then, when the temperature and pressure of the rich amine liquid absorbing the acid gas are increased and decreased, the compound is decomposed to release the acid gas, and the rich amine liquid is regenerated into lean amine liquid.
The amine liquid regeneration tower heats the rich amine liquid entering the regeneration tower from the tower top by using the rising hot gas heated by the tower bottom reboiler, so that the compounds are decomposed to release acid gas, and the lean amine liquid is regenerated. The evaporated acid gas (with amine liquid steam) enters a regeneration tower reflux tank through a tower top seawater condenser, the uncondensed acid gas leaves the regenerator reflux tank through a demister and enters an incinerator, and liquid at the bottom of the reflux tank is pumped to the top of the regeneration tower by a reflux pump. The acid gas evaporated from the top of the regeneration tower is cooled from 97 ℃ to 50 ℃ by a seawater condenser. A large amount of heat is taken away by the seawater, so that on one hand, a large amount of latent heat cannot be effectively utilized, and on the other hand, the seawater is unfavorable for environmental protection, and therefore, the heat of the part is necessary to be utilized.
Disclosure of Invention
In view of the above problems, the present invention aims to provide an amine liquid regeneration system and process applied to a floating liquefied natural gas facility, which can effectively utilize the residual heat of the gas at the top of the regeneration tower, thereby improving the heat utilization rate of the whole amine liquid regeneration system and improving the environmental protection performance to a certain extent.
In order to achieve the above purpose, the present invention adopts the following technical scheme: an amine liquid regeneration system applied to a floating liquefied natural gas facility, which is characterized in that: the system comprises an amine liquid absorption tower provided with a feed gas inlet, wherein the top outlet of the amine liquid absorption tower is connected with the hot flow inlet of a treated gas heat exchanger, the hot flow outlet of the treated gas heat exchanger is connected with the inlet of a treated gas buffer tank, the top gas outlet of the treated gas buffer tank is connected with an incinerator, the bottom liquid outlet of the treated gas buffer tank is connected with the bottom outlet of the amine liquid absorption tower after being converged and then connected to the cold flow inlet of a waste heat utilization heat exchanger, the cold flow outlet of the waste heat utilization heat exchanger is connected with the inlet of an amine liquid flash tower, the top gas outlet of the amine liquid flash tower is connected with the incinerator, the bottom liquid outlet of the amine liquid flash tower is connected with the cold flow inlet of a lean-rich amine liquid heat exchanger, the cold flow outlet of the lean-rich amine liquid heat exchanger is connected with the inlet of an amine liquid regeneration tower, the top outlet of the amine liquid regeneration tower is connected with the hot flow inlet of the waste heat utilization heat exchanger, the hot flow outlet of the waste heat utilization heat exchanger is connected with the hot flow inlet of a regeneration tower top condenser, the heat outlet of the regeneration tower is connected with the inlet of a reflux tower, and the reflux liquid of the regeneration tower is connected with the bottom of the reflux tower through the reflux pump; the bottom outlet of the amine liquid regeneration tower is connected with a cold flow inlet of a reboiler at the bottom of the regeneration tower, a hot flow inlet of the reboiler at the bottom of the regeneration tower is connected with a hot flow inlet of the lean amine liquid heat exchanger after being converged with a lean amine liquid outlet at the bottom of the amine liquid regeneration tower, the hot flow outlet of the lean amine liquid heat exchanger is connected with an inlet of a lean amine liquid cooler, an outlet of the lean amine liquid cooler is connected with an inlet of an amine liquid storage tank, an outlet of the amine liquid storage tank is connected with an inlet of a lean amine liquid high-pressure pump, and an outlet of the lean amine liquid high-pressure pump is connected with an inlet of the amine liquid absorption tower.
And a cold flow outlet of the lean-rich amine liquid heat exchanger is also connected with an inlet of the amine liquid flash tower.
And a cold flow outlet of the reboiler at the bottom of the regeneration tower is also connected with an inlet of the amine liquid regeneration tower.
An amine liquid regeneration process applied to a floating liquefied natural gas facility comprises the following steps: 1) Introducing the raw material gas into an amine liquid absorption tower, enabling the raw material gas to be in contact with lean amine liquid in the amine liquid absorption tower for deacidification, enabling the deacidified raw material gas to enter a treated gas heat exchanger for heat exchange with seawater, and enabling the cooled raw material gas to enter a treated gas buffer tank; after merging the liquid substance at the bottom of the treatment gas buffer tank with the rich amine liquid flowing out of the bottom of the amine liquid absorption tower, enabling the liquid substance to enter a waste heat utilization heat exchanger for heat exchange, enabling the rich amine liquid after heat exchange and temperature rise to enter an amine liquid flash evaporation tower for crude acid gas removal, and separating out methane and CO in the flash evaporation process 2 Gas entryThe incinerator, the rich amine liquid after flash evaporation is heated by lean amine liquid in a lean amine liquid heat exchanger, and then enters an amine liquid regeneration tower; 2) The rich amine liquid entering the amine liquid regeneration tower is heated by the ascending gas heated by the reboiler at the bottom of the regeneration tower, and is decomposed to release acid gas; the gas enters a waste heat utilization heat exchanger to exchange heat with rich amine liquid which is ready to enter an amine liquid flash tower, then enters a regeneration tower top condenser, enters a regeneration tower reflux tank to carry out gas phase and liquid phase separation after condensation, and the separated gas part enters an incinerator, and the liquid returns to the amine liquid regeneration tower through a reflux pump; 3) The lean amine liquid flowing out from the reboiler at the bottom of the amine liquid regeneration tower and the regeneration tower is heated by a lean amine liquid heat exchanger to prepare the rich amine liquid entering the amine liquid regeneration tower, the lean amine liquid after heat exchange is cooled by a lean amine liquid cooler, and then is pumped to an amine liquid absorption tower by a lean amine liquid high-pressure pump.
Due to the adoption of the technical scheme, the invention has the following advantages: 1. the invention can reduce the heat load of the reboiler at the bottom of the regeneration tower because the temperature of the rich amine liquid entering the top of the amine liquid regeneration tower is increased. 2. The invention realizes the waste heat utilization of the tower top gas of the amine liquid regeneration tower through the waste heat utilization heat exchanger, thereby reducing the heat exchange load of the seawater of the condenser at the regeneration tower top, reducing the equipment investment and the operation cost and achieving the aim of environmental protection. 3. According to the invention, an amine liquid flash tank in the existing amine liquid regeneration process is replaced by an amine liquid flash tower, part of the rich amine liquid heated by the lean amine liquid is connected back to the amine liquid flash tower, the rich amine liquid in the tower is heated and coarsely removed, and for an FLNG device, the regeneration efficiency of a subsequent amine liquid regeneration tower can be better ensured. 4. The invention utilizes the waste heat utilization heat exchanger to increase the temperature of the rich amine liquid entering the amine liquid flash tower, thereby increasing CO 2 And methane evolution.
Drawings
FIG. 1 is a schematic illustration of the process flow of the present invention.
Detailed Description
The present invention will be described in detail with reference to the accompanying drawings and examples.
The invention provides an amine liquid regeneration system applied to a floating liquefied natural gas facility, which comprises an amine liquid absorption tower a provided with a raw material gas inlet, wherein the top outlet of the amine liquid absorption tower a is connected with the hot flow inlet of a treatment gas heat exchanger b, the hot flow outlet of the treatment gas heat exchanger b is connected with the inlet of a treatment gas buffer tank c, the top gas outlet of the treatment gas buffer tank c is connected with an incinerator, the bottom liquid outlet of the treatment gas buffer tank c is connected with the cold flow inlet of a waste heat utilization heat exchanger d after being converged with the bottom outlet of the amine liquid absorption tower a, the cold flow outlet of the waste heat utilization heat exchanger d is connected with the inlet of an amine liquid flash tower e, the top gas outlet of the amine liquid flash tower e is connected with the incinerator, the bottom liquid outlet of the amine liquid flash tower e is connected with the cold flow inlet of a lean rich amine liquid heat exchanger f, the cold flow outlet of the lean amine liquid heat exchanger f is connected with the inlet of an amine liquid regeneration tower g, the top outlet of the amine liquid regeneration tower g is connected with the hot flow inlet of the waste heat utilization heat exchanger d, the hot flow outlet of the waste heat utilization heat exchanger d is connected with the inlet of a top condenser h of the tower, and the top of the heat recovery tower h is connected with the reflux tower i through the reflux tower is connected with the reflux tower i; the bottom outlet of the amine liquid regeneration tower g is connected with the cold flow inlet of a reboiler k at the bottom of the regeneration tower, a heat medium passes through from the hot flow inlet to the hot flow outlet of the reboiler k at the bottom of the regeneration tower, the cold flow outlet of the reboiler k at the bottom of the regeneration tower is converged with the lean amine liquid outlet at the bottom of the amine liquid regeneration tower g and then is connected to the hot flow inlet of a lean amine liquid heat exchanger f, the inlet of a lean amine liquid cooler l at the hot flow outlet of the lean amine liquid heat exchanger f is connected, the outlet of the lean amine liquid cooler l is connected with the inlet of an amine liquid storage tank m, the outlet of the amine liquid storage tank m is connected with the inlet of a lean amine liquid high-pressure pump n, and the outlet of the lean amine liquid high-pressure pump n is connected with the inlet of an amine liquid absorption tower a.
Further, the cold flow outlet of the lean-rich amine liquid heat exchanger f is also connected with the inlet of the amine liquid flash tower e, so that a small part of the rich amine liquid flowing out from the bottom of the amine liquid flash tower e flows back to the amine liquid flash tower e after being heated by the lean amine liquid.
Further, the cold flow outlet of the regeneration tower bottom reboiler k is also connected to the inlet of the amine liquid regeneration tower g.
Based on the amine liquid regeneration system applied to the floating liquefied natural gas facility, the invention also provides an amine liquid regeneration process, which comprises the following steps:
1) Introducing raw material gas into an amine liquid absorption tower a, enabling the raw material gas to be in contact with lean amine liquid in the amine liquid absorption tower a for deacidification, enabling the deacidified raw material gas to enter a treated gas heat exchanger b for heat exchange with seawater, and enabling the cooled raw material gas to enter a treated gas buffer tank c; after merging the liquid substance at the bottom of the treatment gas buffer tank c with the rich amine liquid flowing out of the bottom of the amine liquid absorption tower a, the rich amine liquid enters a waste heat utilization heat exchanger d for heat exchange, the rich amine liquid after heat exchange and temperature rise enters an amine liquid flash evaporation tower e for acid gas crude removal, and methane and CO separated in the flash evaporation process are separated 2 The gas enters an incinerator, and the flash-evaporated rich amine liquid is heated by lean amine liquid in a lean amine liquid heat exchanger f and then enters an amine liquid regeneration tower g;
2) The rich amine liquid entering the amine liquid regeneration tower g is heated by the ascending gas heated by the reboiler k at the bottom of the regeneration tower, and is decomposed to release acid gas; the gas enters a waste heat utilization heat exchanger d to exchange heat with rich amine liquid which is ready to enter an amine liquid flash tower e, then enters a regeneration tower top condenser h, enters a regeneration tower reflux tank i to carry out gas phase and liquid phase separation after condensation, and the separated gas part enters an incinerator, and the liquid returns to an amine liquid regeneration tower g through a reflux pump j;
3) The lean amine liquid flowing out from the amine liquid regeneration tower g and the reboiler k at the bottom of the regeneration tower firstly enters a lean amine liquid heat exchanger f to heat the rich amine liquid which enters the amine liquid regeneration tower g, the lean amine liquid after heat exchange is cooled by a lean amine liquid cooler l, and then is sent to an amine liquid absorption tower a by a lean amine liquid high-pressure pump n.
The process of the invention is an improvement to the existing process, and the differences relative to the existing process are as follows:
(1) The top gas of the amine liquid regeneration tower g is connected to a heat flow inlet of the waste heat utilization heat exchanger d, the temperature of the top gas of the amine liquid regeneration tower g is reduced from about 100 ℃ to about 82 ℃, and the heat of the top gas of the tower is recovered;
(2) The tower top gas enters a regeneration tower top condenser h to exchange heat to 50 ℃ after heat exchange;
(3) The condensed tower top gas enters a regeneration tower reflux tank i for gas phase and liquid phase separation;
(4) In the step (3), the gas phase obtained by separating the gas phase from the liquid phase contains a large amount of CO 2 And H 2 S, CO is carried out in gas phase 2 Is discharged after being trapped or purified, and the liquid phase material is conveyed to the top of the regeneration tower through a reflux pump j;
(5) An inlet material flow of an amine liquid flash tower e is connected to a cold flow inlet of a waste heat utilization heat exchanger d, and the temperature of the amine liquid entering the tower is increased by about 10 ℃ through heat exchange;
(6) The heated rich amine liquid after heat exchange enters an amine liquid flash tower e;
(7) In the lean-rich amine liquid heat exchanger f, the rich amine liquid is heated by the lean amine liquid to be heated to about 83 ℃, and the rich amine liquid is subjected to crude acid gas removal in the amine liquid flash tower e;
(8) The flash gas at the top of the tower in the step (7) contains about 78 ℃, and directly enters an incinerator without preheating, so that heat is saved;
(9) The rich amine liquid at the bottom of the amine liquid flash tower e in the step (8) enters a lean-rich amine liquid heat exchanger f, and exchanges heat from about 78 ℃ to about 110 ℃;
(10) And (5) feeding the heated rich amine liquid into an amine liquid regeneration tower g.
In the step (2), the heat exchange and the temperature rise of the tower top material flow are carried out through the waste heat utilization heat exchanger d, so that the heat exchange load of the seawater in the regenerated tower top condenser h is reduced.
In the steps (6) and (7), the temperature of the rich amine liquid entering the amine liquid flash tower e is increased, so that CO is more separated out from the flash gas in the step (7) than that in the original process flow 2 And methane gas.
In the step (10), the temperature of the rich amine liquid entering the top of the amine liquid regeneration tower g is higher than that of the original process flow, and the heat load of a reboiler k at the bottom of the regeneration tower is reduced after the rough stripping of the amine liquid flash tower e is carried out.
The foregoing embodiments are only illustrative of the present invention, and the implementation steps of the method may be changed, and all equivalent changes and modifications performed on the basis of the technical solution of the present invention should not be excluded from the protection scope of the present invention.
Claims (2)
1. An amine liquid regeneration system applied to a floating liquefied natural gas facility, which is characterized in that: the system comprises an amine liquid absorption tower provided with a feed gas inlet, wherein the top outlet of the amine liquid absorption tower is connected with the hot flow inlet of a treated gas heat exchanger, the hot flow outlet of the treated gas heat exchanger is connected with the inlet of a treated gas buffer tank, the top gas outlet of the treated gas buffer tank is connected with an incinerator, the bottom liquid outlet of the treated gas buffer tank is connected with the bottom outlet of the amine liquid absorption tower after being converged and then connected to the cold flow inlet of a waste heat utilization heat exchanger, the cold flow outlet of the waste heat utilization heat exchanger is connected with the inlet of an amine liquid flash tower, the top gas outlet of the amine liquid flash tower is connected with the incinerator, the bottom liquid outlet of the amine liquid flash tower is connected with the cold flow inlet of a lean-rich amine liquid heat exchanger, the cold flow outlet of the lean-rich amine liquid heat exchanger is connected with the inlet of an amine liquid regeneration tower, the top outlet of the amine liquid regeneration tower is connected with the hot flow inlet of the waste heat utilization heat exchanger, the hot flow outlet of the waste heat utilization heat exchanger is connected with the hot flow inlet of a regeneration tower top condenser, the heat outlet of the regeneration tower is connected with the inlet of a reflux tower, and the reflux liquid of the regeneration tower is connected with the bottom of the reflux tower through the reflux pump; the bottom outlet of the amine liquid regeneration tower is connected with a cold flow inlet of a reboiler at the bottom of the regeneration tower, a hot flow inlet of the reboiler at the bottom of the regeneration tower is connected with a hot flow inlet of a lean amine liquid heat exchanger after being converged with a lean amine liquid outlet at the bottom of the amine liquid regeneration tower, the hot flow outlet of the lean amine liquid heat exchanger is connected with an inlet of a lean amine liquid cooler, an outlet of the lean amine liquid cooler is connected with an inlet of an amine liquid storage tank, an outlet of the amine liquid storage tank is connected with an inlet of a lean amine liquid high-pressure pump, and an outlet of the lean amine liquid high-pressure pump is connected with an inlet of the amine liquid absorption tower;
the cold flow outlet of the lean-rich amine liquid heat exchanger is also connected with the inlet of the amine liquid flash tower, so that a small part of the rich amine liquid flowing out from the bottom of the amine liquid flash tower flows back to the amine liquid flash tower after being heated by the lean amine liquid, and the rich amine liquid is primarily removed;
and a cold flow outlet of the reboiler at the bottom of the regeneration tower is also connected with an inlet of the amine liquid regeneration tower.
2. An amine liquid regeneration process based on the amine liquid regeneration system of claim 1 applied to a floating lng facility, comprising the steps of:
1) Introducing the raw material gas into an amine liquid absorption tower, enabling the raw material gas to be in contact with lean amine liquid in the amine liquid absorption tower for deacidification, enabling the deacidified raw material gas to enter a treated gas heat exchanger for heat exchange with seawater, and enabling the cooled raw material gas to enter a treated gas buffer tank; after merging a liquid substance at the bottom of the treatment gas buffer tank with rich amine liquid flowing out of the bottom of the amine liquid absorption tower, enabling the liquid substance to enter a waste heat utilization heat exchanger for heat exchange, enabling the rich amine liquid subjected to heat exchange and temperature rise to enter an amine liquid flash evaporation tower for acid gas coarse removal, enabling methane and CO2 gas separated out in the flash evaporation process to enter an incinerator, enabling the rich amine liquid subjected to flash evaporation to be heated by the lean amine liquid in a lean rich amine liquid heat exchanger, and then enabling the rich amine liquid to enter an amine liquid regeneration tower;
2) The rich amine liquid entering the amine liquid regeneration tower is heated by the ascending gas heated by the reboiler at the bottom of the regeneration tower, and is decomposed to release acid gas; the gas enters a waste heat utilization heat exchanger to exchange heat with rich amine liquid which is ready to enter an amine liquid flash tower, then enters a regeneration tower top condenser, enters a regeneration tower reflux tank to carry out gas phase and liquid phase separation after condensation, and the separated gas part enters an incinerator, and the liquid returns to the amine liquid regeneration tower through a reflux pump;
3) The lean amine liquid flowing out from the reboiler at the bottom of the amine liquid regeneration tower and the regeneration tower is heated by a lean amine liquid heat exchanger to prepare the rich amine liquid entering the amine liquid regeneration tower, the lean amine liquid after heat exchange is cooled by a lean amine liquid cooler, and then is pumped to an amine liquid absorption tower by a lean amine liquid high-pressure pump.
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| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201810076347.2A CN108048147B (en) | 2018-01-26 | 2018-01-26 | Amine liquid regeneration system and process applied to floating liquefied natural gas facility |
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| CN201810076347.2A CN108048147B (en) | 2018-01-26 | 2018-01-26 | Amine liquid regeneration system and process applied to floating liquefied natural gas facility |
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| CN108048147A CN108048147A (en) | 2018-05-18 |
| CN108048147B true CN108048147B (en) | 2023-11-21 |
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| CN110201490A (en) * | 2019-06-21 | 2019-09-06 | 江苏新海石化有限公司 | A kind of amine liquid regenerative system |
| CN110527572B (en) * | 2019-09-11 | 2024-09-06 | 张家港富瑞特种装备股份有限公司 | Natural gas deacidification module |
| CN116445196B (en) * | 2023-04-03 | 2024-03-19 | 广州兴丰能源科技有限公司 | Method and device for efficiently regenerating amine liquid of coupling heat pump |
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