CN109173595B - Method for recovering pressure energy of light hydrocarbon separation device - Google Patents
Method for recovering pressure energy of light hydrocarbon separation device Download PDFInfo
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- CN109173595B CN109173595B CN201811031353.2A CN201811031353A CN109173595B CN 109173595 B CN109173595 B CN 109173595B CN 201811031353 A CN201811031353 A CN 201811031353A CN 109173595 B CN109173595 B CN 109173595B
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- 238000000034 method Methods 0.000 title claims abstract description 67
- 239000004215 Carbon black (E152) Substances 0.000 title claims abstract description 63
- 229930195733 hydrocarbon Natural products 0.000 title claims abstract description 62
- 150000002430 hydrocarbons Chemical class 0.000 title claims abstract description 62
- 238000000926 separation method Methods 0.000 title claims abstract description 26
- 230000002745 absorbent Effects 0.000 claims abstract description 155
- 239000002250 absorbent Substances 0.000 claims abstract description 155
- 239000007788 liquid Substances 0.000 claims abstract description 105
- 238000011084 recovery Methods 0.000 claims abstract description 73
- 238000003795 desorption Methods 0.000 claims abstract description 45
- 238000010521 absorption reaction Methods 0.000 claims abstract description 44
- 239000013589 supplement Substances 0.000 claims abstract description 3
- 239000012535 impurity Substances 0.000 claims description 40
- 230000002378 acidificating effect Effects 0.000 claims description 29
- 239000000463 material Substances 0.000 claims description 16
- 239000002253 acid Substances 0.000 claims description 8
- HZAXFHJVJLSVMW-UHFFFAOYSA-N 2-Aminoethan-1-ol Chemical compound NCCO HZAXFHJVJLSVMW-UHFFFAOYSA-N 0.000 claims description 7
- LVTYICIALWPMFW-UHFFFAOYSA-N diisopropanolamine Chemical compound CC(O)CNCC(C)O LVTYICIALWPMFW-UHFFFAOYSA-N 0.000 claims description 6
- 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 claims description 3
- 102100032373 Coiled-coil domain-containing protein 85B Human genes 0.000 claims description 3
- 101000868814 Homo sapiens Coiled-coil domain-containing protein 85B Proteins 0.000 claims description 3
- QMMZSJPSPRTHGB-UHFFFAOYSA-N MDEA Natural products CC(C)CCCCC=CCC=CC(O)=O QMMZSJPSPRTHGB-UHFFFAOYSA-N 0.000 claims description 3
- 229940043276 diisopropanolamine Drugs 0.000 claims description 3
- CRVGTESFCCXCTH-UHFFFAOYSA-N methyl diethanolamine Chemical compound OCCN(C)CCO CRVGTESFCCXCTH-UHFFFAOYSA-N 0.000 claims description 3
- 230000008929 regeneration Effects 0.000 claims description 3
- 238000011069 regeneration method Methods 0.000 claims description 3
- ZBCBWPMODOFKDW-UHFFFAOYSA-N diethanolamine Chemical compound OCCNCCO ZBCBWPMODOFKDW-UHFFFAOYSA-N 0.000 claims description 2
- 238000002309 gasification Methods 0.000 claims description 2
- 238000010438 heat treatment Methods 0.000 claims description 2
- 230000001050 lubricating effect Effects 0.000 claims description 2
- 230000006837 decompression Effects 0.000 claims 1
- 230000005611 electricity Effects 0.000 abstract description 4
- 238000005265 energy consumption Methods 0.000 abstract description 4
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 description 84
- 239000007789 gas Substances 0.000 description 45
- 229910002092 carbon dioxide Inorganic materials 0.000 description 42
- 239000001569 carbon dioxide Substances 0.000 description 26
- RWSOTUBLDIXVET-UHFFFAOYSA-N Dihydrogen sulfide Chemical compound S RWSOTUBLDIXVET-UHFFFAOYSA-N 0.000 description 24
- 239000000203 mixture Substances 0.000 description 15
- 230000008901 benefit Effects 0.000 description 11
- 238000004523 catalytic cracking Methods 0.000 description 9
- 239000000243 solution Substances 0.000 description 9
- 230000000694 effects Effects 0.000 description 8
- JYLMMZCUGDOOEV-UHFFFAOYSA-N ethane ethene methane Chemical compound C.CC.C=C JYLMMZCUGDOOEV-UHFFFAOYSA-N 0.000 description 7
- UFHFLCQGNIYNRP-UHFFFAOYSA-N Hydrogen Chemical compound [H][H] UFHFLCQGNIYNRP-UHFFFAOYSA-N 0.000 description 6
- 238000004517 catalytic hydrocracking Methods 0.000 description 6
- 230000003111 delayed effect Effects 0.000 description 6
- 229910000037 hydrogen sulfide Inorganic materials 0.000 description 6
- 238000004519 manufacturing process Methods 0.000 description 6
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 6
- VGGSQFUCUMXWEO-UHFFFAOYSA-N Ethene Chemical compound C=C VGGSQFUCUMXWEO-UHFFFAOYSA-N 0.000 description 5
- 239000005977 Ethylene Substances 0.000 description 5
- 239000003921 oil Substances 0.000 description 5
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 description 4
- 229910052799 carbon Inorganic materials 0.000 description 4
- 238000004939 coking Methods 0.000 description 3
- MEKDPHXPVMKCON-UHFFFAOYSA-N ethane;methane Chemical compound C.CC MEKDPHXPVMKCON-UHFFFAOYSA-N 0.000 description 3
- 239000003345 natural gas Substances 0.000 description 3
- 238000005504 petroleum refining Methods 0.000 description 3
- QQONPFPTGQHPMA-UHFFFAOYSA-N propylene Natural products CC=C QQONPFPTGQHPMA-UHFFFAOYSA-N 0.000 description 3
- 125000004805 propylene group Chemical group [H]C([H])([H])C([H])([*:1])C([H])([H])[*:2] 0.000 description 3
- 238000007670 refining Methods 0.000 description 3
- 239000010779 crude oil Substances 0.000 description 2
- 125000004122 cyclic group Chemical group 0.000 description 2
- IJDNQMDRQITEOD-UHFFFAOYSA-N n-butane Chemical compound CCCC IJDNQMDRQITEOD-UHFFFAOYSA-N 0.000 description 2
- 238000004064 recycling Methods 0.000 description 2
- 238000011282 treatment Methods 0.000 description 2
- OVHUTIJPHWTHKJ-UHFFFAOYSA-N 2-methylpropane;propane Chemical compound CCC.CC(C)C OVHUTIJPHWTHKJ-UHFFFAOYSA-N 0.000 description 1
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 1
- 239000006096 absorbing agent Substances 0.000 description 1
- 150000001412 amines Chemical class 0.000 description 1
- 239000007864 aqueous solution Substances 0.000 description 1
- 239000006227 byproduct Substances 0.000 description 1
- GVIZPQPIQBULQX-UHFFFAOYSA-N carbon dioxide;sulfane Chemical compound S.O=C=O GVIZPQPIQBULQX-UHFFFAOYSA-N 0.000 description 1
- 230000000052 comparative effect Effects 0.000 description 1
- 239000002131 composite material Substances 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 239000002283 diesel fuel Substances 0.000 description 1
- 229910001873 dinitrogen Inorganic materials 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- HXVPQBRDTHLINI-UHFFFAOYSA-N ethene methane propane prop-1-ene Chemical group C.C=C.CCC.CC=C HXVPQBRDTHLINI-UHFFFAOYSA-N 0.000 description 1
- PBOWCAALSKGVJD-UHFFFAOYSA-N ethene propane prop-1-ene Chemical group C=C.C=CC.CCC PBOWCAALSKGVJD-UHFFFAOYSA-N 0.000 description 1
- -1 ethylene, propylene Chemical group 0.000 description 1
- 238000005194 fractionation Methods 0.000 description 1
- 239000000446 fuel Substances 0.000 description 1
- 239000003502 gasoline Substances 0.000 description 1
- 239000003350 kerosene Substances 0.000 description 1
- 239000010687 lubricating oil Substances 0.000 description 1
- 239000012528 membrane Substances 0.000 description 1
- 239000003209 petroleum derivative Substances 0.000 description 1
- 229920000642 polymer Polymers 0.000 description 1
- JTXAHXNXKFGXIT-UHFFFAOYSA-N propane;prop-1-ene Chemical group CCC.CC=C JTXAHXNXKFGXIT-UHFFFAOYSA-N 0.000 description 1
- GLZMKXXGMQLDOI-UHFFFAOYSA-N propane;sulfane Chemical compound S.CCC GLZMKXXGMQLDOI-UHFFFAOYSA-N 0.000 description 1
- 239000002904 solvent Substances 0.000 description 1
- 238000010977 unit operation Methods 0.000 description 1
- 238000004148 unit process Methods 0.000 description 1
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Classifications
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- 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
- B01D53/1475—Removing 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
- B01D53/1425—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
- B01D53/1468—Removing hydrogen sulfide
-
- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G70/00—Working-up undefined normally gaseous mixtures obtained by processes covered by groups C10G9/00, C10G11/00, C10G15/00, C10G47/00, C10G51/00
- C10G70/04—Working-up undefined normally gaseous mixtures obtained by processes covered by groups C10G9/00, C10G11/00, C10G15/00, C10G47/00, C10G51/00 by physical processes
- C10G70/06—Working-up undefined normally gaseous mixtures obtained by processes covered by groups C10G9/00, C10G11/00, C10G15/00, C10G47/00, C10G51/00 by physical processes by gas-liquid contact
-
- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
- C10G2300/20—Characteristics of the feedstock or the products
- C10G2300/201—Impurities
-
- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
- C10G2300/20—Characteristics of the feedstock or the products
- C10G2300/201—Impurities
- C10G2300/207—Acid gases, e.g. H2S, COS, SO2, HCN
-
- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G2400/00—Products obtained by processes covered by groups C10G9/00 - C10G69/14
- C10G2400/20—C2-C4 olefins
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- Chemical & Material Sciences (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Engineering & Computer Science (AREA)
- General Chemical & Material Sciences (AREA)
- Chemical Kinetics & Catalysis (AREA)
- Analytical Chemistry (AREA)
- Organic Chemistry (AREA)
- Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
- Gas Separation By Absorption (AREA)
Abstract
The invention relates to a method for recovering pressure energy by a light hydrocarbon separation device, which mainly solves the problems of high energy consumption and high power and electricity charges in the prior art. The invention adopts a method for recovering pressure energy by a light hydrocarbon separation device, a pressure recovery device is additionally arranged between an absorption tower and a desorption tower, the pressure recovery device recovers the pressure energy of a high-pressure rich liquid absorbent and utilizes the pressure energy of a low-temperature lean liquid absorbent, and an auxiliary motor of the pressure recovery device is adopted to supplement insufficient pressure energy, so that the technical scheme of saving external energy and power cost is adopted to better solve the problems, and the method can be used in the light hydrocarbon separation device.
Description
Technical Field
The invention relates to a method for recovering pressure energy by a light hydrocarbon separation device.
Background
At present, in the oil refining process production devices of a catalytic cracking FCC device, a catalytic cracking DCC device, a delayed coking device, a hydrocracking device and the like in the oil refining industry in the crude oil processing process, the produced crude oil is subjected to a series of processing treatments to prepare petroleum products such as gasoline, kerosene, diesel oil, solvent oil and lubricating oil for fuel, and various process refinery gases are by-produced. The process refinery gas is rich in light hydrocarbon gases such as ethylene, propylene and the like, and also contains acidic impurities such as hydrogen sulfide H2S and carbon dioxide CO2, wherein the content of the hydrogen sulfide H2S is 0.3-1.9 vol%, and the content of the carbon dioxide CO2 is 0.0-4.1 vol%. In order to recover the abundant ethylene and propylene contained in the light hydrocarbon gas and prepare the polymer-grade ethylene and the polymer-grade propylene, the acidic impurities of hydrogen sulfide H2S and carbon dioxide CO2 in the light hydrocarbon gas are generally required to be removed.
In the prior art, a reproducible ethanolamine method absorbent is usually adopted to absorb and remove acidic impurities, namely hydrogen sulfide H2S and carbon dioxide CO2, from light hydrocarbon gas, so that the acidic impurities, namely hydrogen sulfide H2S and carbon dioxide CO2, in the light hydrocarbon gas are ensured to be removed to meet the quality standard required by the process. When absorbing acidic impurities such as hydrogen sulfide H2S and carbon dioxide CO2 by an ethanolamine method, the process parameters adopt low temperature and high pressure, and an absorbent can absorb and dissolve a large amount of acidic impurities to become a rich liquid absorbent; when desorbing acidic impurities such as hydrogen sulfide H2S and carbon dioxide CO2, the process parameters adopt high temperature and low pressure, and the absorbent can desorb and release a large amount of acidic impurities to become a barren solution absorbent. Therefore, the absorbent with different process parameters is used for separating the acidic impurities, namely hydrogen sulfide H2S and carbon dioxide CO2, from the light hydrocarbon gas in the light hydrocarbon separation device, and the absorbent can be recycled.
In the prior art, cn03153659.x is a fractionation method for separating liquid hydrocarbon mixtures, and discloses a technical scheme for separating hydrocarbon mixtures by adopting two-step process flows of a light component removal process, a heavy component removal process and a rectification process. CN200910212788.1 discloses a method for deeply removing carbon dioxide from a gas mixture. A composite amine aqueous solution is used as an absorbent, raw gas containing 22 vol% is subjected to absorption treatment for removing carbon dioxide, and the carbon dioxide content of the purified mixed gas is reduced to 0.04-0.80 vol%. CN201310149170.1 discloses a method for removing hydrogen sulfide from crude carbon dioxide by using a heat pump circulation method. CN 201410526096.5A method for improving separation efficiency of associated gas in oil field and recovering carbon dioxide discloses that a double-membrane separator is adopted to purify light hydrocarbon and carbon dioxide in non-condensable gas respectively, three functions of improving light hydrocarbon recovery efficiency, reducing device operation load brought by carbon dioxide and decarbonizing natural gas are realized in the same device, light hydrocarbon yield can reach more than 30%, natural gas carbon dioxide concentration is reduced to below 2%, and natural gas loss rate is less than 0.5%. CN201410573730.0 discloses a method for separating carbon dioxide 'light' impurities and hydrogen sulfide 'heavy' impurities by adopting a heat pump circulation process.
In the unit operation of removing the acid impurities in the light hydrocarbon gas by the light hydrocarbon separation device, when the acid impurities, namely hydrogen sulfide H2S and carbon dioxide CO2, in the light hydrocarbon gas are removed by adopting absorbents with different pressure and temperature process parameters, the absorbents are repeatedly recycled. When the high-pressure rich liquid absorbent is recycled, the high-pressure rich liquid absorbent at the tower bottom outlet of the high-pressure absorption tower is decompressed by a pressure reducing valve and then is sent to the tower top inlet of the low-pressure desorption tower, and the pressure energy of the rich liquid absorbent is wasted; the low-pressure barren solution absorbent at the bottom outlet of the low-pressure desorption tower can be sent to the top inlet of the high-pressure absorption tower only after being pressurized by external input energy, so that the pressurization of the barren solution absorbent is realized by external input energy.
Cn03153659.x and CN200910212788.1 and CN201310149170.1 and CN201410526096.5 and CN201410573730.0 only disclose technical solutions for completing light hydrocarbon separation and removing acidic impurities, hydrogen sulfide H2S and carbon dioxide CO2, and there is no technical method for pressure recovery in the process of removing acidic impurities by a light hydrocarbon separation device, and there is no technical means for pressure recovery of the existing pressure energy by a pressure recovery device; therefore, in the operation process of the unit for removing the acid impurities in the light hydrocarbon gas by the light hydrocarbon separation device in the prior art, the problems of high operation energy consumption and high power electricity cost exist.
Disclosure of Invention
The invention aims to solve the technical problems of high energy consumption and high power electricity cost in the prior art, and provides a novel method for recovering pressure energy by a light hydrocarbon separation device, which has the advantages of low energy consumption and low power electricity cost.
In order to solve the problems, the technical scheme adopted by the invention is as follows: a method for recovering pressure energy by a light hydrocarbon separation device comprises the following steps:
(a) light hydrocarbon gas 11 from outside enters the bottom of the absorption tower 1, meanwhile, the high-pressure barren solution absorbent 26 with reduced temperature and increased pressure enters the top of the absorption tower 1, in the absorption tower 1, the light hydrocarbon gas 11 is in countercurrent contact with the high-pressure barren solution absorbent 26, acidic impurities in the light hydrocarbon gas 11 are absorbed by the high-pressure barren solution absorbent 26, and purified light hydrocarbon gas 12 with the acidic impurities removed flows out from the top of the absorption tower 1 and is sent to outside;
(b) the high-pressure rich liquid absorbent 13 for absorbing the acid impurities flows out from the bottom of the absorption tower 1 and enters the inlet of the pressure reduction end of the pressure recovery device 3; under normal operating conditions, valve 2 is closed and no material passes through the bypass line. In the pressure recovery device 3, the pressure of the high-pressure rich liquid absorbent 13 is converted from high pressure to low pressure and flows out of the pressure recovery device 3, and the low-pressure rich liquid absorbent 14 flows to the low-pressure rich liquid absorbent 15 and enters the flash tank 5;
(c) the low-pressure rich liquid absorbent 15 is flashed in the flash tank 5, the hydrocarbon organic matters are gasified and flow out from the top of the flash tank 5, and the hydrocarbon organic matters 16 are sent out; the un-gasified low-pressure rich liquid absorbent flows out from the bottom of the flash tank 5 to be a low-pressure rich liquid absorbent 17;
(d) the low-pressure rich liquid absorbent 17 enters a lean and rich absorbent heat exchanger 6, is subjected to heat exchange by the lean and rich absorbent heat exchanger 6, is heated to be a high-temperature rich liquid absorbent 18, and then enters a desorption tower 7;
(e) feeding the high-temperature rich liquid absorbent 18 into a desorption tower 7, arranging a reboiler 8 at the bottom of the desorption tower 7, feeding circulating liquid 20 at the bottom of the desorption tower into the reboiler 8 for heating and partial gasification, and returning the circulating liquid to the desorption tower 7; in the desorption tower 7, a reboiler 8 increases the temperature of the high-temperature rich liquid absorbent and enables the high-temperature rich liquid absorbent to be partially gasified, gas is in countercurrent contact with the high-temperature rich liquid absorbent to carry out gas stripping regeneration, acidic impurities in the high-temperature rich liquid absorbent are desorbed, and the acidic impurities 19 flow out of the top of the desorption tower 7 and are sent out; the low-pressure barren liquor absorbent 21 for removing the acid impurities flows out from the bottom of the desorption tower 7;
(f) the low-pressure barren liquor absorbent 21 flowing out from the bottom of the desorption tower 7 enters a barren and rich absorbent heat exchanger 6 to exchange heat and reduce the temperature; under normal operating conditions, the standby booster pump 4 is shut down, and no material passes through the bypass pipeline 25; the cooled low-temperature lean liquid absorbent 22 flows to the low-temperature lean liquid absorbent 23 and enters the pressure recovery device 3;
(g) the low-temperature lean liquid absorbent 23 enters the inlet of the pressure boosting end of the pressure recovery device 3, and the pressure of the low-temperature lean liquid absorbent 23 is converted from low pressure to high pressure in the pressure recovery device 3; under normal working conditions, the high-pressure barren liquor absorbent 24 flowing out of the pressure recovery device 3 flows to the high-pressure barren liquor absorbent 26 to return to the top of the absorption tower 1 for repeated recycling, and the acidic impurities in the light hydrocarbon gas 11 are absorbed again;
the pressure recovery device 3 is an online pressure recovery device adopting the hydraulic turbine principle, the device directly connects a pressure reduction end high-pressure side impeller and a pressure boosting end low-pressure side impeller in the same pump body through a rotating shaft, a high-pressure rich liquid absorbent at the pressure reduction end drives the pressure reduction end high-pressure side impeller, and drives the pressure boosting end low-pressure side impeller to rotate through the rotating shaft, and the pressure of a low-pressure lean liquid absorbent at the pressure boosting end is increased, so that the pressure energy at the pressure reduction end high-pressure side is converted into the mechanical energy of the rotating shaft and then into the pressure energy at the pressure boosting end low-pressure side, and the rotating shaft in the pressure recovery device 3 is the only operating part, so that the pressure recovery device 3 has no shaft seal and no additional lubricating system.
In the above technical solution, preferably, the high-pressure rich liquid absorbent 13 enters the high-pressure side inlet of the pressure reduction end of the pressure recovery device 3, and the low-temperature lean liquid absorbent 23 enters the low-pressure side inlet of the pressure increase end of the pressure recovery device 3; in the pressure recovery device 3, the "pressure energy" of the high-pressure rich liquid absorbent 13 on the high-pressure side of the pressure reduction end is first converted into the "mechanical energy" of the rotating shaft, and then converted into the "pressure energy" of the low-temperature lean liquid absorbent 23 on the low-pressure side of the pressure increase end, whereby the pressure of the low-temperature lean liquid absorbent 23 is increased and converted into the high-pressure lean liquid absorbent 24; meanwhile, the auxiliary motor of the pressure recovery device 3 is started to supplement the insufficient pressure energy, so that the pressure of the high-pressure barren liquor absorbent 24 flowing out of the high-pressure side of the pressure-boosting end of the pressure recovery device 3 meets the pressure required by the absorption operation of the absorption tower 1, and the total power consumption of an external motor is reduced.
In the above technical solution, preferably, when the pressure recovery device 3 has a fault condition, the valve 2 in the bypass closed state is opened and the backup booster pump 4 is opened when the pressure recovery device 3 is in a normal condition, the high-pressure rich liquid absorbent enters the flash tank 5 through the opened valve 2, and the low-temperature lean liquid absorbent 22 enters the top of the absorption tower 1 through the pressurization of the backup booster pump 4 and the pipeline 25; under the condition of no operation of the pressure recovery device 3, the repeated and cyclic operation and use of the absorbent between the absorption tower 1 and the desorption tower 7 are ensured.
In the technical scheme, preferably, the operating pressure range of the absorption tower 1 is 1.7-2.5 MPa, the tower top operating temperature range is 56-72 ℃, and the tower bottom operating temperature range is 58-74 ℃.
In the above technical scheme, preferably, the absorption tower 1 adopts monoethanolamine MEA with a mole fraction of 15-20%, diethanolamine DEA with a mole fraction of 25-35%, diisopropanolamine DIPA with a mole fraction of 20-25%, or methyldiethanolamine MDEA with a mole fraction of 25-30% as an absorbent.
In the technical scheme, preferably, the operating pressure range of the desorption tower 7 is 0.3-1.1 MPa, the operating temperature range of the tower top is 106-112 ℃, and the operating temperature range of the tower bottom is 108-114 ℃.
In the technical scheme, preferably, the material in the reboiler 8 at the bottom of the desorption tower 7 is heated by adopting externally supplied steam, and the material with the mass fraction of 5-25% is gasified.
In the above technical scheme, preferably, the pressure recovery device 3 has an inlet operation pressure range of 1.7-2.5 MPa at the pressure reduction end and an outlet operation pressure range of 0.4-1.2 MPa; the inlet operating pressure range of the boosting end is 0.1-0.9 MPa, and the outlet operating pressure range is 1.9-2.7 MPa.
The invention relates to a method for recovering pressure energy by a light hydrocarbon separation device, which is characterized in that a pressure recovery device 3 is additionally arranged between an absorption tower 1 and a desorption tower 7, the pressure of a high-pressure rich liquid absorbent 13 at the bottom of the absorption tower 1 is converted into a low-pressure rich liquid absorbent 14 from high pressure, and the pressure of a low-temperature lean liquid absorbent 23 at the bottom of the desorption tower 7 is converted into a high-pressure lean liquid absorbent 24 from low pressure, so that the electric power cost is saved by more than 16.29-35.54 ten thousand yuan/year, the energy recovery efficiency is more than 60.00-65.45%, and a better technical effect is obtained.
Drawings
FIG. 1 is a schematic flow diagram of the process of the present invention.
In FIG. 1, 1-absorber column; 2-a pressure reducing valve; 3-a pressure recovery device; 4-standby booster pump; 5-a flash tank; 6-lean rich absorbent heat exchanger; 7-a desorber; 8-a reboiler; 11-light hydrocarbon gas; 12-purifying the light hydrocarbon gas; 13-high pressure rich liquid absorbent; 14-low pressure rich liquid absorbent; 15-low pressure rich liquid absorbent; 16-hydrocarbon organic; 17-low pressure rich liquid absorbent; 18-high temperature rich liquid absorbent; 19-acidic impurities hydrogen sulfide H2S and carbon dioxide CO 2; 20-desorption tower bottom circulating liquid; 21-low pressure lean liquid absorbent; 22-low temperature lean liquid absorbent; 23-a low temperature lean liquor absorbent; 24-high pressure lean liquid absorbent; 25-high pressure lean liquid absorbent; 26-high pressure lean liquid absorbent.
The present invention will be further illustrated by the following examples, but is not limited to these examples.
Detailed Description
Comparative example 1
Taking a 180-million-ton/year catalytic cracking FCC unit, a 60-million-ton/year catalytic cracking DCC unit, a 240-million-ton/year delayed coking unit and a 320-million-ton/year hydrocracking unit as examples of production scales respectively, the light hydrocarbon separation device adopts the prior art, and in the process of removing acid impurities, namely hydrogen sulfide H2S and carbon dioxide CO2, the pressure recovery technology is not adopted, and the pressure energy recovery through the pressure recovery device, the power consumption and the economic benefit of an absorbent delivery pump are not considered, which is shown in Table 1.
TABLE 1 summary of power consumption and economic benefits of delivery pumps
| Name of process equipment | Catalytic cracking FCC unit | Catalytic cracking DCC device | Delayed coking device | Hydrocracking device |
| Production scale (ten thousand tons/year) | 180 | 60 | 240 | 320 |
| Consumption Power of delivery pump (KW) | 67.4 | 44.2 | 81.7 | 93.7 |
| Power of delivery pump motor (KW) | 80 | 55 | 96 | 110 |
| Annual electric power consumption (KWh) | 640000 | 440000 | 768000 | 880000 |
| Calculating Motor efficiency (%) | 84.2 | 80.3 | 85.1 | 85.2 |
| Annual electric power charge (Wanyuan) | 39.49 | 27.15 | 47.39 | 54.30 |
[ example 1 ]
In the petroleum refining industry, taking a catalytic cracking FCC device with the production scale of 180 million tons/year as an example, the by-product process refinery gas of the FCC device contains rich ethylene, and after acidic impurity hydrogen sulfide H2S needs to be removed, the ethylene is separated and recovered to prepare polymer grade ethylene. The composition of the FCC process refinery gas is shown in table 2.
TABLE 2 FCC Process refinery gas composition List
| Component name | Hydrogen gas | Methane | Ethylene | Ethane (III) | Hydrogen sulfide | Total up to |
| Yield/vol% | 40.4 | 26.6 | 15.5 | 16.1 | 1.4 | 100.0 |
The method for recovering pressure energy by adopting the light hydrocarbon separation device is shown in figure 1, and the process flow is as follows: light hydrocarbon gas 11 from outside enters the bottom of the absorption tower 1, meanwhile, the high-pressure lean liquid absorbent 26 with reduced temperature and increased pressure also enters the top of the absorption tower 1, in the absorption tower 1, the light hydrocarbon gas 11 is in countercurrent contact with the high-pressure lean liquid absorbent 26, acidic impurities, namely hydrogen sulfide H2S and carbon dioxide CO2, in the light hydrocarbon gas 11 are absorbed by the high-pressure lean liquid absorbent 26, and the purified light hydrocarbon gas 12 with the acidic impurities removed flows out of the top of the absorption tower 1 and is sent to outside. The high-pressure rich liquid absorbent 13 for absorbing the acidic impurities of hydrogen sulfide H2S and carbon dioxide CO2 flows out from the bottom of the absorption tower 1 and enters the inlet of the pressure reduction end of the pressure recovery device 3. In the pressure recovery device 3, the pressure of the high-pressure rich liquid absorbent 13 is switched from high pressure to low pressure, and flows out of the pressure recovery device 3, and the low-pressure rich liquid absorbent 14 flows to the low-pressure rich liquid absorbent 15 into the flash tank 5. The low-pressure rich liquid absorbent 15 is flashed in the flash tank 5, the hydrocarbon organic matters are gasified and flow out of the top of the flash tank 5, and the hydrocarbon organic matters 16 are sent out. The non-gasified low-pressure rich liquid absorbent flows out of the bottom of the flash tank 5 to be the low-pressure rich liquid absorbent 17. The low-pressure rich liquid absorbent 17 enters the lean rich absorbent heat exchanger 6, is subjected to heat exchange by the lean rich absorbent heat exchanger 6, is heated to be high-temperature rich liquid absorbent 18, and then enters the desorption tower 7. The high-temperature rich liquid absorbent 18 is sent into the desorption tower 7, the reboiler 8 is arranged at the bottom of the desorption tower 7, and the circulating liquid 20 at the bottom of the desorption tower enters the reboiler 8 to be heated and partially gasified and returns to the desorption tower 7. In the desorption tower 7, the reboiler 8 raises the temperature of the high-temperature rich liquid absorbent to partially gasify the high-temperature rich liquid absorbent, the gas is in countercurrent contact with the high-temperature rich liquid absorbent to carry out gas stripping regeneration, the acidic impurities of hydrogen sulfide H2S and carbon dioxide CO2 in the high-temperature rich liquid absorbent are desorbed, and the acidic impurities 19 flow out of the top of the desorption tower 7 and are sent to the outside. The low-pressure lean liquid absorbent 21 for removing acidic impurities, namely hydrogen sulfide H2S and carbon dioxide CO2, flows out of the bottom of the desorption tower 7. The low-pressure lean liquid absorbent 21 flowing out from the bottom of the desorption tower 7 enters the lean rich absorbent heat exchanger 6 to exchange heat and reduce the temperature. The low-temperature lean absorbent 22 after the temperature reduction flows to the low-temperature lean absorbent 23 to enter the pressure recovery device 3. The low-temperature lean liquid absorbent 23 enters the inlet of the pressure-increasing end of the pressure recovery device 3, and the pressure of the low-temperature lean liquid absorbent 23 is converted from low pressure to high pressure in the pressure recovery device 3. The high-pressure barren liquor absorbent 24 flowing out of the pressure recovery device 3 flows to the high-pressure barren liquor absorbent 26 to return to the top of the absorption tower 1 for repeated recycling, and the acidic impurities of hydrogen sulfide H2S and carbon dioxide CO2 in the light hydrocarbon gas 11 are absorbed again. Under the normal operating condition of the arranged pressure recovery device 3, the valve 2 is closed, no material passes through the bypass pipeline, the standby booster pump 4 is closed, and no material passes through the bypass pipeline 25. When the arranged pressure recovery device 3 has a fault working condition, the valve 2 in a bypass closed state under the normal working condition of the pressure recovery device 3 can be simultaneously opened, the standby booster pump 4 is opened, the high-pressure rich liquid absorbent enters the flash tank 5 through the opened valve 2, and the low-temperature lean liquid absorbent 22 enters the top of the absorption tower 1 through the pressurization of the standby booster pump 4 and the pipeline 25. Under the condition of no operation of the pressure recovery device 3, the normal repeated and cyclic operation and use of the absorbent between the absorption tower 1 and the desorption tower 7 are ensured.
The method for recovering pressure energy by adopting the light hydrocarbon separation device has the following process parameters: the operation pressure of the absorption tower 1 is 1.9MPa, the operation temperature of the top of the tower is 58 ℃, and the operation temperature of the bottom of the tower is 60 ℃. The absorption tower 1 adopts monoethanolamine MEA with the mole fraction of 17 percent as an absorbent. The operating pressure of the desorption tower 7 is 0.5MPa, the operating temperature of the top of the tower is 108 ℃, and the operating temperature of the bottom of the tower is 110 ℃. The materials in a reboiler 8 at the bottom of the desorption tower 7 are heated by adopting externally supplied steam, and the materials with the mass fraction of 7 percent are gasified. The inlet operating pressure of the pressure reduction end of the pressure recovery device 3 is 1.9MPa, and the outlet operating pressure is 0.6 MPa; the inlet operating pressure of the boosting end is 0.3MPa, and the outlet operating pressure is 2.1 MPa.
By adopting the method for recovering pressure energy by the light hydrocarbon separation device, the power cost is saved by more than 24.68 ten thousand yuan/year, the energy recovery efficiency is more than 62.50 percent, and other obtained technical effects and economic benefits are shown in Table 8.
[ example 2 ]
Similarly [ example 1 ], the production scale was still 180 million tons/year FCC unit, the process flow was unchanged, the process parameters were unchanged, and only the composition of the FCC process refinery gas was changed, as shown in table 3.
TABLE 3 FCC Process refinery gas composition List
| Component name | Hydrogen gas | Nitrogen gas | Methane | Ethylene | Propane | Propylene (PA) | Carbon four | Hydrogen sulfide | Carbon dioxide | Total up to |
| Yield/vol% | 13.2 | 18.5 | 32.1 | 26.2 | 1.0 | 2.9 | 1.7 | 0.3 | 4.1 | 100.0 |
By adopting the method for recovering pressure energy by the light hydrocarbon separation device, the power cost is saved by more than 24.68 ten thousand yuan/year, the energy recovery efficiency is more than 62.50 percent, and other obtained technical effects and economic benefits are shown in Table 8.
[ example 3 ]
Similarly, (example 1) the process flow was unchanged, the process parameters were unchanged, and only the DCC device was changed to 60 million tons/year catalytic cracking in the oil refining industry, the composition of the DCC process refinery gas is shown in table 4.
TABLE 4 DCC technical refinery gas composition List
| Component name | Hydrogen gas | Methane | Ethylene | Ethane (III) | Propylene (PA) | Propane | Hydrogen sulfide | Total up to |
| Yield/vol% | 23.8 | 32.7 | 27.8 | 13.1 | 0.5 | 0.2 | 1.9 | 100.0 |
Due to the adoption of the method for recovering pressure energy by the light hydrocarbon separation device, the power cost is saved by more than 16.29 ten thousand yuan/year, the energy recovery efficiency is more than 60.00 percent, and other obtained technical effects and economic benefits are shown in Table 8.
[ example 4 ]
Similarly, (example 1) the production scale was still 60 ten thousand tons/year of DCC catalytic cracking unit, the process flow was unchanged, the process parameters were unchanged, and only the composition of the DCC process refinery gas was changed, as shown in table 5.
TABLE 5 DCC technical refinery gas composition List
| Component name | Hydrogen gas | Methane | Ethane (III) | Ethylene | Propane | Propylene (PA) | Hydrogen sulfide | Total up to |
| Yield/vol% | 24.9 | 33.8 | 12.6 | 27.7 | 0.1 | 0.3 | 0.6 | 100.0 |
Due to the adoption of the method for recovering pressure energy by the light hydrocarbon separation device, the power cost is saved by more than 16.29 ten thousand yuan/year, the energy recovery efficiency is more than 60.00 percent, and other obtained technical effects and economic benefits are shown in Table 8.
[ example 5 ]
Similarly, in example 1, the process flow was changed to 240 million tons/year delayed coker in the petroleum refining industry, and the composition of the refinery gas in the delayed coker was shown in table 6.
TABLE 6 delayed coker process refinery gas composition summary
| Component name | Hydrogen gas | Methane | Ethane (III) | Propane | Propylene (PA) | Carbon four | Carbon five | Hydrogen sulfide | Total up to |
| Yield/vol% | 6.1 | 31.9 | 26.8 | 13.1 | 7.4 | 10.1 | 3.0 | 1.6 | 100.0 |
The process parameters were varied as follows: the operating pressure of the absorption tower 1 is 1.7MPa, the operating temperature of the top of the tower is 56 ℃, and the operating temperature of the bottom of the tower is 58 ℃. The absorption tower 1 adopts diisopropanolamine DIPA with the mole fraction of 20 percent as an absorbent. The operating pressure of the desorption tower 7 is 0.3MPa, the operating temperature of the top of the tower is 106 ℃, and the operating temperature of the bottom of the tower is 108 ℃. The material in a reboiler 8 at the bottom of the desorption tower 7 is heated by adopting externally supplied steam, and the material with the mass fraction of 5 percent is gasified. The inlet operating pressure of the pressure reduction end of the pressure recovery device 3 is 1.7MPa, and the outlet operating pressure is 0.4 MPa; the inlet operating pressure of the boosting end is 0.1MPa, and the outlet operating pressure is 1.9 MPa.
Due to the adoption of the method for recovering pressure energy by the light hydrocarbon separation device, the electric power cost is saved by more than 30.60 ten thousand yuan/year, the energy recovery efficiency is more than 64.58 percent, and other obtained technical effects and economic benefits are shown in Table 8.
[ example 6 ]
Similarly, in example 1, the process flow was changed to a 320 million ton/year hydrocracking unit in the petroleum refining industry, and the composition of the process refinery gas in the hydrocracking unit is shown in table 7.
TABLE 7 summary of refinery gas composition for hydrocracking unit process
| Component name | Hydrogen gas | Methane | Ethane (III) | Propane | Isobutane | N-butane | Carbon five | Hydrogen sulfide | Total up to |
| Yield/vol% | 3.64 | 4.65 | 6.28 | 29.90 | 34.67 | 15.44 | 3.79 | 1.63 | 100.00 |
The process parameters were varied as follows: the operation pressure of the absorption tower 1 is 2.5MPa, the operation temperature of the top of the tower is 72 ℃, and the operation temperature of the bottom of the tower is 74 ℃. The absorption tower 1 adopts 30 percent of methyldiethanolamine MDEA as an absorbent. The operating pressure of the desorption tower 7 is 1.1MPa, the operating temperature of the top of the tower is 112 ℃, and the operating temperature of the bottom of the tower is 114 ℃. The material in a reboiler 8 at the bottom of the desorption tower 7 is heated by adopting external steam supply, and the material with the mass fraction of 25 percent is gasified. The inlet operating pressure of the pressure reduction end of the pressure recovery device 3 is 2.5MPa, and the outlet operating pressure is 1.2 MPa; the inlet operating pressure of the boosting end is 0.9MPa, and the outlet operating pressure is 2.7 MPa. Due to the adoption of the method for recovering pressure energy by the light hydrocarbon separation device, the electric power cost is saved by more than 35.54 ten thousand yuan per year, the energy recovery efficiency is more than 65.45 percent, and other obtained technical effects and economic benefits are shown in Table 8.
In summary, the technical effects and economic benefits obtained by adopting the technical scheme of recovering pressure energy by the light hydrocarbon separation device of the invention are shown in table 8 in the embodiments 1 to 6.
TABLE 8 summary of the technical and economic benefits of the invention
Claims (1)
1. A method for recovering pressure energy by a light hydrocarbon separation device comprises the following steps:
(a) light hydrocarbon gas from outside enters the bottom of an absorption tower, meanwhile, a high-pressure barren solution absorbent with reduced temperature and increased pressure enters the top of the absorption tower, the light hydrocarbon gas is in countercurrent contact with the high-pressure barren solution absorbent in the absorption tower, acidic impurities in the light hydrocarbon gas are absorbed by the high-pressure barren solution absorbent to form a high-pressure rich solution absorbent, and purified light hydrocarbon gas with the acidic impurities removed flows out of the top of the absorption tower and is sent to outside;
(b) the high-pressure rich liquid absorbent for absorbing the acidic impurities flows out of the bottom of the absorption tower and is divided into two paths, one path enters the inlet of the pressure reduction end of the pressure recovery device, the other path is a bypass pipeline A, and a valve is arranged on the bypass pipeline A; under the normal working condition, the valve on the bypass pipeline A is closed, and no material passes through the bypass pipeline A; in the pressure recovery device, the pressure of the high-pressure rich liquid absorbent is converted from high pressure to low pressure to form a low-pressure rich liquid absorbent, the low-pressure rich liquid absorbent flows out of the pressure recovery device, and the low-pressure rich liquid absorbent enters a flash tank;
(c) the low-pressure rich liquid absorbent from the pressure recovery device is flashed in the flash tank, the hydrocarbon organic matters are gasified and flow out from the top of the flash tank, and the hydrocarbon organic matters are sent out; the non-gasified low-pressure rich liquid absorbent flows out of the bottom of the flash tank;
(d) the low-pressure rich liquid absorbent from the bottom of the flash tank enters a lean rich absorbent heat exchanger, the lean rich absorbent heat exchanger exchanges heat and heats the absorbent to form a high-temperature rich liquid absorbent, and the high-temperature rich liquid absorbent enters a desorption tower;
(e) a reboiler is arranged at the bottom of the desorption tower, and circulating liquid at the bottom of the desorption tower enters the reboiler to be heated and partially gasified and returns to the desorption tower; in the desorption tower, a reboiler increases the temperature of the high-temperature rich liquid absorbent and partially gasifies the high-temperature rich liquid absorbent, gas is in countercurrent contact with the high-temperature rich liquid absorbent for stripping regeneration, acidic impurities in the high-temperature rich liquid absorbent are desorbed, the desorbed acidic impurities flow out of the top of the desorption tower and are conveyed out of the tower, and meanwhile, a low-pressure lean liquid absorbent is formed; the low-pressure barren solution absorbent for removing the acid impurities flows out from the bottom of the desorption tower;
(f) the low-pressure barren solution absorbent flowing out from the bottom of the desorption tower enters a barren and rich absorbent heat exchanger for heat exchange to reduce the temperature, so that the low-temperature barren solution absorbent is formed; the low-temperature barren solution absorbent is divided into two paths after flowing out of the barren and rich absorbent heat exchanger, one path enters the inlet of the pressure boosting end of the pressure recovery device, the other path is a bypass pipeline B, and a standby booster pump is arranged on the bypass pipeline B; under the normal working condition, the standby booster pump is closed, and no material passes through the bypass pipeline B; the cooled low-temperature barren solution absorbent enters an inlet of a pressure boosting end of the pressure recovery device;
(g) converting the pressure of the low temperature lean liquid absorbent from a low pressure to a high pressure within the pressure recovery unit to form a high pressure lean liquid absorbent; under the normal working condition, the high-pressure barren liquor absorbent flowing out of the pressure recovery device returns to the top of the absorption tower to be recycled, and the acid impurities in the light hydrocarbon gas are absorbed again;
the pressure recovery device is an online pressure recovery device adopting a hydraulic turbine principle, the device directly connects a pressure reduction end high-pressure side impeller and a pressure boosting end low-pressure side impeller in the same pump body through a rotating shaft, a high-pressure rich liquid absorbent at the pressure reduction end drives the pressure reduction end high-pressure side impeller, and drives the pressure boosting end low-pressure side impeller to rotate through the rotating shaft, so that the pressure of a low-pressure lean liquid absorbent at the pressure boosting end is increased, the pressure energy at the pressure reduction end high-pressure side is converted into mechanical energy of the rotating shaft and then into pressure energy at the pressure boosting end low-pressure side, and the rotating shaft in the pressure recovery device is the only operating part, so that the pressure recovery device has no shaft seal and no additional lubricating system; the high-pressure rich liquid absorbent enters a high-pressure side inlet of a pressure reduction end of the pressure recovery device, and the low-temperature lean liquid absorbent enters a low-pressure side inlet of a pressure boosting end of the pressure recovery device; in the pressure recovery device, the pressure energy of the high-pressure rich liquid absorbent on the high-pressure side of the decompression end is firstly converted into the mechanical energy of the rotating shaft and then converted into the pressure energy of the low-temperature lean liquid absorbent on the low-pressure side of the boosting end, so that the pressure of the low-temperature lean liquid absorbent is increased and the low-temperature lean liquid absorbent is converted into the high-pressure lean liquid absorbent; meanwhile, the auxiliary motor of the pressure recovery device is started to supplement insufficient pressure energy, so that the pressure of the high-pressure barren liquor absorbent flowing out of the high-pressure side of the pressure boosting end of the pressure recovery device meets the pressure required by the absorption operation of the absorption tower, and the total power consumption of an external motor is reduced; when the pressure recovery device has a fault working condition, simultaneously opening a valve on a bypass pipeline A and opening a standby booster pump, enabling the high-pressure rich liquid absorbent to enter a flash tank through the valve on the bypass pipeline A, and boosting the low-temperature lean liquid absorbent to the top of the absorption tower through the standby booster pump; under the condition that no pressure recovery device operates, the absorbent is ensured to be repeatedly and circularly operated and used between the absorption tower and the desorption tower; the operating pressure range of the absorption tower is 1.7-2.5 MPa, the operating temperature range of the tower top is 56-72 ℃, and the operating temperature range of the tower bottom is 58-74 ℃; the absorption tower adopts 15-20% of monoethanolamine MEA or 25-35% of diethanolamine DEA or 20-25% of diisopropanolamine DIPA or 25-30% of methyldiethanolamine MDEA as absorbent; the operating pressure range of the desorption tower is 0.3-1.1 MPa, the operating temperature range of the top of the tower is 106-112 ℃, and the operating temperature range of the bottom of the tower is 108-114 ℃; heating the material in a reboiler at the bottom of the desorption tower by adopting externally supplied steam, and ensuring that the inlet operating pressure range of a pressure reduction end of the material gasification pressure recovery device with the mass fraction of 5-25% is 1.7-2.5 MPa, and the outlet operating pressure range is 0.4-1.2 MPa; the inlet operating pressure range of the boosting end is 0.1-0.9 MPa, and the outlet operating pressure range is 1.9-2.7 MPa.
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| CN103373898B (en) * | 2012-04-20 | 2016-02-24 | 新奥科技发展有限公司 | Methanol synthesizing process, system for methanol synthesis |
| WO2014208038A1 (en) * | 2013-06-25 | 2014-12-31 | 川崎重工業株式会社 | System and method for separating and recovering carbon dioxide |
| WO2015011566A2 (en) * | 2013-07-23 | 2015-01-29 | Carbon Clean Solutions Pvt. Ltd | Split line system, method and process for co2 recovery |
| KR20150017050A (en) * | 2013-08-05 | 2015-02-16 | 재단법인 포항산업과학연구원 | Method for the prevention of ammonia vaporization in carbon dioxide absorption process and apparatus for absorbing carbon dioxide using thereof |
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| CN2899919Y (en) * | 2006-05-30 | 2007-05-16 | 国家海洋局天津海水淡化与综合利用研究所 | Controllable pressure exchanging energy recovering device |
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