CN108610229B - Light hydrocarbon separation system and method - Google Patents
Light hydrocarbon separation system and method Download PDFInfo
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- CN108610229B CN108610229B CN201611145935.4A CN201611145935A CN108610229B CN 108610229 B CN108610229 B CN 108610229B CN 201611145935 A CN201611145935 A CN 201611145935A CN 108610229 B CN108610229 B CN 108610229B
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- C—CHEMISTRY; METALLURGY
- C07—ORGANIC CHEMISTRY
- C07C—ACYCLIC OR CARBOCYCLIC COMPOUNDS
- C07C7/00—Purification; Separation; Use of additives
- C07C7/005—Processes comprising at least two steps in series
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- 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
- C10G70/041—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 distillation
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- 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
- C10G70/043—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 fractional condensation
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- Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
- Y02P20/00—Technologies relating to chemical industry
- Y02P20/10—Process efficiency
Abstract
The invention discloses a light hydrocarbon separation system and a method, belonging to the technical field of light hydrocarbon recovery. The separation system includes: the device comprises a primary separation component, a partition tower, a first debutanizer and a second debutanizer which are connected in sequence through pipelines; the dividing wall column is used for separating methane, ethane and propane; the first debutanizer is used for separating isobutane; the second debutanizer is used for separating n-butane, and the light hydrocarbon separation system adopts LNG as a cold source. By utilizing LNG as the cold source of the whole separation system and adopting the next door tower to separate methane, ethane and propane at one time, the energy consumption of the light hydrocarbon separation process is effectively reduced, and besides the separation of light hydrocarbon in dry gas, the energy is saved and the energy utilization efficiency is improved, so that the defects of the light hydrocarbon separation process in the prior art are overcome, and the method has very important significance for developing circular economy.
Description
Technical Field
The invention relates to the technical field of light hydrocarbon recovery in refineries, in particular to a light hydrocarbon separation system and a light hydrocarbon separation method.
Background
The production capacity of ethylene used as a basic raw material in the petrochemical industry is regarded as the embodiment of the national economic comprehensive strength. The ethylene industry has developed rapidly in China in recent years, but some problems still exist. Chinese ethylene products have low equivalent self-sufficiency rate, need a large amount of imports to make up market gaps, and are in a relatively passive position in international competition. Based on the existing ethylene raw material base, the ethylene raw material source is widened, and necessary raw material supplement is provided for the ethylene production of China, wherein the refinery dry gas is the ethylene raw material with larger potential energy, so that the recovery of light hydrocarbon resources in the refinery dry gas has great economic benefit and social benefit.
At present, the light hydrocarbon separation technology of an oil refinery generally adopts a cryogenic separation method, and the cryogenic separation method separates hydrocarbons with higher boiling points in the gradual cooling process by utilizing different boiling points and condensation points of components in raw material gas. Specifically, the raw material gas is subjected to pressurization treatment, condensation separation, refrigeration and other processes in sequence to separate high-purity ethane, propane, butane and the like. However, the traditional light hydrocarbon cryogenic separation process has the problems of complex flow, high energy consumption, especially high refrigeration energy consumption, and high operation cost.
In order to overcome the defects of the conventional light hydrocarbon cryogenic separation process, patent document CN103398546A discloses a light hydrocarbon cryogenic separation method based on LNG cold energy. In the traditional light hydrocarbon cryogenic separation process, LNG is adopted to completely or partially replace a three-machine compression refrigeration system, cold energy is provided for process material flows in sequence, and light hydrocarbon cryogenic separation is completed. But only saves the power consumption of compression refrigeration on the conventional flow, and does not carry out further energy-saving process modification.
In the process of implementing the invention, the inventor finds that the prior art has at least the following problems:
the light hydrocarbon separation process in the prior art has the problem of overlarge refrigeration energy consumption.
Disclosure of Invention
In order to solve the problem of high energy consumption in the light hydrocarbon separation technology in the prior art, the embodiment of the invention provides a light hydrocarbon separation system and a method for effectively reducing energy consumption. The technical scheme is as follows:
a first aspect of an embodiment of the present invention provides a light hydrocarbon separation system, including: the device comprises a primary separation component, a partition tower, a first debutanizer and a second debutanizer which are connected in sequence through pipelines;
the preliminary separation assembly comprises a first cooler, a second cooler and a phase separator which are connected in sequence, and the preliminary separation assembly is connected with a feed inlet of the partition wall tower;
the dividing wall tower is used for separating methane, ethane and propane and comprises a partial condenser and a first reboiler, and a discharge hole at the bottom of the dividing wall tower is connected with a feed inlet of the first debutanizer;
the first debutanizer is used for separating isobutane, and comprises a first condenser, and a tower bottom discharge hole of the first debutanizer is connected with a feed inlet of the second debutanizer;
the second debutanizer is used for separating n-butane and comprises a second condenser and a fourth reboiler;
and LNG is adopted as a cold source in the first cooler, the second cooler, the partial condenser, the first condenser and the second condenser.
Preferably, the light hydrocarbon separation system further comprises an LNG channel for providing a cold source for the light hydrocarbon separation system; the LNG channel is communicated with the second cooler, the partial condenser, the first cooler, the first condenser and the second condenser in sequence;
and the second cooler is an LNG inlet end, and the second condenser is an LNG outlet end.
Preferably, the preliminary separation assembly further comprises: a mixer upstream of and in communication with the first cooler, and a pressure reducing valve downstream of and in communication with the phase separator.
Preferably, the phase separator has a gas outlet, a first liquid outlet and a second liquid outlet, the second liquid outlet being connected to the pressure reducing valve; and the pressure reducing valve is also communicated with the bulkhead tower.
Preferably, a longitudinal partition is arranged in the partition tower, and a third condenser is connected to the middle part of the partition tower.
Preferably, the third condenser is in communication with the LNG passage between the partial condenser and the first cooler such that the LNG passes through the partial condenser, the third condenser, and the first cooler in this order.
Preferably, the first debutanizer is a double-effect rectification system comprising a high-pressure column and a low-pressure column; the high pressure column comprises a feed inlet and a third reboiler; the low-pressure tower comprises a discharge hole, a second reboiler and a first condenser; the tower top of the high pressure tower is communicated with the second reboiler, and the second reboiler is communicated with the upper part of the high pressure tower.
A second aspect of embodiments of the present invention provides a light hydrocarbon separation method using the light hydrocarbon separation system provided in the first aspect, where the method includes:
step one, dry gas and liquefied gas enter a primary separation assembly, are sequentially cooled by a first cooler and a second cooler, and are subjected to primary separation in a phase separator to obtain a hydrocarbon-rich liquid phase;
step two, the hydrocarbon-rich liquid phase enters a dividing wall tower, and components of the hydrocarbon-rich liquid phase are separated in the dividing wall tower:
methane and ethane are withdrawn from the top of the divided wall column; propane is extracted from the middle part of the dividing wall tower; a C4+ stream is withdrawn from the bottom of the divided wall column;
step three, the C4+ material flow enters a first debutanizer through a feed inlet of the first debutanizer, isobutane is separated in the first debutanizer, and a deisobutanized C4+ material flow is discharged;
and step four, enabling the deisobutanized C4+ material flow to enter the second debutanizer, extracting n-butane from the top of the second debutanizer, and discharging a heavy component liquid phase.
Preferably, the first step further comprises introducing the dry gas and the liquefied gas into a mixer, mixing uniformly, and then introducing into the first cooler.
Preferably, the hydrocarbon-rich liquid phase separated in the phase separator is discharged from the bottom of the phase separator, subjected to pressure reduction treatment by a pressure reducing valve, and then enters the dividing wall column.
Preferably, in the second step, the methane and the ethane are discharged from the top of the bulkhead column and enter a dephlegmator, gaseous methane and liquid ethane are collected after dephlegmation, and the residual condensate flows back to the top of the bulkhead column; the gas-liquid mixture in the middle of the dividing wall tower enters a first condenser for condensation, the condensed gas-liquid mixture flows back to the middle of the dividing wall tower, and the propane is extracted from the middle of the dividing wall tower; part of the C4+ material enters the first reboiler to be heated and then flows back to the bottom of the dividing wall tower.
Preferably, the operating pressure of the bulkhead tower is 1 atm-2.5 atm, the temperature of the top of the tower is-104 ℃ to-89 ℃, and the temperature of the bottom of the tower is 4 ℃ to 20 ℃;
preferably, in the third step, the C4+ material firstly enters the high pressure column, and a high pressure overhead vapor and a high pressure bottom material are formed in the high pressure column 301; the tower top steam enters the third reboiler for heat exchange to form condensate, first isobutane is extracted from the condensate, and the rest condensate flows back to the top of the high-pressure tower; and a first deisobutanized C4+ material flow in the high-pressure tower bottom material enters the low-pressure tower, and part of the high-pressure tower bottom material enters a second reboiler to be heated and then flows back to the bottom of the high-pressure tower again.
Preferably, the operating pressure of the high-pressure tower is 2.5 atm-4 atm, the tower top temperature is 16-30 ℃, and the tower bottom temperature is 27-42 ℃.
Preferably, in the third step, low-pressure overhead steam and low-pressure bottom materials are formed in the low-pressure tower, the low-pressure overhead steam enters the first condenser for condensation, second isobutane is extracted after condensation, and the rest condensate flows back to the top of the low-pressure tower; and a second deisobutanized C4+ material in the low-pressure tower bottom material enters a second debutanizer, and part of the high-pressure tower bottom material enters a third reboiler for heating and then reflows to the bottom of the low-pressure tower again.
Preferably, the low-pressure tower is operated under normal pressure, the temperature of the top of the tower is-11 ℃, and the temperature of the bottom of the tower is 2 DEG C
Preferably, in the fourth step, second debutanizer tower top steam and second debutanizer tower bottom materials are formed in the second debutanizer tower, the second debutanizer tower top steam enters the second condenser for condensation, n-butane is extracted after condensation, and the remaining condensate flows back to the top of the second debutanizer tower; and the tower bottom material of the second debutanizer enters a fourth reboiler for heating, then the heavy component liquid phase is extracted, and the residual tower bottom material steam flows back to the bottom of the second debutanizer.
Preferably, the second debutanizer is operated at normal pressure, the temperature at the top of the tower is-1 ℃ and the temperature at the bottom of the tower is 43 ℃.
Preferably, the initial temperature of the LNG feed is-150 ℃ to-110 ℃; and the flow path of the LNG raw material is as follows: and the liquid enters from the second cooler and sequentially passes through the partial condenser, the third condenser, the first cooler, the first condenser and the second condenser.
The technical scheme provided by the embodiment of the invention has the following beneficial effects:
by utilizing LNG as the cold source of the whole separation system and adopting the next door tower to separate methane, ethane and propane at one time, the energy consumption of the light hydrocarbon separation process is effectively reduced, and besides the separation of light hydrocarbon in dry gas, the energy is saved and the energy utilization efficiency is improved, so that the defects of the light hydrocarbon separation process in the prior art are overcome, and the method has very important significance for developing circular economy.
Drawings
In order to more clearly illustrate the technical solutions in the embodiments of the present invention, the drawings needed to be used in the description of the embodiments will be briefly introduced below, and it is obvious that the drawings in the following description are only some embodiments of the present invention, and it is obvious for those skilled in the art to obtain other drawings based on these drawings without creative efforts.
Fig. 1 is a schematic view of a light hydrocarbon separation system according to an embodiment of the present invention.
In the drawings, the respective reference numerals are:
000.LNG feed; 101. dry gas, 102 liquefied gas, 103, a mixer, 104, a first cooler, 105, a second cooler, 106, a cooling feed stream, 107, a phase separator, 108, a hydrogen-rich gas, 109, a hydrocarbon-rich liquid, 110, a pressure reducing valve, 111, a dividing wall column feed stream, 112, wastewater;
201. a dividing wall column, 2011. high pressure column feed, 2012. high pressure column discharge, 202. partition, 203. dephlegmator, 204. third condenser, 205. methane gas, 206. ethane, 207. propane, 208.C4+ stream, 209. first reboiler;
300. the method comprises the following steps of (1) a first debutanizer, 301, a high-pressure tower, 3011, a first debutanizer feeding port, 302, a low-pressure tower, 3021, a first debutanizer discharging port, 303, first isobutane, 304, second isobutane, 305, high-pressure overhead steam, 306, a second reboiler, 307, a first condenser, 308, a second deisobutanized C4+ material flow, 309, a third reboiler, 310, a first deisobutanized C4+ material flow, 311, high-pressure overhead steam condensate;
401. a second debutanizer, 4011, second debutanizer feed inlet, 402, second condenser, 403, fourth reboiler, 404, n-butane, 405, heavies liquid phase.
Detailed Description
In order to make the objects, technical solutions and advantages of the present invention more apparent, embodiments of the present invention will be described in detail with reference to the accompanying drawings.
Before describing the light hydrocarbon separation system and method provided by the embodiments of the present invention, the following concepts are explained first:
(1) LNG: in the embodiment of the invention, LNG is an abbreviation of liquefied natural gas, and the liquefied natural gas is used as a cold source of the light hydrocarbon separation system in the embodiment of the invention;
(2) c4+ materials: is a component with the number of carbon atoms more than or equal to 4;
(3) c5+ materials: is a component with the number of carbon atoms more than or equal to 5.
A first aspect of an embodiment of the present invention provides a light hydrocarbon separation system, specifically referring to fig. 1, the light hydrocarbon separation system includes: a preliminary separation module 100, a dividing wall column 201, a first debutanizer column 300, and a second debutanizer column 401 connected in series by piping. The preliminary separation assembly 100 includes a first cooler 104, a second cooler 105, and a phase separator 107 connected in series, and the preliminary separation assembly 100 is connected to a feed port 2011 of the divided wall column. The dividing wall column 201 is used for separating methane, ethane and propane, and comprises a dephlegmator 203 and a first reboiler 209, and a tower bottom discharge outlet 2012 of the dividing wall column 201 is connected with a feed inlet 3011 of the first debutanizer. The first debutanizer 300 is used for separating isobutane, and comprises a first condenser 307, and a tower bottom discharge port 3021 of the first debutanizer 300 is connected with a feed port 4011 of the second debutanizer 401. The second debutanizer 401 is used for separating n-butane and includes a second condenser 402 and a fourth reboiler 403. And the first cooler 104, the second cooler 105, the dephlegmator 203, the first condenser 307 and the second condenser 402 all use LNG as a cooling source.
The light hydrocarbon separation system provided by the embodiment of the invention separates different components by utilizing the difference between the boiling point and the condensation point of methane, ethane, propane and butane, particularly utilizes LNG as a cold source of the whole separation system, and adopts the partition tower 201 to separate methane, ethane and propane at one time, thereby effectively reducing the energy consumption of the light hydrocarbon separation process. Specifically, LNG at atmospheric pressure is a cryogenic liquid with a boiling point of-162 ℃, which is vaporized and heated to above 0 ℃ before being supplied to downstream users, and a large amount of cold energy is released when LNG is vaporized. The light hydrocarbon separation system provided by the embodiment of the invention can reduce the cost of LNG gasification and realize the separation of light hydrocarbon in dry gas by recovering the cold energy in LNG, and has very important significance for saving resources, improving the utilization efficiency of energy and developing circular economy.
In summary, the light hydrocarbon separation system provided by the embodiment of the present invention effectively reduces the refrigeration energy consumption and compression energy consumption of the whole light hydrocarbon separation process by using LNG as a cold source and using the dividing wall column 201 to separate methane, ethane, and propane, and overcomes the defect of large energy consumption of the cryogenic separation process in the prior art.
Specifically, in order to rationally utilize the cold energy in the LNG, effectively separate the lighter hydrocarbons in the dry gas, this lighter hydrocarbons piece-rate system still includes the LNG passageway. Referring to fig. 1, the LNG passage is connected to the second cooler 105, the dephlegmator 203, the first cooler 104, the first condenser 307, and the second condenser 402 in this order; and second chiller 105 is the LNG inlet and second condenser 402 is the LNG outlet. The LNG channel provides cold sources for coolers or condensers and the like of all parts in the separation system, optimizes the transfer sequence of the LNG cold energy, and realizes the stepped utilization of the LNG cold energy.
Specifically, in order to better implement the operation and operation of the light hydrocarbon separation system, it is preferable that the light hydrocarbon separation system provided by the embodiment of the present invention further includes the following components:
first, the preliminary separation assembly 100 further includes: a mixer 103 located upstream of the first cooler 104 and in communication with said first cooler 104. It should be noted that the upstream of the first cooler 104 is that the feed gas first passes through the mixer 103, and then passes into the first cooler 104. When the raw material is dry gas and other gas and liquid containing light hydrocarbon, the raw material is mixed uniformly by a mixer 103, then the mixed raw material is introduced into a first cooler 104 and a second cooler 105 for cooling, and the obtained cooling raw material flow 106 enters a phase separator 107 for preliminary separation to obtain hydrogen-rich gas 108, wastewater 112 and a hydrocarbon-rich liquid phase 109.
Wherein the phase separator 107 has a gas outlet, a first liquid outlet and a second liquid outlet. And the preliminary separation assembly 100 further includes: a pressure reducing valve 110 located downstream of the phase separator 107 and in communication with the second liquid outlet, and the pressure reducing valve 110 is also in communication with the dividing wall column 201.
A gas outlet in the phase separator 107 is used for discharging hydrogen-rich gas 108, and the hydrogen-rich gas 108 can enter a hydrogen production system for utilization; a first liquid outlet for discharging waste water 112; the second liquid outlet is used for producing the hydrocarbon-rich liquid phase 109, and then the hydrocarbon-rich liquid phase 109 enters a subsequent separation device for light hydrocarbon separation. Further, before the hydrocarbon-rich liquid phase 109 is separated, it is subjected to a pressure reduction treatment, i.e. the hydrocarbon-rich liquid phase 109 is first passed into the pressurizing valve 110, and after pressure reduction, the resulting dividing wall column feed stream 111 enters the dividing wall column 201 through the dividing wall column feed inlet 2011.
A longitudinal partition 202 is provided in the dividing wall column 201, and a third condenser 204 is further connected to the middle portion of the dividing wall column 201.
The dividing wall column 201 is a column that divides a general rectifying column into 2 sections from the middle by a dividing wall 202, and can realize two-column functions and separation of ternary mixtures. In the dividing wall column 201, when the gas-liquid mixture reaches equilibrium, component stratification may be formed according to the difference in boiling point and condensation point of different components. And because the longitudinal partition plate 202 is arranged in the dividing wall tower 201, the back mixing effect of the components positioned in the middle of the tower is effectively avoided, the ideal layering of different components in the dividing wall tower 201 is realized, and the components are further separated. Specifically, in the present embodiment, methane and ethane collect primarily in the upper portion of the dividing wall column 201, propane collects in the middle portion of the dividing wall column 201, and the C4+ material is mostly deposited in the bottom portion of the dividing wall column 201. Compared with the conventional rectifying tower, the bulkhead tower 201 effectively reduces the reboiling load and the condensation load, and meanwhile, the bulkhead tower 201 needs a smaller reflux ratio, so that the energy consumption is effectively reduced, and the energy is saved by 60 percent at most. Furthermore, a demethanizer and a deethanizer are simultaneously adopted in the traditional light hydrocarbon cryogenic separation process to separate methane and ethane in light hydrocarbon, and the partition tower provided by the embodiment of the invention simultaneously separates methane, ethane and propane, so that the equipment and process cost is saved, and the equipment investment of the light hydrocarbon separation system is reduced by about 30%.
In addition, the third condenser 204 connected to the middle of the dividing wall tower 201 can effectively arrange the driving force in the heat transfer process in the tower, reduce the irreversibility of the heat transfer in the tower, and reduce the loss of work, thereby improving the thermodynamic efficiency of the process and achieving the purpose of energy saving. And the third condenser 204 also has LNG as a cold source and communicates with the LNG passage, and specifically, the third condenser 204 is located between the partial condenser 203 and the first cooler 104 so that the LNG passes through the partial condenser 203, the third condenser 204, and the first cooler 104 in this order.
The separation of methane, ethane, and propane by the dividing wall column 201 is specifically: methane and ethane are located in the upper part of the divided wall column 201 and are withdrawn from the top of the divided wall column 201 into a partial condenser 203. Since the boiling point of methane is lower than that of ethane, methane is mainly in a gaseous state and ethane is mainly in a liquid state in the partial condenser 203. Thereby, gaseous methane 205 and liquid ethane 206 are produced separately. And in order to maintain the normal operation of the dividing wall tower 201, part of the condensate in the partial condenser 203 flows back to the top of the dividing wall tower 201, and the temperature of the top of the dividing wall tower 201 is ensured to be-104 ℃ to-89 ℃. Liquid propane is produced at the middle part of the dividing wall column 201; the C4+ feed exits the bottom of the dividing wall column 201 through dividing wall column outlet 2012, wherein a portion of the C4+ feed 208 enters the first debutanizer column 300 through first debutanizer column inlet 3011. And part of the C4+ material enters the first reboiler 209 to be heated, and then flows back to the bottom of the bulkhead tower 201, so that the low-temperature of the bulkhead tower 201 is ensured to be 4-20 ℃, and the operating pressure of the bulkhead tower 201 is 2.5-4 atm.
The double-effect rectification system is mainly designed by utilizing different operating pressures of 2 rectification towers, latent heat of overhead steam 305 of a high-pressure tower 301 is utilized to provide heat for a reboiler (a third reboiler 306 in the embodiment) of a low-pressure tower 302, and the overhead steam 305 of the high-pressure tower is condensed at the same time, so that heat integration is realized, and the purpose of saving energy is achieved. Typically, the theoretical energy savings of a double effect rectification system is 50%.
Specifically, regarding the separation of the first debutanizer column 300: the C4+ feed 208 first enters the higher pressure column 301, forming a higher pressure overhead vapor 305 and a higher pressure bottoms stream within the higher pressure column 301; the overhead vapor 305 enters a third reboiler 306 for heat exchange to form a condensate 311, first isobutane 303 is extracted from the condensate 311, and the rest of condensate flows back to the top of the high-pressure tower 301. The first deisobutanized C4+ stream 310 in the high pressure column bottoms enters the low pressure column 302, and the remaining high pressure column bottoms enters the second reboiler 309 to be heated and then flow back to the bottom of the high pressure column 301. The operating pressure of the high-pressure column 301 is 2.5atm to 4atm, the temperature at the top of the column is 16 ℃ to 30 ℃, and the temperature at the bottom of the column is 27 ℃ to 42 ℃.
Further, the first deisobutanized C4+ material flow 310 forms low-pressure overhead steam and low-pressure bottom material in the low-pressure tower 302, the low-pressure overhead steam enters a first condenser 307 for condensation, second isobutane 304 is extracted after condensation, and the residual condensate flows back to the top of the low-pressure tower 302; and a second deisobutanizer C4+ material 308 in the low-pressure tower bottom material enters a second debutanizer 401, and the rest high-pressure tower bottom material enters a third reboiler 306 to be heated and then flows back to the bottom of the low-pressure tower 302 again. The low pressure column 302 was operated at atmospheric pressure, with temperatures at the top of the column of-11 ℃ and at the bottom of the column of 2 ℃.
After the second deisobutanizer C4+ material 308 enters a second debutanizer 401, second debutanizer tower top steam and second debutanizer tower bottom material are formed, the second debutanizer tower top steam enters a second condenser 402 for condensation, normal butane 404 is extracted after condensation, and the residual condensate flows back to the top of the second debutanizer 402; the material at the bottom of the second debutanizer enters a fourth reboiler 403 for heating, then a heavy component liquid phase 405 is extracted, and the rest material steam at the bottom of the second debutanizer 403 reflows. And the second debutanizer 401 is operated at atmospheric pressure, with a top temperature of-1 deg.C and a bottom temperature of 43 deg.C, respectively.
Therefore, the light hydrocarbon separation system provided by the embodiment of the invention realizes the separation of methane, ethane, propane and butane in the dry gas, effectively recovers the ethylene raw material in the dry gas, reduces the resource waste and has important economic value.
In a second aspect, the embodiment of the present invention provides a separation method using the above light hydrocarbon separation system, where the method includes:
firstly, dry gas 101 and liquefied gas 102 enter a primary separation assembly 100, are sequentially cooled by a first cooler 104 and a second cooler 105, and are subjected to primary separation in a phase separator 107 to obtain a hydrocarbon-rich liquid phase 109;
step two, the hydrocarbon-rich liquid phase 109 enters the dividing wall column 201, and in the dividing wall column 201, the components of the hydrocarbon-rich liquid phase 109 are separated:
methane and ethane are withdrawn from the top of the divided wall column 201; propane is withdrawn from the middle of the dividing wall column 201; c4+ stream 208 exits the bottom of dividing wall column 201;
step three, the C4+ stream 208 enters a first debutanizer 300 through a first debutanizer feed inlet 3011, isobutane 303 and 304 are separated in the first debutanizer 300, and a second deisobutanized C4+ stream 308 is discharged;
and step four, feeding the second deisobutanized C4+ material flow 308 into a second debutanizer 401, collecting n-butane 404 from the top of the second debutanizer 401, and discharging a heavy component liquid phase 405.
The separation of light hydrocarbon in the dry gas 101 is realized through the steps, the separated light hydrocarbon can be utilized, and meanwhile, the first aspect is combined, so that the LNG cold energy is effectively utilized, the resources are reasonably utilized, and the energy consumption of light hydrocarbon separation is saved.
Further, the separation method using the light hydrocarbon separation system of the first aspect further comprises the following specific steps:
firstly, the first step further comprises the step of introducing the dry gas 101 and the liquefied gas 102 into a mixer 103, uniformly mixing and then introducing into a first cooler 104. The hydrocarbon-rich liquid phase 109 separated in the phase separator 107 is discharged from the bottom of the phase separator 107, subjected to pressure reduction treatment by a pressure reducing valve 110, and then introduced into the dividing wall column 201.
Secondly, in the second step, steam at the top of the next-door column and bottom materials of the next-door column are formed in the next-door column 201, methane and ethane are discharged from the top of the next-door column 201 and then enter a partial condenser 203, gaseous methane 205 and liquid ethane 206 are collected after fractional condensation, and the residual condensate flows back to the top of the next-door column 201; the gas-liquid mixture in the middle of the dividing wall tower 204 enters a first condenser 204 for condensation, the condensed gas flows back to the middle of the dividing wall tower 201, and the propane 207 is extracted from the middle of the dividing wall tower 201; the C4+ material 208 in the tower bottom material of the dividing wall tower enters the first debutanizer 300, and the residual tower bottom material of the dividing wall tower enters the first reboiler 209 to be heated and then flows back to the bottom of the dividing wall tower 201. The operation pressure of the bulkhead tower 201 is 1 atm-2.5 atm, the temperature of the top of the tower is-104 ℃ to-89 ℃, and the temperature of the bottom of the tower is 4 ℃ to 20 ℃.
In step three, the C4+ material 208 firstly enters the high-pressure tower 301, and high-pressure overhead steam 305 and high-pressure bottom material are formed in the high-pressure tower 301; the tower top steam 305 enters a third reboiler 306 for heat exchange to form a condensate 311, first isobutane 303 is extracted from the condensate 311, and the rest condensate flows back to the top of the high-pressure tower 301; the first deisobutanized C4+ stream 310 in the high pressure column bottom material enters the low pressure column 302, and the rest high pressure column bottom material enters the second reboiler 309 to be heated and then flows back to the bottom of the high pressure column 301. The operating pressure of the high-pressure tower 301 is 2.5atm to 4atm, the temperature of the top of the tower is 16 ℃ to 30 ℃, and the temperature of the bottom of the tower is 27 ℃ to 42 ℃. When the first deisobutanized C4+ material flow 311 enters the low-pressure tower 302, low-pressure tower top steam and low-pressure tower bottom materials are formed in the low-pressure tower 302, the low-pressure tower top steam enters the first condenser 307 for condensation, second isobutane 304 is extracted after condensation, and the residual condensate flows back to the top of the low-pressure tower 302; and a second deisobutanizer C4+ material 308 in the low-pressure tower bottom material enters a second debutanizer 401, and the rest high-pressure tower bottom material enters a third reboiler 306 to be heated and then flows back to the bottom of the low-pressure tower 302 again. The low pressure column 302 was operated at atmospheric pressure, with temperatures at the top of the column of-11 ℃ and at the bottom of the column of 2 ℃ respectively.
Finally, in the fourth step, second debutanizer tower top steam and second debutanizer tower bottom materials are formed in the second debutanizer 401, the second debutanizer tower top steam enters a second condenser 402 for condensation, normal butane 404 is extracted after condensation, and the residual condensate flows back to the top of the second debutanizer 402; the material at the bottom of the second debutanizer enters a fourth reboiler 403 for heating, then a heavy component liquid phase 405 is extracted, and the rest material steam at the bottom of the second debutanizer 403 reflows. The second debutanizer 401 is operated at atmospheric pressure, with a top temperature of-1 deg.C and a bottom temperature of 43 deg.C, respectively.
Moreover, the initial temperature of the LNG raw material 000 serving as a cold source is-150 ℃ to-110 ℃ by integrating the integral separation method. And the flow path of the LNG raw material 000 is as follows: enters from the second cooler 105 and passes through the dephlegmator 203, the third condenser 204, the first cooler 104, the first condenser 307, and the second condenser 402 in this order. The method for separating the light hydrocarbon fully realizes the step utilization of the LNG cold energy and the recovery of the light hydrocarbon in the dry gas, effectively reduces the cost for gasification of the LNG before the LNG is supplied to users and the energy consumption of the light hydrocarbon separation process, and has important economic benefits and popularization prospects.
The specific application of the light hydrocarbon separation system and method will be described in detail below.
Example one
In this embodiment, 80 ten thousand tons/year of light hydrocarbon recovered from a refinery is used as a research object, and the composition of dry gas and liquefied gas from each device after desulfurization treatment is as follows:
mixing the desulfurized 1284kmol/h dry gas 101 with 402kmol/h liquefied gas 102, and then feeding the mixture into a light hydrocarbon separation system provided by the embodiment of the invention:
the initial separation assembly is cooled to-100 ℃ by a first cooler 104 and a second cooler 105 in sequence, and then enters a phase separator 107 to be separated to obtain a hydrocarbon-rich liquid phase 109. The hydrocarbon-rich liquid phase 109 is discharged from the bottom of the phase separator 107, is reduced in pressure by a pressure reducing valve 110, and then enters the dividing wall column 201 from the side of the dividing wall 202.
The dividing wall tower 201 is operated under normal pressure, the temperature of the top of the tower is-104 ℃, the temperature of the bottom of the tower is 4 ℃, the separation of methane, ethane, propane and other heavy components is realized in the tower, furthermore, a small amount of methane gas 205 leaves from the top of the tower and is sent to a gas pipe network, liquid ethane 206 is extracted from the top of the tower, liquid propane 207 is extracted from the side of the tower, and a C4+ material flow 208 leaves from the bottom of the dividing wall tower 201 and enters a high-pressure tower 301.
The operation pressure of the high-pressure tower 301 is 2.5atm, the tower top temperature is 16 ℃, the tower bottom temperature is 27 ℃, the low-pressure tower 302 is operated under normal pressure, the tower top temperature is-11 ℃, and the tower bottom temperature is 2 ℃. Isobutane 303,304 exits overhead from the higher pressure column 301 and the lower pressure column 302. The high pressure column overhead vapor 305 is used to supply heat to the low pressure column reboiler 306 while the overhead vapor condenses back to the top of the high pressure column. A second deisobutanized C4+ stream 308 exits from the bottom of the low pressure column 302 into a second debutanizer 401.
The second debutanizer 401 is operated at atmospheric pressure, with a top temperature of-1 deg.C, a bottom temperature of 43 deg.C, n-butane 404 withdrawn at the top, and liquid phase heavy components 405 withdrawn at the bottom.
The LNG raw material 000 is fed at the initial temperature of-150 ℃ and 4000kmol/h, and sequentially passes through the second cooler 105, the partial condenser 203, the third condenser 204, the first cooler 104, the first condenser 307 and the second condenser 402, so that the comprehensive utilization of the LNG cold energy is realized. The temperature of the LNG after heat exchange is-149 ℃, 148 ℃, 147 ℃, 123 ℃ and 72 ℃ in sequence, and finally the LNG leaves the system at-34 ℃. The product stream results for example one are shown below:
the results show that the product ethane, propane, isobutane and isobutane have molar purities of 99.9% and above, the yields are 99%, 99.8%, 99.3% and 99.5%, and compared with the conventional process, the energy is saved by 31.8%.
Example two
The operation pressure of the dividing wall tower 201 is 1.5atm, the tower top temperature is-98 ℃, the tower bottom temperature is 10 ℃, the operation pressure of the high-pressure tower 301 is 3atm, the tower top temperature is 20 ℃, and the tower bottom temperature is 32 ℃.
The LNG raw material 000 is fed at the initial temperature of-110 ℃ and 5000kmol/h, and sequentially passes through the second cooler 105, the partial condenser 203, the third condenser 204, the first cooler 104, the first condenser 307 and the second condenser 402, so that the comprehensive utilization of the LNG cold energy is realized. The temperature of LNG after heat exchange is-108 ℃, 106 ℃, 104 ℃, 87 ℃ and 49 ℃ in sequence, and finally the LNG leaves the system at-25 ℃. The product stream results for example two are shown below:
the results show that the product ethane, propane, isobutane and isobutane have molar purities of 99.9% and above, the yields are 99.5%, 99.6%, 99.4% and 99.1%, respectively, and the energy is saved by 30% compared with the conventional process.
EXAMPLE III
The operation pressure of the partition tower 201 is 2.5atm, the tower top temperature is-89 ℃, the tower bottom temperature is 20 ℃, the operation pressure of the high-pressure tower 301 of the debutanizer I is 4atm, the tower top temperature is 30 ℃, and the tower bottom temperature is 42 ℃.
The LNG raw material 000 is fed at the initial temperature of-130 ℃ and 4400kmol/h, and sequentially passes through the second cooler 105, the partial condenser 203, the third condenser 204, the first cooler 104, the first condenser 307 and the second condenser 402, so that the comprehensive utilization of the LNG cold energy is realized. The temperature of LNG after heat exchange is-129 ℃, 127 ℃, 125 ℃, 105 ℃ and 60 ℃ in sequence, and finally the LNG leaves the system at-30 ℃. The product stream results for example three are shown below:
the results show that the product ethane, propane, isobutane and isobutane have molar purities of 99.9% and above, the yields are 99.2%, 99.1%, 99.8% and 99.7%, respectively, and compared with the conventional process, the energy is saved by 33%.
The above description is only for the purpose of illustrating the preferred embodiments of the present invention and is not to be construed as limiting the invention, and any modifications, equivalents, improvements and the like that fall within the spirit and principle of the present invention are intended to be included therein.
Claims (19)
1. A light hydrocarbon separation system, comprising: a preliminary separation module (100), a dividing wall tower (201), a first debutanizer tower (300) and a second debutanizer tower (401) which are connected in sequence through pipelines;
the preliminary separation assembly (100) comprises a first cooler (104), a second cooler (105) and a phase separator (107) which are connected in sequence, and the preliminary separation assembly (100) is connected with a feed inlet (2011) of the dividing wall tower;
the dividing wall tower (201) is used for separating methane, ethane and propane and comprises a dephlegmator (203) and a first reboiler (209), and a bottom discharge hole (2012) of the dividing wall tower (201) is connected with a feed hole (3011) of the first debutanizer;
the first debutanizer tower (300) is used for separating isobutane, and comprises a first condenser (307), and a tower bottom discharge hole (3021) of the first debutanizer tower (300) is connected with a feed hole (4011) of the second debutanizer tower (401);
the second debutanizer tower (401) is used for separating n-butane and comprises a second condenser (402) and a fourth reboiler (403);
and the first cooler (104), the second cooler (105), the dephlegmator (203), the first condenser (307) and the second condenser (402) all adopt LNG as a cold source.
2. The light hydrocarbon separation system of claim 1, further comprising an LNG channel to provide a cold source for the light hydrocarbon separation system;
the LNG channel is communicated with the second cooler (105), the dephlegmator (203), the first cooler (104), the first condenser (307) and the second condenser (402) in sequence;
and the second cooler (105) is an LNG inlet and the second condenser (402) is an LNG outlet.
3. The light hydrocarbon separation system of claim 2, wherein the preliminary separation assembly (100) further comprises a mixer (103) upstream of the first cooler (104) and in communication with the first cooler (104).
4. The light hydrocarbon separation system of claim 3, wherein the phase separator (107) has a gas outlet, a first liquid outlet, and a second liquid outlet;
the preliminary separation assembly (100) further comprises: a pressure reducing valve (110) located downstream of the phase separator (107) and in communication with the phase separator (107);
and the second liquid outlet is connected with the pressure reducing valve (110), and the pressure reducing valve (110) is also communicated with the bulkhead tower (201).
5. The light hydrocarbon separation system according to claim 2, wherein a longitudinal partition (202) is provided in the divided wall column (201), and a third condenser (204) is further connected to a middle portion of the divided wall column (201).
6. The light hydrocarbon separation system of claim 5, wherein the third condenser (204) is in communication with the LNG passageway between the partial condenser (203) and the first cooler (104) such that the LNG passes sequentially through the partial condenser (203), the third condenser (204), and the first cooler (104).
7. The light hydrocarbon separation system of claim 2, wherein the first debutanizer column (300) is a double-effect rectification system comprising a higher pressure column (301) and a lower pressure column (302);
the high pressure column (301) comprises a feed inlet (3011) and a third reboiler (309);
the low pressure column (302) comprises a discharge port (3021), a second reboiler (306) and a first condenser (307);
the top of the high pressure column (301) is in communication with the second reboiler (306), the second reboiler (306) being in communication with the upper portion of the high pressure column (301).
8. A method for separating light hydrocarbons using the light hydrocarbon separation system of any of claims 1 to 7, the method comprising:
firstly, dry gas (101) and liquefied gas (102) enter a primary separation assembly (100), are sequentially cooled by a first cooler (104) and a second cooler (105), and are subjected to primary separation in a phase separator (107) to obtain a hydrocarbon-rich liquid phase (109);
step two, the hydrocarbon-rich liquid phase (109) enters a dividing wall column (201), and in the dividing wall column (201), the components of the hydrocarbon-rich liquid phase (109) are separated:
methane and ethane are withdrawn from the top of the divided wall column (201); propane is withdrawn from the middle of the divided wall column (201); a C4+ stream (208) is withdrawn from the bottom of the divided wall column (201);
step three, the C4+ stream (208) enters a first debutanizer (300) through a first debutanizer feed inlet (3011), isobutane (303,304) is separated in the first debutanizer (300), and a second deisobutanized C4+ stream (308) is discharged;
and step four, the second deisobutanized C4+ material flow (308) enters the second debutanizer (401), n-butane (404) is collected from the top of the second debutanizer (401), and a heavy component liquid phase (405) is discharged.
9. The separation method of the light hydrocarbon separation system according to claim 8, wherein the first step further comprises introducing the dry gas (101) and the liquefied gas (102) into a mixer (103), mixing them uniformly, and then introducing them into the first cooler (104).
10. The separation process of the light hydrocarbon separation system of claim 9, wherein the hydrocarbon-rich liquid phase (109) separated in the phase separator (107) is discharged from the bottom of the phase separator (107), is subjected to pressure reduction by a pressure reducing valve (110), and then enters the divided wall column (201).
11. The separation method of the light hydrocarbon separation system according to claim 8, wherein in the second step, a dividing wall column overhead vapor and a dividing wall column bottom material are formed in the dividing wall column (201),
the methane and the ethane enter a partial condenser (203) after being discharged from the top of the dividing wall tower (201), gaseous methane (205) and liquid ethane (206) are collected after the partial condensation, and the residual condensate flows back to the top of the dividing wall tower (201);
the gas-liquid mixture in the middle of the dividing wall tower (201) enters a first condenser (204) for condensation, the condensed gas flows back to the middle of the dividing wall tower (201), and the propane (207) is extracted from the middle of the dividing wall tower (201);
c4+ material (208) in the dividing wall tower bottom material enters a first debutanizer (300), and the rest of the dividing wall tower bottom material enters a first reboiler (209) for heating and then reflows to the bottom of the dividing wall tower (201).
12. The separation method of the light hydrocarbon separation system according to claim 11, wherein the operation pressure of the divided wall column (201) is 1atm to 2.5atm, the temperature of the top of the column is-104 ℃ to-89 ℃, and the temperature of the bottom of the column is 4 ℃ to 20 ℃.
13. The separation process for a light hydrocarbon separation system of claim 8, wherein in step three,
the C4+ material (208) first enters the high pressure column (301) to form a high pressure overhead vapor (305) and a high pressure bottoms material in the high pressure column (301);
the overhead steam (305) enters the third reboiler (306) for heat exchange to form a condensate (311), first isobutane (303) is extracted from the condensate (311), and the rest condensate flows back to the top of the high-pressure tower (301);
and a part of a first deisobutanized C4+ stream (310) in the high-pressure tower bottom material enters a low-pressure tower (302), and the rest of the high-pressure tower bottom material enters a second reboiler (309) to be heated and then flows back to the bottom of the high-pressure tower (301).
14. The separation process of the light hydrocarbon separation system of claim 13, wherein the operating pressure of the high pressure column (301) is 2.5atm to 4atm, the temperature at the top of the column is 16 ℃ to 30 ℃, and the temperature at the bottom of the column is 27 ℃ to 42 ℃.
15. The separation process for a light hydrocarbon separation system of claim 14, wherein step three is performed
Forming a low pressure overhead vapor and a low pressure bottoms stream within the low pressure column (302),
the steam at the top of the low-pressure tower enters the first condenser (307) for condensation, second isobutane (304) is produced after condensation, and the rest condensate flows back to the top of the low-pressure tower (302);
and a part of second deisobutanized C4+ material (308) in the low-pressure tower bottom material enters a second debutanizer (401), and the rest of the high-pressure tower bottom material enters a third reboiler (306) for heating and then reflows to the bottom of the low-pressure tower (302).
16. The separation process for light hydrocarbon separation systems according to claim 15 wherein the low pressure column (302) is operated at atmospheric pressure with a top temperature of-11 ℃ and a bottom temperature of 2 ℃ respectively.
17. The separation process for a light hydrocarbon separation system of claim 8, wherein in step four,
forming second debutanizer tower top steam and second debutanizer tower bottom materials in the second debutanizer tower (401),
the steam at the top of the second debutanizer tower enters a second condenser (402) for condensation, n-butane (404) is produced after condensation, and the residual condensate flows back to the top of the second debutanizer tower (402);
and the material at the bottom of the second debutanizer enters a fourth reboiler (403) for heating, then a heavy component liquid phase (405) is extracted, and the steam of the residual material at the bottom of the second debutanizer (403) flows back.
18. The separation process of the light hydrocarbon separation system of claim 17, wherein the second debutanizer column (401) is operated at atmospheric pressure, with a top temperature of-1 ℃ and a bottom temperature of 43 ℃, respectively.
19. The separation process for light hydrocarbon separation systems according to claim 8, wherein the initial temperature of the LNG feed (000) is in the range of-150 ℃ to-110 ℃;
and the flow path of the LNG raw material (000) is as follows: enters from the second cooler (105) and passes through the dephlegmator (203), the third condenser (204), the first cooler (104), the first condenser (307) and the second condenser (402) in sequence.
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| CN112760127B (en) * | 2019-11-01 | 2022-04-12 | 中国石化工程建设有限公司 | Oil-gas separation and recovery device and method |
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| GB2604559B8 (en) * | 2019-12-19 | 2024-01-17 | Kellogg Brown & Root Llc | Dividing wall column in alkylation process for reactor recycle and product separation |
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