CA2040763A1 - Method of operating an unsaturated gas plant - Google Patents
Method of operating an unsaturated gas plantInfo
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- CA2040763A1 CA2040763A1 CA 2040763 CA2040763A CA2040763A1 CA 2040763 A1 CA2040763 A1 CA 2040763A1 CA 2040763 CA2040763 CA 2040763 CA 2040763 A CA2040763 A CA 2040763A CA 2040763 A1 CA2040763 A1 CA 2040763A1
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Abstract
METHOD OF OPERATING AN UNSATURATED GAS PLANT
ABSTRACT
A method is disclosed for operating a refinery gas plant such as the unsaturated gas plant (USGP) of a catalytic hydrocarbon conversion process that results in a reduction of the corrosive effect of acid gases on the gas plant vessels and equipment. The method comprises contacting acidic hydrocarbon feedstreams to an unsaturated gas plant separator zone with lean acid gas absorbing absorbent in an absorbtion zone comprising at least one liquid absorber bed and one vapor absorber bed. The liquid and vapor absorber beds are located upstream of the separator zone. The feedstreams to the gas plant comprise unstabilized, or wild, liquid gasoline and liquid and vapor output streams from the liquid-vapor separator for inter stage wet gas compressor of the conversion process main fractionator. Accordingly, these feed streams are deacidified before separation in the USGP deethanizer-absorber, sponge absorber, and debutanizer. This also eliminates the need for deacidification of the gas plant product stream.
ABSTRACT
A method is disclosed for operating a refinery gas plant such as the unsaturated gas plant (USGP) of a catalytic hydrocarbon conversion process that results in a reduction of the corrosive effect of acid gases on the gas plant vessels and equipment. The method comprises contacting acidic hydrocarbon feedstreams to an unsaturated gas plant separator zone with lean acid gas absorbing absorbent in an absorbtion zone comprising at least one liquid absorber bed and one vapor absorber bed. The liquid and vapor absorber beds are located upstream of the separator zone. The feedstreams to the gas plant comprise unstabilized, or wild, liquid gasoline and liquid and vapor output streams from the liquid-vapor separator for inter stage wet gas compressor of the conversion process main fractionator. Accordingly, these feed streams are deacidified before separation in the USGP deethanizer-absorber, sponge absorber, and debutanizer. This also eliminates the need for deacidification of the gas plant product stream.
Description
`` 2 ~ 3 METHOD OF OPERATING ~N UNSATURATED GAS PLANT
This invention relates to a method of operating the unsaturated gas plant of a hydrocarbon catalytic conversion process.
Refinery processes such as hydrocracking, coking and catalytic cracking produce substantial quantities of sour gases which are typically collected in a gas plant such as an unsaturated gas plant (USGP). Figure 1 presents a proc~ss schematic for a typical fluid catalytic cracking plant incorporating an unsaturated gas plant downstream of the main fluid catalytic cracking (FCC) fractionator. In the FCC process shown, feed (20), such as gas oil, is heated in a heater (21) and passed to the bottom of the riser section (22) of a catalytic cracXing reactor (23) where the feed comes into contact with catalyst recirculated from a catalyst regenerator (24) at high temperature. The feed is cracked in the riser section (22) to provide an over-head stream (25) while catalyst is recycled through the regenerator (24) by way of conduits (26,27). The overhead stream (25), after catalyst separation, passes to the main FCC fractionator (19) where it is separated into a gasoline and light gas fraction (18), light fuel oil (28) and heavy fuel oil (29) and a bottoms fraction (30) which may be recycled (31) to the FCC feed. The gasoline and light gas fraction (18) is passed to an accumulator (17) to provide a reflux stream (16) to the main fractionator (19~. Also exiting from the accumulator are wet gases which are compressed in compressors (15) and passed by way of a cooler (31) and a conduit (32) to the lower section of an absorber/stripper (33). A "wild" or unstabilized gasoline fraction from the accumulator is passed to the 7 ~ 3 upper section of the absorber/stripper through conduit (34). The absorber/stripper overhead product is a light gas and C2- fraction (35) which is passed to a sponge absorber 45 for separation of the C2- fraction as overhead 46. The bottom fraction of the absorber/-stripper (33) is passed through line (36) to a debutanizer (37), where a C4- overhead is passed to depropanizer (38) to provide a propane and propylene product (39). The debutanizer bottoms effluent comprises a C5+ fraction and is passed to a gasoline splitter (41) to produce a light gasoline fraction (42) and heavy gasoline fraction (43), a portion of which is returned through conduit (44) to absorber/stripper (33).
In so far as olefinic gases produced in the typical FCC process described above generally contain acid gases, their removal is conventionally conducted as part of the USGP operations. These acid gases are primarily hydrogen sulfide and carbon dioxide but also include hydrogen cyanide. A large variety of acid gas removal processes are available that separate into processes based upon chemical solvent action including solvents such as monoetholamine (MEA), diethyanolamine (DEA), and hot potassium carbonate; processes depending on physical solvent action such as Selexol and Recti sol; and processes based on dry adsorbents such as molecular sieves, activated charcoal and iron sponge.
Conventionally, these acid gas removal processes are installed downstream of the sponge absorber and debutanizer. Consequently, the acid gases are carried through the various upstream separation processes of the USGP including the absorber-deethanizer, sponge absor~er and debutanizerO This configuration tends to increase the rate of acid gas induced corrosion of a large portion of the vessels and ancillary equipment in the USGP, leading to increased maintenance operations and plant downtime.
7 ~ 3 A process has now been discovered for operating an unsaturated gas plant of a ~atalytic hydrocarbon conversion process that results in a reduction of the corrosive effect of acid yases on USGP vessels and equipment.
Accordingly, the invention resides in a method for operating an unsaturated gas plant of a catalytic hydrocarbon conversion process, comprising the step of contacting an acidic hydrocarbon feedstream to a gas plant separator zone with a lean acid absorbent in an absorption zone comprising at least one liquid absorber bed and at least one vapor absorber bed upstream of said separator zone, said feedstream comprising unstabilized liquid gasoline and liquid and vapor output streams from a liquid-vapor separator for inter-stage liquid and compressor effluents from a fractionator of said conversion process.
More particularly, the method of the invention comprises combining unsaturated gasoline and liquid output streams and countercurrently contacting the combined streams with lean absorbent in a liquid absorber bed to produce deacidified liquid hydrocarbon effluent, which is then passed to the separator zone.
Partially acidified absorbent from the liquid absorber bed is passed to the vapor absorber bed where the vapor output stream is contacted countercurrently with the partially acidified absorbent to produce deacidified vapor hydrocarbon effluent. The deacidified vapor hydrocarbon effluent is then passed to the separator zone. Rich absorbent is withdrawn from the vapor absorber bed for regeneration.
In the accompanying drawings, Fiqure 1 is a schematic diagram of a prior art fluid catalytic cracking process including an USGP, Figure 2 is a schematic diagram detailing a conventional USGP design, `` 2 ~ 3 Figure 3 is a schematic diagram illustrating the design of a USGP according to one example of the present invention.
Figure 4 is a schematic diagram illustrating the design of a USGP according to a further example of the present invention.
Referring to Figure 2, in the conventional USGP
design shown, the feedstreams to the plant are principally derived from the main fractionator of the associated hydrocarbon conversion process and include wild or unstabilized gasoline, hydrocarbon gases from the compressor outlet and interstage liquids. These feedstreams are acidic in nature in that they are relatively rich in acidic gases such as hydrogen sulfide and hydrogen cyanide. Wild or unstabilized gasoline (210) from the hydrocarbon conversion process is passed to an upper portion of a deethanizer-absorber (220). The compressor outlet gases (205) and inter-stage liquid (207) are fed by way of a cooler (209) to a separator (211). From the separator, a vapor stream (213) is transferred to the mid-portion of the deethanizer-absorber while a liquid stream (217) is transferred to the lower portion of the deethanizer-absorber. Due to the vapor/liquid equilibrium conditions at the top of the deethanizer-absorber (220), a significant amount of lighter hydrocarbons are vaporized from the lean oil introduced into the deethanizer-absorber and leave the top of the column with the residue gas. This material is passed by conduit (219) to sponge absorber (230), from which the light hydrocarbons are transferred as an overhead stream to the bottom section of an amine absorber (240). An amine, such as diethanolamine, is introduced (223) into a top portion of the absorber (240) to affect acid gas removal of the light hydrocarbon. The overhead from the absorber (240) is then recovered (227) as deacidified fuel gas.
.
7 ~ 3 Sufficient reboil is added to the bottom of the stripping section of the absorber-deethanizer (220) to remove at least a portion o~ absorbed ethane and methane from the bottom liquid product. The deethanized oil is then passed via conduit (229) to debutanizer (250) where essentially all the recovered C3-C4 are fractionated and removed as overhead product through conduit (231). From the debutanizer a bottom stream (233) comprising C5+ hydrocarbons is recovered.
A portion of the C5+ hydrocarbon may be cooled and recycled to the top of the deethanizer-absorber tower.
The debutanizer overhead (231) is transferred to the bottom portion of further amine absorber (260) wherein acid gases are removed in contact with a diethanolamine stream (237). The diacidifisd overhead stream (239) from amine absorber (260) comprising LPG is recovered and subjected to further desulfurization as appro-priate.
In the foregoing conventional USGP design it will be appreciated that the acid gases contained in the feedstreams are present during the ma~or course of the plant operation in vessels (220), (230), and (250).
Accordingly, these vesseIs and their separation operations are subject to chemically corrosive attack by these gases before their removal in amine absorber vessels (240) and (~60).
Referring to Figure 3, in the USGP of said one example of the invention, the principal separation operations represented by deethanizer-absorber zone A, sponge absorber zone B and debutanizer zone C are located downstream of amine absorber operations as opposed to a location upstream as practiced in the prior art heretofore. This is achieved by installing diethanolamine absorber D containing two amine absorption zones E and F upstream of the aforestated separation zones. Amine absorption zones E and F are interconnected such that amine can flow from zone E to -` 20A-07~3 zone F. In the preferred process compressor outlet gases (310) and inter-stage liquids (315) are cooled in a cooler (320) and then separated in separator (330).
The liquid fraction (335) from separator (330) is mixed with wild gasoline feedstream (340) and the mixture is introduced into the bottom portion of amine absorber zone E in countercurrent flow with a fresh diethanol amine (DEA) mixture (350) introduced into the top portion of zone E. Partially spent DE~ is passed via line (355) to the upper portion of zone F in combina-tion with fresh DEA (360). The gaseous fraction (365) is passed to the lower portion of zone F in counter-current contact with DEA. Spent DEA is withdrawn from a lower portion o~ zone F. The deacidified wild gasoline stream is passed as an overhead (375) from zone E to the upper portion of absorber deethanizer A. The deacidified vapor fraction is transferred (38n) from zone F to the middle portion of deethanizer A. From the deethanizer-absorber a deacidified ov~rhead is treated in sponge absorber B to produce deacidi~ied fuel gas (385). The bottom fraction from zone A is separated in debutanizer C to produce a deacidified LPG
(390) as overhead and deacidified C5 hydrocaxbons as a bottom fraction (395).
In the arrangement described in Figure 3, FCC wild gasoline and the high pressure separator liquids are mixed and amine treated upstream of the deethanizer-absorber. Preferably, about 50-80% of the total amine circulation rate is sent to this amine absorber. The deethanizer-absorber vapor feed is then sent to another amine absorber where preferably 20-50% of the total amine circulation rate is fed to the absorber upper tray and the rich amine from the other amine absorber is fed to a few trays below the upper tray. In an alternative design, zone F receives the cooled compressor interstage vapor, while the inter-stage - 2~7~
liquid is mixed with the wild gasoline and the combined stream is treated in zone E.
Figure 4 illustrates a higher recovery variation in which, as in the embodiment shown in Figure 1, the USGP separation zones A, B, and C are located downstream of the DEA amine absorber D. However, in the instant embodiment, absorber D contains three separate but interconnected amine absorber zones E, F, and G, each of which is fed with a fresh amine stream.
Lean DEA is introduced (410) into a top portion of zone B. Partially spent DEA is transferred (415) in conjunction with fresh DEA (420) ~rom a bottom portion of zone E to the top of zone F. From the bottom of zone F partially spent DEA stream and fresh DEA (430) are passed to the top of zone G. Rich DEA is withdrawn from a bottom portion of zone G. Wild gasoline is introduced (440) into the bottom portion of zone F
countercurrent to the flow of DEA. The liquid fraction (450) from separator (455) is introduced to the bottom portion of zone E also countercurrent to the flow of DEA while the vapor portion (460) from the separator is passed to the lower portion of zone F.
In Figure 4, deacidified wild gasoline (46) is withdrawn from a bottom portion of zone E and introduced to a top portion of the deethanizer-absorber zone A. The deacidified vapor fraction is transferred (470) to the mid portion or lower portion of zone A
from a bottom portion of zone F while an overhead stream from zone E is introduced into a lower portion of deethanizer-absorber zone A.
As in the Figure 3 embodiment, the deacidified effluents from zone A are further treated and separated in sponge absorber B and debutanizer C to produce deacidified fuel gas, deacidified LPG, and deacidified C5 hydrocarbons.
In the foregoing design, Figure 4, the three deethanizer-absorber feedstreams including the high 2~763 pressure separator li.qllid, high pressure separator vapor, and FCC wild gasoline are amine treated in three amine absorbers. In this design ~he USGP LPG recovery is improved due to higher hydrocarbons partial pressure in the deethanizer-absorber and sponge absorber and deacidification after removing the recoverable acids and C02.
This invention relates to a method of operating the unsaturated gas plant of a hydrocarbon catalytic conversion process.
Refinery processes such as hydrocracking, coking and catalytic cracking produce substantial quantities of sour gases which are typically collected in a gas plant such as an unsaturated gas plant (USGP). Figure 1 presents a proc~ss schematic for a typical fluid catalytic cracking plant incorporating an unsaturated gas plant downstream of the main fluid catalytic cracking (FCC) fractionator. In the FCC process shown, feed (20), such as gas oil, is heated in a heater (21) and passed to the bottom of the riser section (22) of a catalytic cracXing reactor (23) where the feed comes into contact with catalyst recirculated from a catalyst regenerator (24) at high temperature. The feed is cracked in the riser section (22) to provide an over-head stream (25) while catalyst is recycled through the regenerator (24) by way of conduits (26,27). The overhead stream (25), after catalyst separation, passes to the main FCC fractionator (19) where it is separated into a gasoline and light gas fraction (18), light fuel oil (28) and heavy fuel oil (29) and a bottoms fraction (30) which may be recycled (31) to the FCC feed. The gasoline and light gas fraction (18) is passed to an accumulator (17) to provide a reflux stream (16) to the main fractionator (19~. Also exiting from the accumulator are wet gases which are compressed in compressors (15) and passed by way of a cooler (31) and a conduit (32) to the lower section of an absorber/stripper (33). A "wild" or unstabilized gasoline fraction from the accumulator is passed to the 7 ~ 3 upper section of the absorber/stripper through conduit (34). The absorber/stripper overhead product is a light gas and C2- fraction (35) which is passed to a sponge absorber 45 for separation of the C2- fraction as overhead 46. The bottom fraction of the absorber/-stripper (33) is passed through line (36) to a debutanizer (37), where a C4- overhead is passed to depropanizer (38) to provide a propane and propylene product (39). The debutanizer bottoms effluent comprises a C5+ fraction and is passed to a gasoline splitter (41) to produce a light gasoline fraction (42) and heavy gasoline fraction (43), a portion of which is returned through conduit (44) to absorber/stripper (33).
In so far as olefinic gases produced in the typical FCC process described above generally contain acid gases, their removal is conventionally conducted as part of the USGP operations. These acid gases are primarily hydrogen sulfide and carbon dioxide but also include hydrogen cyanide. A large variety of acid gas removal processes are available that separate into processes based upon chemical solvent action including solvents such as monoetholamine (MEA), diethyanolamine (DEA), and hot potassium carbonate; processes depending on physical solvent action such as Selexol and Recti sol; and processes based on dry adsorbents such as molecular sieves, activated charcoal and iron sponge.
Conventionally, these acid gas removal processes are installed downstream of the sponge absorber and debutanizer. Consequently, the acid gases are carried through the various upstream separation processes of the USGP including the absorber-deethanizer, sponge absor~er and debutanizerO This configuration tends to increase the rate of acid gas induced corrosion of a large portion of the vessels and ancillary equipment in the USGP, leading to increased maintenance operations and plant downtime.
7 ~ 3 A process has now been discovered for operating an unsaturated gas plant of a ~atalytic hydrocarbon conversion process that results in a reduction of the corrosive effect of acid yases on USGP vessels and equipment.
Accordingly, the invention resides in a method for operating an unsaturated gas plant of a catalytic hydrocarbon conversion process, comprising the step of contacting an acidic hydrocarbon feedstream to a gas plant separator zone with a lean acid absorbent in an absorption zone comprising at least one liquid absorber bed and at least one vapor absorber bed upstream of said separator zone, said feedstream comprising unstabilized liquid gasoline and liquid and vapor output streams from a liquid-vapor separator for inter-stage liquid and compressor effluents from a fractionator of said conversion process.
More particularly, the method of the invention comprises combining unsaturated gasoline and liquid output streams and countercurrently contacting the combined streams with lean absorbent in a liquid absorber bed to produce deacidified liquid hydrocarbon effluent, which is then passed to the separator zone.
Partially acidified absorbent from the liquid absorber bed is passed to the vapor absorber bed where the vapor output stream is contacted countercurrently with the partially acidified absorbent to produce deacidified vapor hydrocarbon effluent. The deacidified vapor hydrocarbon effluent is then passed to the separator zone. Rich absorbent is withdrawn from the vapor absorber bed for regeneration.
In the accompanying drawings, Fiqure 1 is a schematic diagram of a prior art fluid catalytic cracking process including an USGP, Figure 2 is a schematic diagram detailing a conventional USGP design, `` 2 ~ 3 Figure 3 is a schematic diagram illustrating the design of a USGP according to one example of the present invention.
Figure 4 is a schematic diagram illustrating the design of a USGP according to a further example of the present invention.
Referring to Figure 2, in the conventional USGP
design shown, the feedstreams to the plant are principally derived from the main fractionator of the associated hydrocarbon conversion process and include wild or unstabilized gasoline, hydrocarbon gases from the compressor outlet and interstage liquids. These feedstreams are acidic in nature in that they are relatively rich in acidic gases such as hydrogen sulfide and hydrogen cyanide. Wild or unstabilized gasoline (210) from the hydrocarbon conversion process is passed to an upper portion of a deethanizer-absorber (220). The compressor outlet gases (205) and inter-stage liquid (207) are fed by way of a cooler (209) to a separator (211). From the separator, a vapor stream (213) is transferred to the mid-portion of the deethanizer-absorber while a liquid stream (217) is transferred to the lower portion of the deethanizer-absorber. Due to the vapor/liquid equilibrium conditions at the top of the deethanizer-absorber (220), a significant amount of lighter hydrocarbons are vaporized from the lean oil introduced into the deethanizer-absorber and leave the top of the column with the residue gas. This material is passed by conduit (219) to sponge absorber (230), from which the light hydrocarbons are transferred as an overhead stream to the bottom section of an amine absorber (240). An amine, such as diethanolamine, is introduced (223) into a top portion of the absorber (240) to affect acid gas removal of the light hydrocarbon. The overhead from the absorber (240) is then recovered (227) as deacidified fuel gas.
.
7 ~ 3 Sufficient reboil is added to the bottom of the stripping section of the absorber-deethanizer (220) to remove at least a portion o~ absorbed ethane and methane from the bottom liquid product. The deethanized oil is then passed via conduit (229) to debutanizer (250) where essentially all the recovered C3-C4 are fractionated and removed as overhead product through conduit (231). From the debutanizer a bottom stream (233) comprising C5+ hydrocarbons is recovered.
A portion of the C5+ hydrocarbon may be cooled and recycled to the top of the deethanizer-absorber tower.
The debutanizer overhead (231) is transferred to the bottom portion of further amine absorber (260) wherein acid gases are removed in contact with a diethanolamine stream (237). The diacidifisd overhead stream (239) from amine absorber (260) comprising LPG is recovered and subjected to further desulfurization as appro-priate.
In the foregoing conventional USGP design it will be appreciated that the acid gases contained in the feedstreams are present during the ma~or course of the plant operation in vessels (220), (230), and (250).
Accordingly, these vesseIs and their separation operations are subject to chemically corrosive attack by these gases before their removal in amine absorber vessels (240) and (~60).
Referring to Figure 3, in the USGP of said one example of the invention, the principal separation operations represented by deethanizer-absorber zone A, sponge absorber zone B and debutanizer zone C are located downstream of amine absorber operations as opposed to a location upstream as practiced in the prior art heretofore. This is achieved by installing diethanolamine absorber D containing two amine absorption zones E and F upstream of the aforestated separation zones. Amine absorption zones E and F are interconnected such that amine can flow from zone E to -` 20A-07~3 zone F. In the preferred process compressor outlet gases (310) and inter-stage liquids (315) are cooled in a cooler (320) and then separated in separator (330).
The liquid fraction (335) from separator (330) is mixed with wild gasoline feedstream (340) and the mixture is introduced into the bottom portion of amine absorber zone E in countercurrent flow with a fresh diethanol amine (DEA) mixture (350) introduced into the top portion of zone E. Partially spent DE~ is passed via line (355) to the upper portion of zone F in combina-tion with fresh DEA (360). The gaseous fraction (365) is passed to the lower portion of zone F in counter-current contact with DEA. Spent DEA is withdrawn from a lower portion o~ zone F. The deacidified wild gasoline stream is passed as an overhead (375) from zone E to the upper portion of absorber deethanizer A. The deacidified vapor fraction is transferred (38n) from zone F to the middle portion of deethanizer A. From the deethanizer-absorber a deacidified ov~rhead is treated in sponge absorber B to produce deacidi~ied fuel gas (385). The bottom fraction from zone A is separated in debutanizer C to produce a deacidified LPG
(390) as overhead and deacidified C5 hydrocaxbons as a bottom fraction (395).
In the arrangement described in Figure 3, FCC wild gasoline and the high pressure separator liquids are mixed and amine treated upstream of the deethanizer-absorber. Preferably, about 50-80% of the total amine circulation rate is sent to this amine absorber. The deethanizer-absorber vapor feed is then sent to another amine absorber where preferably 20-50% of the total amine circulation rate is fed to the absorber upper tray and the rich amine from the other amine absorber is fed to a few trays below the upper tray. In an alternative design, zone F receives the cooled compressor interstage vapor, while the inter-stage - 2~7~
liquid is mixed with the wild gasoline and the combined stream is treated in zone E.
Figure 4 illustrates a higher recovery variation in which, as in the embodiment shown in Figure 1, the USGP separation zones A, B, and C are located downstream of the DEA amine absorber D. However, in the instant embodiment, absorber D contains three separate but interconnected amine absorber zones E, F, and G, each of which is fed with a fresh amine stream.
Lean DEA is introduced (410) into a top portion of zone B. Partially spent DEA is transferred (415) in conjunction with fresh DEA (420) ~rom a bottom portion of zone E to the top of zone F. From the bottom of zone F partially spent DEA stream and fresh DEA (430) are passed to the top of zone G. Rich DEA is withdrawn from a bottom portion of zone G. Wild gasoline is introduced (440) into the bottom portion of zone F
countercurrent to the flow of DEA. The liquid fraction (450) from separator (455) is introduced to the bottom portion of zone E also countercurrent to the flow of DEA while the vapor portion (460) from the separator is passed to the lower portion of zone F.
In Figure 4, deacidified wild gasoline (46) is withdrawn from a bottom portion of zone E and introduced to a top portion of the deethanizer-absorber zone A. The deacidified vapor fraction is transferred (470) to the mid portion or lower portion of zone A
from a bottom portion of zone F while an overhead stream from zone E is introduced into a lower portion of deethanizer-absorber zone A.
As in the Figure 3 embodiment, the deacidified effluents from zone A are further treated and separated in sponge absorber B and debutanizer C to produce deacidified fuel gas, deacidified LPG, and deacidified C5 hydrocarbons.
In the foregoing design, Figure 4, the three deethanizer-absorber feedstreams including the high 2~763 pressure separator li.qllid, high pressure separator vapor, and FCC wild gasoline are amine treated in three amine absorbers. In this design ~he USGP LPG recovery is improved due to higher hydrocarbons partial pressure in the deethanizer-absorber and sponge absorber and deacidification after removing the recoverable acids and C02.
Claims (10)
1. A method for operating an unsaturated gas plant of a catalytic hydrocarbon conversion process, comprising contacting an acidic hydrocarbon feedstream to a gas plant separator zone with lean acid absorbent in an absorption zone comprising at least one liquid absorber bed and one vapor absorber bed upstream of said separator zone, said feedstreams comprising unstabilized liquid gasoline and liquid and vapor output streams from a liquid-vapor separator for inter-stage liquid and compressor effluents from a fractionator of said conversion process.
2. The method of claim 1 wherein said separator zone comprises deethanizer zone and debutanizer zone.
3. The method of claim 2 further comprising introducing deacidified liquid and vapor effluent from said absorption zone to said deethanizer zone; and separating an overhead stream comprising deacidified fuel gas and a bottoms stream comprising deacidified LPG and C5+ hydrocarbons.
4. The method of claim 3 further comprising, passing said deacidified LPG and C5+ hydrocarbons to debutanizer zone; and separating an overhead stream comprising LPG and a bottoms stream comprising C5+
hydrocarbons.
hydrocarbons.
5. The method of claim 1 further comprising;
(a) combining said unstabilized gasoline and said liquid output stream and countercurrrently contacting combined streams with said lean absorbent in said liquid absorber bed to produce deacidified liquid hydrocarbon effluent;
(b) passing step (a) hydrocarbon effluent to said saparator zone;
(c) passing partially acidified absorbent from said liquid absorber bed to said vapor absorber bed;
(d) contacting said vapor output stream countercurrently with said partially acidified absorbent in said vapor absorber bed to produce deacidified vapor hydrocarbon effluent;
(e) passing step (d) vapor hydrocarbon effluent to said separator zone; and (f) withdrawing rich absorbent from said vapor absorber bed.
(a) combining said unstabilized gasoline and said liquid output stream and countercurrrently contacting combined streams with said lean absorbent in said liquid absorber bed to produce deacidified liquid hydrocarbon effluent;
(b) passing step (a) hydrocarbon effluent to said saparator zone;
(c) passing partially acidified absorbent from said liquid absorber bed to said vapor absorber bed;
(d) contacting said vapor output stream countercurrently with said partially acidified absorbent in said vapor absorber bed to produce deacidified vapor hydrocarbon effluent;
(e) passing step (d) vapor hydrocarbon effluent to said separator zone; and (f) withdrawing rich absorbent from said vapor absorber bed.
6. The method of claim 5 wherein fresh, lean absorbent is mixed with step (c) partially acidified absorbent.
7. The method of claim 1 wherein said absorption zone comprises a first and second liquid absorber beds and a vapor absorber bed.
8. The method of claim 7 further comprising;
deacidifying said liquid output stream in said first absorber bed in countercurrent contact with said lean absorbent;
passing partially acidified absorbent from said first bed to said second bed and deacidifying said gasoline therein in countercurrent contact with said partially acidified absorbent and fresh, lean absorbent;
passing partially acidified absorbent from said second bed to said vapor bed and deacidifying said vapor output therein in countercurrent contact with said partially acidified absorbent and fresh, lean absorbent; and passing deacidified liquid output stream, gasoline stream and vapor stream from said absorption zone to said separator zone.
deacidifying said liquid output stream in said first absorber bed in countercurrent contact with said lean absorbent;
passing partially acidified absorbent from said first bed to said second bed and deacidifying said gasoline therein in countercurrent contact with said partially acidified absorbent and fresh, lean absorbent;
passing partially acidified absorbent from said second bed to said vapor bed and deacidifying said vapor output therein in countercurrent contact with said partially acidified absorbent and fresh, lean absorbent; and passing deacidified liquid output stream, gasoline stream and vapor stream from said absorption zone to said separator zone.
9. A method for deacidifying acidic liquid and vapor hydrocarbon feedstreams to a catalytic hydrocarbon conversion process unsaturated gas plant, comprising:
contacting said liquid feedstreams in an absorber bed with acid absorbing absorbent in countercurrent flow;
withdrawing deacidified liquid feedstreams and passing said deacidified liquid feedstreams to said unsaturated gas plant deethanizer-debutanizer separator zone;
contacting said vapor feedstream in an absorber bed with acid absorbing absorbent in countercurrent flow;
withdrawing deacidifed vapor feedstream and passing said deacidified vapor feedstream to said unsaturated gas plant deethanizer-debutanizer separator zone.
contacting said liquid feedstreams in an absorber bed with acid absorbing absorbent in countercurrent flow;
withdrawing deacidified liquid feedstreams and passing said deacidified liquid feedstreams to said unsaturated gas plant deethanizer-debutanizer separator zone;
contacting said vapor feedstream in an absorber bed with acid absorbing absorbent in countercurrent flow;
withdrawing deacidifed vapor feedstream and passing said deacidified vapor feedstream to said unsaturated gas plant deethanizer-debutanizer separator zone.
10. The method of any preceding claim wherein said absorbent is diethanolamine.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA 2040763 CA2040763A1 (en) | 1989-06-21 | 1991-04-18 | Method of operating an unsaturated gas plant |
Applications Claiming Priority (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US07/369,169 US5015364A (en) | 1989-06-21 | 1989-06-21 | Method and means for refinery gas plant operation |
| CA 2040763 CA2040763A1 (en) | 1989-06-21 | 1991-04-18 | Method of operating an unsaturated gas plant |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CA2040763A1 true CA2040763A1 (en) | 1992-10-19 |
Family
ID=25674561
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA 2040763 Abandoned CA2040763A1 (en) | 1989-06-21 | 1991-04-18 | Method of operating an unsaturated gas plant |
Country Status (1)
| Country | Link |
|---|---|
| CA (1) | CA2040763A1 (en) |
-
1991
- 1991-04-18 CA CA 2040763 patent/CA2040763A1/en not_active Abandoned
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