CN103608431A - Process and apparatus for recovering hydroprocessed hydrocarbons with two strippers in series - Google Patents
Process and apparatus for recovering hydroprocessed hydrocarbons with two strippers in series Download PDFInfo
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- CN103608431A CN103608431A CN201280029976.0A CN201280029976A CN103608431A CN 103608431 A CN103608431 A CN 103608431A CN 201280029976 A CN201280029976 A CN 201280029976A CN 103608431 A CN103608431 A CN 103608431A
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- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D3/00—Distillation or related exchange processes in which liquids are contacted with gaseous media, e.g. stripping
- B01D3/34—Distillation or related exchange processes in which liquids are contacted with gaseous media, e.g. stripping with one or more auxiliary substances
- B01D3/38—Steam 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
- C10G49/00—Treatment of hydrocarbon oils, in the presence of hydrogen or hydrogen-generating compounds, not provided for in a single one of groups C10G45/02, C10G45/32, C10G45/44, C10G45/58 or C10G47/00
- C10G49/22—Separation of effluents
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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
- C10G69/00—Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one other conversion process
- C10G69/02—Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one other conversion process plural serial stages only
- C10G69/04—Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one other conversion process plural serial stages only including at least one step of catalytic cracking in the absence of hydrogen
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- General Chemical & Material Sciences (AREA)
- Organic Chemistry (AREA)
- Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
Abstract
A process and apparatus are disclosed for recovering hydroprocessing effluent from a hydroprocessing unit utilizing a hot stripper and a cold stripper. A net overhead stream from the hot stripper is forwarded to the cold stripper for further stripping. The invention is particularly suitable for hydrotreating residue feed streams. The hot stripped stream may be subjected to fluid catalytic cracking. The apparatus and process eliminate the need for a fired heater in the product recovery unit.
Description
The application requires the U. S. application No.13/213 submitting on August 19th, 2011, and 205 and No.13/213,225 right of priority.
Invention field
The field of the invention is the recovery of the hydrocarbon flow of hydrogenation processing.
Background of invention
Hydrogenation is processed the method that under the existence that can be included in hydrogenation processing catalyst and hydrogen, hydrocarbon is changed into more valuable product.
Hydrocracking for becoming hydrocarbon cracking the hydrogenation working method of lower molecular weight hydrocarbon under the existence of hydrogen and hydrocracking catalyst.Depend on required output, hydrocracking unit can contain the bed of one or more identical or different catalyzer.Slurry hydrocracking is for resid feed being cracked into the slurried catalysis process of gas oil and fuel.
Due to rule and the regulations of environmental concerns and formulation in the recent period, vendible fuel must meet about pollutent as the more and more lower restriction of sulphur and nitrogen.New regulations require from diesel oil substantially completely except desulfuration.For example, ultra-low-sulphur diesel (ULSD) requires to be generally to be less than 10wppm sulphur.
Hydrotreatment is for for removing heteroatoms if sulphur and nitrogen are to meet fuel specification and to make the hydrogenation working method that olefin(e) compound is saturated from hydrocarbon flow.Hydrotreatment can be carried out high or low depressing, but conventionally under the pressure lower than hydrocracking, carries out.Can be by the resid feed hydrotreatment of the bottoms of the bottoms from normal pressure crude tower and/or reduced crude tower so that it be more suitable for fluid catalytic cracking or other method for improving.Diesel oil and petroleum naphtha are by Residual oil hydrotreatment is produced, and necessary recovery with compensatory value.
Hydrogenation processing recovery unit generally include for by the effluent of hydrogenation processing with stripping medium if steam stripped is to remove the stripper of undesired hydrogen sulfide.Then before in entering product separation column, steam stripped effluent is heated in fired heater to cut point to reclaim product as petroleum naphtha, kerosene and diesel oil.
Because harsh processing condition used are as high-temperature and pressure, hydrogenation processing is that energy expenditure is very large.Along with the time goes over, although spent many effort about improving the energy characteristics of hydrogenation processing, focus is to reduce reactor heaters load.Yet, need large heater loads before in entering product separation column, steam stripped effluent to be heated.
Therefore, still need to from add hydroprocessed effluent streams, reclaim improving one's methods of fuel Products.These class methods more Energy Efficient to meet the cumulative demand of refinery.
Summary of the invention
In method embodiment, the present invention includes hydrogenation working method, described method comprises processes to provide hydrogenation processing effluent stream by hydrocarbon charging hydrogenation in hydrogenation processing reactor.By the hotter hydrogenation processing effluent stream for a part of hydrogenation processing effluent stream in hot stripper stripping so that hot stripping material stream to be provided.Finally, by the colder hydrogenation processing effluent stream for a part of hydrogenation processing effluent stream and the steam that carrys out self-heating stripper in cold stripper stripping so that cold stripping material stream to be provided.
In other method embodiment, the present invention includes for reclaim the hydrogenation processed products recovery method of product from colder hydrogenation processing effluent stream and hotter hydrogenation processing effluent stream, described method comprise by hotter hydrogenation processing effluent stream in hot stripper stripping so that hot stripping material stream to be provided.By colder hydrogenation processing effluent stream and the steam that carrys out self-heating stripper in cold stripper stripping so that cold stripping material stream to be provided.
In other method embodiment, the present invention includes hydrogenation working method, described method comprise by hydrocarbon charging in hydrogenation processing reactor hydrotreatment so that hydrogenation processing effluent stream to be provided.By the hotter hydrogenation processing effluent stream for a part of hydrogenation processing effluent stream in hot stripper stripping so that hot stripping material stream to be provided.By the colder hydrogenation processing effluent stream for a part of hydrogenation processing effluent stream and the steam that carrys out self-heating stripper in cold stripper stripping so that cold stripping material stream to be provided.By the fluid catalytic cracking of hot stripping material stream.Finally cold stripping material flow point is heated up in a steamer.
In equipment embodiment, the present invention includes hydrogenation processing units, described equipment comprises hydrogenation processing reactor.Hot stripper is communicated with that with hydrogenation processing reactor hotter hydrogenation is processed to effluent stream stripping.Cold stripper is communicated with that with hydrogenation processing reactor colder hydrogenation is processed to effluent stream stripping.Finally, cold stripper is communicated with hot stripper.
In another equipment embodiment, the present invention further comprises for processing the hydrogenation processed products recovery system of cold hydrogenation processing effluent stream and hot hydrogenation processing effluent stream, and described equipment comprises and adds hydroprocessed effluent streams pipeline with heat and is communicated with that hot hydrogenation is processed to the steam stripped hot stripper of effluent stream.Cold stripper is communicated with that with the cold hydroprocessed effluent streams pipeline that adds cold hydrogenation is processed to effluent stream stripping.Finally, cold stripper is communicated with hot stripper.
In another equipment embodiment, the present invention further comprises hydrogenation processing units, and described equipment comprises hydrotreating reactor.Hot stripper is communicated with that with hydrotreating reactor hotter hydrogenation is processed to effluent stream stripping.Cold stripper be communicated with hydrotreating reactor with will be colder hydrogenation processing effluent stream stripping and cold stripper be communicated with hot stripper.Fluid catalytic cracking unit is communicated with carrying out the bottoms pipeline of self-heating stripper.Finally, product separation column is communicated with carrying out the bottoms pipeline of self cooling stripper.
Accompanying drawing summary
This figure is the simplification of flowsheet figure of one embodiment of the invention.
Definition
Term " connection " means material and is flowing in operation and allows between listed assembly.
Term " downstream connection " means at least a portion and flows into the object outflow that the material in downstream connection object can be communicated with from its in operation.
The material that at least a portion that means term " upstream connection " flows out from upstream connection object can flow in the object of its connection in operation.
Term " be directly communicated with " means in downstream components, not experience from flowing to of upstream component the composition causing due to physics fractionation or chemical conversion to be changed.
Term " tower " means distillation tower or has the tower of the component of different volatility for separating of one or more.Unless otherwise noted, the condenser that each tower is included in top of tower with condensation and make a part of top product flow back to that stream is back to the top of tower and at the reboiler of tower bottom with gasification and a part of bottom stream is sent back to the bottom of tower.Can be by the feeding preheating of tower.Top pressure is the pressure of the vapor outlet port place overhead vapor of tower.Bottom temp is liquid bottom temperature out.Top product pipeline and bottoms pipeline refer to the clean pipeline that refluxes or boil to tower again from downstream column.Stripping tower saves the reboiler at tower bottom, but provides demand for heat and detachment dynamic by fluidisation inert media as steam.
As used herein, term " true boiling-point " (TBP) means for measuring the test method of the boiling point of material, it is corresponding to ASTM D2892, its liquefied gas for the production of standard quality, distillation fraction and Residual oil, and based on this, can obtain analytical data, and be determined in tower with 5:1 reflux ratio and use 15 theoretical trays to produce temperature with respect to quality and the volume yield of the above cut of the figure of distillation quality %.
As used herein, term " transformation efficiency " means feedstock conversion and becomes the transformation efficiency at the material of diesel boiling range or following boiling.It is 343-399 ℃ (650-750 ℉) that the diesel oil cut point of diesel boiling range is used true boiling-point distillation method.
As used herein, term " diesel boiling range " means to use true boiling-point distillation method boiling point for the hydrocarbon of 132-399 ℃ (270-750 ℉).
As used herein, term " separator " means to have entrance and at least one overhead vapor exports and bottom liquid exports and can have the container from the water export of hopper.The class separator of flash tank for being communicated with the separator downstream that can operate under elevated pressures.
Describe in detail
The feature of traditional hydrogenation fabrication design is a stripper that receives two kinds of chargings, and described two kinds of chargings are for can carrying out the colder hydrogenation processing effluent stream of self cooling flash tank and can processing effluent stream from the hotter hydrogenation of heat-lightening steaming pot.Although these two kinds material streams contain very different compositions, they can be traced back to from the same position of hydrogenation processing reactor and possibility heat separator.The overhead vapor stream of heat separator can enter in cold separator, and comes the liquid of self cooling separator can enter in cold flash tank, and the bottom liquid of heat separator can enter in heat-lightening steaming pot simultaneously.Traditionally, the liquid of hot and cold flash tank is fed in single stripper.Stripper bottom product stream becomes the charging of product separation column.This list stripper design invalid derives from the mixing of the liquid of heat-lightening steaming pot and cold flash tank in identical stripper, and the separation that its partial cancellation had previously realized in heat separator, therefore need to double heating in the fired heater that leads to product separation column.
Applicant advises using two strippers, the hot stripper of the effluent stream of processing for hot hydrogenation, described effluent stream can be the liquid from heat-lightening steaming pot, and the cold stripper of the effluent stream of processing for cold hydrogenation, and described effluent stream can be the liquid from cold flash tank.
Aspect normal pressure and/or decompression residual oil hydrotreatment, produce some light hydrocarbons as diesel oil and lighter hydrocarbon.The diesel oil producing with compared with the amount of lighter hydrocarbons, compare and be not large with the amount of desulfurization Residual oil product, but in some cases, it may be economical reclaiming this material.Ordinary method is used single stripper as mentioned above also all stripping materials to be heated in product fractionation feed heater to by diesel oil with compared with light material, gasify, so can it is separated in product separation column.This produces fired heater load large for product fractionation feed heater, because the heat of real mass is desulfurized the sensible heat of normal pressure and/or decompression residual oil, absorbs.The cost of this material of heating that ideal is avoids unnecessary.
The present invention uses two strippers to replace a realization and conventional single stripper to design essentially identical processing object, but does not cause almost same high cost of energy, because the normal pressure of desulfurization and decompression residual oil are not heated after stripping.Still reclaim the distillment of substantial part and compared with light material, make capital and use cost minimize simultaneously.
Hydrogenation machining cell be Residual oil hydrotreating unit aspect in, the heat that contains all desulfurization normal pressures and decompression residual oil product is added to hydroprocessed effluent streams to be fed in hot stripper, it is removed the diesel oil of hydrogen sulfide and as much and compared with light material, meets the end point specification that keeps diesel product simultaneously.At this on the one hand, hot stripper bottoms can be walked around product separation column and process in as fluid catalytic cracking unit at lift unit.Therefore, eliminate together the fired heater in product recovery unit.
The clean top product of self-heating stripper is together with mainly comprising diesel oil and feeding in cold stripper compared with the cold hydroprocessed effluent streams that adds of lighter hydrocarbons in the future.In cold stripper, hydrogen sulfide and boiling point are removed at top at petroleum naphtha with compared with the hydrocarbon in light boiling range.In addition, heat separator operates to limit the terminal of the diesel product producing in cold stripper bottoms by this way.The bottoms of cold stripper can be sent into further processing in another unit, or send into product separation column, described product separation column can be naphtha splitter, there, at top, can produce other petroleum naphtha, and recyclable be the bottoms of diesel boiling range material.Because the diesel oil producing in expection Residual oil hydrotreating unit is not ultra-low-sulphur diesel (ULSD), go possibly further processing.Therefore, diesel oil material can be sent in distillment hydrotreating unit further to reduce sulphur, and if necessary, this processing comprises adjusts some performance, for example cetane value improves, pour point declines or other method for improving.
Equipment and method 10 for hydrogenation processing hydrocarbon comprise hydrogenation machining cell 12 and product recovery unit 14.Hydrogen make-up air-flow in hydrocarbon flow in hydrocarbon pipeline 16 and hydrogen make pipeline 18 is fed in hydrogenation machining cell 12.To add hydroprocessed effluent streams fractionation in product recovery unit 14.Equipment and method 10 also can comprise crude oil fractionation unit 110 and/or fluid catalytic cracking unit 200.
Can be in conjunction with the hydrocarbon incoming flow in feeding line 16 so that the incoming flow of the hydrogenation processing in feeding line 20 to be provided by the hydrogen stream in the supplementary hydrogen gas lines 76 of the hydrogen make-up from pipeline 18.Hydrogenation processing incoming flow in pipeline 20 can be heated by heat exchange and in fired heater 22 and fed in hydrogenation processing reactor 24.
On the one hand, methods described herein and equipment are used in particular for hydrogenation processing hydrocarbon-containing feedstock.Illustrative hydrocarbon feed comprises the flow containing hydrocarbons that contains the component of boiling point more than 288 ℃ (550 ℉), and for example atmospheric gas oil, boiling point are that the vacuum gas oil (VGO), deasphalted oil, coking overhead product, straight run, pyrolysis-derived oils, high boiling point synthetic oil, turning oil, hydrocracking charging, cat cracker overhead product, boiling point of 315 ℃ of (600 ℉)-565 ℃ (1050 ℉) is at 343 ℃ (650 ℉) or above atmospheric resids and the decompression residual oil of boiling point more than 510 ℃ (950 ℉).
On the one hand, the charging in pipeline 16 can be resid feed.In aspect this, crude oil feeding can be processed in crude oil fractionation unit 110.Crude oil feeding enters in pipeline 112 also can be by a series of interchanger (not shown)s in crude oil fractionation unit 110, and described interchanger is suitably passed to crude oil from the product of atmospheric distillation tower 130 by heat.Oil is delivered in pipeline 112 to the bottom of atmospheric distillation tower 130.Inertia stripping medium is added in distillation tower 130 to provide in heat demand the heavy component from tower stripping compared with light constituent as steam in pipeline 136.Various product of distillation are taken out from atmospheric distillation tower 130 and can in attached tower, use more stripping medium strippings to remove compared with light constituent from clean product stream and to make returning in tower 130 compared with light constituent of self-cleaning product stream.Atmospheric gas oil material stream is taken out in pipeline 138 near air distillation tower bottom.Diesel stream is taken out at atmospheric distillation tower 130 near middles in pipeline 144.Kerosene(oil)fraction is taken out in pipeline 148 near atmospheric distillation tower 130 tops.Can make the part of coal oil flow of taking out from tower boil again and return in tower, clean coal oil flow be removed in pipeline 148 simultaneously.By petroleum naphtha with compared with light ends fractionation, in pipeline 150, from the top of atmospheric distillation tower 130, take out the cooling or condensation being delivered in receptor 152 by water cooler.Make to return in atmospheric distillation tower 130 from a part of liquid of receptor 152, and another part is recovered in pipeline 154.The appropriate hydrocarbon gas lighter than petroleum naphtha taken out in pipeline 156 from receptor 152.Atmospheric resids material stream bottom from atmospheric distillation tower 130 in bottoms pipeline 158 is taken out.Atmospheric resids material stream in bottoms pipeline 158 can provide incoming flow 16 and adjust by the control valve on it via pipeline 162.
On the other hand, can and feed in the vacuum column 170 operating under sub-atmospheric pressure via pipeline 164 a part of atmospheric resids material stream heating in bottoms pipeline 158.Control valve adjustment on pipeline 164 is by its flow.Exhaust flow can reclaim in top product pipeline 172 from vacuum column 170.Pressure reduction gas oil plant stream can reclaim in the pipeline 174 that sides stream.Decompression residual oil material stream can reclaim and provide a part of incoming flow 16 in bottoms pipeline 176 from bottom.Can be by the inertia stripping medium in pipeline 178 if steam introducing vacuum column bottom be to provide heat demand and to carry out separation.Also expect the use of reboiler.
The hydrogenation processing of carrying out in hydrogenation machining cell 12 can be hydrocracking or hydrotreatment.Hydrocracking refers to that wherein hydrocarbon is cracked into the method for lower molecular weight hydrocarbon under the existence of hydrogen.Hydrocracking also comprises slurry hydrocracking, wherein resid feed is mixed to prepare slurry and is cracked into compared with low-boiling products with catalyzer and hydrogen.VGO in product can recirculation be called the coke precursors of middle phase with control.
The hydrogenation processing of carrying out in hydrogenation machining cell can be also hydrotreatment.Hydrotreatment is method that wherein hydrogen contacts under the existence of suitable catalyst with hydrocarbon, described catalyzer mainly for from hydrocarbon feed, remove heteroatoms as sulphur, nitrogen and metal be active.In hydrotreatment, the hydrocarbon that can make to have two keys and triple bond is saturated.Also can make aromatic saturation.Some hydroprocessing processs are particularly useful for making aromatic saturation.Also can reduce the cloud point of hydrotreatment products.
Hydrotreatment is the preferred method in hydrogenation machining cell 12, especially true during resid feed in hydrogenation machining cell process piping 16.Therefore, term " hydrogenation processing " comprises term " hydrotreatment " herein.
If hydrogenation processing reactor 24 is as hydrotreating reactor operation, it can provide the per pass conversion of 10-30 volume %.If hydrogenation processing reactor 24 is as the operation of Residual oil hydrotreating reactor, it can provide the per pass conversion of 10-20 volume %.
If hydrogenation processing reactor 24 is as hydrocracking reactor operation, it can provide at least 20 volume % that hydrocarbon feedstock conversion becomes the product of boiling point below diesel oil cut point, is conventionally greater than the total conversion rate of 60 volume %.Hydrocracking reactor can be to be greater than the Partial Conversion rate of 50 volume % or the complete conversion operation of at least 90 volume % chargings based on total conversion rate.Hydrocracking reactor can operate under mild hydrogenation cracking conditions, the 20-60 volume % that described mild hydrogenation cracking conditions provides hydrocarbon feedstock conversion to become the product of boiling point below diesel oil cut point, preferably 20-50 volume % total conversion rate.
If hydrogenation processing reactor 24 is hydrocracking reactor, the first container in hydrocracking reactor 24 or bed can comprise hydrotreating catalyst with before use hydrocracking catalyst hydrocracking in the container subsequently in hydrocracking reactor 24 or bed by it, hydrocarbon charging is saturated, demetalization, desulfurization or denitrogenation.If hydrocracking reactor is mild hydrogenation cracking case, it can contain several hydrotreating catalyst beds, thereafter less hydrocracking catalyst bed.If hydrogenation processing reactor 24 is slurry hydrocracking reactor, it can be in Continuous Liquid Phase with to upflow mode operation, and demonstrate and be different from the figure that describes fixed-bed reactor.If hydrogenation processing reactor 24 is hydrotreating reactor, it can comprise more than one container and a plurality of hydrotreating catalyst bed.Hydrotreating reactor also can comprise the hydrotreating catalyst that is suitable for making aromatic saturation, Hydrodewaxing and hydroisomerization.
If want mild hydrogenation cracking to produce the balance of middle runnings and gasoline, the low levels zeolite alkali that hydrocracking catalyst can be used soft silica-aluminum oxide alkali or combine with one or more VIII families or group vib metallic hydrogenation component.On the other hand, when compare middle runnings with gasoline production be obviously preferred in converted product, partially or completely hydrocracking can be carried out with catalyzer in the first hydrocracking reactor 24, and described catalyzer comprises any crystalline zeolite cracking alkali that deposits VIII family metallic hydrogenation component on it conventionally.Other hydrogenation component can be selected from group vib to be combined with zeolite alkali.
Zeolite as cracking alkali is sometimes referred to as molecular sieve in the art, and conventionally silicon-dioxide, aluminum oxide and one or more exchangeable cation, consists of as sodium, magnesium, calcium, rare earth metal etc.Their feature is further to have 4-14 dust (10
-10the crystal pores of relative homogeneous diameter rice).Preferably use the zeolite of the relative high silicon dioxide/alumina molar ratio with 3-12.The suitable zeolite of finding in nature comprises for example mordenite, stilbite, heulandite, alkali zeolite, dachiardite, chabazite, erionite and faujusite.Suitable synthetic zeolite comprises for example B, X, Y and L crystal type, for example synthetic faujasites and mordenite.Preferred zeolite is for having 8-12 dust (10
-10rice) those of crystal aperture, wherein silica/alumina mole ratio is 4-6.An example that belongs to the zeolite of preferred group is synthetic Y zeolite.
Naturally occurring zeolite finds with na form, alkaline earth metal form or mixed form conventionally.First synthetic zeolite is almost always prepared with na form.Under any circumstance, for being used as cracking alkali, preferably most or all original zeolite monovalent metals and polyvalent metal and/or with ammonium salt ion-exchange, its post-heating to be to decompose the ammonium ion relevant with zeolite, leaves hydrogen ion and/or in fact by further except anhydrating and the exchange position of decationizing on their position.Hydrogen or " decationizing " Y zeolite with this character are more particularly described in US3, in 130,006.
Mix polyvalent metal-hydrogen zeolite can by first with ammonium salt ion-exchange, then with the anticommuting of polyvalent metal salt part, then calcine and prepare.In some cases, as the synthesizing flokite in the situation that, hydrogen form can be prepared by the direct acid treatment of alkali metal zeolites.On the one hand, preferred cracking alkali is based on initial ion exchange capacity at least 10%,, those of preferred at least 20% poor metallic cation.On the other hand, desirable and suitable zeolites is a kind of that wherein at least 20% ion-exchange capacity meets by hydrogen ion.
The active metal that is used as hydrogenation component in the preferred hydrocracking catalyst of the present invention is those of VIII family, i.e. iron, cobalt, nickel, ruthenium, rhodium, palladium, osmium, iridium and platinum.Except these metals, other promotor also can therewith be used, and comprises group vib metal, for example molybdenum and tungsten.In catalyzer, the amount of metal hydride can change in wide region.Briefly say, can use the amount of 0.05-30 % by weight.The in the situation that of precious metal, conventionally preferably use 0.05-2 % by weight.
For being incorporated to the method for metal hydride, be that base mateiral is contacted with the aqueous solution with the suitable combination thing of required metal, wherein metal exists with cationic form.After adding selected metal hydride, then gained catalyst fines is filtered, dry, along with adding lubricant, tackiness agent etc., granulate if necessary, and in air at the temperature lower calcination of for example 371-648 ℃ (700-1200 ℉) so that catalyst activation ammonium ion is decomposed.As selection, can first alkaline constituents be granulated, add thereafter hydrogenation component and pass through calcining and activating.
Aforementioned catalyzer can be used with the form of not diluted, maybe can catalyzer, thinner or the tackiness agent of efflorescence catalyzer and other relative less activity of the ratio of 5-90 % by weight is as cogelled in aluminum oxide, silica gel, silica-alumina, activated clay etc. mixes and common granulation.The metal hydride adding that these thinners can directly be used or they can contain minor proportions is as group vib and/or VIII family metal.The hydrocracking catalyst of other metal promoted also can be used in the inventive method, and it comprises for example aluminophosphate molecular sieve, crystalline chromosilicates and other crystalline silicate.Crystalline chromosilicates is more completely described in US4, in 363,718.
By a kind of route, hydrocracking condition can comprise that 290 ℃ (550 ℉) are to 468 ℃ (875 ℉), the temperature of preferably 343 ℃ (650 ℉) to 445 ℃ (833 ℉), 4.8MPa (standard) is (700psig) to 20.7MPa (standard) pressure (3000psig), and 0.4 to being less than 2.5hr
-1liquid hourly space velocity (LHSV), and 421 (2,500scf/bbl) to 2,527Nm
3/ m
3oil (15, hydrogen rate 000scf/bbl).If need mild hydrogenation cracking, condition can comprise that 315 ℃ (600 ℉) are to the temperature of 441 ℃ (825 ℉), 5.5MPa (standard) (800psig) to 13.8MPa (standard) (2000psig) or more generally 6.9MPa (standard) (1000psig) to 11.0MPa (standard) pressure (1600psig), 0.5-2hr
-1, preferred 0.7-1.5hr
-1liquid hourly space velocity (LHSV), and 421Nm
3/ m
3oil (2,500scf/bbl) to 1,685Nm
3/ m
3oil (10, hydrogen rate 000scf/bbl).
Slurry hydrocracking catalyst is generally the ferrous sulfate hydrate that granularity is less than 45 μ m, on the one hand, major portion, at least 50 % by weight have the granularity that is less than 10 μ m.Ferric sulfate monohydrate is suitable catalyzer.Bauxite catalyzer can be also suitable.On the one hand, the catalyzer based on fresh feed 0.01-4.0 % by weight is added in hydrocarbon charging.As selecting or in addition, can using oil-soluble catalyst.Oil-soluble catalyst comprises metal ring alkyl salt or the metal octoates based on fresh feed 50-1000wppm.Metal can be molybdenum, tungsten, ruthenium, nickel, cobalt or iron.
Slurry hydrocracking reactor on the one hand 3.5MPa (standard) (508psig) to 24MPa (standard) (3, under pressure 481psig), operate, and do not form coke in reactor.Temperature of reactor can be 350-600 ℃, and wherein the temperature of 400-500 ℃ is typical.LHSV is 4h based on fresh feed conventionally
-1below, 0.1-3hr
-1scope be suitable, 0.2-1hr
-1scope be specially suitable.One way pitch transformation efficiency can be 50-95 % by weight.Hydrogen feed rate can be 674-3370Nm
3/ m
3(4000-20,000scf/bbl) oil.Also defoamer can be added in slurry hydrocracking reactor 24, add on the one hand its top, to reduce the tendency that produces foam.
Suitable hydrotreating catalyst for the present invention is any known conventional hydrotreating catalyst, and comprise by high surface area support material, at least one VIII family metal on preferential oxidation aluminium, preferred iron, cobalt and nickel, more preferably cobalt and/or nickel, with at least one VI family metal, those that preferred molybdenum and tungsten form.Other suitable hydrotreating catalyst comprises zeolite catalyst, and noble metal catalyst, and wherein precious metal is selected from palladium and platinum.Within the scope of the present invention be for identical hydrotreating reactor 96 more than a class hydrotreating catalyst.VIII family metal is conventionally with 2-20 % by weight, and preferably the amount of 4-12 % by weight exists.VI family metal is conventionally with 1-25 % by weight, and preferably the amount of 2-25 % by weight exists.
Preferred hydrotreatment reaction conditions comprises that 290 ℃ (550 ℉) are to 455 ℃ (850 ℉), 316 ℃ suitably (600 ℉) is to 427 ℃ (800 ℉), the temperature of preferably 343 ℃ (650 ℉) to 399 ℃ (750 ℉), 2.1MPa (standard) (300psig), preferably 4.1MPa (standard) (600psig) to 12.4MPa (standard) (1800psig), preferred 6.9MPa (standard) pressure (1000psig), 0.5-4hr
-1, preferred 1.5-3.5hr
-1fresh hydrocarbon-containing feedstock liquid hourly space velocity, and 168Nm
3/ m
3(1,000scf/bbl) to 1,011Nm
3/ m
3oil (6,000scf/bbl), preferred 168Nm
3/ m
3oil (1,000scf/bbl) to 674Nm
3/ m
3(4, hydrogen rate 000scf/bbl), with hydrotreating catalyst or hydrotreating catalyst combination for oil.For Residual oil hydrotreatment, pressure can be for (3000psig) equally high with 20.6MPa (standard), and the liquid hourly space velocity of fresh hydrocarbon-containing feedstock can be 0.1-1hr
-1, preferred 0.15-0.5hr
-1, and hydrogen rate can be preferably 168Nm
3/ m
3oil (1,000scf/bbl) to 674Nm
3/ m
3oil (5,000scf/bbl).
Add that hydroprocessed effluent streams leaves hydrogenation processing reactor 24 and carry in adding hydroprocessed effluent streams pipeline 26.Add hydroprocessed effluent streams and comprise the material that can become colder hydrogenation processing effluent stream and hotter hydrogenation processing effluent stream.Hydrogenation machining cell can comprise one or more separators and be separated into cold hydrogenation processing effluent stream and hot hydrogenation processing effluent stream hydrogenation is processed to effluent stream.
Add in hydroprocessed effluent streams pipeline 26 add hydroprocessed effluent streams on the one hand in entering heat separator 30 before can with pipeline 20 in hydrogenation process incoming flow heat exchange with cooling.Heat separator separation adds hydroprocessed effluent streams to provide a part of cold hydrogenation that comprises in top product pipeline 32 to process the steam hydrocarbonaceous heat separator top product stream of effluent stream and the liquid hydrocarbon-containing heat separator bottom product stream that comprises a part of cold hydrogenation processing effluent stream and a part of hot hydrogenation processing effluent stream in bottoms pipeline 34.Heat separator 30 in hydrogenation processing sections 12 is communicated with hydrogenation processing reactor 24 downstreams.When operation hydrogenation machining cell 12 is during with hydrotreatment resid feed, heat separator 30 can operate to limit the terminal of the diesel product that cold stripper 60 bottoms produce under certain condition.Heat separator 30 is in 177 ℃ (350 ℉) to 371 ℃ (700 ℉) lower operation, preferably in 232 ℃ (450 ℉) to 315 ℃ (600 ℉) lower operation.Heat separator 30 can operate under than the lower a little pressure of hydrogenation processing reactor 24, thereby explains the pressure drop of interventional instrument.Heat separator can (493psig) operate at 3.4MPa (standard) to 20.4MPa (standard) pressure (2959psig).
Steam hydrocarbonaceous heat separator top product stream in top product pipeline 32 is cooling before can be in entering cold separator 36.Due to the reaction of carrying out in hydrogenation processing reactor 24, wherein nitrogen, chlorine and sulphur are removed from charging, form ammonia and hydrogen sulfide.Under representative temperature, ammonia and hydrogen sulfide are in conjunction with forming curing ammonium, and ammonia and chloropexia formation ammonium chloride.Each compound has characteristic sublimation temperature, its tolerable compound coating equipment, particularly heat exchanging apparatus, thus weaken its performance.For preventing from carrying this class deposition of curing ammonium in the pipeline 32 of heat separator top product stream or chlorination ammonium salt, can by appropriate washing water (not shown), in pipeline 32, in temperature, some place more than the characteristic sublimation temperature at every kind of compound introduces in upstream line 32.
Liquid hydrocarbon-containing material stream in heat separator bottoms pipeline 34 can be processed to effluent stream in 14 fractionation of product recovery unit as hot hydrogenation.On the one hand, the pressure of the liquid hydrocarbon-containing material in bottoms pipeline 34 stream can reduce and in heat-lightening steaming pot 44 flash distillation so that the lighting end flash evaporation top product stream that comprises a part of cold hydrogenation processing effluent stream in top product pipeline 46 and the heavy liquid stream that comprises the hot hydrogenation processing of at least a portion effluent stream in bottoms pipeline 48 to be provided.Heat-lightening steaming pot 44 can be separated into for liquid being added to hydroprocessed effluent streams any separator of steam and liquid distillate.Heat-lightening steaming pot 44 can be at the temperature identical with heat separator 30, but 2.1MPa (standard) (300psig) to 6.9MPa (standard) (1000psig), be less than suitably under 3.4MPa (standard) lower pressure (500psig) and operate.Can be by the heavy liquid stream further fractionation in product recovery unit 14 in bottoms pipeline 48.On the one hand, the heavy liquid stream in bottoms pipeline 48 can be introduced in hot stripper 50 and comprised at least a portion, suitably, all hotter hydrogenation processing effluent streams.Hot stripper 50 is communicated with the downstream, bottom of heat-lightening steaming pot 44 via bottoms pipeline 48.
On the one hand, the processing of the liquid hydrogenation in cold separator bottom product pipeline 40 effluent stream can be used as the fractionation in product recovery unit 14 of cold hydrogenation processing effluent stream.On the other hand, the pressure of cold separator liquid bottom product stream can reduce and in cold flash tank 52 flash distillation with the cold separator liquid bottom product stream in separated bottoms pipeline 40.Cold flash tank 52 can be for adding hydroprocessed effluent streams and be separated into any separator of steam and liquid distillate.Cold flash tank can be communicated with the bottom of cold separator 36 via bottoms pipeline 40.Cold stripper 60 can be communicated with bottoms pipeline 56 downstreams of cold flash tank 52.
On the other hand, the heat of steam flash distillation top product stream in top product pipeline 46 can be used as the fractionation in product recovery unit 14 of cold hydrogenation processing effluent stream.On the other hand, can flash evaporation top product stream is cooling and separated in cold flash tank 52.Cold separator liquid bottom product stream in the separable pipeline 40 of cold flash tank 52 and the flash evaporation vapor overhead product stream in top product pipeline 46 are to provide cold flash distillation top product stream in top product pipeline 54 and the cold flash distillation bottom product stream that comprises the cold hydrogenation processing of at least a portion effluent stream in bottoms pipeline 56.Cold flash distillation bottom product stream in bottoms pipeline 56 comprises at least a portion, suitably all cold hydrogenation processing effluent streams.On the one hand, cold stripper 60 is communicated with cold flash tank 52 downstreams via bottoms pipeline 56.Cold flash tank 52 can be with the bottoms pipeline 40 of cold separator 50, the top product pipeline 46 of heat-lightening steaming pot 44 and hydrogenation processing reactor 24 downstreams be communicated with.Cold separator bottom product stream in bottoms pipeline 40 and the flash evaporation top product stream in top product pipeline 46 can together with or enter dividually in cold flash tank 52.On the one hand, flash evaporation top product pipeline 46 feeds in cold flash tank 52 together with cold separator bottom product stream in conjunction with cold separator bottom product pipeline 40 and by flash evaporation top product stream.Cold flash tank 52 can be at the temperature identical with cold separator 50, but conventionally 2.1MPa (standard) (300psig) to 7.0MPa (standard) (1000psig), preferably not higher than operating under 3.1MPa (standard) lower pressure (450psig).Also can will in pipeline 42, come the current of the hopper of self cooling separator to send in cold flash tank 52.The current of flash distillation are removed in pipeline 62 from the hopper of cold flash tank 52.
The cold separator top product of the steam that comprises hydrogen stream in top product pipeline 38 is rich in hydrogen.Cold separator top product stream in top product pipeline 38 can or be filled washing tower 64 by column plate, there it is washed to remove hydrogen sulfide and ammonia by the washings in pipeline 66 as amine aqueous solution.Renewable and the recirculation of spent scrub stream in pipeline 68 turns back in washing tower 64.The rich hydrogen material of washing is flowed through and by pipeline 70, from washer, is discharged and can in recycle compressor 72, compress to provide the air-flow of the recycle hydrogen in pipeline 74, its processing of steam hydrogenation for compression effluent stream.Recycle compressor 72 can be communicated with hydrogenation processing reactor 24 downstreams.Recycle hydrogen air-flow in pipeline 74 can be supplemented so that the hydrogen stream in hydrogen gas lines 76 to be provided by make-up stream 18.The middle catalyst bed that a part of material in pipeline 74 can be sent into hydrogenation processing reactor 24 exports to control the temperature in of catalyst bed (not shown) subsequently.
Can will be able near its top, feed in hot stripping tower 50 by the hot hydrogenation processing effluent stream in flash evaporation bottoms pipeline 48.The hot hydrogenation processing effluent stream that comprises at least a portion liquid and add hydroprocessed effluent streams can be used in hot stripping tower 50 from pipeline 94 for rare gas element is if the hot stripping medium stripping of steam is to provide the stream of the heat steam top product in top product pipeline 96.Stripping medium is generally middle pressure steam, and does not represent relative temperature about the hot and cold mark of stripping medium.Can be by the condensation separated in the receptor 98 of hot top of at least a portion heat steam stream.Hot top receptor 98 is communicated with top product pipeline 96 downstreams of hot stripping tower 50.Hot top receptor 98 is separated into exhaust flow and bottom product stream by the heat steam top product stream of hot stripper.Top product pipeline 100 from receptor 98 transports vapor waste air-flows further to process.The bottom product stream of the unstable liquid material from receptor 98 bottoms in bottoms pipeline 102 is separable into the backflow part that is back to hot stripping tower 50 tops in pipeline 104 and can be for be delivered to the process portion in cold stripper 60 in process pipeline 106.
If the processing of the hydrogenation in pipeline 16 charging comprises Residual oil, hydrogenation machining cell 12 can be used as the operation of Residual oil hydrotreating unit, and hydrogenation processing reactor 24 is hydrotreating reactor.In aspect this, the hot hydrogenation processing effluent stream in pipeline 48 can contain all desulfurization Residual oil products.In aspect this, the function of hot stripper 50 is to remove the diesel oil of hydrogen sulfide and as much and compared with light material, meet the end point specification that keeps diesel product simultaneously.In aspect this, heat steam top product stream in top product pipeline 96 comprises diesel oil, petroleum naphtha, hydrogen, hydrogen sulfide, steam and other gas, and the bottom product stream from receptor 98 bottoms in bottoms pipeline 102 comprises unsettled liquid diesel, petroleum naphtha and compared with light material.
Hot stripping tower 50 can be with the bottom temp of 160 ℃ of (320 ℉)-360 ℃ (680 ℉) and 0.5MPa (standard) (73psig) to 2.0MPa (standard) top pressure operation (292psig).Temperature in top receptor 98 be 38 ℃ (100 ℉) to 66 ℃ (150 ℉), and pressure and hot stripping tower 50 tops basic identical.
On the one hand, cold stripper 60 is communicated with hot stripping tower 50 downstreams with self-heating stripping tower 50 material stream stripping in future.In other words, cold stripper is connected with hot stripping tower 50.On the other hand, cold stripper is communicated with top product pipeline 96 downstreams of hot stripping tower 50, so steam stripped in cold stripper 60, to carry out the material stream of self-heating stripping tower 50 be at least a portion top product stream that carrys out self-heating stripping tower 50 in top product pipeline 96.On the other hand, cold stripper 60 is communicated with coming bottoms pipeline 102 downstreams of self-heating top receptor 98.By the hot receiver bottom product stream of stripping unstable liquid material in cold stripper 60, described product stream comprises the hydrogen sulfide in process pipeline 106, diesel oil material can enter the bottom of cold stripper 60 separated with hydrogen sulfide, and described hydrogen sulfide can enter the top of cold stripper 60.Also expect that hot stripping tower 50 can be communicated with that with cold stripper 60 downstreams the material from cold stripper 60 is flowed to stripping.
The hot stripping material stream of hydrogenation processing produces in the bottoms pipeline 108 of hot stripping tower 50.Can by the further processing of the hot stripping material stream of at least a portion in bottoms pipeline 108, for example, feed in fluid catalytic cracking unit 200.Therefore, fluid catalytic cracking unit can be communicated with bottoms pipeline 108 downstreams of hot stripper.
Can will can heat and near top of tower, feed in cold stripper 60 by the cold hydrogenation processing effluent stream in cold flash distillation bottoms pipeline 56 on the one hand.The process pipeline that leads to cold stripper 60 106 entrances that are communicated with bottoms pipeline 102 downstreams of carrying out self-heating top receptor 98 can be at the higher height of cold hydrogenation processing effluent stream entrance than in pipeline 56.Can together with the process flow of carrying out self-heating stripping tower 50, be used for the cold stripping medium stripping of self cooling stripping medium pipeline 78 in cold stripper 60 by comprising cold hydrogenation processing effluent stream that at least a portion liquid adds hydroprocessed effluent streams, described stripping medium is that rare gas element is as steam.Stripping medium is generally middle pressure steam, and does not represent relative temperature about the hot and cold mark of stripping medium.
On the one hand, when hydrogenation machining cell 12 hydrotreatment resid feed, supply with that the hot receiver bottoms in process pipeline 106 of cold stripper 60 and cold in pipeline 56 add that hydroprocessed effluent streams charging can comprise diesel oil and compared with lighter hydrocarbons, thus can by they together stripping so that the cold vapor stream of petroleum naphtha, hydrogen, hydrogen sulfide, steam and other gas in top product pipeline 80 to be provided.
Cold top receptor 82 is communicated with top product pipeline 80 downstreams.Can be by the condensation separated in the receptor 82 of cold top of the cold vapor stream of at least a portion.Cold top receptor 82 is separated into exhaust flow and the unstabilizing liquid liquid stream in top product pipeline 84 by the cold top product stream from cold stripper 60 in top product pipeline 80.Top product pipeline 84 from receptor 82 carries vapor exhaust further to process.The vapor exhaust of the next self cooling top receptor 82 in top product pipeline 84 together with being mixed for, the vapor exhaust of carrying out self-heating top receptor 98 in top product pipeline 100 further can be processed, because these material streams can have similar composition.Therefore, come self cooling top receptor 82 top product pipeline 84 can with top product pipeline 100 combinations that carry out self-heating top receptor 98.
Unstable liquid from receptor 82 bottoms is separable into the backflow part and the product part that are back to cold stripper 60 tops in pipeline 86, described product part can be carried with further fractionation in product pipeline 88, for example, in separation column (not shown).Cold stripper 60 can be with the bottom temp of 149 ℃ (300 ℉) to 260 ℃ (500 ℉) and 0.5MPa (standard) (73psig) to 2.0MPa (standard) top pressure operation (290psig).Temperature in top receptor 82 be 38 ℃ (100 ℉) to 66 ℃ (150 ℉), and pressure and cold stripper 60 tops basic identical.
At hydrogenation machining cell 12 as in aspect Residual oil hydrotreating unit operation, petroleum naphtha and compared with light material, in cold top product pipeline 80, be recovered and in cold top receptor 82 be separated into petroleum naphtha and compared with light material.Can be by the further fractionation of unstable petroleum naphtha in pipeline 88 to remove gas from petroleum naphtha.
Hydrogenation in bottoms pipeline 92 can be processed to cold stripping material stream and send into further processing.On the one hand, the cold stripping material stream in bottoms pipeline 92 can be used to the process heaters heating of comparing not strong with fired heater, and feed in product separation column 120.Therefore, product separation column 120 is communicated with bottoms pipeline 92 downstreams of cold stripper 60 but is not directly communicated with hot stripping tower 50.In other words, on the one hand, bottom product stream 92 flows in product separation column 120, but does not come the material stream of self-heating stripping tower 50 to flow into product separation column 120 and not first by another unit operation, for example, pass through cold stripper 60.By the cold stripping material stream fractionation in product separation column 120 in bottoms pipeline 92, but not by the hot stripping material stream fractionation in product separation column 120 in bottoms pipeline 108.Cold stripping material stream can be in entering product separation column 120 before with bottoms pipeline 126 in the bottom product stream from product separation column 90 or other suitable material stream heat exchange.
Bottom product stream from product separation column is separable into the clean bottom product stream in bottoms pipeline 126 and boils and return to the part in tower.For product separation column 120, also expect and use inert media stripping.
At hydrogenation machining cell 12, as in aspect Residual oil hydrotreating unit operation, product separation column 120 can be knockout tower, and it is created in naphtha stock stream at top and in the diesel stream of bottom.Top product stream in pipeline 114 comprises petroleum naphtha.All the other liquid from receptor 116 bottoms provide the clean naphtha stock stream in pipeline 118.Clean naphtha stock in pipeline 118 may need further processing before flowing in sneaking into gasoline pool, for example, in naphtha splitter.Bottom product stream from product separation column is separable into the clean diesel stream in diesel oil pipe 126 and boils and return to the part in tower.The clean diesel oil of the generation in pipeline 120 is not ULSD and can sends in distillment hydrotreating unit (not shown) further to remove desulfuration and to adjust possibly cetane value, pour point or other performance.
The hydrogenation producing in the bottoms pipeline 108 of hot stripping tower 50 can be processed to the further processing in fluid catalytic cracking unit 200 of hot stripping material stream, especially true when operating hydrogenation machining cell 12 with hydrotreatment resid feed.Also expect that hot stripping material is flowed through processed by further hydrogenation.Fluid catalytic cracking unit 200 comprises reactor 210 and catalyst regenerator 240.Suitable catalyzer is those that commonly use in fluid catalytic cracking field, for example active amorphous clays class catalyzer and/or high activity, crystalline molecular sieve.It is preferred that molecular sieve catalyst is compared with amorphous catalyst, because their more improved selectivity to required product.Zeolite is molecular sieve the most frequently used in fluidized catalytic cracking method.The large pore zeolite of preferred combination in activated alumina material, for example y-type zeolite.Process variable generally includes the cracking reaction temperature of 400-600 ℃ and the catalyst regeneration temperature of 500-900 ℃.Under cracking and the absolute pressure of regeneration below 0.5MPa, carry out.Hot stripping material in pipeline 108 is circulated to undue orchestration 214 is assigned in lifter 220 and contact with the new regenerative heat cracking catalyst material stream of the fluidisation entering from regenerated catalyst standpipe 216.This contact can be carried out in narrow reactor lifter 220, extends upwardly to reaction vessel 230 bottoms.The uniform contact of charging and catalyzer can be as auxiliary in steam by the gas from fluidizing gas distribution device 218.Heat from regenerated catalyst gasifies charging, is cracked into lighter molecular weight hydrocarbon thereafter when the two is upwards delivered in reaction vessel 230 along reactor lifter 220 under the existence at catalyzer.Thereafter in reaction vessel 230, use cyclonic separator that the light hydrocarbon product of cracking is separated with cracking catalyst, described cyclonic separator can comprise main separator 232 and one or two 234 stages of cyclone.Product gas exports 236 by product and leaves reaction vessel 230 and enter in pipeline 238 to be delivered in downstream fluid catalytic cracking main fractionating tower (not shown) to reclaim product stream as petroleum naphtha and turning oil.Inevitable side reaction occurs in reactor lifter 220, leave deposits of coke on catalyzer, it reduces catalyst activity.Useless or coking catalyst need to regenerate further to use.Coking catalyst falls into stripping stage 222 after separated with gaseous product hydrocarbon, there steam or other rare gas element is injected to from coking catalyst adverse current, clean any residual hydrocarbon steam by nozzle.After stripping operation, coking catalyst is fed in catalyst regenerator 240 by spent catalyst vertical tube 224.
Figure has described the revivifier 240 of the type that is called burner.Yet the revivifier of other type is suitable.In catalyst regenerator 240, oxygen-containing gas is introduced with contact coking catalyzer by air distributor 242 as the material stream of air, its upper coke depositing that burns, and regenerated catalyst and stack gas are provided.Catalyst regeneration process adds the heat of real mass on catalyzer, and the heat absorption cracking reaction of energy to occur in compensatory reactionBu Changfanying device lifter 220 is provided.Catalyzer and air along the burner lifter 244 that is positioned at catalyst regenerator 240 together to upper reaches and after regeneration first by settling vessel 246 by discharge and separated.Leaving the regenerated catalyst of settling vessel 246 and the more fine separation of stack gas uses the first and second stage cyclonic separators 248 in catalyst regenerator 240 to realize.The catalyzer separated with stack gas distributed by cyclone 248 by each dipping tube, and in catalyzer, relatively light stack gas is sequentially left cyclone 248 and left regeneration container 240 by flue gas outlet 250 simultaneously.Regenerated catalyst is by regenerated catalyst standpipe 216 recirculation Returning reactor lifters 220.Due to coke burning, at catalyst regenerator 240 tops, by exporting the 250 stack gas steams that leave, contain CO, CO
2and H
2o, and other species on a small quantity.
In product recovery unit 14, the use of two strippers can operate without fired heater product recovery unit 14.Only by the further fractionation of cold stripping bottoms.The not strong well heater of comparing with fired heater can provide enough heater loads of cold stripping bottoms.Hot stripping bottoms can be sent into and needed if any the machining cell of minimum preheating as in fluid catalytic cracking unit.Although use two strippers rather than one, this equipment and method instead intuitively make capital and running cost minimize.
Described the preferred embodiments of the invention herein, comprising that contriver is known carries out best mode of the present invention.Be to be understood that described embodiment is only for exemplary, and should be not understood to limit the scope of the invention.
Do not further describe, believe that those skilled in the art can use previous description, integrated degree ground is used the present invention.Therefore, it is only illustrative that aforementioned preferred specific embodiments is interpreted as, and the rest part of limit publicity content never in any form.
In the preceding article, unless otherwise noted, all temperature are with a ℃ description, and all parts and percentage ratio are weighing scale.Pressure, at container exit, particularly provides at vapor outlet port place in having the container of a plurality of outlets.
In previous description, those skilled in the art can easily determine principal character of the present invention, and can not depart from its spirit and scope and make various changes and modifications of the present invention so that it is suitable for various uses and condition.
Claims (10)
1. a hydrogenation working method, it comprises:
By hydrocarbon charging hydrogenation in hydrogenation processing reactor, process to provide hydrogenation processing effluent stream;
By the hotter hydrogenation processing effluent stream for the described hydrogenation of part processing effluent stream in hot stripper stripping so that hot stripping material stream to be provided; With
By the colder hydrogenation processing effluent stream for the described hydrogenation of part processing effluent stream and from the steam of described hot stripper in cold stripper stripping so that cold stripping material stream to be provided.
2. according to the hydrogenation working method of claim 1, wherein the described steam from described hot stripper is at least a portion top product stream from described hot stripper.
3. according to the hydrogenation working method of claim 2, it further comprises the top product stream of described hot stripper is separated into exhaust flow and bottom product stream, and described bottom product stream is fed in described cold stripper.
4. according to the hydrogenation working method of claim 1, it further comprises described cold stripping material stream, rather than hot stripping material stream, fractionation in separation column.
5. according to the hydrogenation working method of claim 1, wherein hydrocarbon charging is resid feed.
6. according to the hydrogenation working method of claim 1, it further comprises in described hot stripping material stream infeed fluid catalytic cracking unit.
7. a hydrogenation processing units, it comprises:
Hydrogenation processing reactor;
Hot stripper, it is communicated with that with hydrogenation processing reactor hotter hydrogenation is processed to effluent stream stripping;
Cold stripper, it is communicated with that with hydrogenation processing reactor colder hydrogenation is processed to effluent stream stripping, and described cold stripper is communicated with described hot stripper.
8. according to the hydrogenation processing units of claim 7, wherein said cold stripper is communicated with the top product pipeline of described hot stripper.
9. according to the hydrogenation processing units of claim 7, wherein hydrogenation processing reactor is hydrotreating reactor.
10. according to the hydrogenation processing units of claim 7, it further comprises fluid catalytic cracking unit, and described fluid catalytic cracking unit is communicated with the bottoms pipeline of described hot stripper.
Applications Claiming Priority (5)
| Application Number | Priority Date | Filing Date | Title |
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| US13/213,205 US8936716B2 (en) | 2011-08-19 | 2011-08-19 | Process for recovering hydroprocessed hydrocarbons with two strippers in series |
| US13/213,225 US8715595B2 (en) | 2011-08-19 | 2011-08-19 | Apparatus for recovering hydroprocessed hydrocarbons with two strippers in series |
| US13/213,205 | 2011-08-19 | ||
| US13/213,225 | 2011-08-19 | ||
| PCT/US2012/051128 WO2013028454A2 (en) | 2011-08-19 | 2012-08-16 | Process and apparatus for recovering hydroprocessed hydrocarbons with two strippers in series |
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| CN103608431B CN103608431B (en) | 2016-01-06 |
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| CN106906002A (en) * | 2015-12-23 | 2017-06-30 | 阿克森斯公司 | The hydrotreating roused using stripper and low pressure separator in distillation stage or hydrogenating conversion process |
| CN108472572A (en) * | 2015-12-29 | 2018-08-31 | 环球油品公司 | Method and apparatus for recovering light hydrocarbons from PSA tail gas |
| CN108472574A (en) * | 2015-12-29 | 2018-08-31 | 环球油品公司 | Method and apparatus for absorbing recycling light hydrocarbon by sponge |
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| US10781380B2 (en) | 2015-12-29 | 2020-09-22 | Uop Llc | Process and apparatus for recovering hydrogen from hydroprocessed hot flash liquid |
| US10717936B2 (en) | 2016-08-01 | 2020-07-21 | Sabic Global Technologies B.V. | Catalytic process of simultaneous pyrolysis of mixed plastics and dechlorination of the pyrolysis oil |
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Also Published As
| Publication number | Publication date |
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| CN103608431B (en) | 2016-01-06 |
| WO2013028454A2 (en) | 2013-02-28 |
| WO2013028454A9 (en) | 2013-11-21 |
| WO2013028454A3 (en) | 2013-05-02 |
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