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Publication numberUS3193486 A
Publication typeGrant
Publication dateJul 6, 1965
Filing dateOct 23, 1962
Priority dateOct 23, 1962
Publication numberUS 3193486 A, US 3193486A, US-A-3193486, US3193486 A, US3193486A
InventorsPayne Richard B
Original AssigneeSinclair Research Inc
Export CitationBiBTeX, EndNote, RefMan
External Links: USPTO, USPTO Assignment, Espacenet
Process for recovering catalyst particles in residual oils obtained in the conversion of hydrocarbon oils
US 3193486 A
Abstract  available in
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Claims  available in
Description  (OCR text may contain errors)

R. B. PAYNE 3,193,486 NG ESIDUAL HYDROGARBON OILS July 6, 1965 PROCESS FOR RECOVERI CATALYST PARTICLES IN E OILS OBTAINED IN THE CONVERSION OF Filed Oct. 25, 1962 HOlVNOIlOVHd mPEmwzwomm INVENTOR.

RICHARD B. PAYNE imam/Mafia,

ATTORNEY United States Patent 3,193,486 PROCESS FGR RECOVERHNG CATALYST PAR- TlCLES IN RESIDUAL GILS OBTAINED IN THE CON VERSION OF HYDROCARBON OILS Richard B. Payne, Park Forest, lll., assignor to Sinclair Research, Inc, Wilmington, Del., a corporation of Delaware Filed Oct. 23, 1962, Ser. No. 232,375 5 Ciairns. (Cl. 20850) This invention relates to an improved method for the catalytic cracking of mineral hydrocarbon oils. Particularly, the present invention relates to the catalytic cracking of a mineral hydrocarbon oil where the cracking unit has associated with it a coking operation. Specifically, the present invention relates to a process for the catalytic cracking of a mineral hydrocarbon oil and coking of fractionator bottoms to provide process heat, improved product yield and catalyst recovery.

Fluid catalytic cracking processes are generally operated with a bottom draw from the primary fractionator. These bottoms contain heavy cracked oil and suspended catalyst which was not removed from the cracking efiiuent by the cyclone separators in the cracking reactor. This fractionator bottoms product is either generally recycled to the reactor or processed through a settler to concentrate the catalyst into a slurry. The slurry is usually sent to the catalytic reactor and the clarified oil used as a heavy residual fuel. The latter procedure is generally preferred because the liquid fractionator bottoms has high coking and low cracking tendencies under the usual catalytic cracking conditions. As a consequence cracking operations necessarily produce substantial amounts of high carbon-residue materials from which entrained catalyst must be separated by costly operations.

It has now been found that when a fluidized coking unit is combined with a catalytic cracking unit, to which unit the fractionator bottoms containing suspended cracking catalyst is fed there results improved product yield and catalyst recovery While providing means for adding process heat to the cracking operation. The coker is operated to form coke on the catalyst in the fractionator bottoms and to produce an overhead product. Coke ladened catalyst particles can then be fed to a regenerator for their heating value and for catalyst recovery, and the overhead fraction from the coker may be further treated to yield light gases, gasoline and gas oil suitable as a feedstock to the cracking unit or the overhead fraction may be sent directly to the cracking unit without further processing.

The feeds to the present process are those materials which boil primarily above the gasoline range. Advantageous feedstocks are the petroleum gas oils which may be straight run or previously cracked stocks or their mixtures. Gas oils include any fraction distilled from petroleum or other mineral oil which has an initial boiling point of at least about 400 F., say up to about 850 F., and an end boiling point of at least about 600 F., and boiling substantially continuously between the initial boiling point and the end boiling point. Usually the boiling range extends over at least about 100 F.

Catalytic cracking is ordinarily eiiected to produce gasoline as the most valuable product and is generally conducted at temperatures of about 750 to 1050 F., preferably about 850 to 975 F., at pressures up to about 100 p.s.i.g., preferably about atmospheric to 5 or p.s.i.g., and advantageously without substantial addition of free hydrogen to the system. In the cracking operation, a batch, semicontinuous or continuous system may be used but most often is a continuous fluidized system.

3,198,486 Patented July 6, 1965 "ice The cracking catalyst is of the solid refractory metal oxide type known in the art, for instance silica, alumina-,- magesia, titania, etc., or their mixtures. Of most importance are the synthetic gel-containing catalysts, such as the synthetic and the semi-synthetic, i.e., synthetic gel supported on a carrier such as natural clay, cracking catalysts. The cracking catalysts which have received the widest acceptance today are usually predominantly silica, that is silica-based, and may contain solid acididc oxide promoters, e.g. alumina, magnesia, etc., With the promoters usually being less than about 50% of the catalyst, preferably about 5 to 25%. These compositions are calcined to a state of very slight hydration. The catalytic cracking process involves using a finely divided form or fluidized solid catalyst; in a highly prefered form of this invention finely divided (fluidized) catalyst, for instance having particles predominantly in the 20 to or even micron range, is disposed as a fluidized bed in the reaction zone to which the feed is charged continuously and is reacted essentially in the vapor phase.

Vaporous products are taken overhead and a portion of the catalyst is continuously withdrawn and passed to a regeneration zone where coke or carbon is burned from the catalyst in a fluidized bed by contact with a free oxygen-containing gas before its return to the re action zone. In cracking, coke yield may be held to a minimum through the use of good steam striping and a high steam partial pressure and removal of coke from the catalyst is performed by regeneration. Regeneration of a catalyst to remove carbon is a relatively quick procedure in most commercial catalytic conversion operations. For example, in a typical fluidized cracking unit, a portion of catalyst is continually being removed from the reactor and sent to the regenerator for contact with air at about 950 to 1200 F., more usually about 1000 to 1150 F. Combustion of coke from the catalyst is rapid, and for reasons of economy only enough air is used to supply the needed oxygen. Average residence time for a portion of catalyst in the regenerator may be on the order of about six minutes and the oxygen content of the effluent gases from the regenerator is desirably less than about /2%. The regeneration of any particular quantum of catalyst is generally regulated to give a carbon content of less than about 1.0%, generally less than about 0.5%. V

In a typical operation the catalytic cracking of the hydrocarbon feed would normally result in the conversion of about 40 to 70%, preferably about 50 to 60%, of the feedstock into a product boiling in the gasoline range. The effluent from the cracker, containing a minor amount, for instance, about 0.6 to 2 lbs/gal. of the cracking catalyst which was not removed by the cyclone separator in the reactor, may be conveniently distilled to remove materials boiling below the gasoline range; gasoline boiling in the range up to about 430 F., and cycle oil fractions boiling up to about 950 F. which may be recycled to the cracking reactor. The fractionator bottoms usually boiling primarily above about 750 F., comprise a heavy oil slurry stream containing entrained catalyst particles primarily of a size up to for instance about 80 microns, is removed and charged to the coking unit. The distillation is preferably carried out at near atm spheric pressure.

Coking processes of one type or another have been practiced in the petroleum refining art for many years. A primary objective in all these processes has been to convert as large a proportion as possible of the feedstock to the coker to lighter hydrocarbon fractions while keeping coke formations to a minimum. In the present invention fluidized coking apparatus is used, such as disclosed are characterized by the formation of relatively small amounts of coke and improved yields of lighter hydrocarbon products. In the present case the fractionator bottoms containing the suspended catalyst is charged to the coking unit. The charge feed may be mixed with a dispersion medium such as steam or the latter may be separately applied to give a compact fluidized bed or dispersed fluidized system. The pressure to be employed in the coking zone is conventional and atmospheric, subatmospheric or superatmospheric pressures can be used. Preferably, however, the-pressure is advantageously kept low ranging from atmospheric up to about 75 p.s.i.g. Temperatures prevailing in the coking zone should be sufficiently high to effect coking of the fractionator bottoms on the suspended catalyst particles before the bottoms feed comes incontact with the walls of the coker in order to prevent the coke from collecting along the Walls and not on the catalyst particles. These temperatures will vary depending on the composition of the bottomsfraction as Well as the physical conditions prevailing in the system, i.e. the diameter of the reaction zone, the size of the spray particles as they are fed into the coking unit, and

other related factors. 7 In general, the temperatures in the reactor should be suificiently high to effect readily coking of the feed particles on the suspended catalyst particles,

cracking of the hydrocarbon products recovered from,

the fractionator bottoms. The temperature in the coking unit will usually vary from about 800 to 1200 F., preferably from about 900 to 1000 F. The heat to the coke can be supplied by a coke burner which burns a portion of the coke to provide heat and/ or catalyst from the regenerator standpipe.

a The fractionator bottoms can zone at rates varying within a relatively wide range. The bottoms from the fractionator will generally supply essentially all of the feed to the coking unit, but if desiredpetroleum residua, as for instance, vacuum residua, atmospheric residua, tars, pitches, etc. boiling primarily above about 950 F. may be supplied to the coking unit from an outside source. Dispersion steam superheated to about the same temperature as maintained in the coking reactor can be used to improve distribution. The fluidiz- .ing steam flow will of course, depend on the coke particle size with higher steam'velocities being avoided on account.

of economic reasons. Generally the steam flow maybe in the range of about to 100 lbs./bbl. of hydrocarbon feed with a preferred steam flow rate being about to lbs./bbl. of feed to yield coke ladened catalyst particles having a size of about 20 to 80 or even 150 microns. The coke ladened catalyst particles are removed from the bottom of the coker and transferred to the regeneration zone where these particles are subjec tedto regenerating conditions described above to supply heat'to the cracking system. The catalyst particles after the coke has been removed can be recycled to the catalytic cracking zone for further use;

A portion of the coke laden catalyst can be withdrawn from the return line to the regenerator and sent to a burner I where the coke is burned oif and hot catalyst is'added to the incoming fractionator bottoms feedto maintain a desired range of catalyst to oil ratio of 10:1 to 40:1 and provide the additional heat required for the process. Alternatively, if extra catalyst particles are needed in the V coking reaction a slip stream of regenerated catalyst from the regenerator may be introduced to the feed line to the coker. r s a H 3 The overhead fraction from'the coker is removed and may be treated with molecular hydrogenin the presence of a sulfur resistant hydrogenation catalyst prior to charging the overhead or a fraction thereof, to the catalytic cracking operation alone or in combination withother V feedstock constituents. Such catalysts usually have as an active component a so-called metal, for instance, selected from the group consisting of tin, vanadium, metals of Groups VB and VIB in'the Periodic Table and metals of the'iron group, frequently disposed as inorganic com ponents, for instance, oxides, sulfides or other compounds,

supported on a'solid carrier exemplified by alumina, silica, etc. The amount of catalytically active metal in the supported catalysts is usually about 1 to 30 weight percent of the catalyst and preferably about 3 to 20 weight percent,

, with there being at least about 1%, preferably at least be supplied to the coking V about 2%, ofeach catalytically active metal when combinations are used. The hydrotreating is conducted at a temperature of about 600 to 900 F., preferably about 650 to 750 F., pressures of about 300'to 3000 p.s.i.g., preferably about 500 to 2000 p.s.i.g.; weight'hourly space elocitiesKWfi-ISV) of about 0.1 to 10, preferably about 0.5 to '5; molecular hydrogen is provided in amounts of about 500 to 10,000, preferably about 1000-to 7500 standard cubic feet of hydrogen per barrel of 'oil.

By so treating, the hydrocarbon overhead fraction may be given an improved hydrogen-to-carbon ratio and the amount of contaminants, such as coke-formers, sulfur and nitrogen may be reduced. Alternatively, the coker overhead fraction maybe fed directly to the catalytic cracking unitwithout pretreating and recovery of all the products may be made in the 'cracking units recovery system.

The present inventionmay be illustrated by reference to the accompanying schematic of the preferred embodiment of the presentinvention.

, A typical Mid-Continent gas oil having an API gravity of about 27, a Conradson carbon of about 0.3 weight percent, a kinematic viscosity of about 5.5 centistokes at 210 F., andan initial boiling point above about 450 F. at atmospheric pressure is preheated to about 60.0 to 700 F. and introduced into catalytic cracking unit 2, via line 4, mixed with a finely divided, cracking catalyst. The catalyst introduced into feed. line 4 is a Nalcat synthetic gel cracking catalyst containing 25% A1 0 the balance silica, and having fluidizable particle size.

The reactor 2. is an elongated vessel having disposed in its lower portion, grid 6, 'forrsupporting the fluidized catalyst bed. The overhead from the catalytic reactor 7 passes through the cyclone separator 53 with catalyst fines being returned to the fluidized bed by the cyclone dip are removed via annulus 10 to line 12 to catalyst riser 14 and conveyed by the action of dry air entering line 14 at 16 to regenerator it .In regenerator 18, the catalyst is decoked and then passed through standpipe 20 and recycled to the reaction zone2,,by feed line 4.

1 The cracking conditions in the reactor 2, comprise a temperature of about 915 F. and a pressure of about 10 p.s.i.g. The feedstock mixture is conveyed to the cracker at a weight hourly space velocity of about 3 and a catalyst to oil ratio of about 7. The catalyst is with drawn via annulus 10, and lines 12 and 14 to regenerator 18 and is contacted with air at 1050 F. to burn off the carbon. The overhead from reaction vessel, 2, passes through cyclone separator 25 to linen and conveyed via line 24 to fractionating column 26. Pressures of about 10 to 80 p.s.i. g. are maintained in the fractionating column. Line 2'8 provides for the removal of fixed gases and gasoline, e.g. boiling up to about 430 F., for further processing for fuel recovery'and se'parationJ Line 30 7 provides for the removal of light cycle oils, e.g. boiling cracking, etc. or may be recycled to the'catalytic cracking unit 2 by means not shown."

The heavy material boiling above about 750 F. and.

containing the entrained catalyst particles is removed from the bottom of the fractionator tower 26 by line 34. The bottoms, from fractionation tower 26, containing the entrained cracking catalyst particle, represents the feed to coking reactor 36 and is charged through pump 38 and lines 40 and 42. Residual hydrocarbon oil may be added by line 41. The bottoms amounting to, for instance, about 3 to 15% by volume of the hydrocarbon cracked product may have an API gravity of up to about 25 and a Conradson carbon residue in the range of about 1.52.5% or more. The coking temperature is maintained in the reaction vessel at about 975 F. Dispersion steam, superheated up to about 1000 F. or more is introduced into the coker through line 43. As the coke particles on the entrained catalyst in the bottoms feed grow larger they are discharged through line 52 to line 14 where these coke ladened catalyst particles are conveyed to regenertor 18 to remove the coke. A slip stream may be withdrawn from line 52 and passed to unit 46 via line 48 where the coke is burnt oil? and hot catalyst is added to the incoming fractionator bottoms feed to the coking unit. Unit 46 is a burner of any conventional type where coke is heated in combustion gases such as an oxygen-containing gas, to reaction temperatures of about 1200 to about 1500 F. Flue gases are removed and the coke free catalyst particles are added to the fractionator bottoms via line 44. The heating in unit 46 may take place by means of burning of the carbon or by means of hot flue gases or the combustion of combustible gases in the heater in the presence of the coke ladened catalyst particles. The overhead from vessel 36 passes via lines 54, 55 and 56 to feed line 4 where it is carried into reactor 2. Alternatively the overhead fraction removed by line 54 may be passed by line 58 to hydrogen treater 60 in order to improve its hydrogen-to-carbon ratio. The treated overhead is then removed via line 62 and passed by line 56 to feed line 4.

An analysis of the yield from the process of the method of the present invention is as follows:

Table I Coke wt. percent 14.7 Gas (FOE) 1 vol. percent 12.9 C products:

Propylene vol. percent 3.0 Propane vol. percent 2.0 Iso-butane vol. percent 2.0 Butylene vol. percent 5.5 n-Butane vol. percent 1.7 Gasoline stocks vol. percent 52.6 Distillate stocks vol. percent 35.0

Fuel oil equivalent.

It can be readily seen that by the method of the present invention the coke make is minimized, and the production of usable products is maximized from the fractionator bottoms material. The method of the present invention provides increased process heat by utilizing the heat contained in the recovered coke particle in the regeneration zone, and also for the recovery of catalyst lost from the reactor cyclone separator.

I claim:

1. A process for treating a hydrocarbon oil boiling above the gasoline range comprising contacting said bydrocarbon oil in a cracking zone with a cracking catalyst having a particle size of about 20 to 150 microns under fluidized cracking conditions, removing the cracking effluent containing a small amount of said cracking catalyst, fractionating the cracking efliuent containing said efiluent catalyst particles to recover gasoline and materials in the gas oil range, removing from the fractionator residual material higher boiling than said gas oil and containing said eflluent cracking catalyst, conveying said residual and efiiuent catalyst to a coking zone where said material is subjected in a fluidized state to temperatures of about 800 to 1200 F. to coke said residual on said eflluent catalyst particles, recovering an overhead product, removing coke from said coke-bearing catalyst by burning and passing resulting decoked catalyst particles to said cracking zone; said overhead product from the coking zone being passed to said cracking zone.

2. The method of claim 1 wherein said cracking catalyst is synthetic gel silica-alumina.

3. The method of claim 1 wherein the overhead product from the coking zone is contacted with a sulfur resistant hydrogenation catalyst in the presence of molecular hydrogen at a temperature of about 600 to 900 F. prior to charging to said cracking zone.

4. The method of claim 1 wherein a portion of the coked catalyst is burned and passed to the coking zone to provide heat.

5. The method of claim 3 wherein a portion of the coked catalyst is burned and passed to the coking zone to provide heat.

References Cited by the Examiner UNITED STATES PATENTS 2,319,201 5/43 Angell 208-52 2,391,336 1-2/45 Ogorzaly 208-50 2,658,857 11/53 Roediger 208-67 3,717,862 9/ Murphree 208-127 2,721,168 10/55 Kimberlin et a1 208-127 3,071,535 1/63 Condrasky et al. 208-55 ALPHONSO D. SULLIVAN, Primary Examiner.

Patent Citations
Cited PatentFiling datePublication dateApplicantTitle
US2319201 *May 9, 1940May 18, 1943Universal Oil Prod CoConversion of hydrocarbon oils
US2391336 *Jul 27, 1944Dec 18, 1945Standard Oil Dev CoPetroleum conversion process
US2658857 *Mar 29, 1951Nov 10, 1953Standard Oil Dev CoBituminous saturant
US2721168 *Oct 14, 1954Oct 18, 1955Exxon Research Engineering CoSeed coke production in fluid coking systems using oxidation to increase friability
US3071535 *Jul 6, 1959Jan 1, 1963Gulf Research Development CoProcess for making a low sensitivity premium gasoline
US3717862 *Oct 9, 1970Feb 20, 1973Nittan Co LtdFire detecting system and testing means therefor
Referenced by
Citing PatentFiling datePublication dateApplicantTitle
US3493489 *Apr 17, 1968Feb 3, 1970Chevron ResProcess for the production of jet fuel and middle distillates
US4394250 *Jan 21, 1982Jul 19, 1983Chevron Research CompanyDelayed coking process
US4552645 *Mar 9, 1984Nov 12, 1985Stone & Webster Engineering CorporationProcess for cracking heavy hydrocarbon to produce olefins and liquid hydrocarbon fuels
US4663019 *Mar 9, 1984May 5, 1987Stone & Webster Engineering Corp.Thermal cracking, coking, using coke for heat
US4946583 *May 20, 1985Aug 7, 1990Gfk Gesellschaft Fur Kohleverflussigung MbhProcess for the liquefaction of coal
US5268090 *Mar 16, 1992Dec 7, 1993UopFCC process for reducing sox using H2 S free lift gas
US6811682 *Oct 2, 2002Nov 2, 2004Exxonmobil Research And Engineering CompanyCycle oil conversion process
US7737068 *Dec 20, 2007Jun 15, 2010Chevron U.S.A. Inc.processing effluent stream containing unsupported catalyst in uncoverted fee; pyrolizing Group VI and VIII metal sulfid catalyst slurried in heavy oil to provide lighter oil products and a coke which is leachable so that valuable metals can be recovered; filtering ammonium molybdate product
US7790646 *Dec 20, 2007Sep 7, 2010Chevron U.S.A. Inc.Conversion of fine catalyst into coke-like material
Classifications
U.S. Classification208/50, 208/127, 208/55, 208/161, 208/67
International ClassificationC10G51/00, C10G69/00, C10G51/02
Cooperative ClassificationC10G69/00, C10G51/02
European ClassificationC10G51/02, C10G69/00