Patent Publication Number: US-4728416-A

Title: Cracking blends of gas oil and residual oil

Description:
CROSS-REFERENCE TO RELATION APPLICATIONS 
     This application is a continuation-in-part of the following pending U.S. application filed in the name of the inventor herein: Ser. No. 094,216, now U.S. Pat. No. 4,34l,624, and Ser. No. 094,092, now U.S. Pat. No. 4,332,673, both filed Nov. 14, 1979; and Ser. No. 246,751, now U.S. Pat. No. 4,376,696, and Ser. No. 246,782, now U.S. Pat. No. 4,375,404, and Ser. No. 246,791, now U.S. Pat. No. 4,376,038 all filed Mar. 23, 1981, the entire disclosures of each of the aforementioned applications hereby being incorporated herein by reference. 
    
    
     TECHNICAL FIELD 
     This invention relates to fluid catalytic cracking of blends of gas oils and residual oils into lighter fractions, which may for example include gasoline, heating oil and/or other products. 
     BACKGROUND ART 
     In the art of fluid catalytic cracking it is known to crack a gas oil feed in a cracking zone at an elevated temperature in the presence of a cracking catalyst. The cracking reaction tends to deposit coke on the catalyst. Thus, at the conclusion of the cracking reaction the resultant vapor products are separated from the catalyst particles and the latter are regenerated in a regeneration zone by burning coke off of the catalyst. The catalyst is circulated between the cracking zone and the regeneration zone, whereby coke-laden spent catalyst separated from the products is delivered to the regeneration zone for regeneration, and regenerated catalyst, freed of its coke deposit and discharged from the regeneration zone, is returned to the cracking zone for contact with additional gas oil feed. Many suitable types of apparatus for performing such reactions are known to persons skilled in the art. For a number of examples see U.S. Pat. No. 4,200,520, column 1, lines 45-60. See also U.S. Pat. Nos. 4,066,533 and 4,070,159 to George D. Myers, et al. 
     The gas oil feed conventionally employed in fluid catalytic cracking typically comprise virgin gas oils, recycled streams from fluid catalytic cracking and thermally cracked material boiling below about 1050° F., typically in the range of about 600° F. to about 1050° F., and more typically less than 1025° F. or in many cases less than 1000° F. All of these feeds typically contain rather small amounts of heavy metals such as nickel and vanadium, which are understood to be present in the form of high molecular weight organo metallic compounds. The quantity of such metals present in the feeds may for example be expressed in terms of equivalent nickel, which is the total amount of nickel (Ni) content plus 20% of the vanadium (V) content of the feed, i.e., Ni +V/5. 
     During the course of the cracking reaction the above-mentioned metals are deposited on the circulating catalyst. During the life of a given catalyst particle, as it repeatedly is exposed to feed, the accumulation of metallic nickel and vanadium thereon progressively increases. Generally speaking the operators of fluid catalytic cracking units practice continuous or intermittent introduction of fresh catalyst to the unit to make up for any losses of catalyst from the system and/or to assist in manintaining the desired level of catalytic activity in the catalyst inventory. As persons skilled in the art will readily appreciate, the nickel and vanadium accumulation may vary from one particle to another within the inventory, but the overall or average inventory of metals on catalyst is in general a function of the amount of such metals present on the fresh catalyst added to the system, the amount of such metals present in the feeds supplied to the system, the relative quantities in which feed and catalyst are brought into contact with one another over an extended period of operation, and the amounts of catalyst introduction and withdrawal (if any) which occur during such operating period. It has been reported that in typical fluid catalytic cracking operations the process is controlled in such a manner as to cause the metal content of the catalysts to equilibriate at a level in the range of about 200 to about 1400 parts per million based on the weight of the catalyst. 
     Heretofore the present inventor has in certain applications filed in the sole name of the present inventor and jointly with Lloyd E. Busch, described the RCC process, a process of fluid catalytic conversion of carbo-metallic oils to liquid products similar to those obtained in FCC processes. The RCC process is for example disclosed in U.S. Pat. Nos. 4,341,624, 4,347,122, 4,299,687, 4,354,923 and 4,332,673 the entire disclosures of which are hereby incorporated by reference. In RCC processing the feed as a whole will normally contain substantial proportions of components which will not boil below 1025° F. or 1050° F. Such high boiling components generally impart to the carbo-metallic oil feeds considerably higher Conradsen or Ramsbottom carbon values than are typical with gas oil feeds. Moreover these higher boiling components are frequently or usually the repositories of the organo-metallic compounds which are the source of the nickel and vanadium contamination of the feed. Thus in carbo-metallic oil feeds one will generally find a metals content, expressed in equivalent nickel (see above) or nickel equivalents of at least about 4. Nickel equivalents may be expressed in terms of the equation: ##EQU1## wherein each of the above indicated metals is expressed in parts by million by weight of such metal, as metal, based on the weight of the feed. Because of the much larger metals contents of carbo-metallic oils, they tend to impart to the circulating catalyst inventories substantially higher metals accumulations than are found in FCC processing. For example, the metals accumulation on catalyst may range from substantially in excess of 600 ppm nickel equivalents to as high as 70,000 ppm nickel equivalents. In many instances the nickel equivalents of metals accumulated on the catalyst inventory will exceed 3000 ppm. The combined operating difficulties associated with high metals and coke precursors in feed and high rates of metal and coke deposition on catalyst have represented a severe challenge for refiners. 
     Standing somewhat as a middle ground between these two extremes is the practice of fluid catalytic cracking blends of gas oil, as above described, with various residual oils, the latter containing significantly more metals and/or coke precursors than are common in the typical FCC gas oils. For example see U.S. Pat. Nos. 3,781,197 and 3,785,959 by Millard C. Bryson et al. These patents disclose the cracking of a gas oil admixed with controlled amounts of residual oils, which may or may not have been hydro-desulphurized, over zeolite catalysts. Reportedly, such procedure provides improved yields of gasoline and may improve the clear octane value of certain boiling ranges of the resultant liquid fuel, i.e. gasoline, product. The teachings of this art, in common with prior FCC practice, regard the accumulation of metal on the catalyst as deleterious. 
     SUMMARY OF THE INVENTION 
     The present invention comprises an improvement in the known process of catalytic cracking wherein a gas oil feed is cracked in a cracking zone at an elevated temperature in the presence of a cracking catalyst. In accordance with prior procedure the cracking catalyst is regenerated in a regeneration zone by burning coke off of the catalyst, and catalyst is circulated between the cracking zone and the regeneration zone. The present invention is an improvement for obtaining a naphtha product of improved octane number. It comprises introducing a sufficient amount of a nickel and vanadium metals-containing heavy feedstock with the gas oil feed into the cracking zone to deposit nickel and vanadium metals on the catalyst and to raise the nickel and vanadium metals content of the catalyst to a level ranging from about 1500 to about 6000 parts per million of said metals expressed as equivalent nickel, based on the weight of the catalyst. The level of nickel and vanadium on the catalyst is maintained in the aforementioned range by adding low nickel and vanadium metals-containing catalyst to the system, e.g. to the regeneration zone. High nickel and vanadium metals-containing catalyst may be withdrawn from the system if the system losses of catalyst are not sufficient to balance the rate of catalyst addition. 
     The following are some optional but preferred embodiments of the foregoing general process. For example, the foregoing process may be practiced using a metals-containing heavy feedstock, added to the gas oil feed, which has a final boiling point about 1050° F. This however does not imply that any or all of the materials in the heavy feedstock will boil above 1050° F., since the heavy materials in question may crack before they boil, and some of the feed components may be incapable of boiling. According to another alternative embodiment the metals-containing heavy feedstock may be added to the gas oil feed prior to the introduction of the feed, i.e. the resultant mixture, into the cracking zone. The metals-containing heavy feedstock may for example contain from about 2 to about 1000 ppm of equivalent nickel, based on the weight of said heavy feedstock. Optionally, the metals-containing feedstock may be continuously added with the gas oil feed in amounts ranging above 0% to about 25% and higher, based on the volume of the gas oil, and fresh catalyst may be added to the unit at a rate of 0.08 pounds to about 0.50 pounds per barrel of gas oil feed processed. and catalyst may be withdrawn at a rate sufficient to maintain the unit in balance. However, ratios of heavy feedstock to gas oil feed in excess of 25%, ranging as high as 66% or more are contemplated. Accordingly the fresh catalyst addition rate may, if desired, be adjusted upwardly from the range indicated. The option of operating with 0 to 25% heavy feedstock based on gas oil volume may be practiced in conjunction with the use of a gas oil feed boiling within the range of about 600° F. to about 1050° F. and addition of the metals containing heavy feedstock to the gas oil feed prior to the introduction of the feed into the cracking zone. A preferred range of metals on catalyst ranges from about 2500 to about 4000 ppm expressed as equivalent nickel. The preferred catalysts for carrying out the invention comprise crystalline alumino silicate zeolite. These and other optional embodiments of the invention are described in greater detail in the accompanying drawings and in the various and preferred embodiments set forth below. 
    
    
     BRIEF DESCRIPTION OF THE DRAWINGS 
     FIG. 1 is a schematic diagram of a first form of catalytic cracking unit useful in conducting the process of the present invention. 
     FIG. 2 is a schematic diagram of a preferred form of apparatus useful for conducting the invention. 
    
    
     BEST AND VARIOUS OTHER ILLUSTRATIVE MODES FOR CARRYING OUT THE INVENTION 
     The present invention is notable in providing a simple, relatively straight-forward and highly productive approach to the conversion of gas oil feeds and carbo-metallic oil feeds, such as reduced crude, to various lighter products such as gasoline. The carbo-metallic feed comprises or is composed of oil which boils above about 600° F. Such oil, or at least the 650° F.+ portion thereof, is characterized by a heavy metal content of at least about 4, preferably more than about 5, and most preferably at least about 5.5 ppm of nickel equivalents by weight and by a carbon residue on pyrolysis of at least about 1% and more preferably at least about 2% by weight. Two established tests for determining the carbon residue on pyrolysis of a feed are recognized, the Conradsen carbon and Ramsbottom carbon tests, the former being described in ASTM D-189-76 and the latter being described in ASTM Test No. D-524-76. 
     In accordance with the invention, the gas oil feed and carbo-metallic oil feed, in the form of separate or combined streams of pumpable liquid, are brought into contact with hot conversion catalysts in a weight ratio of catalyst to total feed in the range of about 3 to about 18 and preferably more than about 6. 
     The feed in said mixture undergoes a conversion step which includes cracking while the mixture of feed and catalyst is flowing through a progressive flow type reactor. The feed, catalyst, and other materials may be introduced at one or more points. The reactor includes an elongated reaction chamber which is at least partly vertical or inclined and in which the feed material, resultant products and catalyst are maintained in contact with one another while flowing as a dilute phase or stream for a predetermined riser residence time in the range of about 0.5 to about 10 seconds. 
     The reaction is conducted at a temperature of about 900° to about 1400° F., measured at the reaction chamber exit, under a total pressure of about 10 to about 50 psia (pounds per square inch absolute) under conditions sufficiently severe to provide a conversion per pass in the range of about 50% or more and to lay down coke on the catalyst in an amount in the range of about 0.3 to about 3% by weight and preferably at least about 0.5%. The overall rate of coke production, based on weight of fresh feed, is in the range of about 4 to about 14% by weight. 
     At the end of the predetermined residcnce time, the catalyst is separated from the products, is stripped to remove high boiling components and other entrained or adsorbed hydrocarbons and is then regenerated with oxygen-containing combustion-supporting gas under conditions of time, temperature and atmosphere sufficient to reduce the carbon on the regenerated catalyst to about 0.25% or less and preferably about 0.05% or less by weight. 
     Depending on how the process of the invention is practiced, one or more of the following additional advantages may be realized. If desired, and preferably, the process may be operated without added hydrogen in the reaction chamber. If desired, and preferably, the process may be operated without prior hydrotreating of the feed and/or without other process of removal of asphaltenes of metals from the feed, and this is true even where the carbo-metallic oil component contains more than about 4, or more than about 5 or even more than about 5.5 ppm Nickel Equivalents by weight of heavy metal and has a carbon residue on pyrolysis greater than about 1%, greater than about 1.4% or greater than about 2% by weight. Moreover, all of the converter feed, as above described, may be cracked in one and the same conversion chamber. The cracking reaction may be carried out with a catalyst which has previously been used (recycled, except for such replacement as required to compensate for normal losses and deactivation) to crack a feed mixture under the above described conditions. Heavy hydrocarbons not cracked to gasoline in a first pass may be recycled with or without hydrotreating for further cracking in contact with the same kind of feed in which they were first subjected to cracking conditions, and under the same kind of conditions; but operation in a substantially once-through or single pass mode (e.g. less than about 15% by volume of recycle based on volume of fresh feed) is preferred. 
     According to one preferred embodiment or aspect of the invention, at the end of the predetermined residence time referred to above, the catalyst is projected in a direction established by the elongated reaction chamber or an extension thereof, while the products, having lesser momentum, are caused to make an abrupt change of direction, resulting in an abrupt, substantially instantaneous ballistic separation of products from catalyst. The thus separated catalyst is then stripped, regenerated and recycled to the reactor as above described. 
     According to another preferred embodiment or aspect of the invention, the converter feed contains 650° F.+ material which has not been hydrotreated and is characterized in part by containing at least about 5.5 parts per million of nickel equivalents of heavy metals. The converter feed is brought together not only with the above mentioned cracking catalyst, but also with additional gaseous material including steam whereby the resultant suspension of catalyst and feed also includes gaseous material wherein the ratio of the partial pressure of the added gaseous material relative to that of the feed is in the range of about 0.25 to about 4. The vapor residence time is in the range of about 0.5 to about 3 seconds when practicing this embodiment or aspect of the invention. This preferred embodiment or aspect and the one referred to in the preceeding paragraph may be used in combination with one another or separately. 
     According to another preferred embodiment or aspect of the invention, the feed material is not only brought into contact with the catalyst, but also with one or more additional materials including particularly liquid water in a weight ratio relative to feed ranging from about 0.04 to about 0.25, more preferably about 0.04 to about 0.2 and still more preferably about 0.05 to about 0.15. Such additional materials, including the liquid water, may be brought into admixture with the feed prior to, during or after mixing the feed with the aforementioned catalyst, and either after or, preferably, before, vaporization of the feed. The feed, catalyst and water (e.g. in the form of liquid water or in the form of steam produced by vaporization of liquid water in contact with the feed) are introduced into the progressive flow type reactor, which may or may not be a reactor embodying the above described ballistic separation, at one or more points along the reactor. While the mixture of feed, catalyst and steam produced by vaporization of the liquid water flows through the reactor, the feed undergoes the above mentioned conversion step which includes cracking. The feed material, catalyst, steam and resultant products are maintained in contact with one another in the above mentioned elongated reaction chamber while flowing as a dilute phase or stream for the above mentioned predetermined riser residence time which is in the range of about 0.5 to about 10 seconds. 
     The present invention provides a process for the continuous catalytic conversion of a wide variety of feed materials to lower molecular weight products, while maximizing production of highly valuable liquid products, and making it possible, if desired, to avoid vacuum distillation and other expensive treatments such as hydrotreating. The term &#34;oils&#34;, includes not only those predominantly hydrocarbon compositions which are liquid at room temperature (i.e., 68° F.), but also those predominantly hydrocarbon compositions which are asphalts or tars at ambient temperature but liquify when heated to temperatures in the range of up to about 800° F. The invention is applicable to carbo-metallic oils, whether of petroleum origin or not. For example, provided they have the requisite boiling range, carbon residue on pyrolysis and heavy metals content, the invention may be applied to the processing of such widely diverse materials as heavy bottoms from crude oil, heavy bitumen crude oil, those crude oils known as &#34;heavy crude&#34; which approximate the properties of reduced crude, shale oil, tar sand extract, products from coal liquification and solvated coal, atmospheric and vacuum reduced crude, extracts and/or bottoms (raffinate) from solvent de-asphalting, aromatic extract from lube oil refining, tar bottoms, heavy cycle oil, slop oil, other refinery waste streams and mixtures of the foregoing. Such mixtures can for instance be prepared by mixing available hydrocarbon fractions, including oils, tars, pitches and the like. Also, powdered coal may be suspended in the carbo-metallic oil. Persons skilled in the art are aware of techniques for demetalation of carbo-metallic oils, and demetalated oils may be converted using the invention; but is is an advantage of the invention that it can employ as feedstock carbo-metallic oils that have had no prior demetalation treatment. Likewise, the invention can be applied to hydrotreated feedstocks; but it is an advantage of the invention that it can successfully convert carbo-metallic oils which have had substantially no prior hydrotreatment. However, the preferred application of the process is to reduced crude, i.e., that fraction of crude oil boiling at and above 650° F., in admixture with virgin gas oils. 
     In accordance with the invention one provides a carbo-metallic oil feedstock, at least about 70%, more preferably at least about 85% and still more preferably about 100% (by volume) of which boils at and above about 650° F. All boiling temperatures herein are based on standard atmospheric pressure conditions. In carbo-metallic oil partly or wholly composed of material which boils at and above abcut 650° F., such material is referred to herein as 650° F.+ material; and 650° F.+ material which is part of or has been separated from an oil containing components boiling above and below 650° F. may be referred to as a 650° F.+ fraction. But the terms &#34;boils above&#34; and &#34;650° F.+ &#34; are not intended to imply that all of the material characterized by said terms will have the capability of boiling. The carbo-metallic oils contemplated by the invention may contain material which may not boil under any conditions; for example, certain asphalts and asphaltenes may crack thermally during distillation, apparently without boiling. Thus, for example, when it is said that the feed comprises at least about 70% by volume of material which boils above about 650° F., it should be understood that the 70% in question may include some material which will not boil or volatilize at any temperature. These non-boilable materials when present, may frequently or for the most part be concentrated in portions of the feed which do not boil below about 1000° F., 1025° F. or higher. Thus, when it is said that at least about 10%, more preferably about 15% and still more preferably at least about 20% (by volume) of the 650° F.+ fraction will not boil below about 1000° F. or 1025° F., it should be understood that all or any part of the material not boiling below about 1000° or 1025° F., may or may not be volatile at and above the indicated temperatures. 
     Preferably, the carbo-metallic feeds, or at least the 650° F.+ material therein, have a carbon residue on pyrolysis of at least about 2 or greater. For example, the Conradson carbon content may be in the range of about 2 to about 12 and most frequently at least about 4. A particularly common range is about 4 to about 8. Those feeds having a Conradson carbon content greater than about 6 especially need special means for controlling excess heat. 
     Preferably, the carbo-metallic feed has an average composition characterized by an atomic hydrogen to carbon ratio in the range of about 1.2 to about 1.9, and preferably about 1.3 to about 1.8. 
     The carbo-metallic feeds employed in accordance with the invention, or at least the 650° F.+ material therein, may contain at least about 4 parts per million of Nickel Equivalents, as defined above, of which at least about 2 parts per million is nickel (as metal, by weight). Carbo-metallic oils within the above range can be prepared from mixtures of two or more oils, some of which do and some of which do not contain the quantities of Nickel Equivalents and nickel set forth above. It should also be noted that the above values for Nickel Equivalents and nickel represent time-weighted averages for a substantial period of operation of the conversion unit, such as one month, for example. It should also be noted that the heavy metals have in certain circumstances exhibited some lessening of poisoning tendency after repeated oxidations and reductions on the catalyst, and the literature describes criteria for establishing &#34;effective metal&#34; values. For example, see the article by Cimbalo, et al, entitled &#34;Deposited Metals Poison FCC Catalyst&#34;, Oil and Gas Journal, May 15, 1972, pp 112-122, the contents of which are incorporated herein by reference. If considered necessary or desirable, the contents of Nickel Equivalents and nickel in the carbo-metallic oils processed according to the invention may be expressed in terms of &#34;effective metal&#34; values. Notwithstanding the gradual reduction in poisoning activity noted by Cimbalo, et al, the regeneration of catalyst under normal FCC regeneration conditions may not, and usually does not, severely impair the dehydrogenation, demethanation and aromatic condensation activity of heavy metals accumulated on cracking catalyst. 
     It is known that about 0.2 to about 5 weight percent of &#34;sulfur&#34; in the form of elemental sulfur and/or its compounds (but reported as elemental sulfur based on the weight of feed) appears in FCC feeds and that the sulfur and modified forms of sulfur can find that way into the resultant gasoline product and, where lead is added, tend to reduce its susceptibility to octane enhancement. Sulfur in the product gasoline often requires sweetening when processing high sulfur containing crudes. To the extent that sulfur is present in the coke, it also represents a potential air pollutant since the regenerator burns it to SO 2  and SO 3 . However, we have found that in our process the sulfur in the feed is on the other hand able to inhibit heavy metal activity by maintaining metals such as Ni, V, Cu and Fe in the sulfide form in the reactor. These sulfides are much less active than the metals themselves in promoting dehydrogenation and coking reactions. Accordingly, it is acceptable to carry out the invention with a carbo-metallic oil having at least about 0.3%, acceptably more than about 0.8% and more acceptably at least about 1.5% by weight of sulfur in the 650° F.+ fraction. 
     The carbo-metallic oils useful in the invention may and usually do contain significant quantities of compounds containing nitrogen, a substantial portion of which may be basic nitrogen. For example, the total nitrogen content of the carbo-metallic oils may be at least about 0.05% by weight. Since cracking catalysts owe their cracking activity to acid sites on the catalyst surface or in its pores, basic nitrogen-containing compounds may temporarily neutralize these sites, poisoning the catalyst. However, the catalyst is not permanently damaged since the nitrogen can be burned off the catalyst during regeneration, as a result of which the acidity of the active sites is restored. 
     The carbo-metallic oils may also include significant quantities of pentane insolubles, for example at least about 0.5% by weight, and more typically 2% or more or even about 4% or more. These may include for instance asphaltenes and other materials. 
     Alkali and alkaline earth metals generally do not tend to vaporize in large quantities under the distillation conditions employed in distilling crude oil to prepare the vacuum gas oils normally used as FCC feedstocks. Rather, these metals remain for the most part in the &#34;bottoms&#34; fraction (the non-vaporized high boiling portion) which may for instance be used in the production of asphalt or other by-products. However, reduced crude and other carbo-metallic oils are in many cases bottoms products, and therefore may contain significant quantities of alkali and alkaline earth metals such as sodium. These metals deposit upon the catalyst during cracking. Depending on the composition of the catalyst and magnitude of the regeneration temperatures to which it is exposed, these metals may undergo interactions and reactions with the catalyst (including the catalyst support) which are not normally experienced in processing VGO under conventional FCC processing conditions. If the catalyst characteristics and regeneration conditions so require, one will of course take the necessary precautions to limit the amounts of alkali and alkaline earth metal in the feed, which metals may enter the feed not only as brine associated with the crude oil in its natural state, but also as components of water or steam which are supplied to the cracking unit. Thus, careful desalting of the crude used to prepare the carbo-metallic feed may be important when the catalyst is particularly susceptible to alkali and alkaline earth metals. In such circumstances, the content of such metals (hereinafter collectively referred to as &#34;sodium&#34;) in total feed can be maintained at about 1 ppm or less, based on the weight of the feedstock. Alternatively, the sodium level of the feed may be keyed to that of the catalyst, so as to maintain the sodium level of the catalyst which is in use substantially the same as or less than that of the replacement catalyst which is charged to the unit. 
     According to a particularly preferred embodiment of the invention, the carbo-metallic oil feedstock constitutes at least about 70% by volume of material which boils above about 650° F., and at least about 10% of the material which boils above about 650° F. will not boil below about 1025° F. The average composition of this 650° F.+ material may be further characterized by: (a) an atomic hydrogen to carbon ratio in the range of about 1.3 to about 1.8: (b) a Conradson carbon value of at least about 2; (c) at least about four parts per million of Nickel Equivalents, as defined above, of which at least about two parts per million is nickel (as metal, by weight); and (d) at least one of the following: (i) at least about 0.3% by weight of sulfur, (ii) at least about 0.05% by weight of nitrogen, and (iii) at least about 0.5% by weight of pentane insolubles. Very commonly, the preferred feed will include all of (i), (ii), and (iii), and other components found in oils of petroleum and non-petroleum origin may also be present in varying quantities providing they do not prevent operation of the process. 
     Although there is no intention of excluding the possibility of using a feedstock which has previously been subjected to some cracking, the present invention has the definite advantage that it can successfully product large conversions and very substantial yields of liquid hydrocarbon fuels from carbo-metallic oils which have not been subjected to any substantial amount of cracking. Thus, for example, and preferably, at least about 85%, more preferably at least about 90% and most preferably substantially all of of the carbo-metallic feed introduced into the present process is oil which has not previously been contacted with cracking catalyst under cracking conditions. Moreover, the process of the invention is suitable for operation in a substantially once-through or single pass mode. Thus, the volume of recycle, if any, based on volume of total fresh feed is preferably about 15% or less and more preferably about 10% or less. 
     In general, the weight ratio of catalyst to total fresh feed (feed which has not previously been exposed to cracking catalyst under cracking conditions) used in the process is in the range of about 3 to about 18. Preferred and more preferred ratios are about 4 to about 12, more preferably about 5 to about 10 and still more preferably about 6 to about 10, a ratio of about 10 presently being considered most nearly optimum. Within the limitations of product quality requirements, controlling the catalyst to oil ratio at relatively low levels within the aforesaid ranges tends to reduce the coke yield of the process, based on fresh feed. 
     In conventional FCC processing of VGO, the ratio between the number of barrels per day of plant through-put and the total number of tons of catalyst undergoing circulation throughout all phases of the process can vary widely. For purposes of this disclosure, daily plant through-put is defined as the number of barrels of fresh feed boiling above about 650° F. which that plant processes per average day of operation to liquid products boiling below about 430° F. For example, in one commercially successful type of FCC-VGO operation, about 8 to about 12 tons of catalyst are under circulation in the process per 1000 barrels per day of plant through-put. In another commercially successful process, this ratio is in the range of about 2 to 3. While the present invention may be practiced in the range of about 2 to about 30 and more typically about 2 to about 12 tons of catalyst inventory per 1000 barrels of daily plant through-put, it is preferred to carry out the process of the present invention with a very small ratio of catalyst weight to daily plant through-put. More specifically, it is preferred to carry out the process of the present invention with an inventory of catalyst that is sufficient to contact the feed for the desired residence time in the above indicated catalyst to oil ratio while minimizing the amount of catalyst inventory, relative to plant through-put, which is undergoing circulation or being held for treatment in other phases of the process such as, for example, stripping, regeneration and the like. Thus, more particularly, it is preferred to carry out the process of the present invention with about 2 to about 5 and more preferably about 2 tons of catalyst inventory or less per thousand barrels of daily plant through-put. 
     In the practice of the invention, catalyst may be added continuously or periodically, such as, for example, to make up for normal losses of catalyst from the system. Moreover, catalyst addition may be conducted in conjunction with withdrawal of catalyst, such as, for example, to maintain or increase the average activity level of the catalyst in the unit. For example, the rate at which virgin catalyst is added to the unit may be in the range of about 0.1 to about 3, more preferably about 0.15 to about 2, and most preferably to about 0.2 to about 1.5 pounds per barrel of feed. If on the other hand equilibrium catalyst from FCC operation is to be utilized, replacement rates as high as about 5 pounds per barrel can be practiced. Where circumstances are such that the catalyst employed in the unit is below average in resistance to deactivation and/or conditions prevailing in the unit are such as to promote more rapid deactivation, one may employ rates of addition greater than those stated above; but in the opposite circumstances, lower rates of addition may be employed. By way of illustration, if a unit were operated with a metal(s) loading of 5000 ppm Ni+V in parts by weight on equilibrium catalyst, one might for example employ a replacement rate of about 2.7 pounds of catalyst introduced for each barrel (42 gallons) of feed processed. However, operation at a higher level such as 10,000 pom Ni+V on catalyst would enable one to substantially reduce the replacement rate, such as for example to about 1.3 pounds of catalyst per barrel of feed. Thus, the levels of metal(s) on catalyst and catalyst replacement rates may in general be respectively increased and decreased to any value consistent with the catalyst activity which is available and desired for conducting the process. 
     Without wishing to be bound by any theory, it appears that a number of features of the process to be described in greater detail below, such as, for instance, the residence time and optional mixing of steam with the feedstock, tend to restrict the extent to which cracking conditions produce metals in the reduced state on the catalyst from heavy metal sulfide(s), sulfate(s) or oxide(s) deposited on the catalyst particles by prior exposures to carbo-metallic feedstocks and regeneration conditions. Thus, the process appears to afford significant control over the poisoning effect of heavy metals on the catalyst even when the accumulations of such metals are quite substantial. 
     Accordingly, the process may be practised with catalyst bearing accumulations of heavy metal(s) in the form of elemental metal(s), oxide(s), sulfide(s) or other compounds which heretofore would have been considered quite intolerable in conventional CC-VGO operations. Thus, operation of the process with catalyst bearing heavy metals accumulations in the range of about 1,500 or more ppm Equivalent Nickel, on the average, is contemplated. The concentration of Equivalent Nickel metals on catalyst can range up to about 6,000 ppm. More preferably, the accumulation may be in the range of about 2,500 to about 4,000 ppm, or about 2,800 to about 4,200 ppm. The foregoing ranges are based on parts per million of Equivalent Nickel, in which the metals are expressed as metal, by weight, measured on and based on regenerated equilibrium catalyst. 
     In any event, the equilibrium concentrations of heavy metals in the circulating inventory of catalyst can be controlled (including maintained or varied as desired or needed) by manipulation of the rate of catalyst addition discussed above. Thus, for example, addition of catalyst may be maintained at a rate which will control the heavy metals accumulation on the catalyst in one of the ranges set forth above. Alternatively, the relative quantities of gas oil feed and carbo-metallic oil feed may be varied as well as the catalyst to oil weight ratio employed in the cracking reaction. 
     In general, it is preferred to employ a catalyst having a relatively high level of cracking activity, providing high levels of conversion and productivity at low residence times. The conversion capabilities of the catalyst may be expressed in terms of the conversion produced during actual operation of the process and/or in terms of conversion produced in standard catalyst activity tests. For example, it is preferred to employ catalyst which, in the course of extended operation under prevailing process conditions, is sufficiently active for sustaining a level of conversion of at least about 50% and more preferably at least about 60%. In this connection, conversion is expresscd in liquid volume percent, based on fresh feed. 
     Also, for example, the preferred catalyst may be defined as one which, in its virgin or equilibrium state, exhibits a specified activity expressed as a percentage in terms of MAT (micro-activity test) conversion. For purposes of the present invention the foregoing percentage is the volume percentage of standard feedstock which a catalyst under evaluation will convert to 430° F. end point gasoline, lighter products and coke at 900° F., 16 WHSV (weight hourly space velocity, calculated on a moisture free basis, using clean catalyst which has been dried at 1100° F., weighted and then conditioned, for a period of at least 8 hours at about 25° C. and 50% relative humidity, until about one hour or less prior to contacting the feed) and 3C/O (catalyst to oil weight ratio) by ASTM D-32 MAT test D-3907-80, using an appropriate standard feedstock, e.g. a sweet light primary gas oil, such as that used by Davison, Division of W. R. Grace, having the following analysis and properties: 
     
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API Gravity at 60° F., degrees                                     
                    31.0                                                  
Specific Gravity at 60° F., g/cc                                   
                    0.8708                                                
Ramsbottom Carbon, wt. %                                                  
                    0.09                                                  
Conradson Carbon, wt. % (est.)                                            
                    0.04                                                  
Carbon, wt. %       84.92                                                 
Hydrogen, wt. %     12.94                                                 
Sulfur, wt. %       0.68                                                  
Nitrogen, ppm       305                                                   
Viscosity at 100° F., centistokes                                  
                    10.36                                                 
Watson K Factor     11.93                                                 
Aniline Point       182                                                   
Bromine No.         2.2                                                   
Paraffins, Vol. %   31.7                                                  
Olefins, Vol. %     1.6                                                   
Naphthenes, Vol. %  44.0                                                  
Aromatics, Vol. %   22.7                                                  
Average Molecular Weight                                                  
                    284                                                   
Nickel              Trace                                                 
Vanadium            Trace                                                 
Iron                Trace                                                 
Sodium              Trace                                                 
Chlorides           Trace                                                 
B S &amp; W             Trace                                                 
______________________________________                                    
Distillation        ASTM D-1160                                           
______________________________________                                    
IBP                 445                                                   
10%                 601                                                   
30%                 664                                                   
50%                 701                                                   
70%                 734                                                   
90%                 787                                                   
FBP                 834                                                   
______________________________________                                    
 
    
     The gasoline end point and boiling temperature-volume percent relationships of the product produced in the MAT conversion test may for example be determined by simulated distillation techniques, for example modifications of gas chromate graphic &#34;Sim-D&#34;, ASTM D-2887-73. The results of such simulations are in reasonable agreement with the results obtained by subjecting larger samples of material to standard laboratory distillation techniques. Conversion is calculated by subtracting from 100 the volume percent (based on fresh feed) of those products heavier than gasoline which remain in the recovered product. 
     On page 935-937 of Hougen and Watson, Chemical Process Principles, John Wiley &amp; Sons, Inc., N.Y. (1947), the concent of &#34;Activity Factors&#34; is discussed. This concept leads to the use of &#34;relative activity&#34; to compare the effectiveness of an operating catalyst against a standard catalyst. Relative activity measurements facilitate recognition of how the quantity requirements of various catalysts differ from one another. Thus, relative activity is a ratio obtained by dividing the weight of a standard or reference catalyst which is or would be required to produce a given level of conversion, as compared to the weight of an operating catalyst (whether proposed or actually used) which is or would be required to produce the same level of conversion in the same or equivalent feedstock under the same or equivalent conditions. Said ratio of catalyst weights may be expressed as a numerical ratio, but preferably is converted to a percentage basis. The standard catalyst is preferably chosen from among catalysts useful for conducting the present invention, such as for example zeolite fluid cracking catalysts, and is chosen for its ability to produce a predetermined level of conversion in a standard feed under the conditions of temperature, WHSV, catalyst to oil ratio and other conditions set forth in the preceding description of the MAT conversion test and in ASTM D-32 MAT test D-3907-80. Conversion is the volume percentage of feedstock that is converted to 430° F. endpoint gasoline, lighter products and coke. For standard feed, one may employ the above-mentioned light primary gas oil, or equivalent. 
     For purposes of conducting relative activity determinations, one may prepare a &#34;standard catalyst curve&#34;, a chart or graph of conversion (as above defined) vs. reciprocal WHSV for the standard catalyst and feedstock. A sufficient number of runs is made under ASTM D-3907-80 conditions (as modified above) using standard feedstock at varying levels of WHSV to prepare an accurate &#34;curve&#34; of conversion vs. WHSV for the standard feedstock. This curve should traverse all or substantially all of the various levels of conversion including the range of conversion within which it is expected that the operating catalyst will be tested. From this curve, one may establish a standard WHSV for test comparisons and a standard value of reciprocal WHSV correspoinding to that level of conversion which has been chosen to represcnt 100% relative activity in the standard catalyst. For purposes of the present disclosure the aformentioned reciprocal WHSV and level of conversion are, respectively, 0.0625 and 75%. In testing an operating catalyst of unknown relative activity, one conducts a sufficient number of runs with that catalyst under D-3907-80 conditions (as modified above) to establish the level of conversion which is or would be produced with the operating catalyst at standard reciprocal WHSV. Then, using the above-mentioned standard catalyst curve, one establishes a hypothetical reciprocal WHSV constituting the reciprocal WHSV which would have been required, using the standard catalyst, to obtain the same level of conversion which was or would be exhibited, by the operating catalyst at standard WHSV. The relative activity may then be calculated by dividing the hypothetical reciprocal WHSV by the reciprocal standard WHSV, which is 1/16, or 0.0625. The result is relative activity expressed in terms of a decimal fraction, which may then be multiplied by 100 to convert to percent relative activity. In applying the results of this determination, a relative activity of 0.5, or 50%, means that it would take twice the amount of the operating catalyst to give the same conversion as the standard catalyst, i.e., the production catalyst is 50% as active as the reference catalyst. 
     The catalyst may be introduced into the process in its virgin form or, as previously indicated, in other than virgin form; e.g. one may use equilibrium catalyst withdrawn from another unit, such as catalyst that has been employed in the cracking of a different feed. Whether characterized on the basis of MAT conversion activity or relative activity, the preferred catalysts may be described on the basis of their activity &#34;as introduced&#34; into the process of the present invention, or on the basis of their &#34;as withdrawn&#34; or equilibrium activity in the process of the present invention, or on both of those bases. A preferred activity level of virgin and non-virgin catalyst &#34;as introduced&#34; into the process of the present invention is at least about 60% by MAT conversion, and preferably at least about 20%, more preferably at least about 40% and still more preferably at least about 60% in terms of relative activity. However, it will be appreciated that, particularly in the case of non-virgin catalysts supplied at high addition rates, lower activity levels may be acceptable. An acceptable &#34;as withdrawn&#34; or equilibrium activity level of catalyst which has been used in the process of the present invention is at least about 20% or more, but about 40% or more and preferably about 60% or more are preferred values on a relative activity basis, and an activity level of 60% or more on a MAT conversion basis is also contemplated. More preferably, it is desired to employ a catalyst which will, under the conditions of use in the unit, establish an equilibrium activity at or above the indicated level. The catalyst activities are determined with catalyst having less than 0.01 coke, e.g. regenerated catalyst. 
     One may employ any hydrocarbon cracking catalyst having the above indicated conversion capabilities. A particularly preferred class of catalysts includes those which have pore structures into which molecules of feed material may enter for adsorption and/or for contact with active catalytic sites within or adjacent the pores. Various types of catalysts are available within this classification, including for example the layered silicates, e.g. smectites. Although the most widely available catalysts within this classification are the well-known zeolite-containing catalysts, non-zeolite catalysts are also contemplated. 
     The preferred zeolite-containing catalysts may include any zeolite, whether natural, semi-synthetic or synthetic, alone or in admixture with other materials which do not significantly impair the suitability of the catalyst, provided the resultant catalyst has the activity and pore structure referred to above. For example, if the virgin catalyst is a mixture, it may include the zeolite component associated with or dispersed in a porous refractory inorganic oxide carrier, in such case the catalyst may for example contain about 1% to about 60%, more preferably about 15 to about 50%, and most typically about 20 to about 45% by weight, based on the total weight of catalyst (water free basis) of the zeolite, the balance of the catalyst being the porous refractory inorganic oxide alone or in combination with any of the known adjuvants for promoting or suppressing various desired and undesired reactions. For a general explanation of the genus of zeolite, molecular sieve catalysts useful in the invention, attention is drawn to the disclosures of the articles entitled &#34;Refinery Catalysts Are a Fluid Business&#34; and &#34;Making Cat Crackers Work On Varied Diet&#34;, appearing respectively in the July 26, 1978 and Sept. 13, 1978 issues of Chemical Week magazine. The descriptions of the aforementioned publications are incorporated herein by reference. 
     For the most part, the zeolite components of the zeolite-containing catalysts will be those which are known to be useful in FCC cracking processes. In general, these are crystalline aluminosilicates, typically made up of tetra coordinated aluminum atoms associated through oxygen atoms with adjacent silicon atoms in the crystal structure. However, the term &#34;zeolite&#34; as used in this disclosure contemplates not only aluminosilicates, but also substances in which the aluminum has been partly or wholly replaced, such as for instance by gallium and/or other metal atoms, and further includes substances in which all or part of the silicon has been replaced, such as for instance by germanium. Titanium and zirconium substitution may also be practiced. 
     Most zeolitcs are prepared or occur naturally in the sodium form, so that sodium cations are associated with the electro-negative sites in the crystal structure. The sodium cations tend to make zeolites inactive and much less stable when exposed to hydrocarbon conversion conditions, particularly high temperatures. Accordingly, the zeolite may be ion exchanged, and where the zeolite is a component of a catalyst composition, such ion exchanging may occur before or after incorporation of the zeolite as a component of the composition. Suitable cations for replacement of sodium in the zeolite crystal structure include ammonium (decomposable to hydrogen), hydrogen, rare earth metals, alkaline earth metals, etc. Various suitable ion exchange procedures and cations which may be exchanged into the zeolite crystal structure are well known to those skilled in the art. 
     Examples of the naturally occuring crystalline aluminosilicate zeolites which may be used as or included in the catalyst for the present invention are faujasite, mordenite, clinoptilote, chabazite, analcite, crionite, as well as levynite, dachiardite, paulingite, noselite, ferriorite, heulandite, scolccite, stibite, harmotome, phillipsite, brewsterite, flarite, datolite, melinite, caumnite, leucite, lazurite, scaplite, mesolite, ptolite, nephline, matrolite, offretite and sodalite. 
     Examples of the synthetic crystalline aluminosilicatc zeolites which are useful as or in the catalyst for carrying out the present invention are Zeolite X, U.S. Pat. No. 2,882,244, Zeolite Y, U.S. Pat. No. 3,130,007; and Zeolite A, U.S. Pat. No. 2,882,243; as well as Zeolite B, U.S. Pat. No. 3,008,803; Zeolite D, Canada patent No. 661,981; Zeolite E, Canada patent No. 614,495; Zeolite F, U.S. Pat. No. 2,996,358; Zeolite H. U.S. Pat. No. 3,010,789; Zeolite J., U.S. Pat. No. 3,011,869; Zeolite L, Belgian patent No. 575,177; Zeolite M., U.S. Pat. No. 2,995,423, Zeolite O, U.S. Pat. No. 3,140,252; Zeolite Q, U.S. Pat. No. 2,991,151; Zeolite S, U.S. Pat. No. 3,054,657, Zeolite T, U.S. Pat. No. 2,950,952; Zeolite W, U.S. Pat. No. 3,012,853; Zeolite Z, Canada patent No. 614,495; and Zeolite Omega, Canada patent No. 817,915. Also, ZK-4HJ, alpha beta and ZSM-type zeolites are useful. Moreover, the zeolites described in U.S. Pat. Nos. 3,140,249, 3,140,253, 3,944,482 and 4,137,151 are also useful, the disclosures of said patents being incorporated herein by reference. 
     The crystalline aluminosilicate zeolites having a faujasite-type crystal structure are particularly preferred for use in the present invention. This includes particularly natural faujasite and Zeolite X and Zeolite Y. 
     The crystalline aluminosilicate zeolites, such as synthetic faujasite, will under normal conditions crystallize as regularly shaped, discrete particles of about one to about ten microns in size, and, accordingly, this is the size range frequently found in commercial catalysts which can be used in the invention. Preferably, the particle size of the zeolites is from about 0.1 to about 10 microns and more preferably is from about 0.1 to about 2 microns or less. For example, zeolites prepared in situ from calcined kaolin may be characterized by even smaller crystallites. Crystalline zeolites exhibit both an interior and an exterior surface area, which we have defined as &#34;portal&#34; surface area, with the largest portion of the total surface area being internal. By portal surface area, we refer to the outer surface of the zeolite crystal through which reactants are considered to pass in order to convert to lower boiling products. Blockages of the internal channels by, for example, coke formation, blockages of entrance to the internal channels by deposition of coke in the portal surface area, and contamination by metals poisoning, will greatly reduce the total zeolite surface area. Therefore, to minimize the effect of contamination and pore blockage, crystals larger than the normal size cited above are preferably not used in the catalysts of this invention. 
     Commercial zeolite-containing catalysts are available with carriers containing a variety of metal oxides and combination thereof, including for example silica, alumina, magnesia, and mixtures thereof and mixtures of such oxides with clays as e.g. described in U.S. Pat. No. 3,034,948. One may for example select any of the zeolite-containing molecular sieve fluid cracking catalysts which are suitable for production of gasoline from vacuum gas oils. However, certain advantages may be attained by judicious selection of catalysts having marked resistance to metals. A metal resistant zeolite catalyst is, for instance, described in U.S. Pat. No. 3,944,482, in which the catalyst contains 1-40 weight percent of a rare earth-exchanged zeolite, the balance being a refractory metal oxide having specified pore volume and size distribution. Other catalysts described as &#34;metals-tolerant&#34; are described in the above mentioned Cimbalo et al article. 
     In general, it is preferred to employ catalysts having an over-all particle size in the range of about 5 to about 160, more preferably about 40 to about 120, and most preferably about 40 to about 80 microns. For example, a useful catalyst may have a skeletal density of about 150 pounds per cubic foot and an average particle size of about 60-70 microns, with less than 10% of the partlcles having a size less than about 40 microns and less than 80% having a size less than about 50-60 microns. 
     Although a wide variety of other catalysts, including both zeolite-containing and non-zeolite-containing may be employed in the practice of the invention the following are examples of commercially available catalysts which may be employed in practicing the invention: 
     
                       TABLE 2                                                     
______________________________________                                    
          Weight Percent                                                  
Speci-      Zeo-                                                          
fic         lite                                                          
Surface     Con-                                                          
m.sup.2 /g  tent   Al.sub.2 O.sub.3                                       
                           SiO.sub.2                                      
                                Na.sub.2 O                                
                                      Fe.sub.2 O                          
                                            TiO.sub.2                     
______________________________________                                    
AGZ-290 300     11.0   29.5  59.0 0.40  0.11   0.59                       
GRZ-1   162     14.0   23.4  69.0 0.10  0.4   0.9                         
CCZ-220 129     11.0   34.6  60.0 0.60  0.57  1.9                         
Super DX                                                                  
        155     13.0   31.0  65.0 0.80  0.57  1.6                         
F-87    240     10.0   44.0  50.0 0.80  0.70  1.6                         
FOX-90  240      8.0   44.0  52.0 0.65  0.65  1.1                         
HFZ 20  310     20.0   59.0  40.0 0.47  0.54   2.75                       
HEZ 55  210     19.0   59.0  35.2 0.60  0.60  2.5                         
______________________________________                                    
 
    
     The AGZ-290, GRZ-1, CCZ-220 and Super DX catalysts referred to above are products of W. R. Grace and Co. F-87 and FOC-90 are products of Filtrol, while HFZ-20 and HEZ-55 are products of Engelhard/Houdry. The above are properties of virgin catalyst and, except in the case of zeolite content, are adjusted to a water free basis, i.e. based on material ignited at 1750° F. The zeolite content is derived by comparison of the X-ray intensities of a catalyst sample and of a standard material composed of high purity sodium Y zeolite in accordance with draft #6, dated Jan. 9, 1978, of proposed ASTM Standard Method entitled &#34;Determination tion of the Faujasite Content of a Catalyst.&#34; 
     Among the above mentioncd commercially available catalysts, the Supcr D family and especially a catalyst designated GRZ-1 are particularly preferred. For example, Super DX has given particularly good results with Arabian light crude. The GRZ-1, although substantially more expensive than the Super DX at present, appears somewhat more metalstolerant. 
     Although not yet commercially available, it is believed that the best catalysts for carrying out the present invention will be those which, according to proposals advanced by Dr. William P. Hettinger, Jr. and Dr. James E. Lewis, are characterized by matrices with feeder pores having large minimum diameters and large mouths to facilitate diffusion of high molecular weight molecules through the matrix to the portal surface area of molecular sieve particles within the matrix. Such matrices preferably also have a relatively large pore volume in order to soak up unvaporized portions of the carbo-metallic oil feed. Thus significant numbers of liquid hydrocarbon molecules can diffuse to active catalytic sites both in the matrix and in sieve particles on the surface of the matrix. In general it is preferred to employ catalysts with matrices wherein the feeder pores have diameters in the range of about 400 to about 6000 angstrom units, and preferably about 1000 to about 6000 angstrom units. 
     It is considered an advantage that the process of the present invention can be conducted in the substantial absence of tin and/or antimony or at least in the presence of a catalyst which is substantially free of either or both of these metals. 
     Accordingly to a particularly preferred embodiment, the catalyst comprises a Vanadium trap as disclosed in a U.S. Pat. No. 4,485,184 entitled &#34;Trapping of Metals Deposited on Catalytic Materials During Carbo-Metallic Oil Conversion&#34;, filed in the U.S. Patent and Trademark Office on Apr. 10, 1981 in the names of William P. Hettinger Jr., et al, the entire disclosure of which is hereby incorporated by reference. It is also preferred to employ catalysts having metal additives as described in PCT International Application Serial No. PCT/US81/00356, filed in the U.S. Receiving Office on Mar. 19, 1981 in the names of Ashland Oil, Inc., et al, entitled &#34;Immobilization of Vanadia Deposited on Catalytic Materials During Carbo-Metallic Oil Conversion&#34;, and as described in corresponding U.S. National applications, the entire disclosures of which are hereby incorporated by reference. 
     The process of the present invention may be operated with the gas oil feed, carbo-metallic oil feed and catalyst as substantially the sole materials charged to the reaction zone. But the charging of additional materials is not excluded. The charging of recycled oil to the reaction zone has already been mentioned. As described in greater detail below, still other materials fulfilling a variety of functions may also be charged. In such case, gas oil, carbo-metallic oil and catalyst usually represent the major proportion by weight of the total of all materials charged to the reaction zone. 
     Certain of the additional materials which may be used perform functions which offer significant advantages over the process as performed with only gas oil, carbo-metallic oil and catalyst. Among these functions are: controlling the effects of heavy metals and other catalyst contaminants; enhancing catalyst activity; absorbing excess heat in the catalyst as received from the regenerator; disposal of pollutants or conversion thereof to a form or forms in which they may be more readily separated from products and/or disposed of; controlling catalyst temperature; diluting gas oil and carbo-metallic oil vapors to reduce their partial pressure and increase the yield of desired products; adjusting feed/catalyst contact time; donation of hydrogen to a hydrogen deficient carbo-metallic oil feedstock, for example as disclosed in a U.S. paten application Ser. No. 246,791, now U.S. Pat. No. 4,376,038, entitled &#34;Use of Naphtha in Carbo-Metallic Oil Conversion&#34; and filed in the name of George D. Myers on Mar. 23, 1981; assisting in the dispersion of the feed; and possibly also distillation of products. Certain of the metals in the heavy metals accumulation on the catalyst are more active in promoting undesired reactions when they are in the form of elemental metal, than they are when in the oxidized form produced by contact with oxygen in the catalyst regenerator. However, the time of contact between catalyst and vapors of feed and product in past conventional catalytic cracking was sufficient so that hydrogen released in the cracking reaction was able to reconvert a significant portion of the less harmful oxides back to the more harmful elemental heavy metals. One can take advantage of this situation through the introduction of additional materials which are in gaseous (including vaporous) form in the reaction zone in admixture with the catalyst and vapors of feed and products. The increased volume of material in the reaction zone resulting from the presence of such additional materials tends to increase the velocity of flow through the reaction zone with a corresponding decrease in the residence time of the catalyst and oxidized heavy metals borne thereby. Because of this reduced residence time, there is less opportunity for reduction of the oxidized heavy metals to elemental form and therefore less of the harmful elemental metals are available for contacting the feed and products. 
     Added materials may be introduced into the process in any suitable fashion, some examples of which follow. For instance, they may be admixed with the oil feedstock prior to contact of the latter with the catalyst. Alternatively, the added materials may, if desired, be admixed with the catalyst prior to contact of the latter with the feedstock. Separate portions of the added materials may be separately admixed with both catalyst and feed material. Moreover, the feedstock, catalyst and additional materials may, if desired, be brought together substantially simultaneously. A portion of the added materials may be mixed with catalyst and/or feed material in any of the above described ways, while additional portions are subsequently brought into admixture. For example, a portion of the added materials may be added to the feed material and/or to the catalyst before they reach the reaction zone, while another portion of the added materials is introduced directly into the reaction zone. The added materials may be introduced at a plurality of spaced locations in the reaction zone or along the length thereof, if elongated. 
     The amount of additional materials which may be present in the feed, catalyst or reaction zone for carrying out the above functions, and others, may be varied as desired; but said amount will preferably be sufficient to substantially heat balance the process. These materials may for example be introduced into the reaction zone in a weight ratio relative to feed of up to about 0.4, preferably in the range of about 0.02 to about 0.4, more preferably about 0.03 to about 0.3 and most preferably about 0.05 to about 0.25. 
     For example, many or all of the above desirable functions may be attained by introducing H 2  O to the reaction zone in the form of steam or of liquid water or a combination thereof in a weight ratio relative to feed in the range of about 0.04 or more, or more preferably about 0.05 to about 0.1 or more. Without wishing to be bound by any theory, it appears that the use of H 2  O tends to inhibit reduction of catalyst-borne oxides, sulfites and sulfides to the free metallic form which is believed to promote condensation-dehydrogenation with consequent promotion of coke and hydrogen yield and accompanying loss of product. Moreover, H 2  O may also, to some extent, reduce deposition of metals onto the catalyst surface. There may also be some tendency to desorb nitrogen-containing and other heavy contaminant-containing molecules from the surface of the catalyst particles, or at least some tendency to inhibit their absorption by the catalyst. It is also believed that added H 2  O tends to increase the acidity of the catalyst by Bronsted acid formation which in turn enhances the activity of the catalyst. Assuming the H 2  O as supplied is cooler than the regenerated catalyst and/or the temperature of the reaction zone, the sensible heat involved in raising the temperature of the H 2  O upon contacting the catalyst in the reaction zone or elsewhere can absorb excess heat from the catalyst. Where the H 2  O is or includes recycled water that contains for example about 500 to about 5000 ppm of H 2  S dissolved therein, a number of additional advantages may accrue. The ecologically unattractive H 2  S need not be vented to the atmosphere, the recycled water does not require further treatment to remove H 2  S and the H 2  S may be of assistance in reducing coking of the catalyst by passivation of the heavy metals, i.e. by conversion thereof to the sulfide form which has a lesser tendency than the free metals to enhance coke and hydrogen production. In the reaction zone, the presence of H 2  O can dilute the carbo-metallic oil vapors, thus reducing their partial pressure and tending to increase the yield of the desired products. It has been reported that H 2  O is useful in combination with other materials in generating hydrogen during cracking; thus it may be able to act as a hydrogen donor for hydrogen deficient carbo-metallic oil feedstocks. The H 2  O may also serve certain purely mechanical functions such as: assisting in the atomizing or dispersion of the feed; competing with high molecular weight molecules for adsorption on the surface of the catalyst, thus interrupting coke formation; steam distillation of vaporizable product from unvaporized feed material; and disengagement of product from catalyst upon conclusion of the cracking reaction. It is particularly preferred to bring together H 2  O, catalyst and feed material substantially simultaneously. For example, one may admix H 2  O and feedstock in an atomizing nozzle and immediately direct the resultant spray into contact with the catalyst at the downstream end of the reaction zone. 
     The addition of steam to the reaction zone is frequently mentioned in the literature of fluid catalytic cracking. Addition of liquid water to the feed is discussed relatively infrequently, compared to the introduction of steam directly into the reaction zone. However, in accordance with the present invention it is particularly preferred that liquid water be brought into intimate admixture with the feed material in a weight ratio of about 0.04 to about 0.25 at or prior to the time of introduction of the oil into the reaction zone, whereby the water (e.g., in the form of liquid water or in the form of steam produced by vaporization of liquid water in contact with the oil) enters the reaction zone as part of the flow of feedstock which enters such zone. Although not wishing to be bound by any theory, it is believed that the foregoing is advantageous in promoting dispersion of the feedstock. Also, the heat of vaporization of the water, which heat is absorbed from the catalyst, from the feedstock, or from both, causes the water to be a more efficient heat sink than steam alone. Preferably the weight ratio of liquid water to feed is about 0.04 to about 0.2 more preferably about 0.05 to about 0.15. 
     Of course, the liquid water may be introduced into the process in the above described manner or in other ways, and in either event the introduction of liquid water may be accompanied by the introduction of additional amounts of water as steam into the same or different portions of the reaction zone or into the catalyst and/or feedstock. For example, the amount of additional steam may be in a weight ratio relative to feed in the range of about 0.01 to about 0.25, with the weight ratio of total H 2  O (as steam and liquid water) to feedstock being about 0.3 or less. The charging weight ratio of liquid water relative to steam in such combined use of liquid water and steam may for example range from about 15 which is presently preferred, to about 0.2. Such ratio may be maintained at a predetermined level within such range or varied as necessary or desired to adjust or maintain heat balance. 
     Other materials may be added to the reaction zone to perform one or more of the above described functions. For example, the dehydrogenation-condensation activity of heavy metals may be inhibited by introducing hydrogen sulfide gas into the reaction zone. Hydrogen may be made available for hydrogen deficient carbo-metallic oil feedstocks by introducing into the reaction zone either a conventional hydrogen donor diluent such as a heavy naphtha or relatively low molecular weight carbon-hydrogen fragment contributors, including for example: light paraffins; low molecular weight alcohols and other compounds which permit or favor intermolecular hydrogen transfer; and compounds that chemically combine to generate hydrogen in the reaction zone such as by reaction of carbon monoxide with water, or with alcohols, or with olefins, or with other materials or mixtures of the foregoing. 
     All of the above mentioned additional materials (including water), alone or in conjunction with each other or in conjunction with other materials, such as nitrogen or other inert gases, light hydrocarbons, and others, may perform any of the above-described functions for which they are suitable, including without limitation, acting as diluents to reduce feed partial pressure and/or as heat sinks to absorb excess heat present in the catalyst as received from the regeneration step. The foregoing is a discussion of some of the functions which can be performed by materials other than the gatalyst and feedstock when they are introduced into the reaction zone, and it should be understood that other materials may be added or other functions performed without departing from the spirit of the invention. 
     The invention may be practiced in a wide variety of apparatus. However, the preferred apparatus includes means for rapidly vaporizing as much feed as possible and efficiently admixing feed and catalyst (although not necessarily in that order), for causing the resultant mixture to flow as a dilute suspension in a progressive flow mode, and for separating the catalyst from cracked products and any uncracked or only partially cracked feed at the end of a predetermined residence time or times, it being preferred that all or at least a substantial portion of the product should be abruptly separated from at least a portion of the catalyst. 
     For example, the apparatus may include, along its elongated reaction chamber, one or more points for introduction of carbo-metallic feed, one or more points for introduction of catalyst, one or more points for introduction of additional material, one or more points for withdrawal of products and one or more points for withdrawal of catalyst. The means for introducing feed, catalyst and other material may range from open pipes to sophisticated jets or spray nozzles, it being preferred to use means capable of breaking up the liquid feed into fine droplets. According to a particularly preferred embodiment based on a suggestion which is understood to have emanated from Mr. Steven M. Kovach, the liquid water and carbo-metallic oil, prior to their introduction into the riser, are caused to pass through a propeller, apertured disc, or any appropriate high shear agitating means for forming a &#34;homogenized mixture&#34; containing finely divided droplets of oil and/or water with oil and/or water present as a continuous phase. 
     It is preferred that the reaction chamber, or at least the major portion thereof, be more nearly vertical than horizontal and have a length to diameter ratio of at least about 10, more preferably about 20 or 25 or more. Use of a vertical riser type reactor is preferred. If tubular, the reactor can be of uniform diameter throughout or may be provided with a continuous or step-wise increase in diametcr along the reaction path to maintain or vary the velocity along the flow path. 
     In general, the charging means (for catalyst and feed) and the reactor configuration are such as to provide a relatively high velocity of flow and dilute suspension of catalyst. For example, the vapor or catalyst velocity in the riser will be usually at least about 25 and more typically at least about 35 feet per second. This velocity may range up to about 55 or about 75 feet or about 100 feet per second or higher. The vapor velocity at the top of the reactor may be higher than that at the bottom and may for example be about 80 feet per second at the top and about 40 feet per second at the bottom. The velocity capabilities of the reactor will in general be sufficient to prevent substantial build-up of catalyst bed in the bottom or other portions of the riser, whereby the catalyst loading in the riser can be maintained below about 4 or 5 pounds, as for example about 0.5 pounds, and below about 2 pounds, as for example 0.8 pound, per cubic foot, respectively, at the upstream (e.g. bottom) and downstream (e.g. top) ends of the riser. 
     The progressive flow mode involves, for example, flowing of catalyst, feed and products as a stream in a positively controlled and maintained direction established by the elongated nature of the reaction zone. This is not to suggest however that there must be strictly linear flow. As is well known, turbulent flow and &#34;slippage&#34; of catalyst may occur to some extent especially in certain ranges of vapor velocity and some catalyst loadings, although it has been reported adviseable to employ sufficiently low catalyst loadings to restrict slippage and back-mixing. 
     Most preferably the reactor is one which abruptly separates a substantial portion or all of the vaporized cracked products from the catalyst at one or more points along the riser, and preferably separates substantially all of the vaporized cracked products from the catalyst at the downstream end of the riser. A preferred type of reactor embodies ballistic separation of catalyst and products; that is, catalyst is projected in a direction established by the riser tube, and is caused to continue its motion in the general direction so established, while the products, having lesser momentum, are caused to make an abrupt change of direction, resulting in an abrupt, substantially instantaneous separation of product from catalyst. In a preferred embodiment referred to as a vented riser, the riser tube is provided with a substantially unobstructed discharge opening at its downstream end for discharge of catalyst. An exit port in the side of the tube adjacent the downstream end receives the products. The discharge opening communicates with a catalyst flow path which extends to the usual stripper and regenerator, while the exit port communicates with a product flow path which is substantially or entirely separated from the catalyst flow path and leads to separation means for separating the products from the relatively small portion of catalyst, if any, which manages to gain entry to the product exit port. Examples of a ballistic separation apparatus and technique as above described, are found in U.S. Pat. Nos. 4,066,533 and 4,070,159 to Myers et al, the disclosures of which patents are hereby incorporated herein by reference in their entireties. According to a particularly preferred embodiment, based on a suggestion understood to have emanated from Paul W. Walters, Roger M. Benslay and Dwight F. Barger, the ballistic separation step includes at least a partial reversal of direction by the product vapors upon discharge from the riser tube; that is, the product vapors make a turn or change of direction which exceeds 90° at the riser tube outlet. This may be accomplished for example by providing a cup-like member surrounding the riser tube at its upper end, the ratio of cross-sectional area of the cup-like member relative to the cross-sectional area of the riser tube outlet being low e.g. less than 1 and preferably less than about 0.6. Preferably the lip of the cup is slightly downstream of, or above the downstream end or top of the riser tube, and the cup is preferably concentric with the riser tube. By means of a product vapor line communicating with the interior of the cup but not the interior of the riser tube, having its inlet positioned within the cup interior in a direction upstream of the riser tube outlet, product vapors emanating from the riser tube and entering the cup by reversal of direction are transported away from the cup to catalyst and product separation equipment. Such an arrangement can produce a high degree of completion of the separation of catalyst from product vapors at the riser tube outlet, so that the required amount of auxiliary catalyst separation equipment such as cyclones is greatly reduced, with consequent large savings in capital investment and operating cost. 
     Preferred conditions for operation of the process are described below. Among these are feed, catalyst and reaction temperatures, reaction and feed pressures, residence time and levels of conversion, coke production and coke laydown on catalyst. 
     In conventional FCC operations with VGO, the feedstock is customarily preheated, often to temperatures significantly higher than are required to make the feed sufficiently fluid for pumping and for introduction into the reactor. For example, preheat temperatures as high as about 700° or 800° F. have been reported. But in our process as presently practiced it is preferred to restrict preheating of the feed, so that the feed is capable of absorbing a larger amount of heat from the catalyst while the catalyst raises the feed to conversion temperature, at the same time minimizing utilization of external fuels to heat the feedstock. Thus, where the nature of the feedstock permits, it may be fed at ambient temperature. Heavier stocks may be fed at preheat temperatures of up to about 600° F., typically about 200° F. to about 500° F., but higher preheat temperatures are not necessarily excluded. 
     The catalyst fed to the reactor may vary widely in temperature, for example from about 1100° to about 1600° F., more preferably about 1200° to about 1500° F. and most preferably about 1300° to about 1400° F., with about 325° to about 1375° being considered optimum at present. 
     As indicated previously, the conversion of the charge stock to lower molecular weight products may be conducted at a temperature of about 900° to about 400° F., measured at the reaction chamber outlet. The reaction temperature as measured at said outlet is more preferably maintained in the range of about 965° to about 1300° F., still more preferably about 975° to about 200° F., and most preferably about 980° to about 1150° F. Depending upon the temperature selected and the properties of the feed, all of the feed may or may not vaporize in the riser. 
     Although the pressure in the reactor may, as indicated above, range from about 10 to about 50 psia, preferred and more preferred pressure ranges are about 15 to about 35 and about 20 to about 35. In general, the partial (or total) pressure of the feed may be in the range of about 3 to about 30, more preferably about 7 to about 25 and most preferably about 10 to about 17 psia. The feed partial pressure may be controlled or suppressed by the introduction of gaseous (including vaporous) materials into the reactor, such as for instance the steam, water and other additional materials described above. The process has for example been operated with the ratio of feed partial pressure relative to total pressure in the riser in the range of about 0.2 to about 0.8, more typically about 0.3 to about 0.7 and still more typically about 0.4 to about 0.6, with the ratio of added gaseous material (which may include recycled gases and/or steam resulting from introduction of H 2  O to the riser in the form of steam and/or liquid water) relative to total pressure in the riser correspondingly ranging from about 0.8 to about 0.2, more typically about 0.7 to about 0.3 and still more typically about 0.6 to about 0.4. In the illustrative operations just described, the ratio of the partial pressure of the added gaseous material relative to the partial pressure of the feed has been in the range of about 0.25 to about 4.0, more typically about 0.4 to about 2.3 and still more typically about 0.7 to about 1.7. 
     Although the residence time of feed and product vapors in the riser may be in the range of about 0.5 to about 10 seconds, as described above, preferred and more preferred values are about 0.5 to about 6 and about 1 to about 4 seconds, with about 1.5 to about 3.0 seconds currently being considered about optimum. For example, the process has been operated with a riser vapor residence time of about 2.5 seconds or less by introduction of copious amounts of gaseous materials into the riser, such amounts being sufficient to provide for example a partial pressure ratio of added gaseous materials relative to hydrocarbon feed of about 0.8 or more. By way of further illustration, the process has been operated with said residence time being about two seconds or less, with the aforesaid ratio being in the range of about 1 to about 2. The combination of low feed partial pressure, very low residence time and ballistic separation of products from catalyst are considered especially beneficial for the conversion of carbo-metallic oils. Additional benefits may be obtained in the foregoing combination when there is a substantial partial pressure of added gaseous material, especially H 2  O as described above. 
     Depending upon whether there is slippage between the catalyst and hydrocarbon vapors in the riser, the catalyst riser residence time may or may not be the same as that of the vapors. Thus, the ratio of average catalyst reactor residence time versus vapor reactor residence time, i.e. slippage, may be in the range of about 1 to about 5, more preferably about 1 to about 4 and most preferably about 1 to about 3, with about 1 to about 2 currently being considered optimum. 
     In practice, there will usually be a small amount of slippage, e.g., at least about 1.05 or 1.2. In an operating unit there may for example be a slippage of about 1.1 at the bottom of the riser and about 1.05 at the top. 
     In certain types of known FCC units, there is a riser which discharges catalyst and product vapors together into an enlarged chamber, usually considered to be part of the reactor, in which the catalyst is disengaged from product and collected. Continued contact of catalyst, uncracked feed (if any) and cracked products in such enlarged chamber results in an overall catalyst feed contact time appreciably exceeding the riser tube residence times of the vapors and catalysts. When practicing the process of the present invention with ballistic separation of catalyst and vapors at the downstream (e.g. upper) extremity of the riser, such as is taught in the above mentioned Myers et al patents, the riser residence time and the catalyst contact time are substantially the same for a major portion of the feed and product vapors. It is considered advantageous if the vapor riser residence time and vapor catalyst contact time are substantially the same for at least about 80%, more preferably at least about 90% and most preferably at least about 95% by volume of the total feed and product vapors passing through the riser. By denying such vapors continucd contact with catalyst in a catalyst disengagement and collection chamber one may avoid a tendency toward re-cracking and diminished selectivity. 
     In general, the combination of catalyst to oil ratio, temperatures, pressures and residence times should be such as to effect a substantial conversion of the mixture of feedstocks. It is an advantage of the process that very high levels of conversion can be attained in a single pass; for example the conversion may be in excess of 50% and may range to about 90% or higher. Preferably, the aforementioned conditions are maintained at levels sufficient to maintain conversion levels in the range of about 60 to about 90% and more preferably about 70 to about 85%. The foregoing conversion levels are calculated by subtracting from 100% the percentage obtained by dividing the liquid volume of fresh feed into 100 times the volume of liquid product boiling at and above 430° F. (tbp, standard atmospheric pressure). 
     These substantial levels of conversion may and usually do result in relatively large yields of coke, such as for example about 4 to about 14% by weight based on fresh feed, more commonly about 6 to about 13% and most frequently about 10 to about 13%. The coke yield can more or less quantitatively deposit upon the catalyst. At contemplated catalyst to oil ratios, the resultant coke laydown may be in excess of about 0.3, more commonly in excess of about 0.5 and very frequently in excess of about 1% of coke by weight, based on the weight of moisture free regenerated catalyst. Such coke laydown may range as high as about 2%, or about 3%, or even higher. 
     In common with conventional FCC operations on VGO, the present process includes stripping of spent catalyst after disengagement of the catalyst from product vapors. Persons skilled in the art are acquainted with appropriate stripping agents and conditions for stripping spent catalyst, but in some cases the present process may require somewhat more severe conditions than are commonly employed. This may result, for example, from the use of a carbo-metallic oil having constituents which do not volatilize under the conditions prevailing in the reactor, which constituents deposit themselves at least in part on the catalyst. Such adsorbed, unvaporized material can be troublesome from at least two standpoints. First, if the gases (including vapors) used to strip the catalyst can gain admission to a catalyst disengagement or collection chamber connected to the downstream end of the riser, and if there is an accumulation of catalyst in such chamber, vaporization of these unvaporized hydrocarbons in the stripper can be followed by adsorption on the bed of catalyst in the chamber. More particularly, as the catalyst in the stripper is stripped of adsorbed feed material, the resultant feed material vapors pass through the bed of catalyst accumulated in the catalyst collection and/or disengagement chamber and may deposit coke and/or condensed material on the catalyst in said bed. As the catalyst bearing such deposits moves from the bed and into the stripper and from thence to the regenerator, the condensed products can create a demand for more stripping capacity, while the coke can tend to increase regeneration temperatures and/or demand greater regeneration capacity. For the foregoing reasons, it is preferred to prevent or restrict contact between stripping vapors and catalyst accumulations in the catalyst disengagement or collection chamber. This may be done for example by preventing such accumulations from forming, e.g. with the exception of a quantity of catalyst which essentially drops out of circulation and may remain at the bottom of the disengagement and/or collection chamber, the catalyst that is in circulation may be removed from said chamber promptly upon settling to the bottom of the chamber. Also, to minimize regeneration temperatures and demand for regeneration capacity, it may be desirable to employ conditions of time, temperature and atmosphere in the stripper which are sufficient to reduce potentially volatile hydrocarbon material borne by the stripped catalyst to about 10% or less by weight of the total carbon loading on the catalyst. Such stripping may for example include reheating of the catalyst, extensive stripping with steam, the use of gases having a temperature considered higher than normal for FCC/VGO operations, such as for instance flue gas from the regenerator, as well as other refinery stream gases such as hydrotreater off-gas (H 2  S containing), hydrogen and others. For example, the stripper may be operated at a temperature of about 350° F. using steam at a pressure of about 150 psig and a weight ratio of steam to catalyst of about 0.002 to about 0.003. On the other hand, the stripper may be operated at a temperature of about 1025° F. or higher. 
     Substantial conversion of carbo-metallic oils to lighter products in accordance with the invention tends to produce sufficiently large coke yields and coke laydown on catalyst to require some care in catalyst regeneration. In order to maintain adequate activity in zeolite and non-zeolite catalysts, it is desirable to regenerate the catalyst under conditions of time, temperature and atmosphere sufficient to reduce the percent by weight of carbon remaining on the catalyst to about 0.25% or less, whether the catalyst bears a large heavy metals accumulation or not. Preferably this weight percentage is about 0.1% or less and more preferably about 0.05% or less, especially with zeolite catalysts. The amounts of coke which must therefore be burned off of the catalysts when processing carbo-metallic oils are usually substantially greater than would be the case when cracking VGO. The term coke when used to describe the present invention, should be understood to include any residual unvaporized feed or cracking product, if any such material is present on the catalyst after stripping. 
     Regeneration of catalyst, burning away of coke deposited on the catalyst during the conversion of the feed, may be performed at any suitable temperature in the range of about 1100° to about 1600° F., measured at the regenerator catalyst outlet. This temperature is preferably in the range of about 1200° to about 1500° F., more preferably about 1275° to about 1425° F. and optimally about 1325° to about 1375° F. The process has been operated, for example, with a fluidized regenerator with the temperature of the catalyst dense phase in the range of about 1300° to about 1400° F. 
     In accordance with the invention, regeneration may be done while maintaining the catalyst in one or more fluidized beds in one or more fluidization chambers. Such fluidized bed operations are characterized, for instance, by one or more fluidized dense beds of ebulliating particles having a bed density of, for example, about 25 to about 50 pounds per cubic foot. Fluidization is maintained by passing gases, including combustion supporting gases, through the bed at a sufficient velocity to maintain the particles in a fluidized state but at a velocity which is sufficiently small to prevent substantial entrainment of particles in the gases. For example, the lineal velocity of the fluidizing gases may be in the range of about 0.2 to about 4 feet per second and preferably about 0.2 to about 3 feet per second. The average total residence time of the particles in the one or more beds is substantial, ranging for example from about 5 to about 30, more preferably about 5 to about 20 and still more preferably about 5 to about 10 minutes. From the foregoing, it may be readily seen that the fluidized bed regeneration of the present invention is readily distinguishable from the short-contact, low-density entrainment type regeneration which has been practiced in some FCC operations. 
     When regenerating catalyst to very low levels of carbon on regenerated catalyst, e.g. about 0.1% or less or about 0.05% or less, based on the weight of regenerated catalyst, it is acceptable to burn off at least about the last 10% or at least about the last 5% by weight of coke (based on the total weight of coke on the catalyst immediately prior to regeneration) in contact with combustion producing gases containing excess oxygen. In this connection it is contemplated that some selected portion of the coke, ranging from all of the coke down to about the last 5 or 10% by weight, can be burned with excess oxygen. By excess oxygen is meant an amount in excess of the stoichiometric requirement for burning all of the hydrogen, all of the carbon and all of the other combustible components, if any, which are present in the abovementioned selected portion of the coke immeidately prior to regeneration. The gaseous products of combustion conducted in the presence of excess oxygen will normally include an appreciable amount of free oxygen. Such free oxygen, unless removed from the by-product gases or converted to some other form by a means or process other than regeneration, will normally manifest itself as free oxygen in the flue gas from the regenerator unit. In order to provide sufficient driving force to complete the combustion of the coke with excess oxygen, the amount of free oxygen will normally be not merely appreciable but substantial, i.e. there will be a concentration of at least about 2 mole percent of free oxygen in the total regeneration flue gas recovered from the entire, completed regeneration operation. While such technique is effective in attaining the desired low levels of carbon on regenerated catalyst, it has its limitations and difficulties as will become apparent from the discussion below. 
     Heat released by combustion of coke in the regenerator is absorbed by the catalyst and can be readily retained thereby until the regenerated catalyst is brought into contact with fresh feed. When processing carbo-metallic oils to the relatively high levels of conversion involved in the present invention, the amount of regenerator heat which is transmitted to fresh feed by way of recycling regenerated catalyst can substantially exceed the level of heat input which is appropriate in the riser for heating and vaporizing the feed and other materials, for supplying the endothermic heat of reaction for cracking, for making up the heat losses of the unit and so forth. Thus, in accordance with the invention, the amount of regenerator heat transmitted to fresh feed may be controlled, or restricted where necessary, within certain approximate ranges. The amount of heat so transmitted may for example be in the range of about 500 to about 1200, more particularly about 600 to about 900, and more particularly about 650 to about 850 BTUs per pound of fresh feed. The aforesaid ranges refer to the combined heat, in BTUs per pound of fresh feed, which is transmitted by the catalyst to the feed and reaction products (between the contacting of feed with catalyst and the separation of product from catalyst) for supplying the heat of reaction (e.g. for cracking) and the difference in enthalpy between the products and the fresh feed. Not included in the foregoing are the heat made available in the reactor by the adsorption of coke on the catalyst, nor the heat consumed by heating, vaporizing or reacting recycle streams and such added materials as water, steam naphtha and other hydrogen donors, flue gases and inert gases, or by radiation and other losses. 
     One or a combination of techniques may be utilized in this invention for controlling or restricting the amount of regeneration heat transmitted via catalyst to fresh feed. For example, one may add a combustion modifier to the cracking catalyst in order to reduce the temperature of combustion of coke to carbon dioxide and/or carbon monoxide in the regenerator. Moreover, one may remove heat from the catalyst through heat exchange means, including for example heat exchangers (e.g. steam coils) built into the regenerator itself, whereby one may extract heat from the catalyst during regeneration. Heat exchangers can be built into catalyst transfer lines, such as for instance the catalyst return line from the regenerator to the reactor, whereby heat may be removed from the catalyst after it is regenerated. The amount of heat imparted to the catalyst in the regenerator may be restricted by reducing the amount of insulation on the regenerator to permit some heat loss to the surrounding atmosphere, especially if feeds of exceedingly high coking potential are planned for processing; in general, such loss of heat to the atmosphere is considered economically less desirable than certain of the other alternatives set forth herein. One may also inject cooling fluids into portions of the regenerator other than those occupied by the dense bed, for example water and/or steam, whereby the amount of inert gas available in the regenerator for heat absorption and removal is increased. 
     Another suitable and preferred technique for controlling or restricting the heat transmitted to fresh feed via recycled regenerated catalyst involves maintaining a specified ratio between the carbon dioxide and carbon monoxide formed in the regenerator while such gases are in heat exchange contact or relationship with catalyst undergoing regeneration. In gencral, all or a major portion by weight of the coke present on the catalyst immediately prior to regeneration is removed in at least one combustion zone in which the aforesaid ratio is controlled as described below. More particularly, at least the major portion more preferably at least about 65% and more preferably at least about 80% by weight of the coke on the catalyst is removed in a combustion zone in which the molar ratio of CO 2  to CO is maintained at a level substantially below 5, e.g. about 4 or less. Looking at the CO 2  /CO relationship from the inverse standpoint, it is preferred that the CO/CO 2  molar ratio should be at least about 0.25 and preferably at least about 0.3 and still more preferably about 1 or more or even 1.5 or more. While persons skilled in the art are aware of techniques for inhibiting the burning of CO to CO 2 , it has been suggested that the mole ratio of CO:CO 2  should be kept less than 0.2 when regenerating catalyst with large heavy metal accumulations resulting from the processing of carbo-metallic oils, in this connection see for example U.S. Pat. No. 4,162,213 to Zrinscak, Sr. et al. In this invention, however, CO production is increased while catalyst is regenerated to about 0.1% carbon or less, and preferably about 0.5% carbon or less. Moreover, according to a preferred method of carrying out the invention the sub-process of regeneration, as a whole, may be carried out to the above-mentioned low levels of carbon on regenerated catalyst with a deficiency of oxygen; more specifically, the total oxygen supplied to the one or more stages of regeneration can be and preferably is less than the stoichiometric amount which would be required to burn all hydrogen in the coke to H 2  O and to burn all carbon in the coke to CO 2 . If the coke includes other combustibles, the aforementioned stoichiometric amount can be adjusted to include the amount of oxygen required to burn them. 
     Still another particularly preferred technique for controlling or restricting the regeneration heat imparted to fresh feed via recycled catalyst involves the diversion of a portion of the heat borne by recycled catalyst to added materials introduced into the reactor, such as the water, steam, naphtha, other hydrogen donors, flue gases, inert gases, and other gaseous or vaporizable materials which may be introduced into the reactor. 
     The larger the amount of coke which must be burned from a given weight of catalyst, the greater the potential for exposing the catalyst to excessive temperatures. Many otherwise desirable and useful cracking catalysts are particularly susceptible to deactivation at high temperatures, and among these are quite a few of the costly molecular sieve or zeolite types of catalyst. The crystal structures of zeolites and the pore structures of the catalyst carriers generally are somewhat susceptible to thermal and/or hydrothermal degradation. The use of such catalysts in catalytic conversion processes for carbo-metallic feeds creates a need for regeneration techniques which will not destroy the catalyst by exposure to highly severe temperatures and steaming. Such need can be met by a multi-stage regeneration process which includes conveying spent catalyst into a first regeneration zone and introducing oxidizing gas thereto. The amount of oxidizing gas that enters said first zone and the concentration of oxygen or oxygen bearing gas therein are sufficient for only partially effecting the desired conversion of coke on the catalyst to carbon oxide gases. The partially regenerated catalyst is then removed from the first regeneration zone and is conveyed to a second regeneration zone. Oxidizing gas is introduced into the second regeneration zone to provide a higher concentration of oxygen or oxygen-containing gas than in the first zone, to complete the removal of carbon to the desired level. The regenerated catalyst may then be removed from the second zone and recycled to the reactor for contact with fresh feed. 
     Multi-stage regeneration offers the possibility of combining oxygen deficient regeneration with the control of the CO:CO 2  molar ratio. Thus, about 50% or more, more preferably about 65% to about 95%, and more preferably about 80% to about 95% by weight of the coke on the catalyst immediately prior to regeneration may be removed in one or more stages of regeneration in which the molar ratio of CO:CO 2  is controlled in the manner described above. In combination with the foregoing, the last 5% or more, or 10% or more by weight of the coke originally present, up to the entire amount of coke remaining after the preceding stage or stages, can be removed in a subsequent stage of regeneration in which more oxygen is present. Such process is susceptible of operation in such a manner that the total flue gas recovered from the entire, completed regeneration operation contains little or no excess oxygen, i.e. on the order of about 0.2 mole percent or less, or as low as about 0.1 mole percent or less, which is substantially less than the 2 mole percent which has been suggested elsewhere. Thus, multi-stage regeneration is particularly beneficial in that it provides another convenient technique for restricting regeneration heat transmitted to fresh feed via regenerated catalyst and/or reducing the potential for thermal deactivation, while simultaneously affording an opportunity to reduce the carbon level on regenerated catalyst to those very low percentages (e.g. about 0.1% or less) which particularly enhance catalyst activity. For example, a two-stage regeneration process may be carried out with the first stage burning about 80% of the coke at a bed temperature of about 1300° F. to produce CO and CO 2  in a molar ratio of CO/CO 2  of about 1 and the second stage burning about 20% of the coke at a bed temperature of about 1350° F. to produce substantially all CO 2  mixed with free oxygen. Use of the gases from the second stage as combustion supporting gases for the first stage, along with additional air introduced into the first stage bed, results in an overall CO to CO 2  ratio of about 0.6, with a catalyst residence time of about 5 to 15 minutes total in the two zones. Moreover, where the regeneration conditions, e.g. temperture or atmosphere, are substantially less severe in the second zone than in the first zone (e.g. by at least about 10 and preferably at least about 20° F.), that part of the regeneration sequence which involves the most severe conditions is performed while there is still an appreciable amount of coke on the catalyst. Such operation may provide some protection of the catalyst from the more severe conditions. A particularly preferred embodiment of the invention is two-stage fluidized regeneration at a maximum temperature of about 1500° F. with a reduced temperature of at least about 10 or 20° F. in the dense phase of the second stage as compared to the dense phase of the first stage, and with reduction of carbon on catalyst to about 0.05% or less or even about 0.025% or less by weight in the second zone. In fact, catalyst can readily be regenerated to carbon levels as low as 0.01% by this technique, even though the carbon on catalyst prior to regeneration is as much as about 1%. 
     In most circumstances, it will be important to insure that no adsorbed oxygen containing gases are carried into the riser by recycled catalyst. Thus, whenever such action is considered necessary, the catalyst discharged from the regenerator may be stripped with appropriate stripping gases to remove oxygen containing gases. Such stripping may for instance be conducted at relatively high temperatures, for example about 1350° to about 1370° F., using steam, nitrogen or other inert gas as the stripping gas(es). The use of nitrogen and other inert gases is beneficial from the standpoint of avoiding a tendency toward hydro-thermal catalyst deactivation which may result from the use of steam. 
     The following comments and discussion relating to metals management, carbon management and heat management may be of assistance in obtaining best results when operating the invention. Since these remarks are for the most part directed to what is considered the best mode of operation, it should be apparent that the invention is not limited to the particular modes of operation discussed below. Moreover, since certain of these comments are necessarily based on theoretical considerations, there is no intention to be bound by any such theory, whether expressed herein or implicit in the operating suggestions set forth hereinafter. 
     Although discussed separately below, it is readily apparent that metals management, carbon management and heat management are inter-related and interdependent subjects both in theory and practice. While coke yield and coke laydown on catalyst are primarily the result of the relatively large quantities of coke precursors found in carbo-metallic oils, the production of coke is exacerbated by high metals accumulations, which can also significantly affect catalyst performance. Moreover, the degree of success experienced in metals management and carbon management will have a direct influence on the extent to which heat management is necessary. Moreover, some of the steps taken in support of metals management have proved very helpful in respect to carbon and heat management. 
     As noted previously the presence of a large heavy metals accumulation on the catalyst tends to aggravate the problem of dehydrogenation and aromatic condensation, resulting in increased production of gases and coke for a feedstock of a given Ramsbottom carbon value. The introduction of substantial quantities of H 2  O into the reactor, either in the form of steam or liquid water, appears highly beneficial from the standpoint of keeping the heavy metals in a less harmful form, i.e. the oxide rather than metallic form. This is of assistance in maintaining the desired selectivity. 
     Also, a unit design in which system components and residence times are selected to reduce the ratio of catalyst reactor residence time relative to catalyst regenerator residence time will tend to reduce the ratio of the times during which the catalyst is respectively under reduction conditions and oxidation conditions. This too can assist in maintaining desired levels of selectivity. 
     Whether the metals content of the catalyst is being managed successfully may be observed by monitoring the total hydrogen plus methane produced in the reactor and/or the ratio of hydrogen to methane thus produced. In general, it is considered that the hydrogen to methane mole ratio should be less than about 1 and preferably about 0.6 or less, with about 0.4 or less being considered about optimum. In actual practice the hydrogen to methane ratio may range from about 0.5 to about 1.5 and average about 0.8 to about 1. 
     Careful carbon management can improve both selectivity (the ability to maximize production of valuable products), and heat productivity. In general, the techniques of metals control described above are also of assistance in carbon management. The usefulness of water addition in respect to carbon management has already been spelled out in considerable detail in that part of the specification which relates to added materials for introduction into the reaction zone. In general, those techniques which improve dispersion of the feed in the reaction zone should also prove helpful, these include for instance the use of fogging or misting devices to assist in dispersing the feed. 
     Catalyst to oil ratio is also a factor in heat management. In common with prior FCC practice on VGO, the reactor temperature may be controlled in the practice of the present invention by respectively increasing or decreasing the flow of hot regenerated catalyst to the reactor in response to decreases and increases in reactor temperature, typically the outlet temperature in the case of a riser type reactor. Where the automatic controller for catalyst introduction is set to maintain an excessive catalyst to oil ratio, one can expect unnecessarily large rates of carbon production and heat release, relative to the weight of fresh feed charged to the reaction zone. 
     Relatively high reactor temperatures are also beneficial from the standpoint of carbon management. Such higher temperatures foster more complete vaporization of feed and disengagement of product from catalyst. 
     Carbon management can also be facilitated by suitable restriction of the total pressure in the reactor and the partial pressure of the feed. In general, at a given level of conversion, relatively small decreases in the aforementioned pressures can substantially reduce coke production. This may be due to the fact that restricting total pressure tends to enhance vaporization of high boiling components of the feed, encourage cracking and facilitate disengagement of both unconverted feed and higher boiling cracked products from the catalyst. It may be of assistance in this regard to restrict the pressure drop of equipment downstream of and in communication with the reactor. But if it is desired or necessary to operate the system at higher total pressure, such as for instance because of operating limitations (e.g. pressure drop in downstream ecuipment) the above described benefits may be obtained by restricting the feed partial pressure. Suitable ranges for total reactor pressure and feed partial pressure have been set forth above, and in general it is desirable to attempt to minimize the pressures within these ranges. 
     The abrupt separation of catalyst from product vapors and unconverted feed (if any) is also of great assistance. It is for this reason that the so-called vented riser apparatus and technique disclosed in U.S. Pat. Nos. 4,070,159 and 4,066,533 to George D. Myers et al is the preferred type of apparatus for conducting this process. For similar reasons, it is beneficial to reduce insofar as possible the elapsed time between separation of catalyst from product vapors and the commencement of stripping. The vented riser and prompt stripping tend to reduce the opportunity for coking of unconverted feed and higher boiling cracked products adsorbed on the catalyst. 
     A particularly desirable mode of operation from the standpoint of carbon management is to operate the process in the vented riser using a hydrogen donor if necessary, while maintaining the feed partial pressure and total reactor pressure as low as possible, and incorporating relatively large amounts of water, steam and if desired, other diluents, which provide the numerous benefits discussed in greater detail above. Moreover, when liquid water, steam, hydrogen donors, hydrogen and other gaseous or vaporizable materials are fed to the reaction zone, the feeding of these materials provides an opportunity for exercising additional control over catalyst to oil ratio. Thus, for example, the practice of increasing or decreasing the catalyst to oil ratio for a given amount of decrease or increase in reactor temperature may be reduced or eliminated by substituting either appropriate reduction or increase in the charging ratios of the water, steam and other gaseous or vaporizable material, or an appropriate reduction or increase in the ratio of water to steam and/or other gaseous materials introducod into the reaction zone. 
     Heat management includes measures taken to control the amount of heat released in various parts of the process and/or for dealing successfully with such heat as may be released. Unlike conventional FCC practice using VGO, wherein it is usually a problem to generate sufficient heat during regeneration to heat balance the reactor, the processing of carbo-metallic oils generally produces so much heat as to require careful management thereof. 
     Heat management can be facilitated by various techniques associated with the materials introduced into the reactor. Thus, heat absorption by feed can be maximized by minimum preheating of feed, it being necessary only that the feed temperature be high enough so that it is sufficiently fluid for successful pumping and dispersion in the reactor. When the catalyst is maintained in a highly active state with the suppression of coking (metals control), so as to achieve higher conversion, the resultant higher conversion and greater selectivity can increase the heat absorption of the reaction. In general, higher reactor temperatures promote catalyst conversion activity in the face of more refractory and higher boiling constituents with high coking potentials. While the rate of catalyst deactivation may thus be increased, the higher temperature of operation tends to offset this loss in activity. Higher temperatures in the reactor also contribute to enhancement of octane number, thus offsetting the octane depressant effect of high carbon down. Other techniques for absorbing heat have also been discussed above in connection with the introduction of water, steam, and other gaseous or vaporizable materials into the reactor. 
     As noted above, the invention can be practised in the above-described mode and in many others. An illustrative non-limiting example is described by the accompanying schematic diagrams in the figure and by the description of this figure which follows. 
     FIG. 1 is a schematic diagram of an apparatus for carrying out the process of the present invention. The feedstock (which may have been heated in a feed preheater not shown) and water (when used) supplied through delivery pipe 9, are fed by feed supply pipe 10 having a control valve 11 to a wye 12 in which they mix with a flow of catalyst delivered through supply pipe 13 and controlled by valve 14. Of course a variety of mixing arrangements may be employed, and provisions may be made for introducing the other added materials discussed above. The mixture of catalyst and feed, with or without such additional materials, is then introduced into riser 18. 
     Although riser 18 appears vertical in the drawing, persons skilled in the art will recognize that the riser need not be vertical, as riser type reactors are known in which an appreciable portion of the riser pipe is non-vertical. Thus, riser pipes having an upward component of direction are contemplated, and usually the upward component of their upwardly flowing inclined portions is substantial, i.e. at least about 30°. It is also known to provide risers which have downwardly flowing inclined or vertical portions, as well as horizontal portions. Folded risers are also known, in which there are both upwardly extending and downwardly extending segments. Moreover, it is entirely feasible to practice the process of the invention in an inclined and/or vertical pipe in which the feed and catalyst are introduced at an upper elevation and in which the feed and catalyst moves under the influence of gravity and the down flow of the feed to a lower elevation. Thus, in general, the invention contemplates the use of reaction chambers having a long L/D ratio and having a significant deviation from horizontal. 
     At the upper end of the riser 18 is a chamber 19 which receives the catalyst from the riser. Means are provided for causing product vapors to undergo a sufficient change of direction relative to the direction traveled by the catalyst particles, whereby the vapors are suddenly and effectively separated from the catalyst. Thus, there is &#34;ballistic&#34; separation of catalyst particles and product vapors as described above. 
     In the present schematic diagram, the disengagement chamber 19 includes an upward extension 20 of riser pipe 18 having an open top 21 through which the catalyst particles are discharged. This embodiment makes use of the so-called vented riser described in the above-mentioned Myers et al patents. Because of the refractory nature of the feedstock fractions, relatively high severity is required, but the rapid disengagement of catalyst from lighter cracked products in the vented riser prevents overcracking of desirable liquid products such as gasoline to gaseous products. The product vapors are caused to undergo a sudden change of direction into lateral port 22 in the side of riser extension 20, the catalyst particles being, for the most part, unable to follow the products vapors into port 22. 
     The vapors and those few particles which do manage to follow them into port 22 are transferred by cross pipe 23 to a cyclone separator 24. It is an advantage of the vented riser system shown that it can function satisfactorily with a single stage cyclone separator. However, in the present embodiment the cyclone separator 24 is employed as a first stage cyclone separator which is connected via transfer pipe 17 with optional secondary cyclone separator 25. The cyclone separator means, whether of the single- or multi-stage type, separates from the product vapors those small amounts of catalyst which do enter the lateral port 22. Product vapors are discharged from disengagement chamber 19 through product discharge pipe 26. 
     The catalyst particles which discharge from open top 21 of riser pipe extension 20, and those catalyst particles which are discharged from the discharge legs 27 and 28 of primary and secondary cyclones 24 and 25 drop to the bottom of disengagement chamber 19. The inventory and residence time of catalyst in chamber 19 are preferably minimized. During startup those catalyst particles which are present may be kept in suspension by fluffing jets 30 supplied with steam through steam supply pipe 29. Spent catalyst spilling over from the bottom of disengagement chamber 19 passes via drop leg 31 to a stripper chamber 32 equipped with baffles 33 and steam jet 34. Any of the other stripping gases referred to above may be employed with or in place of the steam. 
     Carbon is burned from the surface of the catalyst in the combustor 38 which receives stripped catalyst via downcomer pipe 39 and control valve 40. Blowers 41 and 42, in association with a valve and piping arrangement generally indicated by 44, supply air to combustion air jets 48 at the bottom of the combustor and to fluffing jets 49 at an elevated position. Air preheater 43, although usually unused when processing heavy hydrocarbons in accordance with the invention, may be employed when starting up the unit on VGO; then, when the unit is switched over to the gaso oil and carbo-metallic feed mixture, preheater operation may be discontinued (or at least reduced). Supplemental fuel means may be provided to supply fuel through the combustion air jets 48; but such is usually unnecessary since the carbon lay down on the catalyst supplies more than enough fuel to maintain the requisite temperatures in the regeneration section. Regenerated catalyst, with must of the carbon burned off, departs the combustor through an upper outlet 50 and cross pipe 51 to a secondary chamber 52, where it is deflected into the lower portion of the chamber by a baffle 53. Although the use of two stage regeneration is contemplated, and preferred, in this particular embodiment the secondary chamber 52 was operated primarily as a separator chamber, although it can be used to remove additional carbon down to about 0.01% or less in the final stages of regeneration. 
     Catalyst moves in up to three different directions from the secondary chamber 52. A portion of the catalyst may be circulated back to combustor 38 via catalyst recirculation loop 55 and control valve 56 for heat control in the combustor. Some of the catalyst is entrained in the product gases, such as CO and/or CO 2  produced by burning the carbon on the catalyst in the combustor, and the entrained catalyst fines pass upwardly in chamber 52 to two sets of primary and secondary cyclones generally indicated by 57 and 58 which separate these catalyst fines from the combustion gases. Catalyst collected in the cyclones 57,58 and discharged through their drop legs is directed to the bottom of chamber 52 where catalyst is kept in suspension by inert gas and/or steam jets 59 and by a baffle arrangement 54, the latter facilitating discharge of regenerated catalyst through outlet 69 to catalyst supply pipe 13 through which it is recirculated for contact with fresh feed at wye 12, as previously described. 
     Combustion product gases produced by regeneration of the catalyst and separated from entrained catalyst fines by the sets 57,58 of primary and secondary cyclones in chamber 52, discharge through effluent pipes 61,62 and heat exchangers 60,63. If such gases contain significant amounts of CO, they may be sent via gas supply pipe 64 to an optional furnace 65 in which the CO is burned to heat heating coil 66 connected with steam boiler 67. Additional heat may be supplied to the contents of the boilers through conduit loop 68, which circulates fluid from the boiler 67 to heat exchangers 60,63 and back to the boiler. This is of course only one example of many possible regeneration arrangements which may be employed. The amount of heat passed from the regenerator back to the riser via regenerated catalyst may be controlled in any of the other ways described above; however it is preferred to control the relative proportions of carbon monoxide and carbon dioxide produced while the catalyst is in heat exchange relationship with the combustion gases resulting from regeneration. An example of this technique is disclosed in the particularly preferred embodiment described in FIG. 2. 
     In FIG. 2, petroleum feedstock is introduced into the lower end of riser reactor 102 through inlet line 101, at which point it is mixed with hot regenerated catalyst coming through line 105 and stripper 114 from regenerator 109. 
     The feedstock is catalytically cracked in passing up riser 102 and the product vapors are ballistically separated from catalyst particles in vessel 103. Riser 102 is of the vented type having an open upper end 140 surrounded by a cup-like member 142 which preferably extends above the upper end 140 of the riser so that the lip of the cup is slightly downstream of the open riser tube as shown in FIG. 2. A pair of product vapor lines 144, 146 communicate with the interior of the cup so as to discharge product vapors entering the cup from the vapor space of vessel 103. The cup forms an annulus 147 around and concentric to the upper end of the riser tube. The transverse cross-sectional area of annulus 147 is preferably less than, more preferably about 60% or less of, the transverse cross-sectional area of riser tube 102. This structure causes product vapors to undergo a reversal in their direction of flow after they are discharged from the riser tube but before they leave the vapor space of vessel 103. The product vapors then make a further turn or change in direction of about 90° as they enter product lines 144 and 146. The product vapors then enter cyclone separators 148, 150 having overhead conduits 152,154, respectively, which convey the vapors to line 104 through a common header 156. The particle separation efficiency of this flow reversal structure is greater by a factor of about 10 or higher than the efficiency of the basic vented riser arrangement described in U.S. Pat. Nos. 4,066,533 and 4,070,159. Due to this increase in efficiency, cyclone separators 148 and 150 may comprise only a single cyclone stage instead of having multiple stages as usually required to prevent excessive carry over of catalyst fines into the overhead vapor line in prior vented riser applications. The catalyst, contaminated with coke, is removed from separator vessel 103 and passed into stripper 119 through line 107. Stripped catalyst is introduced into bed 123 in upper zone 110 of regenerator 109 through line 136. The rate of flow of catalyst into zone 110 is controlled by valve 108. 
     Make-up catalyst, wehther fresh or used, may also be introduced into upper zone 110 using any appropriate solids feeder (not shown). Oxidizing gas, such as air, is introduced into zone 110 through line 121. A portion of the coke on the catalyst is burned in zone 110, and the partially regenerated catalyst flows downwardly through conduit 118 into lower regeneration zone 125. 
     An oxidizing gas, such as air, is introduced into regeneration zone 125 through line 111. The oxidizing gas flows through gas distribution plate 115 and thus into the bed 116 of catalyst particles. This mixture passes upwardly through the bed 116 of coke-contaminated catalyst particles, fluidizing it as well as reacting with the coke, and passes through perforated plate 117 into the bed of catalyst particles in zone 110. 
     The perforations in the plate 117 are large enough so that the upwardly flowing gas readily passes therethrough into zone 110. During regeneration of the catalyst the pressure difference between the upper and lower zones prevents catalyst particles from passing downwardly through the plate. Gases within the regenerator comprising combustion products, nitrogen, and possibly additives for combustion control such as steam and/or chlorine, are separated from suspended catalyst particles by a separator (not shown) and then pass out of the regenerator through line 124. 
     Regenerated catalyst is removed from zone 125 through conduit 126 for return to riser 102 through the stripper 114, the rate of removal being controlled by valve 106. 
     A stripping gas such as steam is introduced into stripper 119 through line 120 to remove volatiles from the catalyst. The volatiles pass from the stripper through line 107 into vessel 103 and then out through line 104. Similarly a stripping gas, such as steam is introduced into stripper 114 through line 112 to remove absorbed nitrogen from the regenerated catalyst before it is returned to the reactor 102. The stripped gases pass through line 126 into the regenerator 109. 
     While this invention may be used with single stage regenerators, or with multiple stage regenerators having concurrent instead of countercurrent flow, it is especially useful in a regenerator of the type shown which is wellsuited for producing gases having a high ratio of CO to CO 2 . 
     In a preferred method of carrying out this invention in a countercurrent flow pattern as in the apparatus in FIG. 2, the amount of oxidizing gas and catalyst are controlled so that the amount of oxidizing gas passing into zone 125 is greater than that required to convert all the coke on the catalyst in this zone to carbon dioxide, and the amount of oxidizing gas passing upwardly from zone 125 into zone 110 together with the oxidizing gas added to zone 110 from line 121 is insufficient to convert all the coke in zone 110 to carbon dioxide. Zone 110 therefore will contain some CO. 
     EXAMPLES 
     Feeds varying in content of gas oil and carbo-metallic oil are cracked in a vented riser type reactor as shown in FIG. 1, using catalyst with varying levels of Equivalent Nickel. Examples 1-7 involved blends of gas oil and carbo-metallic oil, while Examples 8-10 involved 100% carbo-metallic oil feed, i.e. reduced crude. 
     Data on gas oil properties, carbo-metallic oil properties, operating characteristics and product inspections appear in the tables below. The following is a narrative of a representative example, i.e. example 8. 
     A blend comprising 41% by volume of gas oil and 59% of carbo-metallic feed at a preheat temperature of about 500° F. is introduced at a rate of about 108,000 pounds per hour into the bottom zone of a vented riser reactor as shown in FIG. 1 where it is mixed with steam, water and a zeolite catalyst (Filtrol F-87) at a temperature of about 1286° F. The catalyst to oil ratio by weight is 5.7 to 1. 
     The feed blend has a heavy metal content of about 4.7 parts per million equivalent nickel, a sulfur content of about 0.53 percent and a Ramsbottom carbon value of about 2. About 66 percent of the feed boils above 650° F. and about 10 percent of the feed boils above 1,000° F. 
     The water and steam are injected into the riser at a rate of about 4500 and 4100 pounds per hour respectively. The temperature within the reactor is about 975° F. and the pressure is about 42 psia. 
     The catalyst containing about 1.42 percent by weight of coke is removed from the reactor and introduced into a stripper where it is contacted with steam at a catalyst temperature of about 976° F. to remove volatiles adsorbed into the catalyst. 
     The stripped catalyst is introduced into the regenerator as shown in FIG. 1 at a rate of 616,000 pounds per hour. Air is introduced at a rate of about 1.16 MM SCF per hour. The catalyst is regenerated at a temperature of about 1310° F. 
     The catalyst removed from the regenerator and recycled to the reactor for contact with additional feed contains 0.25 percent by weight of residual carbon. 
     Further details are set forth in the following tables: 
     
                                           TABLE I                                 
__________________________________________________________________________
Gas Oil (VGO)                                                             
        (1) (2) (3) (4) (5) (6) (7) (8)                                   
                                      (9)                                 
                                        (10)                              
__________________________________________________________________________
API Grav.                                                                 
        23.3                                                              
            23.6                                                          
                25.2                                                      
                    25.2                                                  
                        27.1                                              
                            24.7                                          
                                25.9                                      
B.P. Data (°F.)                                                    
IBP     580 585 565 561 504 550 556                                       
10% (Vol.)                                                                
        629 629 611 611 545 603 627                                       
50% (Vol.)                                                                
        789 791 777 779 715 774 772                                       
90% (Vol.)                                                                
        932 932 925 925 906 938 936                                       
Sulfur (Wt %)                                                             
        0.54                                                              
            0.53                                                          
                0.60                                                      
                    0.47                                                  
                        0.47                                              
                            0.63                                          
                                0.50                                      
Fe (ppm)                                                                  
        1.5 1.6 0.8 2.2 1.3 0.9 1.0                                       
Ni (ppm)                                                                  
        0.2 0.1 0.1 0.6 0.1 0.2 0.5                                       
V (ppm) 0.1 0.1 0.1 0.2 0.1 2.1 1.1                                       
Ramsbottom                                                                
        0.4 0.38                                                          
                0.31                                                      
                    0.43                                                  
                        0.38                                              
                            0.38                                          
                                0.33                                      
Carbon (wt %)                                                             
__________________________________________________________________________
 
    
     
                                           TABLE II                                
__________________________________________________________________________
Carbomettallic                                                            
Oil-Red. Crude                                                            
        (1) (2) (3) (4) (5) (6) (7)  (8) (9) (10)                         
__________________________________________________________________________
API Grav.                                                                 
        23.1                                                              
            23.1                                                          
                23.2                                                      
                    23.2                                                  
                        22.4                                              
                            22.2                                          
                                23.1 23.6                                 
                                         23.5                             
                                             21.6                         
B.P. Data (°F.)                                                    
IBP     487 484 488 498 488 487 492  465 465 480                          
10% (Vol.)                                                                
        551 550 559 560 550 550 559  555 539 555                          
50% (Vol.)                                                                
        797 795 800 794 816 817 818  820 804 829                          
80% (Vol.)                                                                
        981 980 980 990 992 990 1000 990 985 1000                         
Sulfur (Wt %)                                                             
        0.58                                                              
            0.58                                                          
                0.57                                                      
                    0.62                                                  
                        0.62                                              
                            0.51                                          
                                0.60 0.64                                 
                                         0.58                             
                                             2.07                         
Fe (ppm)                                                                  
        6.7 4.5 5.0 6.3 7.4 8.2 5.5  6.9 4.3 8.8                          
Ni (ppm)                                                                  
        9.6 10.6                                                          
                12.1                                                      
                    12.7                                                  
                        9.8 11.2                                          
                                9.8  6.2 10.5                             
                                             6.0                          
V (ppm) 7.7 7.8 7.5 7.4 6.8 6.3 1.8  14.5                                 
                                         10.2                             
                                             15.3                         
Ramsbottom                                                                
        4.0 3.9 4.1 3.95                                                  
                        4.0 4.0 4.2  2.3 7.6 4.9                          
Carbon (wt %)                                                             
__________________________________________________________________________
 
    
     
                                           TABLE III                               
__________________________________________________________________________
Operating                                                                 
Data    (1)                                                               
           (2)                                                            
              (3)                                                         
                 (4)                                                      
                    (5)  (6)  (7)  (8)  (9)  (10)                         
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Reactor 997                                                               
           998                                                            
              990                                                         
                 991                                                      
                    975  971  975  975  976  980                          
Temp. °F.                                                          
Catalyst:Oil        5.7  5.4  5.9  7.5  7.9  7.9                          
Wt Ratio                                                                  
Red. Crude                                                                
         33                                                               
            34                                                            
               52                                                         
                  52                                                      
                    41   41   41   100  100  100                          
in Feed, Vol. %                                                           
Conversion,                                                               
         73                                                               
            75                                                            
               73                                                         
                  74                                                      
                    64   63   67   64   66   64                           
Vol. %                                                                    
Selectivity to                                                            
         70                                                               
            72                                                            
               71                                                         
                  70                                                      
                    73   70   65                                          
Gasoline                                                                  
Metals on                                                                 
Catalyst                                                                  
N:      283                                                               
           332                                                            
              683                                                         
                 832                                                      
                    2300 2900 3500 4800 5000 5500                         
V       325                                                               
           396                                                            
              733                                                         
                 800                                                      
                    2600 3100 3400 5000 4700 6300                         
Equivalent                                                                
        348                                                               
           411                                                            
              829                                                         
                 992                                                      
                    2820 3520 4180 5800 5940 6760                         
Nickel                                                                    
__________________________________________________________________________
 
    
     
                                           TABLE IV                                
__________________________________________________________________________
Yield (Vol. %)                                                            
        (1)                                                               
           (2)                                                            
              (3)                                                         
                 (4)                                                      
                    (5)                                                   
                       (6)                                                
                          (7) (8)                                         
                                 (9)                                      
                                    (10)                                  
__________________________________________________________________________
H.sub.2 0.8                                                               
           0.8                                                            
              1.6                                                         
                 1.9                                                      
                    3.1                                                   
                       4.4                                                
                          2.5 3.4                                         
                                 3.1                                      
                                    3.7                                   
CH.sub.4                                                                  
        5.1                                                               
           4.5                                                            
              4.2                                                         
                 4.5                                                      
                    3.3                                                   
                       3.9                                                
                          4.1 6.2                                         
                                 5.0                                      
                                    10.6                                  
C.sub.2 H.sub.6                                                           
        7.2                                                               
           6.1                                                            
              5.4                                                         
                 5.7                                                      
                    5.3                                                   
                       5.8                                                
                          7.3 9.2                                         
                                 9.2                                      
                                    9.2                                   
C.sub.3 -C.sub.6                                                          
        25.9                                                              
           26.0                                                           
              22.5                                                        
                 28.6                                                     
                    18.5                                                  
                       21.4                                               
                          24.8                                            
                              23.4                                        
                                 19.9                                     
                                    20.2                                  
C.sub.5 -430° F.                                                   
        51.8                                                              
           52.7                                                           
              52.3                                                        
                 51.2                                                     
                    51.2                                                  
                       46.4                                               
                          48.4                                            
                              46.1                                        
                                 45.2                                     
                                    39.4                                  
430-630° F.                                                        
        16.4                                                              
           15.5                                                           
              17.4                                                        
                 16.3                                                     
                    20.4                                                  
                       19.0                                               
                          15.3                                            
                              16.8                                        
                                 19.8                                     
                                    19.2                                  
630° F.+                                                           
        10.7                                                              
           9.6                                                            
              9.3                                                         
                 9.8                                                      
                    15.6                                                  
                       18.1                                               
                          16.9                                            
                              18.4                                        
                                 15.9                                     
                                    16.6                                  
__________________________________________________________________________
 
    
     
                                           TABLE V                                 
__________________________________________________________________________
Data on C.sub.5-                                                          
430° F. Cut                                                        
       (1) (2) (3) (4) (5) (6) (7) (8) (9) (10)                           
__________________________________________________________________________
API Grav.                                                                 
       53.4                                                               
           54.1                                                           
               54.0                                                       
                   53.6                                                   
                       53.8                                               
                           53.5                                           
                               54.7                                       
                                   54.2                                   
                                       52.7                               
                                           52.4                           
B.P. Data °F.                                                      
IBP    100 102 104 104 108 102 108 94  104 96                             
10% (Vol.)                                                                
       136 128 130 132 136 134 132 118 135 124                            
50% (Vol.)                                                                
       240 230 238 256 240 242 235 238 255 222                            
90% (Vol.)                                                                
       398 392 390 408 402 402 402 404 408 420                            
Ried Vapor                                                                
       6.3 7.7 5.6 5.3 6.5 6.6 6.8 8.8 5.8 7.8                            
Pressure                                                                  
RON    93.0                                                               
           93.0                                                           
               92.8                                                       
                   92.4                                                   
                       92.1                                               
                           92.0                                           
                               92.2                                       
                                   91.6                                   
                                       89.2                               
                                           87.3                           
(Clear)                                                                   
RON-3 ccs/                                                                
       97.8                                                               
           97.9                                                           
               97.4                                                       
                   97.8                                                   
                       98.1                                               
                           97.3                                           
                               97.6                                       
                                   97.3                                   
                                       95.6                               
                                           93.6                           
gal. TEL                                                                  
MON    81.1                                                               
           81.3                                                           
               81.2                                                       
                   81.2                                                   
                       81.0                                               
                           81.5                                           
                               82.0                                       
                                   80.6                                   
                                       78.9                               
                                           77.8                           
(Clear)                                                                   
MON-3 ccs/                                                                
       84.9                                                               
           85.2                                                           
               85.1                                                       
                   85.0                                                   
                       85.3                                               
                           85.4                                           
                               85.6                                       
                                   84.2                                   
                                       83.1                               
                                           81.2                           
gal. TEL                                                                  
__________________________________________________________________________