FIELD OF THE INVENTION

[0001] The present invention relates to NO _x reduction compositions and the method of use thereof to reduce NO _x emissions in refinery processes, and specifically in fluid catalytic cracking (FCC) processes. More particularly, the present invention relates to NO _x reduction compositions and their method of use to reduce the content of gas phase reduced nitrogen species in FCC regenerator off gases released from a fluid catalytic cracking unit (FCCU) regenerator operating in a partial or incomplete combustion mode.

BACKGROUND OF THE INVENTION

[0002] In recent years, there has been an increased concern in the United States and elsewhere about air pollution from industrial emissions of noxious oxides of nitrogen, sulfur and carbon. In response to such concerns, government agencies have in some cases already placed limits on allowable emissions of one or more of the pollutants, and the trend is clearly in the direction of increasingly stringent restrictions. [0003] NO _x , or oxides of nitrogen, in flue gas streams exiting from FCC regenerators is a pervasive problem. FCCUs process heavy hydrocarbon feeds containing nitrogen compounds a portion of which is contained in the coke on the catalyst as it enters the regenerator. Some of this coke nitrogen is eventually converted into NO _x emissions, either in the FCC regenerator or in a downstream CO boiler. Thus, all FCCUs processing nitrogen-containing feeds can have a NO _x emissions problem due to catalyst regeneration.

[0004] In an FCC process, catalyst particles (inventory) are repeatedly circulated between a catalytic cracking zone and a catalyst regeneration zone. During regeneration, coke deposits from the cracking reaction on the catalyst particles and is removed at elevated temperatures by oxidation with oxygen containing gases such as air. The removal of coke deposits restores the activity of the catalyst particles to the point where they can be reused in the cracking reaction. The coke removal step is performed over a wide range of oxygen conditions. At the minimum, there is typically at least enough oxygen to convert essentially all of the coke made to CO and H ₂ O. At the maximum, the

amount of oxygen available is equal to or greater than the amount necessary to oxidize essentially all of the coke to CO ₂ and H ₂ O.

[0005] In an FCC unit operating with sufficient air to convert essentially all of the coke on the catalyst to CO ₂ and H ₂ O ₃ the gas effluent exiting the regenerator will contain "excess oxygen" (typically 0.5 to 4% of total off gas). This combustion mode of operation is usually called "full burn". When the FCCU regenerator is operating in full burn mode, the conditions in the regenerator are for the most part oxidizing. That is, there is at least enough oxygen to convert (burn) all reducing gas phase species (e.g., CO, ammonia, HCN) regardless of whether this actually happens during the residence time of these species in the regenerator. Under these conditions, essentially all of the nitrogen deposited with coke on the catalyst during the cracking process in the FCCU riser is eventually converted to molecular nitrogen or NO _x and exits the regenerator as such with the off gas. The amount of coke nitrogen converted to NO _x as opposed to molecular nitrogen depends on the design, conditions and operation of the FCCU, and especially of the regenerator, but typically, the majority of coke nitrogen exits the regenerator as molecular nitrogen. On the other hand, when the amount of air added to the FCCU regenerator is insufficient to fully oxidize the coke on the cracking catalyst to CO ₂ and H ₂ O, some of the coke remains on the catalyst, while a significant portion of the burnt coke carbon is oxidized only to CO. In FCCUs operating in this fashion, oxygen may or may not be present in the regenerator off gas. However, should any oxygen be present in the regenerator off gas, it is typically not enough to convert all of the CO in the reduced gas phase species in the gas stream. This mode of operation is usually called "partial burn". When an FCCU regenerator is operating in partial burn mode, the CO produced, a known pollutant, cannot be discharged untreated to the atmosphere. To remove the CO from the regenerator off gas and realize the benefits of recovering the heat associated with burning it, refiners typically burn the CO in the regenerator off gas with the assistance of added fuel and air in a burner usually referred to as "the CO boiler". The heat recovered by burning the CO is used to generate steam.

[0006] When the regenerator is operating in partial burn, the conditions in the regenerator, where the oxygen added with air has been depleted and CO concentration

has built up, are overall reducing. That is, there is not enough oxygen to convert/burn all reducing species regardless if some oxygen is actually still present. Under these conditions, some of the nitrogen in the coke is converted to so called "gas phase reduced nitrogen species", examples of which are ammonia and HCN. Small amounts of NO _x may also be present in the partial burn regenerator off gas. When these gas phase reduced nitrogen species are burnt in the CO boiler with the rest of the regenerator off gas, they can be oxidized to NO _x , which is then emitted to the atmosphere. This NO _x along with any "thermal" NO _x formed in the CO boiler burner by oxidizing atmospheric N ₂ constitute the total NO _x emissions of the FCCU unit operating in a partial or incomplete combustion mode.

[0007] FCCU regenerators may also be designed and operated in an "incomplete burn" mode intermediate between full burn and partial burn modes. An example of such an intermediate regime occurs when enough CO is generated in the FCCU regenerator to require the use of a CO boiler, but because the amounts of air added are large enough to bring the unit close to full burn operation mode, significant amounts of oxygen can be found in the off gas and large sections of the regenerator are actually operating under overall oxidizing conditions. In such- case, while gas phase reduced nitrogen species are still found in the off gas, significant amounts of NO _x are also present. In most cases, a majority of this NO _x is not converted in the CO boiler and ends up being emitted to the atmosphere.

[0008] Yet another combustion mode of operating an FCCU, which can also be considered as an "incomplete burn" mode, is nominally in full burn with relatively low amounts of excess oxygen and/or inefficient mixing of air with coked catalyst. In this case, large sections of the regenerator may be under reducing conditions even if the overall regenerator is nominally oxidizing. Under these conditions, reduced nitrogen species and increased amounts of CO may be found in the regenerator off gas along with NO _x . These reduced nitrogen species can be converted to NO _x in a downstream CO boiler before being emitted into the atmosphere.

[0009] Various catalytic approaches have been proposed to control NO _x emissions in the flue gas exiting from the FCCU regenerator.

[0010] For example, recent patents, including U.S. Patent Nos. 6,379,536, 6,280,607, 6,129,834 and 6,143,167, have proposed the use of NO _x removal compositions for reducing NO _x emissions from an FCCU regenerator. U.S. Patent Nos. 6,358,881Bl, 6,165,933 also disclose a NO _x reduction composition, which promotes CO combustion during an FCC catalyst regeneration process step while simultaneously reducing the level of NO _x emitted during the regeneration step. NO _x reduction compositions disclosed by these patents may be used as an additive, which is circulated along with the FCC catalyst inventory, or incorporated as an integral part of the FCC catalyst.

[0011] In U.S. Patent 4,290,878, NO _x is controlled in the presence of a platinum- promoted CO combustion promoter in a full burn combustion mode regenerator by the addition of iridium or rhodium on the combustion promoter in lesser amounts than the amount of platinum.

[0012] U.S. Patent Nos. 4,980,052 and 4,973,399 disclose copper-loaded zeolite additives useful for reducing emissions of NO _x from the regenerator of an FCCU unit operating in full CO-burning mode.

[0013] U.S. Patent 4,368,057 discloses the removal of NH ₃ contaminants of gaseous fuel by reacting the NH ₃ with a sufficient amount of NO.

[0014] Efforts to control ammonia and/or NO _x released in an FCC regenerator operated in a partial or an incomplete mode of combustion have been known.

[0015] For example, recent patent, U.S. Patent No. 6,660,683 Bl discloses compositions for reducing gas phase reduced nitrogen species, e.g. ammonia, and NO _x generated during a partial or incomplete combustion catalytic cracking process. The compositions generally comprise (i) an acidic metal oxide containing substantially no zeolite, (ii) an alkali metal, alkaline earth metal and mixtures thereof, (iii) an oxygen storage component and (iv) a noble metal component, preferably rhodium or iridium, and mixtures thereof.

[0016] Publication No. US-2004-0074809-A1, published April 22, 2004, discloses processes for the reduction of gas phase reduced nitrogen species, e.g. ammonia, in the off gas of an FCCU regenerator operated in a partial or incomplete mode of combustion. Reduced emissions are achieved by contacting the off gas from the FCCU regenerator

with at least one oxidative catalyst/additive composition having the ability to reduce gas phase nitrogen species to molecular nitrogen under partial or incomplete combustion conditions.

[0017] U.S. Patent 5,021,144 discloses reducing ammonia in an FCCU regenerator operating in a partial burn combustion mode by adding a significant excess ( e.g., at least two times) of the amount of a carbon monoxide (CO) combustion or oxidation promoter sufficient to prevent afterburn combustion in the dilute phase of the regenerator.

[0018] U.S. Patent 4,755,282 discloses a process for reducing the content of ammonia in a regeneration zone off gas of an FCCU regenerator operating in a partial or incomplete combustion mode. The process requires passing a fine sized, i.e. 10 to 40 microns, ammonia decomposition catalyst to either the regeneration zone of an FCCU, or an admixture with the off gas from the regeneration zone of the FCCU, at a predetermined make-up rate such that the residence time of the decomposition catalyst relative to the larger FCC catalyst particles will be short in the dense bed of the regenerator due to rapid elutriation of the fine sized ammonia decomposition catalyst particles. The fine sized elutriated decomposition catalyst particles are captured by a third stage cyclone separator and recycled to the regenerator of the FCCU. The decomposition catalyst may be a noble group metal dispersed on an inorganic support.

[0019] U.S. 4,744,962 is illustrative of a post-treatment process to reduce ammonia in the FCCU regenerator flue gas. The post-treatment involves treating the regenerator flue gas to lessen the ammonia content after the gas has exited the FCCU regenerator but before passage to the CO boiler.

[0020] Publication No. US 2004/0245148 Al, published December 9, 2004, discloses reducing ammonia and hydrogen cyanide in a partial burn regenerator flue gas by incorporating precious metals such as ruthenium, rhodium, iridium or mixtures thereof, in the regenerator.

[0021] Simultaneously with NO _x emissions, afterburn may also be a concern for units operating in partial burn or incomplete combustion mode. Gases exiting the catalyst bed of an FCCU operating in partial or incomplete burn combustion mode will consist mainly of CO ₂ , CO, H ₂ O, reduced nitrogen species, other reduced species such as H ₂ S, COS and

hydrocarbons, SO ₂ , and potentially some O ₂ and/or NO. However, depending on the design and mechanical condition of the regenerator, conditions can develop in which sufficient amounts of CO and O ₂ escape the catalyst bed allowing the CO to react with the available O ₂ . This reaction can occur in the regenerator at any point downstream of the dense catalyst bed, including the area above the dense bed (dilute phase), the cyclones where entrained catalyst is separated from the flue gas, the plenum, the overhead space above the cyclones, or even the flue gas pipe. Because afterburn occurs after the dense bed of the cracking catalyst, which acts as a heat sink absorbing the heat released from the exothermic reaction of CO with O ₂ , it can heat up the gases to the point that overheating can occur. The result can be temperatures which approach the metallurgical limit of the materials used to construct the regenerator. High afterburn can limit the useful life of the regenerator equipment, and runaway afterburn can cause catastrophic equipment failure.

[0022] Typically, afterburn is prevented or controlled by adding CO combustion promoters to the cracking catalyst circulating inventory which promote the combustion of CO to CO ₂ . Conventional CO combustion promoters typically comprise an additive comprising 300 to 1000 ppm platinum on alumina, or a much smaller amount of platinum, e.g., amounts which typically achieve from about 0.1 to about 10 ppm in the total cracking catalyst inventory, incorporated directly into all or part of the cracking catalyst.

[0023] While CO combustion promoters can be effectively used to prevent or control afterburn in FCC units, the use of combustion promoters is not desirable in many of the FCC units operated in partial burn or incomplete combustion mode. By promoting the reaction of CO to CO ₂ in an oxygen deficient environment, a combustion promoter can consume oxygen to convert CO, oxygen which otherwise would have been used to convert coke to CO, thereby increasing coke left on the regenerated catalyst (CRC). Increased amounts of CRC on the cracking catalyst returned to the riser will decrease the catalyst activity, and may reduce conversion and product yields. Any increase in the conversion of CO will also increase the heat released in the regenerator, a consequence of the larger heat of combustion for the reaction of CO to CO ₂ compared to the heat of combustion for the reaction of carbon to CO. As a result increased CO conversion can raise the temperature of the dense catalyst bed. Increasing the dense bed temperature can

often be undesirable, since higher regenerated catalyst temperature can negatively affect catalyst circulation, catalyst activity and stability, unit conversion and/or product yields. Thus, many of the FCC units operated in partial burn or incomplete combustion mode, cannot use any CO combustion promoter or any other additive having CO oxidation activity sufficient to be useful as a CO combustion promoter under catalytic cracking conditions.

[0024] Consequently, there remains a need in the refining industry for simple and effective compositions and processes which minimize the content of gas phase reduced nitrogen species and NO _x in an FCCU regenerator operated in a partial or incomplete combustion mode during an FCC process without significantly affecting CO combustion.

SUMMARY OF THE INVENTION

[0025] The essence of the present invention resides in the discovery of particulate compositions which are capable of being circulated throughout an FCCU along with the cracking catalyst inventory to minimize the content of gas phase reduced nitrogen species, e.g. NH ₃ and HCN, and NO _x present in the off gas of the FCCU regenerator when the FCCU regenerator is operated in a partial or incomplete burn mode. Advantageously, the NO _x reduction compositions of the invention exhibit low CO combustion activity, i.e., the compositions do not significantly affect CO combustion, simultaneously with high efficiencies for the oxidation of gas phase reduced nitrogen species to N ₂ when the compositions are present in a FCCU regenerator operating under partial or incomplete burn mode. In accordance with the process of the invention, the gas phase reduced nitrogen species are oxidized to molecular nitrogen prior to passage of the off gas to the CO boiler. This reduced content of gas phase reduced nitrogen species in the off gas provides for an overall reduction OfNO _x emitted into the atmosphere from the FCCU due to a decrease in the amount of the nitrogen species being oxidized to NO _x in the CO boiler as CO is oxidized to CO ₂ .

[0026] Despite the reducing environment in an FCCU regenerator operated in a partial burn or incomplete burn mode, some NO _x may form in the regenerator. In addition to

reducing the content of gas phase reduced nitrogen species, compositions of the invention also enhance the removal of any NO _x formed in the partial or incomplete burn regenerator by catalyzing the reaction of NO _x with reductants typically found in the FCCU regenerator, e.g. CO, hydrocarbons, and gas phase reduced nitrogen species, to form molecular nitrogen. Advantageously, the content of NO _x formed in the regenerator is reduced prior to the NO _x exiting the regenerator and being passed unabated through the CO boiler into the environment.

[0027] In accordance with the present invention, compositions of the invention are comprised of a particulate composition containing a zeolite component having a pore size of less than 7.2 Angstroms and at least one noble metal selected from the group consisting of platinum, palladium, rhodium, iridium, osmium, ruthenium, rhenium and mixtures thereof. In a preferred embodiment of the invention, the zeolite particles are bound with an inorganic binder. The binder preferably comprises silica, alumina or silica-alumina. Preferably, the zeolite is exchanged with hydrogen, ammonium, alkali metal and combinations thereof. The preferred alkali metal is sodium, potassium and combinations thereof.

[0028] In one embodiment of the invention, the zeolite containing compositions of the invention are added to a circulating inventory of the catalytic cracking catalyst as a separate admixture of particles to reduce NO _x emissions released from the FCCU regenerator during the FCC process.

[0029] In another embodiment of the invention, the zeolite containing compositions of the invention are incorporated as an integral component of an FCC catalyst, preferably, containing a Y-type zeolite active cracking component.

[0030] The present invention also provides a process for reducing the content of gas phase reduced nitrogen species released from the regenerator of an FCCU operated in a partial or incomplete mode of combustion without significantly affecting CO combustion. In accordance with the present invention, the process comprises contacting the off gas of an FCCU regenerator operated in a partial or incomplete combustion mode under FCC catalytic conditions with an amount of the compositions of the invention effective to oxidize the gas phase reduced nitrogen species to molecular nitrogen. The invention also

provides a process for reducing NO _x emissions from an FCC process operated in a partial or incomplete combustion mode using the compositions of the invention.

[0031] Accordingly, it is an advantage of this invention to provide compositions which are useful to reduce the content of gas phase reduced nitrogen species released from an

FCCU regenerator operating in partial or incomplete combustion mode during an FCC process.

[0032] It is also an advantage of this invention to provide compositions which are useful to reduce NO _x emissions from an FCCU regenerator operating in partial or incomplete combustion mode by minimizing the amount of reduced nitrogen species emitted from the regenerator during an FCC process.

[0033] Another advantage of the invention is to provide low CO combustion compositions which are effective to reduce the content of gas phase reduced nitrogen species and NO _x released from an FCCU regenerator operating in partial or incomplete combustion mode during an FCC process.

[0034] Another advantage of the invention is to provide compositions which are effective to oxidize gas phase reduced nitrogen species released from an FCCU regenerator operating in partial or incomplete combustion mode to molecular nitrogen, thereby minimizing the conversion of the reduced nitrogen species to NO _x in the downstream CO boiler.

[0035] It is another advantage of this invention to provide compositions which are useful to reduce NO _x emissions from an FCCU regenerator operating in partial or incomplete combustion mode to molecular nitrogen by catalyzing the reaction of NO _x with CO and other reductants typically present in a partial or incomplete burn FCCU regenerator.

[0036] It is another advantage of this invention to provide a process for the reduction of the content of NO _x in the off gas of an FCCU regenerator operating in partial or incomplete combustion mode by reducing the content of gas phase reduced nitrogen species being emitted in the off gas released from the regenerator, prior to passage of the gas to a CO boiler, whereby as CO is oxidized to CO ₂ , a lesser amount of the gas phase reduced nitrogen species is oxidized to NO _x .

[0037] It is another advantage of this invention to provide a process for the reduction of gas phase reduced nitrogen species in an effluent gas stream passed from an FCC regenerator to a CO boiler, whereby as CO is oxidized to CO ₂ a lesser amount of the reduced nitrogen species is oxidized to NO _x .

[0038] Another advantage of this invention is to provide a process for the reduction of the content of NO _x in the off gas of an FCCU regenerator operating in a partial or incomplete combustion mode by the reduction of NO _x being emitted in the off gas released from the regenerator, prior to passage of the gas to the CO boiler where the NO _x remains untreated and is eventually released into the environment. [0039] Yet another advantage of this invention is to provide improved partial or incomplete combustion FCC processes using the compositions of the invention. [0040] These and other aspects of the present invention are described in further detail below.

BRIEF DESCRIPTION OF THE DRAWINGS

[0041] FIG. 1 is a graphic representation of the effectiveness of Additive B, as prepared in EXAMPLE 2, for reducing NH ₃ in a Davison Circulating Riser ("DCR") regenerator operating under partial burn conditions when the additive is blended with an equilibrium cracking catalyst.

[0042] FIG. 2 is a graphic representation of the effectiveness of Additives D, E, F, G, H and I, as prepared in EXAMPLES 4, 5, 6, 7, 8 and 9 respectively, to reduce NO formation during NH ₃ conversion in a Regenerator Test Unit ("RTU").

[0043] FIG. 3 is a graphic representation of the effectiveness of Additives D, E, F, G, H and I, as prepared in EXAMPLES 4, 5, 6, 7, 8 and 9 respectively, for reducing NO by reacting NO with CO in a RTU.

DETAILED DESCRIPTION OF THE INVENTION

[0044] For purposes of this invention the term " NO _x " will be used herein to represent oxides of nitrogen, e.g. nitric oxide, (NO) and nitrogen dioxide (NO ₂ ) the principal noxious oxides of nitrogen, as well as N ₂ O ₄ , N ₂ O ₅ , and mixtures thereof.

[0045] The term reduced "gas phase reduced nitrogen species" is used herein to indicate any gas phase species formed in the regenerator of a fluid catalytic cracking unit during a fluid catalytic cracking process which gas species contains a nitrogen having a nominal charge of less than zero. Examples of gas phase reduced nitrogen species include, but are not limited to, ammonia (NH ₃ ), hydrogen cyanide (HCN), and the like. [0046] The term "afterburn" is used herein to indicate the burning of CO which occurs when CO and O ₂ escaping the dense bed of fluidized cracking catalyst being regenerated in a FCCU regenerator react at any point after the dense catalyst bed, including the area immediately above the dense bed (dilute phase), the cyclones where entrained catalyst is separated from the flue gas, the plenum, overhead above the cyclones, or even the flue gas pipe. Afterburn is measured as the difference between any of the temperatures measured after the regenerator dense bed, or the average of all or any group of such temperatures measured (e.g., dilute phase, cyclone, plenum, overhead, or flue gas temperatures and the like) minus any of the dense bed temperatures or the average of all or any group of dense bed temperatures measured.

[0047] For purposes of this invention the term "low CO combustion or oxidation" as it relates to a composition of matter, is used herein to indicate a composition which does not significantly affect CO oxidation or combustion or does not have sufficient CO combustion or promotion activity to be useful as a CO combustion promoter in an FCCU operating under FCC conditions, so that the composition has to be used in an amount of at least twice, preferably at least three times, more preferably at least five times, and even more preferably at least ten times the amount of a conventional CO combustion promoter consisting of about 700 to about 850 ppm of platinum on an alumina base, in order to obtain similar control of afterburn achieved with a conventional CO combustion promoter.

[0048] The present invention encompasses the discovery that the use of certain zeolite containing additive compositions is very effective to reduce NO _x by oxidizing gas phase reduced nitrogen species released from the FCCU regenerator under FCC process conditions to N ₂ , so as to prevent the formation of NO _x in a downstream CO boiler. Compositions of the invention accomplish NO _x reduction without a substantial change in

hydrocarbon feed conversion or the yield of cracked products. The NO _x reduction compositions of the present invention typically have low CO combustion or oxidation activity under partial or incomplete burn conditions and do not provide sufficient CO promotion activity to be useful in an FCCU regenerator as a CO combustion promoter, [0049] Compositions of the invention typically comprise a composition containing particles of a zeolite component wherein the zeolite has a pore size of less than 7.2 Angstroms and at least one noble metal selected from the group consisting of platinum, palladium, rhodium, iridium, osmium, ruthenium, rhenium and mixtures thereof, with rhodium, iridium, osmium, ruthenium, rhenium and mixtures thereof being preferred, and rhodium, iridium and mixtures thereof being most preferred. In a preferred embodiment of the invention, the zeolite containing particles are bound with an inorganic binder. The novel compositions may be added to the circulating inventory of the catalytic cracking catalyst as a separate particle additive or incorporated as an integral component into the cracking catalyst.

[0050] Zeolites useful in the present invention include zeolites having a pore size of less than 7.2 Angstroms, preferably ranging from about 2 to about 7.1 Angstroms, most preferably ranging from about 3.5 to about 6.5 Angstroms with a SiO ₂ to Al ₂ O ₃ molar ratio of less than about 500, preferably less than 250, most preferably less than 100. Preferably, the zeolite component is a zeolite selected from the group consisting of ZSM- 11, beta, MCM-49, mordenite, MCM-56, Zeolite-L, zeolite Rho, errionite, chabazite, clinoptilolite, MCM-22, MCM-35, MCM-61, Offretite, A, ZSM-12, ZSM-23, ZSM-18, ZSM-22, ZSM-35, ZSM-57, ZSM-61, ZK-5, NaJ, Nu-87, Cit-1, SSZ-35, SSZ-48, SSZ- 44, SSZ-23, Dachiardite, Merlinoite, Lovdarite, Levyne, Laumontite, Epistilbite, Gmelonite, Gismondine, Cancrinite, Brewsterite, Stilbite, Paulingite, Goosecreekite, Natrolite, omega, ferrierite or mixtures thereof. In a more preferred embodiment of the invention, the NO _x reduction zeolite component is a zeolite selected from the group consisting of ferrierite, beta, MCM-49, mordenite, MCM-56, zeolite Rho, errionite, chabazite, clinoptilolite, MCM-22, Offretite, A, ZSM-12, ZSM-23, omega and mixtures thereof. In an even more preferred embodiment of the invention, the NO _x reduction zeolite component is ferrierite.

[0051] In a preferred embodiment of the invention, the zeolite component has a surface area of at least 100 m ² /g, preferably at least 200 m ² /g and most preferably at least 300 m ² /g. In another embodiment of the invention, the zeolite component is exchanged with a material selected from the group consisting of hydrogen, ammonium, alkali metal and combinations thereof, prior to incorporation into the binder or FCC catalyst. The preferred alkali metal is one selected from the group consisting of sodium, potassium and mixtures thereof.

[0052] Optionally, the zeolite component may contain stabilizing amounts, e.g., up to about 25 weight percent, of a stabilizing metal (or metal ion), preferably incorporated into the pores of the zeolite. Suitable stabilizing metals include, but are not limited to, metals selected from the group consisting of Groups IB, 2A, 3B, 4B, 5B, 6B, 7B, 2B 3 A, 4A, 5 A and the Lanthanide Series of The Periodic Table, nickel, iron cobalt and mixtures thereof. Preferably, the stabilizing metals are selected from the group consisting of Groups IB, 3B, 2A, 2B, 3 A and the Lanthanide Series of the Periodic Table, iron and mixtures thereof. Most preferably, the stabilizing metals are selected from the group consisting of lanthanum, aluminum, magnesium, zinc, iron, copper and mixtures thereof. The metal may be incorporated into the pores of the NO _x reduction zeolite by any method known in the art, e.g., ion exchange, impregnation or the like. For purposes of this invention, the Periodic Table referenced herein above is the Periodic Table as published by the American Chemical Society.

[0053] The amount of the zeolite component used in the NO _x reduction compositions of the invention will vary depending upon several factors, including but not limited to, the mode of combining the zeolite with the catalytic cracking catalyst and the type of cracking catalyst used. In one embodiment of the invention, the compositions of the invention are separate catalyst/additive compositions and comprise a particulate composition formed by binding particles of a zeolite component with a suitable inorganic binder. Generally, the amount of the zeolite component present in the particulate compositions of the invention is at least 10, preferably at least 30, most preferably at least 40 and even more preferably at least 50, weight percent based on the total weight of the composition. Typically, the particulate NO _x reduction compositions of the invention

contain from about 10 to about 85, preferably from about 30 to about 80, most preferably, from about 40 to about 75, weight percent of the zeolite component based on the total weight of the NO _x reduction composition.

[0054] Binder materials useful to prepare the particulate compositions of the invention include any inorganic binder which is capable of binding a zeolite powder to form particles having properties suitable for use in the FCCU under FCC process conditions. Typical inorganic binder materials useful to prepare compositions in accordance with the present invention include, but are not limited to, alumina, silica, silica-alumina, aluminum phosphate and the like, and mixtures thereof. Preferably, the binder is selected from the group consisting of alumina, silica, silica-alumina and mixtures thereof. More preferably, the binder comprises alumina. Even more preferably, the binder comprises an acid or base peptized alumina. Most preferably, the binder comprises an alumina sol, e.g., aluminum chlorohydrol. Generally, the amount of binder material present in the particulate catalyst/additive compositions comprises from about 5 to about 50 weight percent, preferably from about 10 to about 30 weight percent, most preferably from about 15 to about 25 weight percent, of the catalyst/additive composition of the invention. [0055] Particulate NO _x reduction compositions of the invention should have a particle size sufficient to permit the composition to be circulated throughout the FCCU simultaneously with the inventory of cracking catalyst during the FCC process. Typically, the composition of the invention will have a mean particle size of greater than 45 μm. Preferably, the mean particle size is from about 50 to about 200 μm, most preferably from about 55 to about 150 μm, even more preferred from about 60 to about 120 μm. The compositions of the invention typically have a Davison attrition index (DI) value of less than 50, preferably less than 20, most preferably less than 15. [0056] While the present invention is not limited to any particular process of preparation, typically the particulate compositions of the invention are prepared by forming an aqueous slurry containing the zeolite, optional zeolite components, the inorganic binder, and optional matrix materials, in an amount sufficient to provide at least 10.0 weight percent of zeolite and at least 5.0 weight percent of binder material in the final catalyst/additive composition and, thereafter, spray drying the aqueous slurry to form

particles. The spray-dried particles are optionally dried at a sufficient temperature for a sufficient time to remove volatiles, e.g., at about 9O ⁰ C to about 32O ⁰ C for up to about 24 hours. In a preferred embodiment of the invention, the zeolite containing aqueous slurry is milled prior to spray-drying to reduce the mean particle size of materials contained in the slurry to 10 μm or less, preferably 5 μm or less, most preferably 3 μm or less. The aqueous slurry may be milled prior to or after incorporation of the binder and/or matrix materials as desired.

[0057] The spray-dried composition may be calcined at a temperature and for a time sufficient to remove volatiles and provide sufficient hardness to the binder for use in the FCCU under FCC process conditions, preferably from about 32O ⁰ C to about 900 ⁰ C from about 0.5 to about 12 hours.

[0058] Optionally, the dried or calcined composition is washed or exchanged with an aqueous solution of ammonia or ammonium salt (e.g., ammonium sulfate, nitrate, chloride, carbonate, phosphate and the like), or an inorganic or organic acid (e.g., sulfuric, nitric, phosphoric, hydrochloric, acetic, formic and the like) to reduce the amount of alkaline metals, e.g. sodium or potassium.

[0059] Typically, particulate NO _x reduction compositions useful in the process of the present invention are prepared by impregnating the base zeolite containing material with an aqueous solution of at least one noble metal salt, e.g. nitrate, chloride, carbonate and sulfate salts, amine complexes, and the like, in an amount sufficient to provide at least 0.1 parts per million of noble metal, measured as the metal, in the final catalyst/additive composition and thereafter drying the impregnated particles to remove volatiles, e.g. typically at about 100 ⁰ C to 250 ⁰ C for up to about 24 hours.

[0060] The amount of the NO _x reduction compositions used in the process of the invention is any amount sufficient to reduce the content of gas phase reduced nitrogen species in the flue gas of an FCCU regenerator operated in a partial or incomplete mode of combustion relative to the content of gas phase reduced nitrogen species present in the flue gas absent the presence of the NO _x reduction compositions. Particulate NO _x reduction compositions useful in the invention process are circulated in the form of separate particle additives along with the main cracking catalyst throughout the FCCU.

Generally, the NO _x reduction composition is used in an amount of at least 0.01, preferably at least 0.05, most preferably at least 0.1, weight percent of the FCC catalyst inventory. The amount of the NO _x reduction composition used ranges from about 0.01 to about 50 weight percent, preferably from about 0.05 to about 30 weight percent, most preferably from about 0.1 to about 20 weight percent of the FCC catalyst inventory. The separate particles may be added to the FCCU in any conventional manner, e.g., with make-up catalyst to the regenerator or other convenient method.

[0061] Where compositions of the invention are integrated into the FCC catalyst particles themselves, any conventional FCC catalyst particle component may be used in combination with the compositions of the invention. When integrated into the FCC catalyst composition, the NO _x reduction composition of the invention typically represents at least about 0.005 wt%, preferably at least about 0.01 wt%, most preferably at least about 0.05 wt%, of the total FCC catalyst composition. Preferably, the amount of the invention compositions used ranges from about 0.005 to about 50 wt%, more preferable from about 0.01 to about 30 weight percent, most preferably from about 0.05 to about 20 wt%, of the total FCC catalyst composition. When incorporated as an integral component of the FCC catalyst composition, the NO _x reducing zeolite component typically represents at least 0.005 wt% of the total FCC catalyst composition. Preferably, the amount of the NO _x reducing zeolite used ranges from about 0.005 to about 50 wt%, most preferably from about 0.05 to about 20 wt%, of the total FCC catalyst composition [0062] In addition to the NO _x reducing zeolite and the noble metal component, the integrated FCC catalyst will typically comprise the cracking catalyst zeolite, inorganic binder materials and optionally, matrix, fillers, and other additive components such as metals traps (for example, traps for Ni and V) to make up the cracking catalyst. The cracking catalyst zeolite, usually a Y, USY or REUSY-type, provides the majority of the cracking activity and is typically present in a range from about 10 to about 75, preferably from about 15 to about 60 and most preferably from about 20 to about 50 weight percent based on the total weight of the composition. Inorganic binder materials useful to prepare integrated catalyst compositions in accordance with the present invention include any inorganic material capable of binding the components of the integrated catalyst to

form particles having properties suitable for use in the FCCU under FCC process conditions. Typically, the inorganic binder materials include, but are not limited to, alumina, silica, silica-alumina, aluminum phosphate and the like, and mixtures thereof. Preferably, the binder is selected from the group consisting of alumina, silica, silica- alumina. Generally, the amount of binder material present in the integrated catalyst composition is less than 50 weight percent, based on the total weight of the catalyst composition. Preferably, the amount of binder material present in the integrated catalyst composition ranges from about 5 to about 45 weight percent, most preferably from about 10 to about 30 weight percent and even more preferably from about 15 to about 25 weight percent, based on the total weight of the composition.

[0063] The matrix materials optionally present in the integrated catalyst compositions of the present invention include, but are not limited to alumina, silica-alumina, rare earth oxides such as lanthana, transition metal oxides such as titania, zirconia, and manganese oxide, Group HA oxides such as magnesium and barium oxides, clays such as kaolin, and mixtures thereof. The matrix or fillers may be present in the integral catalyst in the amount of less than 50 weight percent based on the total weight of the composition. Preferably, the matrix and fillers, if any, are present in an amount ranging from about 1 to about 45 weight present based on the total weight of the catalyst composition. [0064] The particle size and attrition properties of the integral catalyst affect fluidization properties in the unit and determine how well the catalyst is retained in the commercial FCC unit. The integral catalyst composition of the invention typically has a mean particle size of about 45 to about 200 μm, more preferably from about 50μm to about 150μm. The attrition properties of the integral catalyst, as measured by the Davison Attrition Index (DI), have a DI value of less than 50, more preferably less than 20 and most preferably less than 15.

[0065] In a preferred embodiment of the invention, the FCC cracking catalyst contains a Y-type zeolite. The NO _x reduction zeolite containing compositions may be added as a separate additive particle to a circulating inventory of the cracking catalyst or incorporated directly into the Y-type zeolite containing cracking catalyst as an integral component of the catalyst. In either case, it is preferred that the zeolite be present in that

amount sufficient to provide in the total catalyst inventory a ratio of NO _x reduction zeolite to Y-type zeolite of less than 2, preferably less than 1.

[0066] In general, the noble metal component is at least one metal selected from the group consisting of platinum, palladium iridium, rhodium, osmium, or ruthenium, rhenium, and mixtures thereof. Preferably, the noble metal component is selected from the group consisting of iridium, rhodium, osmium, ruthenium, rhenium and mixtures thereof. Most preferably, the noble metal component is rhodium, iridium and mixtures thereof. Typically, the amount of the noble metal component useful in the present invention, calculated as the metal, is at least 0.1 parts per million, preferably at least 0.5 parts per million, most preferably at least 1.0 part per million. In a preferred embodiment of the invention, the amount of the noble metal component ranges from about 0.1 parts per million to about 1.0 wt%, preferably from about 0.5 parts per million to about 5,000 parts per million, most preferably from about 1.0 part per million to about 2,500 parts per million, based on the total weight of the NO _x reduction composition. [0067] The noble metal component may be added as a component of the the NO _x reduction composition using any method known in the art, e.g., ion exchange, impregnation and the like. The noble metal component may be added to the NO _x reducing zeolite prior to incorporation into the NO _x reduction composition. In the alternative, the noble metal component may be added to particles incorporating the NO _x reducing zeolite to form a particulate NO _x reduction composition as described herein above, or to integral catalyst particles comprising the NO _x reducing composition and components of the FCC cracking catalyst. Suitable sources of the noble metal and the optional stabilizing component include aqueous solutions of nitrate, chloride, carbonate and sulfate salts, amine complexes, and the like. The salts or complexes are used in an amount sufficient to provide at least 0.1 parts per million of the noble metal, measured as the metal, in the final composition. Thereafter the composition is dried or calcined to remove volatiles, e.g., drying at about 100°C to about 25O ⁰ C for up to 24 hours or calcining at about 25O ⁰ C to about 900 ⁰ C for up to about 12 hours. [0068] Additional materials optionally present in the compositions of the present invention include, but are not limited to, fillers (e.g., kaolin clay) or matrix materials

(e.g., alumina, silica, silica-alumina, yttria, lanthana, ceria, neodymia, samaria, europia, gadolinia, titania, zirconia, praseodymia and mixtures thereof). When used, the additional materials are used in an amount which does not significantly adversely affect the performance of the compositions to reduce NO _x emissions released from the FCCU regenerator under FCC conditions. In general, the additional materials will comprise no more than about 70 weight percent of the compositions. It is preferred, however, that the NO _x reduction compositions of the invention consist essentially of the NO _x reducing zeolite, at least one noble metal and an inorganic binder.

[0069] It is also within the scope of the invention to include additional zeolite components in the NO _x reduction compositions of the invention. The additional zeolite component may be any zeolite which does not adversely affect the performance of the composition to minimize the amount of gas phase reduction nitrogen species in the FCCU regenerator during an FCC process. Preferably, the additional zeolite component is ZSM-5. Typically, the additional zeolite component is used in an amount ranging from about 1 to about 80, preferably from about 10 to about 70, weight percent of the catalyst/additive compositions. Where the NO _x reduction zeolite is used as an integral component of the catalyst, the additional zeolite component is preferably used in an amount ranging from about 0.1 to about 60, most preferably from about 1 to about 40, weight percent of the catalyst composition.

[0070] It is further within the scope of the present invention to include in the process and composition of the invention other additives conventionally used in FCC process, e.g., SO _x reduction additives, NO _x reduction additives, gasoline sulfur reduction additives, CO combustion promoters, additives for the production of light olefins, and the like. [0071] Somewhat briefly, the FCC process involves the cracking of heavy hydrocarbon feedstocks to lighter products by contacting the feedstock in a cyclic catalyst recirculation cracking process with a circulating fluidizable catalytic cracking catalyst inventory consisting of particles having a mean particle size ranging from about 50 to about 150 μm, preferably from about 60 to about 120 μm. The catalytic cracking of these relatively high molecular weight hydrocarbon feedstocks result in the production of a hydrocarbon product of lower molecular weight. The significant steps in the cyclic FCC process are:

(i) the feed is catalytically cracked in a catalytic cracking zone, normally a riser cracking zone, operating at catalytic cracking conditions by contacting feed with a source of hot, regenerated cracking catalyst to produce an effluent comprising cracked products and spent catalyst containing coke and strippable hydrocarbons; (ii) the effluent is discharged and separated, normally in one or more cyclones, into a vapor phase rich in cracked product and a solids rich phase comprising the spent catalyst;

(iii) the vapor phase is removed as product and fractionated in the FCC main column and its associated side columns to form gas and liquid cracking products including gasoline;

(iv) the spent catalyst is stripped, usually with steam, to remove occluded hydrocarbons from the catalyst, after which the stripped catalyst is oxidatively regenerated in a catalyst regeneration zone to produce hot, regenerated catalyst which is then recycled to the cracking zone for cracking further quantities of feed.

[0072] Conventional FCC catalysts include, for example, zeolite based catalysts with a faujasite cracking component as described in the seminal review by Venuto and Habib, Fluid Catalytic Cracking with Zeolite Catalysts, Marcel Dekker, New York 1979, ISBN 0-8247-6870-1 as well as in numerous other sources such as Sadeghbeigi, Fluid Catalytic Cracking Handbook, Gulf Publ. Co. Houston, 1995, ISBN 0-88415-290-1. Typically, the FCC catalysts consist of a binder, usually silica, alumina, or silica-alumina, a Y type zeolite acid site active component, one or more matrix aluminas and/or silica-aluminas, and fillers such as kaolin clay. The Y zeolite may be present in one or more forms and may have been ultra stabilized and/or treated with stabilizing cations such as any of the rare earths.

[0073] Typical FCC processes are conducted at reaction temperatures of 48O ⁰ C to 600°C with catalyst regeneration temperatures of 600°C to 800°C. As it is well known in the art, the catalyst regeneration zone may consist of a single or multiple reactor vessels. The compositions of the invention may be used in FCC processing of any typical hydrocarbon

feedstock. Suitable feedstocks include petroleum distillates or residuals of crude oils, which, when catalytically cracked, provide a gasoline or a gas oil product. Synthetic feeds having boiling points of about 204 ⁰ C to about 816 ⁰ C, such as oil from coal, tar sands or shale oil, can also be included.

[0074] In order to remove coke from the catalyst, oxygen or air is added to the regeneration zone. This is performed by a suitable sparging device in the bottom of the regeneration zone, or if desired, additional oxygen is added to the dilute phase of the regeneration zone. In the present invention, an under-stoichiometric quantity of oxygen is provided to operate the regeneration zone in a partial or incomplete combustion mode. For purposes of this invention, the regeneration zone is operated in a partial or incomplete combustion mode, when any one of the following conditions is satisfied: (1) there is not sufficient air or oxygen added to the regenerator to convert all the carbon, hydrogen, sulfur and nitrogen in the coke on the spent cracking catalyst to CO ₂ , H ₂ O, SO ₂ and NO; (2) the effluent from the regenerator does not contain enough oxygen to convert all CO and any other reduced nitrogen or sulfur species and hydrocarbons in the regenerator effluent to CO ₂ , H ₂ O, SO ₂ and NO; and/or (3) sufficient amount of CO is present in the regenerator effluent to require the use of a CO boiler to treat the regenerator effluent and convert the CO contained in the effluent to CO ₂ before having the FCCU regenerator effluent discharged into the atmosphere.

[0075] The presence of the compositions in accordance with the invention during the catalyst regeneration step dramatically reduces the emissions of gas phase reduced nitrogen species in the FCCU regenerator effluent. By removing the gas phase reduced nitrogen species from the effluent of the FCCU regenerator, significant reduction of NO _x emissions from the CO boiler is achieved. In some cases, NO _x reduction up to 90% is readily achievable using the compositions and method of the invention. However, as will be understood by one skilled in the catalyst art, the extent of reduced nitrogen species and NO _x reduction will depend on such factors as, for example, the composition and amount of the additive utilized; the design and the manner in which the catalytic cracking unit is operated, including but not limited to, the amount of oxygen used and distribution of air in the regenerator, catalyst bed depth in the regenerator, stripper operation and

regenerator temperature, the properties of the hydrocarbon feedstock cracked, the presence of other catalytic additives that may affect the chemistry and operation of the regenerator, and the design and operation of the CO boiler which impacts the conversion of reduced nitrogen species to NO _x and the formation of thermal NO _x . Thus, since each FCCU is different in some or all of these respects, the effectiveness of the process of the invention may be expected to vary from unit to unit. NO _x reduction compositions of the invention also prevent a significant increase in the production of coke during the FCC process, e.g., less than 20%, preferably less than 10%, relative to the production of coke absent the NOx reduction composition.

[0076] It is further expected that overall NO _x emissions will be advantageously even lower when the invention is used in combination with a CO boiler designed to make the lowest amount of thermal NO _x practical. Typical FCC CO boilers are older technology and are not optimized for minimum thermal NO _x emissions. However they can be replaced or retrofitted with upgrades to state-of-the-art low NO _x designs, including retrofitting with low NO _x burners. Low NO _x burner design approaches and features are described e.g., in appropriate sections in "The John Zinlc Combustion Handbook", editor, Charles E. Baulkal, Jr., published by the CRC Press, 2001, which descriptions are herein incorporated by reference. The formation of NO _x is minimized by avoiding both high temperature and high excess oxygen zones using flame back mixing, exhaust gas recycle to the burner make-up air, staged fuel injection, intense swirl mixing of air and fuel, longer cooler flames, and various combinations of any or all of these design strategies. The present invention enables the benefits of low NO _x burner technology to be realized from an FCC CO boiler so modified, by minimizing the reduced nitrogen species available to be oxidized therein to NO _x . The result is a new low NO _x partial or incomplete burn FCC system that can eliminate the need for capital and operating cost- intensive systems like SCR, SNCR, scrubbers, and other approaches known in the art. [0077] To further illustrate the present invention and the advantages thereof, the following specific examples are given. The examples are given as specific illustrations of the claimed invention. It should be understood, however, that the invention is not limited to the specific details set forth in the examples.

[0078] AU parts and percentages in the examples as well as the remainder of the specification which refers to solid compositions or concentrations are by weight unless otherwise specified. However, all parts and percentages in the examples as well as the remainder of the specification referring to gas compositions are molar or by volume unless otherwise specified.

[0079] Further, any range of numbers recited in the specification or claims, such as that representing a particular set of properties, units of measure, conditions, physical states or percentages, is intended to literally incorporate expressly herein by reference or otherwise, any number falling within such range, including any subset of numbers within any range so recited.

EXAMPLES

EXAMPLE 1

[0080] A composition comprising 75% ferrierite and 25% alumina sol (Additive A) was prepared as follows. An aqueous slurry was prepared which contained 652 Ig of aluminum chlorohydrol solution (23% solids), 4500 g (dry basis) of ferrierite (SiO ₂ ZAl ₂ O ₃ = 20, Na ₂ O + K ₂ O < 0.2) and enough additional water to make a slurry which contained about 40% solids. The slurry was milled, in a Drais mill, to an average particle size of less than 2.5 μm and then spray dried in a Bowen spray dryer. The spray dried product was calcined for 90 minutes at 593 ⁰ C. This sample was designated as Additive A and the properties of this additive are shown in Table 1.

EXAMPLE 2

[0081] About 158 g of Additive A was placed in an inclined beaker on a mechanical rotator. A master Rh solution was prepared by diluting 1.00 Ig RIi from nitrate salt (9% Rh) to 100 g with DI water. The calcined product was then impregnated by gradually spraying on it 16.7 g of the dilute Rh solution further diluted with 75 g DI water, targeting a concentration of 100 ppm Rh on the finished catalyst. The wet impregnated catalyst was dried for 1 hour at 99°C and then calcined for 1 hour at 593 ⁰ C. The finished catalyst was designated Additive B.

EXAMPLE 3

[0082] Additive C was prepared using ferrierite which contained Na and K cations (about 1.02 % Na ₂ O and 7.08% K ₂ O). An aqueous slurry was prepared which contained 41%

solids. The solids in the slurry consisted of 75% ferrierite (sodium and potassium content not included) and 25% alumina from an aluminum chlorohydrol solution (23% solids). The slurry was milled to an average particle size of less than 2.5 μm and then spray- dried. The spray dried product was calcined for about 1 hour at about 425 ⁰ C and then washed with sufficient amount of an aqueous ammonium sulfate solution (30% (NH ₄ ^SO ₄ ) to reduce the sodium and potassium content. The washed product was then flash-dried and stored. The final product had the properties shown in Table 2.

EXAMPLE 4

[0083] Additive C was impregnated with Rh, dried and calcined using the same procedure described in Example 2 except that the amount of additive C used was 200 g (dry basis), and the impregnating solution was made with 0.165 g of a rhodium nitrate solution (12.11% Rh) and 180 g of DI water. The finished catalyst was designated as Additive D, contained 92 ppm Rh, 66% SiO ₂ , 33.6% Al ₂ O ₃ , 0.15% Na ₂ O, 0.7% K ₂ O, 1.5% SO ₄ , and had a surface area of 301 m ² /g.

Table 1

Properties of Additive A

Al ₂ O ₃ % 28.3

Na ₂ O % 0.09

RE ₂ O ₃ % 0.08

SiO ₂ % 71.4

SO ₄ % 0.01

Surface Area m ² /g 328

Zeolite Surface Area m ² /ε 259

Table 2

Properties of Additive C

Al ₂ O ₃ % 33

Na ₂ O % 0.15

RE ₂ O ₃ % 0.4

SiO ₂ % 67

SO ₄ % 1.5

K ₂ O % 0.7

Surface Area m ² /g 298

Zeolite Surface Area m /g 247

EXAMPLE 5

[0084] Additive E was prepared by talcing a sample of 80 g of Additive C and impregnating the sample to a target of 200 ppm Ir by incipient wetness using a dilute solution of 0.029 g of pentamine chloro iridium (III) dichloride (49.9% Ir in the salt) and 61 g DI water. The impregnated catalyst was dried at 120 °C overnight and calcined for 2 hours at 649 °C.

EXAMPLE 6

[0085] Additive F was prepared by taking a sample of 80 g of Additive C and impregnating the sample to a target of 200 ppm Pt by incipient wetness using a dilute solution of 0.503 g platinum tetramine nitrate solution (2.9% Pt) and 61 g of DI water.

The impregnated catalyst was dried at 120 °C overnight and calcined for 2 hours at 649 °C.

EXAMPLE 7

[0086] Additive G was prepared by taking a sample of 109 g of Additive C and impregnating the sample to a target of 100 ppm Pd by incipient wetness using 0.118 g of a palladium nitrate solution (8.46% Pd) and 83 g of DI water. The impregnated catalyst was dried at 120 ⁰ C overnight and calcined for 2 hours at 649 °C.

EXAMPLE 8

[0087] Additive H was prepared by taking a sample of 109 g of Additive C and impregnating the sample to a target of 100 ppm Ru by incipient wetness using 0.667 g of a ruthenium nitrosyl nitrate solution (1.5% Ru) and 83 g DI water. The impregnated catalyst was dried at 120 ⁰ C overnight and calcined for 2 hours at 649 ⁰ C.

EXAMPLE 9

[0088] Additive I was prepared by taking a sample of 109 g of Additive A and impregnating the sample to a target of 100 ppm Rh and 50 ppm Ir by incipient wetness using 0.083 g of rhodium nitrate solution (12.11% Rh), 0.010 g of pentamine chloro iridium (III) dichloride (49.9% Ir in the salt) and 83 g DI water. The impregnated catalyst was dried at 120 ⁰ C overnight and calcined for 2 hours at 649 °C.

EXAMPLE 10

[0089] Additive J was prepared by impregnating 45.35 kg of Additive C with 100 ppm Rh as follows: Additive C was placed in an Eirich mixer and then impregnated with a Rh solution containing 36 g of a rhodium nitrate solution (11.4% Rh) and 20.4 kg of water. The impregnated material was then dried overnight at 149 ⁰ C and finally calcined at 593 ⁰ C for 1 hour. The final Additive J contained 93 ppm Rh, 64% SiO ₂ , 32.2% Al ₂ O ₃ , 0.17% Na ₂ O, 0.7% K ₂ O ₅ 1.4% SO ₄ , and had a surface area of 292 m ² /g.

EXAMPLE 11

[0090] The activity of Additive B for reducing NH ₃ emissions from an FCC unit was evaluated by using the Davison Circulating Riser (DCR). The description of the DCR has been published in: (a) G. W. Young, G. D. Weatherbee, and S. W. Davey, "Simulating Commercial FCCU yields with the Davison Circulating Riser (DCR) pilot plant unit," National Petroleum Refiners Association (NPRA) Paper AM88-52; and (b) G. W. Young, "Realistic Assessment of FCC Catalyst Performance in the Laboratory," in Fluid Catalytic Cracking: Science and Technology, J. S. Magee and M. M. Mitchell, Jr. Eds., Studies in Surface Science and Catalysis Volume 76, p. 257, Elsevier Science Publishers B.V., Amsterdam 1993, ISBN 0-444-89037-8, which descriptions are herein incorporated by reference. A commercial FCC feed having the properties shown in Table 3 was used for these tests. The DCR was initially charged with approximately 1900 g of an equilibrium cracking catalyst having the properties shown in Table 4. The DCR regenerator was operated at 705 ⁰ C and the air flow rate was adjusted so as to achieve a CO ₂ /CO ratio of 7.0 and virtually no O ₂ in the regenerator flue gas. After stabilization of the unit, the baseline NH ₃ emissions data were collected using a MKS Online Products FTIR multigas analyzer (model 2030). Subsequently, 100 g of a blend containing 10 g of Additive B and 90 g of the equilibrium cracking catalyst was injected into the DCR and NH ₃ emissions were continuously collected for about 1.5 hours. No increase in NO

emissions was detected upon injection of Additive B. Also no other nitrogen oxides (e.g., NO ₂ or N ₂ O) were detected during this test. As shown in Figure 1 and Table 5, Additive B is effective in reducing NH ₃ emissions even when used at 0.5 wt.% of the overall catalyst inventory. These data demonstrate that Additive B is very efficient at converting reduced nitrogen species to molecular N ₂ in the FCC unit regenerator.

Table 3 Properties of the FCC feed used in DCR tests of Examples 11 and 13

API Gravity @60 ⁰ F 23.2

Sulfur, wt.% 0.02

Total Nitrogen, wt.% 0.13

Basic Nitrogen, wt.% 0.04

Conradson Carbon, wt.% 0.03

K Factor 11.40

Simulated Distillation, vol. % at ⁰ F

5 453

20 576

40 660

60 743

80 838

Final Boiling Point 1153

Table 4 Properties of equilibrium cracking catalyst used in the DCR test of Example 11

SiO ₂ wt.% 49.01

Al ₂ O ₃ wt.% 46.05

RE ₂ O ₃ wt.% 1.44

Na ₂ O wt.% 0.32

TiO ₂ wt.% 1.16

Ni ppm 1060

V ppm 1760

Sb ppm 270

SA m ² /g 174

Zeolite m ² /g 127

Table 5

NH ₃ reduction by Additive B in the DCR regenerator operating in partial burn mode

Average NH ₃ NH ₃ emissions after

Additive Level emissions with 1.5 hours on-stream NH ₃ reduction

(wt.%) equilibrium catalyst with Additive B

(ppmv) (ppmv)

0.5 128 69 46

EXAMPLE 12

[0091] The activity of Additives D through I to reduce NH ₃ emissions from an FCC unit regenerator operating in partial burn or incomplete combustion was compared to the activity of the cracking catalyst alone. The experiments were conducted by reacting NH ₃ with CO at various levels of O ₂ in a Regenerator Test Unit (RTU). The RTU is a lab-scale reactor system specifically designed to simulate the operation of a FCC unit regenerator. The RTU is described in detail in G. Yaluris and A. W. Peters "Studying the Chemistry of the FCCU Regenerator Under Realistic Conditions," Designing Transportation Fuels for a Cleaner Environment, J.G. Reynolds and M.R. Khan, eds., p. 151, Taylor & Francis, 1999, ISBN: 1-56032-813-4, which description is herein incorporated by reference. After calcination for 2 hours at 593 ⁰ C, each additive was blended at 0.5 wt% level with a commercially available FCC catalyst (OCTACAT®-DCH, obtained from Grace Davison), which had been deactivated for 4 hours at 816 °C in a fluidized bed reactor with 100% stream. The cracking catalyst alone, or the additive/cracking catalyst blend was fed to the RTU reactor operating at 700 ⁰ C. The gas feed to the RTU was a mixture of NH ₃ and CO containing approximately 500 ppm NH ₃ , 5000-5500 ppm CO, and various amounts of O ₂ added as 4% O ₂ in N ₂ , with the balance being nitrogen. The total gas feed rate excluding the O ₂ containing gas feed was 1000-1100 seem. All additives were effective in converting NH ₃ in excess of 99%. As observed in Figure 2, all Additives are also effective in minimizing the conversion of NH ₃ to NO. However, Additives D, E and I are the most effective in minimizing conversion of NH ₃ to NO. No other nitrogen oxides (e.g., NO ₂ or N ₂ O) were detected, indicating the conversion to molecular nitrogen of any NH ₃ not converted to NO.

EXAMPLE 13

[0092] The activity of Additive B for reducing NO emissions from the FCC unit regenerator was evaluated in the DCR under full burn regeneration conditions with the same commercial FCC feed shown in Table 3. The DCR was operated with 1% excess

O ₂ in the regenerator, and with the regenerator at 705 ⁰ C. The DCR was charged initially with approximately 1800 g of a commercially available cracking catalyst,

SUPERNOVA® DMR+ obtained from Grace Davison. The cracking catalyst was hydro thermally deactivated in a fluidized bed reactor with 100% steam for 4 h at 816 ⁰ C. After stabilization of the unit, the baseline NO emissions data were collected using an online Lear-Siegler SO ₂ /NO Analyzer (SM8100A). Subsequently, a blend of 100 g of catalyst was added to the DCR consisting of 95.25 g of the hydrothermally deactivated

SUPERNOVA® DMR+ catalyst and 4.75 g of a commercially available conventional CO combustion promoter (CP-3®, obtained from Grace Davison), which had been deactivated for 20 hours at 788 ⁰ C without any added Ni or V using the Cyclic Propylene Steaming method (CPS). The CPS method has been described in L. T. Boock, T. F. Petti, and J. A Rudesill, "Contaminant-Metal Deactivation and Metal-Dehydrogenation Effects During Cyclic Propylene Steaming of Fluid Catalytic Cracking Catalysts," Deactivation and Testing of Hydrocarbon Processing Catalysts, ACS Symposium Series 634, p. 171 (1996), ISBN 0-8412-3411-6, which description is herein incorporated by reference. NO emissions data were continuously collected, and once the unit was again stabilized, a blend containing 0.525g of the deactivated CP-3 ^® with 26.25 g of Additive B and 183.75 g of the deactivated SuperNova® DMR+ catalyst was added to the DCR. The NO emissions data is shown Table 6. It can be observed from these data that Additive B is effective for reducing NO emissions in the FCC unit regenerator.

Table 6 NO reduction by Additive B in the DCR regenerator operating in full burn mode

Average NO emissions NO emissions after

Additive Level with equilibrium catalyst 3 hours on Additive ^Q reduction

(wt.%) and 0.25% CP-3 added B ₍ o _λ

(ppmv) (ppmv)

1.25 263 180 32

EXAMPLE 14

[0093] The activity of Additives D through I for reducing NO emissions from the FCCU regenerator was assessed by measuring the activity for catalyzing the reduction of NO by CO in the RTU. After calcination for 2 hours at 593°C, each additive was blended at 0.5% level with a FCC catalyst, OCTACAT ^® -DCH obtained from Grace Davison, which had been deactivated for 4 hours at 816 ⁰ C in a fluidized bed reactor with 100% steam. The cracking catalyst alone or the blend was then fed to the RTU reactor operating at 700 ⁰ C. The gas feed to the reactor was a mixture containing approximately 5000-5500 ppm CO, 500-550 ppm NO, various amounts of oxygen added as 4% O ₂ ZN ₂ , and the balance nitrogen. The total gas feed rate excluding the O ₂ containing gas feed was 1000- 1100 seem. The amount of oxygen during this experiment was varied so that the conditions in the RTU reactor would simulate reducing and oxidizing areas of an FCCU regenerator. The results are shown in Figure 3. The data show that with the exception of Additive G, all additives are effective in reducing NO emissions. However, Additives D, E and I are the most effective in reducing NO emissions.

EXAMPLE 15

[0094] The CO oxidation activity of Additives E through J was assessed in the RTU using a cracking catalyst coked in the Davison Circulating Riser (DCR). The FCC catalyst, OCTACAT ^Φ -DCH obtained from Grace Davison, Columbia, MD, was first deactivated for 4 hours at 816 ⁰ C in a fluidized bed reactor with 100% steam before being coked by being circulated in the DCR to react with a FCC feed. The properties of the coked catalyst are shown in Table 7 below. For comparison purposes, the CO oxidation activity of a conventional CO combustion promoter (CP-3® obtained from Grace Davison), which had been deactivated for 20 hours at 788 ⁰ C without any added Ni or V using the CPS method, was also evaluated. Each additive tested was mixed with the coked cracking catalyst at 0.2 wt.% (Additives E-J) or 0.1 wt.% additive level (CP-3 ^® ). The coked catalyst or the blend was then fed into the RTU reactor operating at 700 ⁰ C respectively, and the coke was burnt with a gas mixture of air and nitrogen so that there was 1.1% O ₂ in the RTU reactor effluent. The CO measured at the reactor effluent is a measure of the CO combustion activity under catalytic cracking conditions and the actual amount of CO present is inversely correlated to the CO oxidation activity of the additive. The results recorded in Table 8 below show that Additives E through J are not effective as CO combustion promoters even when used at twice the amount of the conventional CO promoter.

Table 7 Properties of coked catalyst used in Example 15

SiO ₂ wt% 53.4

AI ₂ O ₃ wt% 43.5

RE ₂ O ₃ wt% 0.14

Na ₂ O wt% 0.43

SO ₄ wt% 0.67

Fe ₂ O ₃ Wt% 0.59

TiO ₂ wt% 0.99

C wt% 0.87

Surface Area m ² /g 189

Table 8

CO emissions during coked FCC catalyst regeneration in the RTU with Additives E through J and CP-3 ^® blended with the coked catalyst

Additive Amount CO emissions

(Wt. %) (ppmv)

No additive 3440

CP-3 ^® 0.1 750

Additive E 0.2 2100

Additive F 0.2 1740

Additive G 0.2 3520

Additive H 0.2 3410

Additive I 0.2 1850

Additive J 0.2 3100

[0095] Although the present invention has been primarily described in conjunction with examples and by reference to embodiments thereof, it is evident that many alternatives, modifications and variations will be apparent to those skilled in the art in light of the foregoing description. Accordingly, it is intended to embrace within the invention all such alternatives, modifications and variations that fall within the spirit and scope of the appended claims.