# US 7,744,745 B2 · Process for fluid catalytic cracking of hydrocarbon feedstocks with high levels of basic nitrogen > Agents: this data is available as JSON from the patentgrep API and MCP server — see https://patentgrep.com/llms.txt - Number: US 7,744,745 B2 - Document ID: US7744745B2 - Status: Granted - Kind: B2 - Application number: 12/166,779 - Filed: 2008-07-02 - Published: 2009-04-02 - Granted: 2010-06-29 - Earliest claimed: 2003-10-22 - Assignees: Petroleo Brasileiro S.A. - Petrobras - Inventors: Claudia Maria de L. Alvarenga Baptista; Elizabeth M. Moreira; Henrique Soares Cerqueira - Web page: https://patentgrep.com/patent/US7744745B2 ## CPC - C10G 51/06: plural parallel stages only - C10G 11/05: Crystalline alumino-silicates, e.g. molecular sieves - C10G 11/18: according to the "fluidised-bed" technique - C10L 1/04: essentially based on blends of hydrocarbons - C10G 2300/107: Atmospheric residues having a boiling point of at least about 538 °C - C10G 2300/1074: Vacuum distillates - C10G 2300/1077: Vacuum residues - C10G 2300/202: Heteroatoms content, i.e. S, N, O, P - C10G 2300/301: Boiling range - C10G 2300/308: Gravity, density, e.g. API - C10G 2400/02: Gasoline - C10G 2400/28: Propane and butane - C10L 2200/0438: Middle or heavy distillates, heating oil, gasoil, marine fuels, residua - C10G: CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION (cracking to hydrogen or synthesis gas C01B; cracking or pyrolysis of hydrocarbon gases to individual hydrocarbons or mixtures thereof of definite or specified constitution C07C; cracking to cokes C10B); RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES - C10L: FUELS NOT OTHERWISE PROVIDED FOR; NATURAL GAS; SYNTHETIC NATURAL GAS OBTAINED BY PROCESSES NOT COVERED BY SUBCLASSES C10G OR C10K; LIQUIFIED PETROLEUM GAS; USE OF ADDITIVES TO FUELS OR FIRES; FIRE-LIGHTERS ## Abstract A process is described for fluid catalytic cracking of hydrocarbons with high levels of basic nitrogen, where hydrocarbon feedstocks A and B with different levels of basic nitrogen are injected in a segregated fashion, into different risers of a multiple riser FCCU that possesses at least two risers. The injection of the feedstocks is made in such a way that feedstock A, to be injected in the riser with greater volume—main riser 7—possessing a level of basic nitrogen at least 200 ppm lower than the level of feedstock B to be injected into the riser with lower volume—secondary riser (8). ## Claims ### Claim 1 A process for fluid catalytic cracking of hydrocarbon feedstocks with high levels of basic nitrogen, in a multiple riser FCCU, operating with feedstocks A and B, wherein the process comprises the following steps: a) placing in contact with a zeolite catalyst, in a main riser of the FCCU, a hydrocarbon feedstock A which possesses a level of basic nitrogen at least 200 ppm lower than feedstock B that is being processed in a secondary riser of the FCCU; b) simultaneously, placing in contact with the zeolite catalyst, in the secondary riser of the FCCU, a hydrocarbon feedstock B comprised of a mixture made up of between 95 and 40%, in volume, of hydrocarbon streams with a content of catalyst-damaging basic nitrogen of between 1000 and 3500 ppm, and between 5 and 60%, by weight, of a cooling fluid capable of increasing a circulation in the secondary riser and of cooling a regenerator, in order to adjust the thermal balance of the FCCU and maintain a circulation of the catalyst in the main riser, at proper levels, so that a catalyst/oil ratio remains in a range of between 4.5 and 8.5; c) maintaining the operation of the FCCU within the conditions of catalytic cracking; d) recovering from a tube products of the cracking reaction with an increase in conversion of bottom fractions, a greater proportion of gasoline and LPG, at the same time with a lower proportion of coke and combustible gas; e) recovering from a catalyst separation device spent catalyst and passing the spent catalyst to a regenerator for removing coke from the spent catalyst and regenerating the zeolite catalyst; and f) separating the regenerated zeolite catalyst; and g) passing the regenerated zeolite catalyst to the main riser and the secondary riser wherein the regenerated zeolite catalyst is extracted from a single zone within the regenerator. ### Claim 2 (depends on 1) The process according to claim 1, wherein the FCCU includes a main riser and two secondary risers. ### Claim 3 (depends on 1) The process according to claim 1, wherein the FCCU includes a main riser and three or more secondary risers. ### Claim 4 (depends on 1) The process according to claim 1, wherein said hydrocarbon feedstock A comprises a heavy hydrocarbon stream with a boiling point of between 340° C. and 560° C. and an ° API of between 8 and 28. ### Claim 5 (depends on 4) The process according to claim 4, wherein the heavy hydrocarbon flow stream of feedstock A comprises vacuum treated heavy gas oil, direct distillation heavy gas oil, atmospheric residue, vacuum residue, deasphalted oil, or a mixture of any proportion thereof. ### Claim 6 (depends on 5) The process according to claim 5, wherein a heavy hydrocarbon stream of feedstock A is a vacuum-treated heavy gas oil with a boiling point of between 380° C. and 540° C. and an ° API of between 15 and 22. ### Claim 7 (depends on 4) The process according to claim 4, wherein the heavy hydrocarbon flow stream of feedstock A comprises isolated streams and mixtures between streams that have levels of catalyst damaging basic nitrogen of between 200 and 3500 ppm. ### Claim 8 (depends on 1) The process according to claim 1, wherein hydrocarbon feedstock A possesses a level of basic nitrogen of at least 500 ppm lower than feedstock B that is being processed in the secondary riser of the FCCU. ### Claim 9 (depends on 1) The process according to claim 1, wherein hydrocarbon feedstock A possesses a level of basic nitrogen at least 1000 ppm lower than feed B that is being processed in the secondary riser of the FC0U. ### Claim 10 (depends on 1) The process according to claim 1, wherein hydrocarbon feedstock A possesses a level of basic nitrogen 3500 ppm lower than feedstock B that is being processed in the secondary riser of the FCCU. ### Claim 11 (depends on 1) The process according to claim 1, wherein the catalyst is a conventional zeolite type for FCC processes of heavy feedstocks containing basic nitrogen, with around 30% zeolite dispersed in an inorganic porous carrier. ### Claim 12 (depends on 1) The process according to claim 1, wherein feedstock B of hydrocarbons with levels of catalyst-damaging basic nitrogen of between 1000 and 3500 ppm is a heavy hydrocarbon stream with a boiling point of between 340° C. and 560° C. and an ° API of between 8 and 28. ### Claim 13 (depends on 12) The process according to claim 12, wherein said heavy hydrocarbon stream of feedstock B comprises vacuum treated heavy gas oil, direct distillation heavy gas oil, atmospheric residue, vacuum residue, deasphalted oil, or a combination of any proportion thereof. ### Claim 14 (depends on 13) The process according to claim 13, wherein one of said heavy hydrocarbon stream of feedstock B to be a deasphalted oil, with an initial boiling point of between 320 and 390° C. and an ° API of between 12 and 18. ### Claim 15 (depends on 1) The process according to claim 1, wherein the cooling fluid in the secondary riser of b) is a light hydrocarbon stream with boiling point between 32 and 350° C. and with a density at 20/4° C. of between 0.7 and 1. ### Claim 16 (depends on 15) The process according to claim 15, wherein a light hydrocarbon stream is added in proportion of between 5 and 60% by volume of the total stream B. ### Claim 17 (depends on 1) The process according to claim 1, wherein the cooling fluid of the secondary riser is an inert stream. ### Claim 18 (depends on 17) The process according to claim 17, wherein said inert stream is water in proportion of between 5 and 10% by volume of the total stream B. ### Claim 19 (depends on 1) The process according to claim 1, wherein the hydrocarbon feedstocks A and B are introduced into the main riser and the secondary riser at temperatures between 100 and 450° C. ### Claim 20 (depends on 19) The process according to claim 19, wherein hydrocarbon feedstocks A and B are introduced into the main riser and the secondary riser at temperatures of between 240 and 360° C. ### Claim 21 (depends on 1) The process according to claim 1, wherein reaction temperatures in the main riser and the secondary riser are controlled at between 510 and 570° C. ### Claim 22 (depends on 21) The process according to claim 21, wherein reaction temperatures in main riser and the secondary riser are controlled at between 520 and 560° C. ### Claim 23 (depends on 1) The process according to claim 1, wherein the regenerated catalyst which leaves the regenerator to enter into the main riser and the secondary riser to be at temperatures of between 650 and 750° C. ### Claim 24 (depends on 23) The process according to claim 23, wherein the regenerated catalyst which leaves the regenerator to enter into the main riser and the secondary riser to be at temperatures of between 680 and 732° C. ### Claim 25 (depends on 1) The process according to claim 1, wherein the residence time of the catalyst particles, in the main riser and the secondary riser fluctuates between 0.3 and 8 seconds. ### Claim 26 (depends on 24) The process according to claim 24, wherein the residence time of the catalyst particles, in the main riser and the secondary riser fluctuates between one and five seconds.