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Publication numberUS3928172 A
Publication typeGrant
Publication dateDec 23, 1975
Filing dateJul 2, 1973
Priority dateJul 2, 1973
Publication numberUS 3928172 A, US 3928172A, US-A-3928172, US3928172 A, US3928172A
InventorsDavis Jr Francis E, Graven Richard G, Lee Wooyoung, Sailor Robert A
Original AssigneeMobil Oil Corp
Export CitationBiBTeX, EndNote, RefMan
External Links: USPTO, USPTO Assignment, Espacenet
Catalytic cracking of FCC gasoline and virgin naphtha
US 3928172 A
Abstract
A combination process is described for improving the quality and volatility of a refinery gasoline pool comprising the recracking of gasoline product of gas oil cracking and separate product recovery thereof, cracking of virgin naphtha and alkylating olefins formed in the combination process for blending with pool gasoline.
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United States Patent [191 Davis, Jr. et al.

[ Dec. 23, 1975 CATALYTIC CRACKING OF FCC GASOLINE AND VIRGIN NAPHTHA [75] Inventors: Francis E. Davis, Jr., Woodbury;

Richard G. Graven; Wooyoung Lee, both of Westmont; Robert A. Sailor, Riverton, all of NJ.

[73] Assignee: Mobil Oil Corporation, New York,

[22] Filed: July 2, 1973 [21] Appl. No.: 376,091

[52] US. Cl. 208/77; 208/ 16; 208/72;

[51] Int. Cl. ...B01J 29/28; C10G 11/04;

[58] Field of Search 208/72, 73, 77, 120

[56] References Cited UNITED STATES PATENTS 2,376,501 5/1945 Nelson et al 208/14 2,406,394 8/1946 Newton 208/74 2,425,555 8/1947 Nelson 208/70 2,426,903 9/1947 Sweeney 208/67 2,921,014 l/l960 Marshall 208/74 2,981,674 4/1961 Good 208/70 3,247,098 4/1966 Kimberlin 208/120 3,284,341 11/1966 Henke et a1, 3,679,576 7/1972 McDonald 3,706,654 12/1972 Bryson et al 208/74 3,748,251 7/1973 Demmel et al. 208/74 3,758,403 9/1973 Rosinski et al. 208/120 3,758,628 9/1973 Strickland et a1 260/683.43 3,761,391 7/1973 Conner 3,761,394 7/1973 Reynolds et al.

3,776,838 12/1973 Youngblood et al.

3,784,463 1/1974 Reynolds et al.

3,816,294 6/1974 Wilson et a1. 208/67 Primary ExaminerDelbert E. Gantz Assistant Examiner--G. E. Schmitkons Attorney, Agent, or Firm-Charles Huggett; Michael G. Gilman; Carl D. Farnsworth [5 7] ABSTRACT A combination process is described for improving the quality and volatility of a refinery gasoline pool comprising the recracking of gasoline product of gas oil cracking and separate product recovery thereof,

cracking of virgin naphtha and alkylating olefins formed in the combination process for blending with pool gasoline.

10 Claims, 3 Drawing Figures U.S. Patent Dec. 23, 1975- Sheet 2 of3 3,928,172

FIGUREH Re. C0.

Hvy Nophfho Oil US. Patent Dec. 23, 1975 Sheet 3 0f? 3,928,172-

Cracked Gasoline 6 as 93 Reg on Gas F I G U R E ]]I CATALYTIC CRACKING OF FCC ANT) VIRGIN NAPHTHAL BACKGROUND OF THE INVENTION,

The fluid catalystsystem as we know it today'embodies the technique of utilizing finely divided solid particulatematerial in a fluid or a freely moving state such that a mass of solids can be circulated much in the same way as a liquid. Thus in catalytic cracking operations, the fluid catalyst is-caused td flow between and through a hydrocarbonconversion zone and aicatalyst regeneration zone. The catalyst has been used in dispersed and/or dense phase condition or combinations thereof to permit contact of reactant materials therewith followed by separation of catalyst particles from products of reaction. Thus the catalyst has been used either as a dense fluid bed of catalyst in the reaction and regeneration zones or passed in a dispersed phase condition upwardly through one'or both zones.

During World War II, the demands for large volumes of high octane gasoline suitable for military use prompted the recracking of gasoline products of thermal and catalytic gas oil crackingoperations over conventional amorphous silica-alumina catalysts in order to achieve high octane materials. Throughout the history of catalytic cracking, hydrocarbon materials insufficiently cracked to produce gasoline boiling range material have been recycled and subjected to further catalytic cracking. To improve the crackability of heavy recycle fractions, they may be subjected to a prehydrogenation treatment before further cracking thereof. Some early patents directed to the techniques above expressed are: Nelson US. Pat. No. 2,376,501 issued May 22, 1945; Newton US. Pat. No. 2,406,394 issued Aug. 27, 1946; Sweeney US. Pat. No. 2,426,903 issued Sept. 2, 1947; Nelson US. Pat. No. 2,425,555 issued Aug. 12, 1947 and Marshall US. Pat. No. 2,921,014 issued Jan. 12, 1960.

During the last decade cracking catalyst compositions comprising crystalline aluminosilicate zeolites have been widely adopted in both fluid and moving bed cracking operations. The use of these zeolite catalysts is so widespread that they represent over 90% of catalyst used in fluid operations today. They are used in dispersed phase riser reaction zones alone or in combination with dense catalyst phase; reaction zones. Most of these composite catalysts consist of a small percentage (5 to of the crystalline zeolite in a larger percentage of an amorphous cracking catalyst such as silica-alumina.

Currently the extreme difficulties encountered throughout the United States because of atmospheric pollution have imposed many requirements or potential requirements on motor fuels. Every effort is being made to reduce atmospheric pollution by products of combustion from automobiles. These efforts, in turn, result in specific detailed objectives with motor fuels. For example, reduced use of tetraethyllead is sought. This necessitates gasolines of high intrinsic octane number. Higher volatility is being considered to ensure good driveability of new engines. For instance, it has been recently proposed by General Motors to set the 50%, 90% and end boiling points of quality gasoline in the range of l90-2 l0F., 280320F. and 330380F. respectively.- Califomia has a bromine number specification for gasoline because olefins in 2 gasoline contribute to pollution. Since sulfur compounds also contribute to pollution, low' sulfur levels are sought.

To meet higher volatility requirements, it is necessary to reduce the boiling ranges of certain blending components of the'gasoline pool such as the gasoline product of catalytic cracking and reforming.

One simple route for lowering the 50% boiling point of gasoline is by undercutting the cracked stock or by lowering the end point ofareforming charge stock. However, this is a most expensive route for producing high volatility gasoline and in times of crude oil shortage, operates to fuels.

SUMMARY OF THE INVENTION It has been discovered that heavy cracked gasoline can be recracked over a zeolite-containing catalyst at particular operating conditions to provide an improved and modern approach to the production of gasoline satisfying stringent new quality specifications as now dictated by the need to reduce emissions from internal combustion engines.

The zeolite catalyst is able to effect a degree of octane improvement necessary for todays needs and not heretofore possible with amorphous silica-alumina catalysts. Moreover the zeolite catalyst effects significant volatility improvement and reduces olefins in the liquid cracked product to a level not practically attainable with a silica-alumina catalyst. Recracking removes the bulk of the sulfur from the heavy cracked gasoline. It produces high yields of propylene, butenes and isobutane which are valuable as alkylation charge stocks.

Cracking of a virgin heavy naphtha over zeolite catalyst effects large'improvements in octane number and volatility, not practical over silica-alumina. It produces gaseous olefins and isobutane, valuable as alkylation feed stocks. I i

There are a number of ways of accomplishing these benefits. As one alternative, cracked naphtha is recycled and/or virgin naphtha is added to a riser cracking zone along with a gas oil feed. A second alternative may involve a multi-stage operation in which a cracked naphtha is recracked or a virgin naphtha iscracked in a separate riser reactor or a dense fluid catalyst bed reactor. As a third alternative, the choice of conditions for cracking heavy cracked gasoline and heavy virgin naphtha can be met in a combination process in which heavy cracked gasoline is recracked at high temperature in a dense bed, gas oil is cracked in dispersed phase in a riser, and virgin naphtha is cracked at a lower temperature in a dense fluid catalyst bed.

DISCUSSION OF SPECIFIC EMBODIMENTS It has been found when following the concepts of this invention that the cracking of selected hydrocarbon fractions under particular operating conditions offers a greater portential in various refinery applications for producing high volatility gasoline, high octane blending stock, ligh t'olefins" for alkylation reactions, aromatic concentrates for use in petrochemicals, improved isobutane production and a reduction in olefin and sulfur in the gasoline product.

Exploratory studies of the concepts of the present invention were made in laboratory bench scale equipment which involved passing a heavy gasoline charge material over to 300 gms. of catalyst in fixed fluidized bed at preselected process conditions. Time on oppose the conservation of energy stream for each cycle of run was 5 minutes and after each cycle the reactor was purged and the catalyst regenerated in-situ. The products were cooled and weathered at 120F. The resulting liquid product was found to have 40-50 volume percent of the total C s produced. Both liquid and gaseous products were fully analyzed. The ranges of operating conditions selected were: reactor temperature from 850 to 1100F; catalyst to oil ratio from 2 to 10 w/w; the liquid hourly space velocity from 1 to 6 and a vapor l residence time of several seconds.

ln another group of examples cracked and virgin naphthas were cracked in a short-contact-time semicommercial riser pilot unit. The riser cracking zone discharge temperature was varied from about 900 to 1 about 1200F. and the catalyst-to-oil ratio was varied from about 8 to 60 w/w. Oil and catalyst contact times were of the order of 4 to 7 seconds.

Most of the examples relate to one identified cracked naphtha and to one identified virgin naphtha. Properties of these naphthas are reported in Table I. The one cracked gasoline or naphtha fraction was produced by cracking over a zeolite catalyst. A few fractions of similar materials but of different boiling ranges were examined.

4 in a similar matrix. Catalyst C was a laboratory steamed catalyst and consisted of 5% of zeolite ZSM-S on catalyst B. Thus it contained about 15% REY and 5% ZSM- 5. Catalyst D was a laboratory steamed catalyst and consisted of 10% ZSM-5 on the matrix material of catalyst A.

RECRACKING OF HEAVY FCC GASOLINE Approximately 23 weight percent (wt.%) of the gasoline charge stock was cracked to C or lighter products when a heavy (260-380F) FCC gasoline was contacted in a dense bed with commercial equilibrium Catalyst A at nominal gas oil cracking conditions (e.g. 1050F. reactor temperature and 6 CIC ratio). Conversion, defined as the weight percent of charge stock converted to C or lighter products and to coke increased with reactor temperature and catalyst to oil ratio (C/O). The cracking activity of Catalyst C was approximately the same as that of Catalyst A.

Conversion to C and lighter, plus coke, is here defined as conversion because these products are generally outside of the gasoline boiling range and therefore not directly usable in motor gasoline. However, isobutane and the light olefins are convertible to alkyl- Four catalysts have been used. Catalyst A was a commercial equilibrium fluid catalyst and consisted of about 10% REy zeolite in a silica-alumina-zirconia-clay matrix. Catalyst B was also a commercial equilibrium fluid catalyst and consisted of about 15% REY zeolite ate and butanes can be used in the finished gasoline to give desired vapor pressure.

Tables 11 and Ill report results of Examples I to XI involving cracking of heavy FCC gasoline.

TABLE ll Example Catalyst Cracking of 260-380 FCC Naphtha in dense bed bench unit 1 11 111 IV Operating Conditions Avg.Reactor Temp. F. Cat.to Oil Ratio, wt. WHSV Conversion to Cr, wt.% charge Product Yields, Charge C Liquid, vol.% Total C s, vol.%

Total C(s, vol.% Total Dry Gas (wt.%) Coke (wt.%) lsobutane, vol.% Butene, vol.% Propene, vol.%

Product Properties Sulfur, wt.%

Research O.N. clear PONA analysis, C.;+, vol.%

TABLE Il-continued Cracking of 260-380 FCC Naphtha in dense bed bench unit Example 1 I1 111 IV V Catalyst A A A C D Paraffins 12.8 10.4 12.4 9.5 14.1 Naphthenes 5.2 4.4 5.3 3.4 7.9 Olefins 1.8 2.3 1.9 1.1 2.8 Aromatics 80.1 82.9 80.4 85.9 75.2

Includes conversion to coke.

TABLE III Cracking of FCC Naphtha in Riser Pilot Plant Example VI VII VIII IX X X1 Catalyst B B B B B A Boiling Range I e Charge 260-3 80 260-450 260-380 Operating Conditions Riser Top Temp.F. 986 1005 1028 1173 1010 1013 Cat.to Oil Ratio,w/w 7.7 19.6 35.3 62.9 20.4 10.1 Oil Contact Time, sec. 5.5 5.1 4.8 5.2 5.0 5.6 Cat.Residence Time, sec. 7.1 6.8 6.7 7.4 6.7 7.2 Conversion to C.,, wt.%

charge* 15.9 24.0 32.9 55.2 25.9 13.2 Product Yields, charge C Liquid, vol.% 84.0 75.8 66.4 42.5 74.3 86.7 Total C s, vo1.% 8.1 9.5 9.5 4.1 9.3 6.6 Total C 's, vol.% 11.8 15.5 18.4 14.1 15.4 10.1 Total Dry Gas, wt.% 6.2 9.3 12.7 29.1 10.2 5.3

Coke, wt.% 15.1 4.06 7.49 16.27 5.28 0.82 lsobutane, vol.% 6.5 9.5 1 1.8 5.8 9.5 4.6 Butene, vol.% 3.2 2.2 1.5 2.6 2.0 4.2 Propene, vol.% 5.3 5.0 4.2 5.1 4.7 4.7 Product Properties Sulfur, wt.% 0.042 0.028 0.023 0.014 0.077 0.042 Bromine No. 5.5 3.1 2.1 1.7 3.1 8.7 Research O.N., clear 100.7 104.3 105.4 110.6 103.9 99.8 PONA Analysis, C vol.%

Paraffins 12.6 8.7 3.2 0.5 6.5 14.3 Naphthene 4.0 1.5 0.1 0.1 1.1 5.9 Olefins 1.9 1.6 1.1 0.1 1.0 3.0 Aromatics 81.6 88.2 95.6 99.3 91.3 76.7

*lncludes conversion to coke Gasoline octane number is of prime importance and the octane number in the absence of lead is of special importance because of problems with air pollution. Example 1, Table 11, illustrates the fact that recracking heavy FCC gasoline to about 17% conversion raises the clear octane number by six units (from 93.5 to 99.5). More extensive conversion increases octane number still further and 33% conversion gives about 12 units (93.5 to 105.4, Example VllI, Table III) while 55% conversion gives about 17 units (93.5 to 110.6, Example IX). Recracking at 3355% conversion converted the cracked gasoline to a liquid product containing over 95% aromatics (Examples VIII and IX). Conversions of 16% up to 55% were obtained in dense bed and riser units. Conversion increased with temperature and with catalyst-to-oil ratio; and octane number (and aromatic content) increased with conversion. Catalysts A, B and C were roughly similar in performance. In the riser cracking unit, heavy FCC gasoline of 260450F. boiling range cracked very much like the 260380F. fraction. (Compare Examples VII and X). Similarly, cracked fractions boiling up to 500F. are desirable charge stocks. Amorphous silica-alumina cracking catalysts are not able to produce these high conversions.

Olefin content and bromine-number of liquid products thus obtained is also of interest because of'the effect of olefins on air pollution. Whereas the original heavy FCC gasoline contained 13.6% olefins, 20% conversion of this fraction by recracking reduced olefins to about 2%; 33% conversion dropped olefins to near 1% while 55% conversion removed essentially all olefin. Similarly, 16% conversion reduced bromine number from 18.8 to about 6 and higher conversion reduced bromine number still more. With these zeolite catalysts, a degree of olefin removal is attained which is not practical with amorphous silicaalumina.

Light olefins (C -C produced could be further processed to produce gasoline blending stocks or separated for certain petrochemical manufacturing. Gasoline cracking over ZSM-5 catalyst showed exceptionally high yields of light olefins as illustrated by Examples V and XIX. For instance, 7075 wt.% of the C lighter products in these examples were light olefins. Therefore, if light olefins are desired, heavy naphtha or FCC gasoline could be processed over ZSM-S catalyst.

TABLE IV THE EFFECT OF RECRACKING HEAVY FCC GASOLINE N VOLATILITY DENSE BED UNIT Example Charge I II III IV V Conversion 0 16.5 22.9 17.2 18.8 17.8

Simulated Distillation, F.

IBP 239 I 13 98 77 17 30 273 231 221 222 227 231 30% 296 279 273 279 274 278 50% 328 300 291 296 286 292 70% 351 335 330 335 322 328 90% 382 376 375 379 354 359 95% 404 414 421 419 375 371 EP 553 606 596 613 527 494 The 10% point is reduced 4050F. and the 50% point is reduced about 3040F. Table IV indicates some reduction in 90% point but an increase in endpoint. At the dense fluid catalyst bed conditions there are some polymerization and condensation reactions to form a small amount of heavy ends. These can be removed as a very few percent of byproduct by distillation.

Table V reports ASTM distillation data for charge and products of a riser pilot plant.

TABLE V THE EFFECT OF RECRACKING HEAVY FCC GASOLINE ON VOLATILITY RISER PILOT PLANT Example Charge VI VII VIII IX Conversion 0 15.9 24.0 32.9 55.2

ASTM Distillation. F.

IBP 280 102 88 103 135 10% 293 202 189 202 220 301 283 272 265 244 309 306 292 283 259 322 329 318 312 286 343 391 422 441 456 499 544 520 El. 361 539 552 591 623 x XI Again, the 10% point is reduced by a large amount. The 50% point is reduced 25 to 60 at the 33-55% conversion. The riser system produces more heavy ends and, in this case, the 90% point was increased.

The 90% point of the charge is retained by removal of 45 9-11 vol.% of heavy ends by redistillation.

Recracking of heavy FCC gasoline has the added beneficial effect of reducing sulfur content. Examples I-IV, Table IV, indicate 50-75% sulfur removal at about 16-23% conversion. Similarly, Examples VI-IX and XI, Table V, resulted in 58-85% sulfur removal at 16-55% conversion.

Cracking of heavy FCC gasoline, unlike reforming, produces olefins which can be alkylated to increase gasoline yield. During the recracking of heavy FCC gas oil cracking experiments has demonstrated that the heavy gasoline fraction can be recracked to produce lighter, cleaner and higher octane gasoline at the expense of the gasoline volume. However, if C C.,= alkylate material is included, the loss in total recoverable liquid per octane boost is much less.

CRACKING OF HEAVY VIRGIN NAPHTI-IA Heavy virgin naphtha is more easily cracked than a heavy gasoline product of catalytic cracking and the cracking reaction can be accomplished at lower temperatures. Tables VI and VII report the results of Examples XII to XXV. Heavy virgin naphtha was cracked in both a dense fluid catalyst bed test unit and in a riser pilot plant test unit.

TABLE VI CRACKING OF 260380 VIRGIN NAPHTHA 1N DENSE BED BENCH UNIT Example XII XIII XIV XV XVI XVII XVIII XIX Catalyst A A A A A B C D Operating Conditions Avg.Reactor Temp.F 850 950 1050 1050 1 l 100 950 I050 Cat.to Oil Rati'o,wt. 10.0 6.2 6.1 2.0 10.1 10.1 6.1 6.0 WHSV 1.2 1.9 2.0 6.0 1.2 1.2 2.0 2.0 Conversion to C wt.% charge* 23.7 25.7 34.4 25.2 45.7 54.2 24.1 17.6 Product Yields, charge C Liquid, vol.% 77.9 74.4 65.5 74.6 53.8 44.6 76.6 82.2 Total C 's, vo1.% 13.1 11.0 10.7 7.0 9.3 7.7 13.4 3.4

TABLE Vl-continued CRACKING OF 260-380 VIRGIN NAPHTHA IN DENSE BED BENCH UNIT 7 Total C"s, vol.% 1 21.0 20.2 22.0 14.5 20.4 21.1 19.0 7.8 Total Dry Gas, wt.% 7.0 9.6 16.0 13.7 21.3 31.9 9.0 11.1 Coke, wt.%' p 1.32 1.11 1.89 0.59 4.23 6.64 0.98 0.45

Isobutane, vol.% 15.2 13.4 12.8 8.3 11.3 11.6 12.2 2.0 Butene. vol.% I 1.8 3.1 5.3 4.0 6.3 4.9 3.4 5.1 Propene, vol.% 2.6 4.4 7.0 1.0 9.8 9.2 4.6 8.5 Liquid Product Properties Research N clear 75.1 69.6 73.2 62.7 82.4 87.8 72.5 58.6 Gravity, API 49.6 48.2 46.1 49.3 41.5 38.8 48.8 50.7 Sulfur, wt.% 1 .001 .003 .001 C .005 .007 .003 .001 .004 PONA Analysis, C vol.% 1 1 Paraflins 38.2 41.3 37.8 42.5 30.6 24.6 39.0 42.9 Naphthenes 16.2 17.7 17.2 21.4 12.4 8.5 15.7 32.4 Olefins 1.1 1.8 2.5 2.7 2.4 2.3 1.6 2.6 Aromatics 44.3 v v 39.1 42.5 33.4 54.6 64.4 43.8 22.1

Includes conversion to coke TABLE VII CRACKING OF VIRGIN NAPI-ITHA IN RISER PILOT PLANT Example XX XX] XXII XXIII XXIV XXV Catalyst B B B B B A Boiling Range, charge 260-380 380-500 260-380 Operating Conditions Riser Top Temp.F. 998 995' 1036 914 977 985 Cat. to Oil Ratio,w/w 13.3 17.3 26.8 37.7 15.1 9.4 Oil Contact Time, sec. 1 5.3 4.4 4.3 5.0 4.2 1 4.9 1 Cat Residence Timesec- 6.9 I 5.8 5.8 7.1 5.6 6. 3 Conversion to Cr 1 wt .%.charge* 27.2 33.6 49.2 32.5 32.7 20.9 Productv Yie1ds,% charge v C Liquid, vo1.% 75.0 68.1 51.8 69.5 72.0 79.9 Total C 's,"vol.% 15.3 16.0 17.7 17.8 17.5 11.0 Total C"s, vol.% 20.8 26.1 33.8 26.1 24.6 16.6 Total Dry Gas, wt.% 10.1 11.7 18.9 9.5 11.5 7.7 Coke, wt.% 1.71 2.73 5.49 3.80 4.13 0.83 lsobutane, vol.% 12.4 1 16.3 21.8 17.5 14.5 8.7 Butene, vol.% -.5.0 4.0 3.4 2.1 5.3 11 3.3 Propene, vo1.% 1 7.8 1 7.4 7.7 4.3 8.5 6.9 Product Properties Research v 0N clear. 79.6. 87.7 97.2 90.0 90.6 77.0 Gravity, API 52.0 53.0 46.6 51.4 50.2 53.7 Sulfur, wt.% v .004 .003 .006 .003 .12 .001 PONA Analysis, C,+, vol.

Paraflins 1 37.7 1 30.5 16.8 28.4 27.0 40.6 Naphthene 13.2 I 6.9 1.9 5.7 6.7 17.5 Olefins 2.4 19 1.3 1.1 2.3 3 5 Aromatics 46.8 60.8 80.1 64.0 64.1 3814 Includes conversion to coke Conversion increases with temperature and with naphtha than on recracking gasoline product of gas oil catalyst-to-oi1 ration as shown by the above tables. cracking, but octane numbers reached are not as high. Catalyst B was more active than catalyst A. Catalyst C At conversion levels of to 55%, the clear octane had an activity much like that of Catalyst A. number was raised from 41 for the change to products Octane improvements are greater on cracking virgin in the 70 to 90 octane number range.

' TABLE VIII THE EFFECI 0F CRACKING HEAVY VIRGIN NAPI-ITHA 0N VOLATlLlTY DENSE BED UNIT Example Charge xII X111 XIV xv XVI XvII XVIII XIV Conversion 0 23.7 25.7 34.4 25.2 45.7 54.2 24.1 17.6 Simulated Distillation, "F

I8? 239 5 2 78 77 20 21 1 10% 264 175 213 229 1 163 232 295 257 258 267 253 275 317 286 288 293 281 298 391 1 319 317 322 308 323 367 354 353 354 338 351 384 392 393 383 353 364 El. .485. 597 599 577 492 516 TABLE IX THE EFFECT OF CRACKING HEAVY VIRGIN NAPHTHA IN VOLATILITY RISER PILOT PLANT Example Charge XX XXI XXII XIII XXIV XXV Conversion 27.2 33.6 49.2 32.5 32.7 20.9 ASTM Distillation,F.

IBP 278 88 83 83 89 86 87 288 I49 I28 130 I33 I22 I56 296 249 217 224 219 I 87 267 303 284 281 273 277 276 288 315 309 309 301 306 366 310 90% 334 363 421 499 369 553 351 508 El. 352 522 528 576 522 640 455 Cracking virgin naphtha improves volatility. The 50% point is lowered 20 to 40F. at conversions of 25 to 50%. The 90% point is reduced in the dense fluid catalyst bed examples (Table VIII). In the riser pilot plant test unit (Table IX) there was some formation of heavy ends and redistillation to remove about 5 to 8 weight percent of heavy ends is needed to maintain the 90% point and the end point. There is a very minor formation of heavy ends in the dense fluid catalyst bed examples which raised the endpoint.

As obtained in recracking of cracked gasoline, liquid cracked products from virgin naphtha have a very low olefin content.

Cracking of virgin naphtha produces very large yields of isobutane, butene and propene, all valuable alkylation charge stocks. Cracking is especially selective to isobutane over these zeolite catalysts at low temperatures. At 850F. and 10 catalyst-to-oil ratio there is a yield of 15% isobutane at 24% conversion. Lower temperatures, such as 800F., and higher catalyst-to-oil ratios, such as 20, will increase isobutane yield.

As for (FCC) fluid catalytic cracking gasoline recracking, ZSM-5 catalysts produce very large yields of light olefins (C -C These light olefins could be alkylated for blending into gasoline pool or separated for petrochemical manufacturing.

The amounts of potential alkylate produced are so large that, at moderate conversions, combined yields of recracked gasoline and alkylate, adjusted to gasoline vapor pressure, approach of the volume of the charge. Table X reports the combined yields of recracked gasoline plus alkylate.

which can be blended in a gasoline pool and high yields of isobutane are obtained which can be alkylated to produce a high octane blending stock.

BRIEF DESCRIPTION OF THE DRAWINGS FIG. I is a diagrammatic sketch in elevation of one arrangement of apparatus and system for practicing the separate riser recracking of gasoline product of gas oil cracking in another separate riser reactor with related product recovery equipment.

FIG. 11 is a diagrammatic sketch in elevation of another arrangement for practicing the concepts identifled with FIG. I except a dense fluid bed of catalyst is relied upon to carry out the recracking of gasoline product of gas oil cracking alone or along with a virgin naphtha fraction.

FIG. 111 is a diagrammatic sketch of a further embodiment and arrangement of reactor systems sequentially connected for practicing the concepts of the invention wherein gasoline product of gas oil cracking is recracked in a dense fluid catalyst bed reaction zone with freshly regenerated catalyst, the catalyst used for gasoline recracking is then used for gas oil cracking in a riser cracking zone and catalyst separated from the riser cracking operation is relied upon for effecting cracking of virgin naphtha.

Referring now to FIG. 1 there is shown a gas oil riser cracking reactor with a product fractionation step in combination with a separate heavy naphtha or gasoline product of gas oil cracking operation in a separate riser reactor with its own independent product recovery system. The recracking operation recovery system is In summary, it has been demonstrated that a significant benefit can be achieved by cracking heavy virgin naphtha over fluid catalytic cracking catalysts since a relatively high octane gasoline product was obtained related to the primary fractionation system in a manner to recover a common gasoline product stream of improved octane rating and a common light cycle oil stream. However, it is also contemplated using a single riser reactor system wherein the gasoline or naphtha to be subjected to recracking initially contacts the hot freshly regenerated catalyst introduced to the riser and the gas oil charge is then introduced to a downstream portion of the riser reactor for cracking thereof to gasoline boiling product. In the arrangement of FIG. I, a regenerator 2 is shown containing a bed of catalyst 4 which is contacted with oxygen-containing regeneration gas such as air introduced by conduit 6 to an air distributor grid 8. Cyclone separators 10 provided with diplegs 12 are located in the upper portion of the regenerator for separating flue gases from entrained catalyst particles. The separated catalyst particles are returned by the diplegs 12 to the catalyst bed 4 and flue gases are removed as by conduit 14. Regenerated catalyst is removed from bed 4 as by withdrawal well 16 and conveyed to conduit 18 communicating with the lower end of riser 20. A catalyst flow control valve 22 is provided in conduit 18. Regenerated catalyst is also conveyed from well 16 by conduit 24 to the bottom portion of riser 26. Catalyst flow control valve 28 is provided in conduit 24. A gas oil feed boiling in the range of 650F. to about lOOF. is introduced by conduit 30 to the bottom portion or riser 26 for admixture with hot regenerated catalyst introduced by conduit 24. A catalyst-oil suspension is thus formed providing a temperature of at least about 950F. and more usually in the range of 1000F. up to about 1100F. which is then passed upwardly through the riser reactor 26 at a velocity to provide a hydrocarbon residence time therein within the range of about 1 second up to about seconds. During passage of the suspension through the riser conversion of the gas oil feed to lower and higher boiling products occurs. These products are separated after removal of catalyst therefrom in a product fractionator as discussed below. The catalysthydrocarbon suspension after traversing the riser reactor is caused to flow directly into a plurality of cyclonic separators 32 attached to the end of the riser through a T-connection. Diplegs 34 attached to separators 32 pass separated catalyst to an annular stripping zone 36 provided with baffles 38. Stripping gas such as steam is introduced to the lower portion of the stripping zone by conduit 40. Stripped catalyst is removed from the lower portion of the stripping zone by conduit 42 and conveyed to the bed of catalyst 4 in the regeneration zone. A flow control valve 44 is provided in conduit 42.

Stripping gas and stripped hydrocarbon material are removed from the bed of catalyst in the stripping zone and enters cyclone separator 46 wherein entrained catalyst particles are separated from the stripping gas. Separated catalyst particles are returned to the catalyst bed by diple g 48. Stripping gas and hydrocarbon material are then passed from separator 46 by a connecting conduit to a plenum chamber 52. Hydrocarbon material separated from the riser reactor 26 by separators 32 pass by connecting conduit 50 to plenum chamber 52. Hydrocarbon material and stripping gas are passed from chamber 52 by conduit 54 to a fractionator 56.

For the purpose of this discussion, fractionator 56 is relied upon to separate a heavy cycle oil (HCO) withdrawn by conduit 58; a light cycle oil (LCO) withdrawn by conduit 60; a heavy naphtha withdrawn by conduit 62; material boiling below the heavy naphtha withdrawn by conduit 64 and a bottoms fraction withdrawn by conduit 66. All or a portion of the bottoms fraction may be passed through heater 66 and returned to the bottom of the tower 56 by conduit 68. Generally the temperature of the bottom of the tower will be about 690F. The material boiling below the heavy naphtha fraction and withdrawn from the fractionator by conduit 64 is passed through cooler 70 and thence by conduit 72 to drum 74 maintained at a temperature of about 100F. In drum 74 a liquid condensate is recovered and recycled by conduit 76 to the upper portion of the fractionator 56 as reflux. Uncondensed product is withdrawn from drum 74 by conduit 78 and passed to cooler 80 and conduit 82 to drum 84 maintained at a temperature of about 100F.

The heavy naphtha separated in fractionator56 and withdrawn by conduit may be passed all or in part by conduit 86 to the inlet of riser reactor 20 where it is combined with hot regenerated catalyst introduced by conduit 18 to form a suspension at a temperature within the range of 950F. to about 1250F. When virgin naphtha is used as the hydrocarbon feed to riser 20 instead of the heavy naphtha fraction it may be introduced by conduit 88. The suspension formed in the bottom of the riser 20 is passed upwardly therethrough under conditions to provide a hydrocarbon residence time in the range of l to about 10 seconds before separating the suspension into a catalyst phase and a hydrocarbon phase in cyclone separator 90. The catalyst phase separated in cyclone 90 is' passed by dipleg 92 to the bed of catalyst in the stripping zone as above discussed. To complete the separation of catalyst particles from hydrocarbon products of cracking the hydrocarbon phase is removed from separator 90 by conduit 94 and passed to a second separator 96. Catalyst separated in separator 96 is passed by dipleg 98 and 92 to the catalyst bed being stripped. Hydrocarbon vapors are recovered from separator 96 and conveyed by conduit 100 to cooler 102 wherein the vapors may or may not be cooled. The vapors then pass by conduit 104 to tower 106 maintained at a bottom temperature of about 550F. and a top temperature of about 350F. A bottoms product boiling in the light cycle oil boiling range is withdrawn from the bottom of the tower by conduit 108 and combined with light cycle oil in conduit 60 withdrawn from fractionator 56. An overhead hydrocarbon portion is withdrawn from tower 106 by conduit 1 10 and combined with hydrocarbon material in conduit 78. Condensate material comprising gasoline boiling range material is withdrawn from drum 84 by conduit 112 and recycled in part by conduit 114 to tower 106 as reflux. The remaining gasoline boiling condensate material is recovered by conduit 116. Uncondensed vaporous material is withdrawn from drum 84 by conduit 118 and sent to, for example, the refinery gas plant.

The processing arrangement of the present invention contemplates injecting the heavy naphtha to be recracked at the base of riser reactor 26 and introducing gas oil to be cracked to a downstream portion of the riser by either or both of inlet conduits 120 or 122. In such an arrangement it is contemplated cracking a virgin naphtha in riser 20 in combination with cracking gas oil alone or in combination with heavy naphtha cracking in riser 26.

Referring now to FIG. II, there is shown diagrammatically in elevation an embodiment of the reactor arrangement of FIG. I in which the heavy naphtha fraction is recracked in a riser discharging into the bottom of a dense fluid bed of catalyst and deactivated catalyst separated from the dense fluid bed cracking step is combined with catalyst separated from the gas oil cracking operation and passed through the catalyst stripping zone. In the arrangement of FIG. II, a heavy naphtha fraction separated from the product of gas oil cracking as shown in FIG. I is introduced by conduit 1 to the bottom of riser 3 for admixture with freshly regenerated catalyst introduced by conduit 5 containing catalyst flow control valve 7. A suspension is formed in the lower portion of riser 3 at an elevated cracking temperature. The suspension passes upwardly through riser 3 and is discharged into the bottom of an enlarged zone 9 containing a dense fluid bed of catalyst 11. Cracking of the gasoline fraction is accomplished in the dense fluid catalyst bed 11.. Hydrocarbon vapors comprising the recracked gasoline vapors are passed through one or more cyclone separators 13 provided with catalyst dipleg 15. The cracked gasoline vapors are withdrawn by conduit 100 and passed to product separation as defined with respect to FIG. I.

In the arrangement of FIG. II, catalyst is Withdrawn from the upper surface of fluid bed 11 into a well 17 defined by baffle 19. The catalyst is withdrawn from well 17 by conduit 21 provided with a flow central valve 23. The riser reactor 27 provided for converting a gas oil feed introduced by conduit 25 is intended to be operated in the same manner as described with respect to FIG. I for riser 26. Thus in the arrangement of FIG. II, the hydrocarbon product of gas oil cracking and stripping gas are withdrawn from the top of the vessel by conduit 54 for separation in a manner similar to that described with respect to FIG. I.

FIG. III departs from the arrangements of either FIG. I or II by the combination of cascading regenerated catalyst first through a dense fluid catalyst bed gasoline recracking zone, then a gas oil riser cracking zone and the catalyst separated from the gas oil cracking operation and collected as a dense fluid bed of catalyst is then relied upon to crack virgin naphtha prior to the catalyst passing to a stripping zone. The stripped catalyst is then passed to a catalyst regeneration operation. The hydrocarbon products of the gasoline recracking step and the separate gas oil cracking step are recovered in a manner similar to that described with respect to FIG. I. Products of virgin naphtha cracking are recovered in the gas oil separation system. In the arrangement of FIG. III, a heavy cracked gasoline fraction is introduced by conduit 31 for admixture with hot regenerated catalyst withdrawn from a catalyst regeneration zone by conduit 33 provided with a catalyst flow control valve 35. A suspension is formed at an elevated temperature of at least lOOOF. which is conveyed by inlet conduit 37 into the bottom portion of a dense fluid bed of catalyst 39 confined in a cracking zone 41. Hydrocarbon product of gasoline cracking is passed through cyclonic separation means 43 provided with separated catalyst dipleg 45. Hydrocarbon vapors are withdrawn by conduit 100 and passed to product separation similar to that described in FIG. I. Catalyst is withdrawn into a well 47 from an upper portion of bed 39 and conveyed therefrom by conduit 49 provided with valve 51 to the bottom portion of gas oil cracking riser 53 to which a gas oil feed is introduced by conduit 55. A suspension at an elevated gas oil cracking temperature is formed in the lower portion of riser 53 and passes upwardly therethrough for discharge into cyclonic separation zones 57 and 59. Hydrocarbon vapors separated in zones 57 and 59 are withdrawn by conduits 61 and 63 communicating with chamber 65 and withdrawal conduit 54. Catalyst particles separated by cyclonic means 57 and 59 are conveyed to a dense fluid bed of catalyst 67 by diplegs 69 and 71. A virgin naphtha fraction is introduced to the collected bed of catalyst discharged from riser 53 by conduit 73 for conversion thereof to higher octane product and olefin constituents as described above. Catalyst bed 67 is a continuous downwardly moving bed of catalyst which passes into a stripping zone beneath the virgin naphtha inlet distributor grid. The catalyst thus sequentially used as above identified passes downwardly through a stripping zone 75 provided with stripping gas introduced by conduit 77. Stripped catalyst is then withdrawn by conduit 79 for transfer to a catalyst regeneration operation. Hydrocarbon vapor product of virgin naphtha cracking and stripping gas pass through cyclonic separation zones 81 and 83 wherein entrained catalyst is separated and returned to the catalyst bed 67 by diplegs 85 and 87. Hydrocarbon vapors and stripping gas then pass by conduit 89 and 91 to chamber 65. Vaporous material withdrawn by conduit 54 is then separated in the manner described with respect to FIG. I.

Catalyst withdrawn from the stripping zone by conduit 79 provided with valve 97 is combined with regeneration gas 93 in the lower portion of a riser regenerator 95. The suspension thus formed passes upwardly through the riser regeneration zone and is discharged into an enlarged separation-regeneration zone 99 and above a dense fluid bed of catalyst 101 in the lower portion thereof. Additional regeneration gas is introduced to a lower portion of the regeneration zone by conduit 103. In the riser and dense catalyst phase regeneration zones, carbonaceous material deposited during hydrocarbon conversion is removed by burning with the introduced oxygen containing regeneration gas. Gaseous products of combustion pass through separators 103 and 105 wherein entrained catalyst fines are removed from the flue gases. Separated catalyst fines are returned to the catalyst bed 101 by diplegs 107 and 109. Flue gases then pass by conduits 111 and 113 into chamber 115 from which they are withdrawn by conduit 117.

In the arrangement of FIG. III, it is preferred that the catalyst employed be a mixture of crystalline zeolite conversion catalyst of small and large pore diameter crystalline materials and that the small pore crystalline material be of the ZSM-5 type. The large pore crystalline zeolite may be either of the X or Y type of crystalline zeolite.

Having thus provided a general discussion of this invention and provided specific embodiments going to the very essence thereof, it is to be understood that no undue restrictions are to be imposed by reason thereof except as defined by the following claims.

We claim:

1. A method for upgrading hydrocarbons which comprises cracking a gas oil boiling range feed in a first cracking zone in the presence of a crystalline zeolite cracking catalyst at an elevated temperature of at least 850F to obtain conversion of the gas oil feed to materials including a heavy cycle oil, a light cycle oil, a heavy naphtha fraction and materials lower boiling than said heavy naphtha fraction, cracking the heavy naphtha fraction above obtained in a second cracking zone in the presence of freshly regenerated crystalline zeolite cracking catalyst at an elevated temperature within the range of 850F to about l000F, separating the product of said heavy naphtha fraction cracking operation in a zone separate from the gas oil product separation under conditions to recover gasoline boiling range material rich in aromatics and lighter hydrocarbon material from a light cycle oil product material, combining said light cycle oil recovered products, combining materials lower boiling than said heavy naphtha product of gas oil cracking with said gasoline boiling and lighter materials separated from the product of said heavy naphtha cracking operation and separating the combined materials lower boiling than light cycle oil into a gasoline boiling range product fraction and a lower boiling uncondensed vaporous product fraction.

2. The method of claim 1 wherein a freshly regenerated crystalline aluminosilicate containing cracking catalyst is sequentially passed through said heavy naphtha cracking step, said gas oil cracking step and a virgin naphtha cracking step before stripping of the catalyst and passing stripped catalyst to catalyst regeneration.

3. The method of claim 2 wherein the cracking catalyst comprises a faujasite type of crystalline zeolite in combination with a crystalline aluminosilicate of the ZSM-S type.

4. The method of claim 1 wherein freshly regenerated catalyst is used for recracking the heavy cracked naphtha material and the gas oil feed and catalyst used in each cracking operation is passed to a common catalyst stripping operation before being regenerated.

5. The method of claim 1 wherein recracking of said heavy naphtha fraction is accomplished in a high temperature riser cracking zone at a temperature of at least 950F.

6. The method of claim 1 wherein the recracking of said heavy naphtha fraction is accomplished in a riser cracking zone.

7. The method of claim 1 wherein recracking of said heavy naphtha fraction is accomplished in a high temperature riser cracking zone terminating in a dense fluid bed cracking zone.

8. The method of claim 1 wherein catalyst separated from said gas oil riser cracking step is used to convert a virgin naphtha at an elevated cracking temperature to improve its octane rating and the products of said virgin naphtha cracking step are separated with products of said gas oil cracking step.

9. The method of claim 1 wherein the heavy naphtha fraction subjected to recracking contains hydrocarbon components boiling up to about 500F.

10. The method of claim 1 wherein a virgin naphtha is cracked in the presence of said heavy cracked naphtha.

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Classifications
U.S. Classification208/77, 208/80, 502/67, 208/78, 585/476, 208/164, 208/120.1, 208/16, 208/72
International ClassificationC10G11/00, C10G11/18
Cooperative ClassificationC10G11/18
European ClassificationC10G11/18