WO1998014535A1

WO1998014535A1 - Alkylation process for desulfurization of gasoline

Info

Publication number: WO1998014535A1
Application number: PCT/US1996/015689
Authority: WO
Inventors: Nick Allen Collins; Jeffrey C. Trewella
Original assignee: Mobil Oil Corporation
Priority date: 1996-09-30
Filing date: 1996-09-30
Publication date: 1998-04-09
Also published as: CA2219681A1

Abstract

Sulfur species present in cracked naphtha (1) are converted and removed by first passing the naphtha (1) over an acid catalyst in an alkylation reactor (4) to alkylate the thiophenic compounds in the naphtha using the olefins, i.e., monoolefins and diolefins, present in the naphtha (1) as alkylating agent. Alkylated thiophenes are concentrated in the heavy portion of the naphtha (8) by distillation, reducing the amount of naphtha that needs to be hydrodesulfurized in the reactor (10). Olefins in cracked naphtha are concentrated in the light portion of the naphtha (7) which is not subsequently hydrotreated. Thus, octane and hydrogen consumption penalties associated with hydrotreating are minimized.

Description

Alkylation Process for Desulfurization of Gasoline

This invention relates to a process for the upgrading of hydrocarbon streams. The invention more particularly relates to a process for upgrading gasoline boiling range petroleum fractions containing olefins and substantial proportions of sulfur impurities.

Heavy petroleum fractions, such as vacuum gas oil, or even resids such as atmospheric resid, may be catalytically cracked to lighter and more valuable products, especially gasoline. The product of catalytic cracking is conventionally recovered and the products fractionated into various fractions such as light gases; naphtha, including light and heavy gasoline; distillate fractions, such as heating oil and Diesel fuel; lube oil base fractions; and heavier fractions. Sulfur in various forms is commonly found in petroleum and petroleum products either as dissolved free sulfur, hydrogen sulfide, or as organic compounds, such as thiophenes, sulfonic acids, mercaptans, alkylsulfates, and alkyl sulfides. Where a petroleum fraction is being catalytically cracked and contains sulfur, the products of catalytic cracking usually contain sulfur impurities which normally require removal, usually by hydrotreating, in order to comply with the relevant product specifications. Such hydrotreating can be done either before or after catalytic cracking. Because naphtha streams from both catalytic, e.g., FCC, and thermal, e.g., coking, cracking processes contribute most of the sulfur present in the gasoline pool, reducing the sulfur content of cracked naphthas will be important in order to meet liquid transportation sulfur specifications and emission standards.

The ease of sulfur removal from petroleum and its products is dependent upon the type of sulfur-containing compound. Hydrogen sulfide and mercaptans are relatively easy to remove whereas aromatic sulfur compounds such as thiophenes are more difficult to remove. Sulfur impurities tend to concentrate in the heavy fraction of the gasoline, as noted in U.S. Patent No. 3,957,625 (Orkin) which proposes a method of removing the sulfur by hydrodesulfu- rization of the heavy fraction of the catalytically cracked gasoline so as to retain the octane contribution from the olefins which are found mainly in the lighter fraction. In one type of conventional, commercial operation, the heavy gasoline fraction is treated in this way. As an alternative, the selectivity for hydrodesulfurization relative to olefin saturation may be shifted by suitable catalyst selection, for example, by the use of a magnesium oxide support instead of the more conventional alumina.

Cracked naphtha, as it comes from the catalytic cracker and without any further treatments such as purifying operations, has a relatively high octane number as a result of the presence of olefinic components. It also has an excellent volumetric yield. As such, cracked gasoline is an excellent contributor to the gasoline pool. It contributes a large quantity of product at a high blending octane number. In some cases, this fraction may contribute as much as up to half the gasoline in the refinery pool. Therefore, it is one of the most desirable components of the gasoline pool.

Other unsaturated fractions boiling in the gasoline boiling range, which are produced in some refineries or petrochemical plants, include pyrolysis gasoline. This is a fraction which is often produced as a by-product in the cracking of petroleum fractions to produce light unsaturates, such as ethylene and propylene. Pyrolysis gasoline may have a very high octane number but is quite unstable in the absence of hydrotreating because, in addition to the desirable olefins boiling in the gasoline boiling range, it also contains a substantial proportion of diolefins, which tend to form gums upon storage or standing. Cracking of naphtha is a highly useful process to increase the yield of gasoline. However, the cracking process also effects sulfur containing materials and results in a reduction in their molecular weight from a range that is greater than the average molecular weight of the gasoline boiling range fraction into a range that is within the molecular weight range of the gasoline fraction. Much of this gasoline boiling range sulfur is contained in aromatic compounds and, consequently, needs to removed by hydrotreating. However, hydrotreating of any of the sulfur containing cracked fractions which boil in the gasoline boiling range, e.g., FCC, pyrolysis and coker naphtha, causes a reduction in the olefin content, and consequently a reduction in the octane number. Further, as the degree of desulfurization increases, the octane number of the normally liquid gasoline boiling range product decreases. Depending on the conditions of the hydrotreating operation, some of the hydrogen may also cause some hydrocracking or aromatic saturation as well as olefin saturation. Various proposals have been made for removing sulfur while retaining the more desirable olefins. U.S. 4,049,542 (Gibson) , for instance, discloses a process in which a copper catalyst is used to desulfurize an olefinic hydrocarbon feed such as catalytically cracked light naphtha .

Other processes for treating catalytically cracked gasolines have also been proposed in the past. For example, U.S. 3,759,821 (Brennan) discloses a process for upgrading catalytically cracked gasoline by fractionating it into a heavier and a lighter fraction and treating the heavier fraction over a ZSM-5 catalyst, after which the treated fraction is blended back into the lighter fraction. Another process in which the cracked gasoline is fractionated prior to treatment is described in U.S. 4,062,762 (Howard) which discloses a process for desulfurizing naphtha by fractionating the naphtha into three fractions each of which is desulfurized by a different procedure, after which the fractions are recombined.

In any case, regardless of the mechanism by which it happens, the decrease in octane which takes place as a consequence of sulfur removal by hydrotreating creates a tension between the growing need to produce gasoline fuels with higher octane number and - because of current ecological considerations -the need to produce cleaner burning, less polluting fuels, especially low sulfur fuels to avoid poisoning of catalyst converters which would adversely affect hydrocarbon emissions. his inherent tension is yet more marked in the current supply situation for low sulfur crudes. An objective of the present invention is to provide a process for reducing the sulfur level in naphtha streams especially the sulfur in naphtha attributable to thiophene or thiophenic compounds, while minimizing product losses in volume and octane number. Sulfur species present in cracked naphthas may be converted and removed by first passing the naphtha over an acid catalyst to alkylate the thiophenic compounds in the naphtha using the indigenous olefins and diolefins present in the naphtha as alkylating agent. Such alkylation reactions provide alkylated thiophenes that concentrate the sulfur species in the heavy portion of the naphtha, greatly reducing the amount of naphtha that needs to be hydrodesulfurized. Furthermore, because the majority of the olefins in cracked naphthas remain concentrated in the light portion of the naphtha which is not subsequently hydrotreated, the octane and hydrogen consumption penalties associated with the hydrotreating of only the sulfur- enriched heavy naphtha are minimized. Similar results can be achieved through A process according to the invention with virgin naphthas having a low olefin content by cofeeding olefin-rich streams. More particularly, the invention comprises a process for upgrading a sulfur-containing feedstream comprising olefinic gasoline boiling range hydrocarbons rich in thiophenic sulfur compounds. The process is carried out by contacting the feedstream with acidic alkylation catalyst particles under alkylation conditions in an alkylation zone to provide an effluent stream comprising hydrocarbons containing alkylated thiophenic sulfur compounds. The alkylated thiophenic compounds are separated from the effluent stream by fractional distillation to provide a heavy naphtha of higher boiling point rich in alkylated thiophenic compounds and a light naphtha portion. The light naphtha portion is recovered to provide gasoline boiling range hydrocarbons containing a reduced amount of thiophe- nic sulfur compounds. Optionally, the heavy naphtha portion may be desulfurized using conventional hydrotreating or other desulfurization processes.

While A process according to the invention specifically achieves the intended benefit of a lowering of the sulfur content of the naphtha feedstream, there are corollary benefits. It is to be expected that A process according to the invention will also lower the amount of aromatic nitrogen compounds in the naphtha as well as the amount of diolefins. The Figure is a schematic drawing of one embodiment of a process according to the invention.

Feed

The feed to the process comprises a sulfur-containing petroleum fraction, generally olefinic, which boils in the gasoline boiling range. Feeds of this type include olefinic light naphthas typically having a boiling range of about C₆ to 165 °C, full range naphthas typically having a boiling range of about C₅ to 215 °C, heavier naphtha fractions boiling in the range of about 127 ° to 210EC, or heavy gasoline fractions boiling at, or at least within, the range of about 165E to 260°, preferably about 165E to 210EC. The preferred feed is a light naphtha or full range naphtha .

While the feedstream to the process preferably comprises a sulfur-containing olefinic petroleum fraction which boils in the gasoline boiling range in which indigenous olefins are used to carry out the alkylation reaction, it is possible to use an additional or cofeed olefin feedstream to the process to provide or supplement alkylating agents for the process. This optional variation of the process could be elected depending on conditions extant in the refinery, including an abundant supply of light olefins or a sulfur-rich gasoline boiling range stream that is not sufficiently rich in indigenous olefins. The process may be operated with the entire gasoline fraction obtained from the catalytic cracking step or, alternatively, with part of it. Because the sulfur tends to be concentrated in the higher boiling fractions, it is preferable, particularly when unit capacity is limited, to separate the higher boiling fractions and process them through the steps of the present process without processing the lower boiling cut. The cut point between the treated and untreated fractions may vary according to the sulfur compounds present but usually, a cut point in the range of from about 100°F (38°C) to about 300°F (150°C), more usually in the range of about 200°F(93°C) to about 300°F(150°C) will be suitable. The exact cut point selected will depend on the sulfur specification for the gasoline product as well as on the type of sulfur compounds present: lower cut points will typically be necessary for lower product sulfur specifications. Sulfur which is present in components boiling below about 150°F(65°C) is mostly in the form of mercaptans which may be removed by extractive type processes such as Merox. Removal of thiophenic compounds and present in higher boiling components, e.g., component fractions boiling above about 180°F(82°C) , is carried out according to a process according to the instant invention.

The sulfur content of these catalytically cracked fractions will depend on the sulfur content of the feed to the cracker as well as on the boiling range of the selected fraction used as the feed in the process. Lighter fractions, for example, will tend to have lower sulfur contents than the higher boiling fractions. As a practical matter, the sulfur content will exceed 50 ppmw and usually will be in excess of 100 ppmw, and in most cases in excess of about 500 ppmw. For the fractions which have 95 percent points over about 380 °F (193 °C) , the sulfur content may exceed about 1,000 ppmw and may be as high as 4,000 or 5,000 ppmw or even higher. Since much of the nitrogen compounds in the feed to a cracker end up as coke, the nitrogen content of cracked naphtha is not as characteristic of the feed as is the sulfur content and is preferably not greater than about 20 ppmw although higher nitrogen levels typically up to about 50 ppmw may be found in certain higher boiling feeds with 95 percent points in excess of about 380 °F (193 °C) . The nitrogen level will, however, usually not be greater than 250 or 300 ppmw. As a result of the cracking which has preceded the steps of the present process, the feed to A process according to the invention will be olefinic, with an olefin content of at least 3 and more typically in the range of 10 to 20, e.g. 15 - 20, weight percent.

Catalyst Many heterogeneous acid catalysts containing either Bronsted acid sites or Lewis acid sites are useful for A process according to the invention. Typical Lewis acids include those derived from A1C1₃, FeCl₃, SbCl₃, BF₃, ZnCl₂, TiCl₄ and P₂0₅; but particularly, Lewis acids such as AlCl₃/silica, AlCl₂/silica, BF₃/silica, Co/Mo/alumina, Mo/- alu ina, MoS₂ are useful for A process according to the invention. Typical Bronsted acids include HF, H₂S0₄ , metallosilicates, silica-alumina, sulfonic acid resins, and the like. Well-known methods of maintaining or recovering catalyst activity, such as promoter cofeed or hydrogenative or oxidative regeneration, may also be employed.

The useful catalysts include the crystalline aluminosilicate zeolites especially the medim pore size zeolites having a silica: alumina ratio of at least 12, and constraint index of about 1 to 12. Representative of these zeolites are ZSM-5, ZSM-11, ZSM-22, ZSM-23, ZSM-35, MCM-22, MCM-36, MCM-49, MCM-49 and ZSM-48. The larger pore size zeolites may also be used as catalysts in the present process, i.e., those zeolites having a Constraint Index of no greater than about 2. Representative of these zeolites are zeolite Beta, TEA mordenite, faujasites, USY and ZSM- 12.

The method by which Constraint Index is determined is described fully in U.S. Patent No. 4,016,218, to which reference is made for details of the method.

One group of preferred catalysts for use in the present invention are the members of the MCM-22 group which includes MCM-22, MCM-36, MCM-49 and MCM-56. MCM-22 is described in U. S. patent 4,954,325. MCM-36 is described in U. S. patent 5,250,277 and MCM-36 (bound) is described in U. S. patent 5,292,698. MCM-49 is described in U. S. patent 5,236,575 and MCM-56 is described in U. S. patent 5,362,697.

The Process

A process according to the invention reduces the sulfur level in naphtha streams while minimizing volume and octane loss. Olefins, either present in cracked naphthas or fed to virgin naphtha, are used to convert sulfur species to higher molecular weight compounds thereby concentrating the sulfur in the "back-end" of the naphtha. Upon fractionation, this redistribution of the sulfur in the naphtha leads to a relatively sulfur-free light naphtha and a sulfur-rich heavy naphtha which may be desulfurized via conventional hydrotreating. Conversion of the sulfur in the heavy fraction of naphtha reduces the amount of naphtha that must be hydrodesulfurized which, in the case of cracked naphthas, leads to lower hydrogen consumption and greater octane-barrels.

The conversion carried out in the process is one of alkylation of aromatic heterocyclic sulfur compounds, i.e., thiophene and related thiophenic compounds, in contact with acidic alkylation catalyst. Preferably, the process is carried out on a cracked naphtha feedsteam at temperatures between 100°F (38°C) and 700°F (371°C) and pressure between atmospheric or autogenous pressure and 7000 kPa. The preferred temperature is 300-400°F (149-204°C).

Various reactor configurations can be employed to carry out the alkylation step of A process according to the invention. These include a down-flow, liquid phase, fixed bed process; an up-flow, fixed bed, trickle phase process; an ebulating, fluidized bed process; or a transport, fluidized bed process. The fixed bed arrangements are preferred for simplicity of operation.

A preferred implementation of the proposed concept is shown schematically in the Figure. Cracked naphtha (1) , possibly prefractionated (2) to obtain a light fraction (3) , is fed to a condensation or alkylation reactor (4) containing acid catalyst where naphtha-range olefins alkylate sulfur species producing heavier sulfur compounds. The reactor effluent (5) is distilled (6) to obtain low- sulfur light naphtha (7) and a heavy naphtha (8) enriched in sulfur. This high-sulfur heavy naphtha may be combined with heavy naphtha (9) from the prefractionator and hydrodesulfurized in reactor (10) using conventional hydrotreating processes or alternatively sent to the distillate pool. The low-sulfur light naphtha (7) may be optionally etherified (11) in etherification reactor (13) or optionally recycled (12) to the sulfur conversion reactor depending on overall desulfurization targets. The naphtha splitter may also have utility in meeting T₉₀ distillation targets.

A series of experiments was performed to illustrate the novelty and advantages of the invention. These experiments are depicted in the following Example 1.

Example 1

Selective condensation of sulfur compounds in cracked naphthas was scoped over zeolite catalysts ZSM-5, MCM-22, and USY in batch studies. Feedstocks included both light (C₅ -100°C, 230 ppmw S) and full-range (C₅ ⁺, 0.14 wt%S) FCC naphthas. These batch runs were conducted at 350 °F (177C) for three hours at autogenous pressure with loadings of 10 grams of light naphtha per gram of catalyst and 11.6 grams of full-range naphtha per grams of catalyst. Results for the light FCC are shown in Table 1 and for the full-range FCC in Table 2.

Table 1

Light FCC Naphtha Sulfur Redistribution

Acid Catalyst

Feed ZSM-5 MCM-22 USY

Sulfur Distribution.wt% of S

<Thiophene 16.8 0.0 0.0 0.0

Thiophene 44.5 0.0 0.0 8.8

Methylthiophenes 33.2 0.0 0.0 0.0

>Methylthiophenes 5 5 100.0 100.0 91.2

Total 100.0 100.0 100.0 100.0

Composition. wt% of HC

Butenes 1.0 0.7 0.0 0.8

Pentenes 26.8 11.5 2.0 16.3

Hexenes 19.7 11.4 3.2 14.6

C₄-C₆ P+N+A 27.6 32.8 35.9 34.3

C₇+ 24.9 43.7 59.0 34.1

Total 100.0 100.0 100.0 100.0

Table 2

Full-range FCC Naphth a Sulfur Redistribution

Acid Catalyst

Feed ZSM-5 MCM-22 USY

Sulfur Distribution. wt% of S

<Benzothiophene 51.7 22.5 14.9 15.7

Benzothiophene 27.8 24.1 9.0 13.5

>Benzothiophene 20.4 53.4 76.1 70.8

Total 100.0 100.0 100.0 100.0

Composition. wt% of HC

>430°F (Benzothiophene) 5.2 8.6 10.7 10.1 As shown in Table 1, all three catalysts were extremely effective in converting the sulfur compounds present in the light FCC naphtha feed to sulfur species boiling above the methylthiophenes (113-116EC) (235-240 °F) and C₇ olefins (80-106EC) (177-223 °F) . This sulfur conversion was also accompanied by significant olefin conversion to C₇ ⁺ products as shown in the detailed hydrocarbon composition.

All three catalysts were also effective in converting sulfur species present in full-range FCC naphtha as shown in Table 2.

Claims

1. A process for upgrading a cracked sulfur- containing naphtha feedstream comprising olefinic, gasoline boiling range hydrocarbons rich in olefins and thiophenic sulfur compounds, which process comprises the following steps : contacting the feedstream having a boiling range between C₅ and 215EC with a particulate acidic alkylation catalyst in an alkylation zone to alkylate the thiophenic sulfur compounds with the olefins in the feed, to provide an effluent stream comprising alkylated thiophenic sulfur compounds and olefinic gasoline boiling range hydrocarbons; separating the alkylated thiophenic compounds from the olefinic gasoline boiling range hydrocarbons by fractional distillation; and recovering a product stream comprising the hydrocarbons containing a reduced amount of the thiophenic sulfur compounds .

2. A process according to claim 1 in which at least 90 wt.% of the thiophenic sulfur compounds are converted to alkylated thiophenic sulfur compounds.

3. A process according to claim 2 in which the catalyst comprises an aluminosilicate zeolite.

4. A process according to claim 3 in which the zeolite ZSM-5, MCM-22, MCM-56, zeolite beta, USY or faujasite.

5. A process according to any of claims 1 to 4 in which the feed stream comprises a full range naphtha fraction having a boiling range within the range of C₅ to 215°C.

6. A process according to any of claims 1 to 4 in which the feedstream comprises a light naphtha fraction having a boiling range within the range of C₆ to 165 °C.

7. A process according to claim 1 in which the feed stream comprises a heavy naphtha fraction having a boiling range within the range of 165E to 260 °C.

8. A process according to any of claims 1 to 7 in which the feed stream comprises a naphtha fraction having a 95% point of at least about 178° C.

9. A process according to any of claims 1 to 8 in which the alkylation is carried out at a temperature between 150° and 370° C and a pressure between atmospheric pressure and 7000 kPaa.

10. A process according to any of claims 1 to 9 which includes cofeeding an olefin feedstream with the gasoline boiling range hydrocarbon feedstream.