Related Information Petroleum distillate streams contain a variety of organic chemical components.

Generally the streams are defined by their boiling ranges which determine the compositions. The processing of the streams also affects the composition. For instance, products from either catalytic cracking or thermal cracking processes contain high concentrations of olefinic materials as well as saturated (alkanes) materials and polyunsaturated materials (diolefins). Additionally, these components may be any of the various isomers of these compounds.

The composition of untreated naphtha as it comes from the crude still, or straight run naphtha, is primarily influenced by the crude source. Naphthas from paraffinic crude sources have more saturated straight chain or cyclic compounds.

As a general rule most of the"sweet" (low sulfur) crudes and naphthas are paraffinic.

The naphthenic crudes contain more unsaturates and cyclic and polycylic compounds. The higher sulfur content crudes tend to be naphthenic. Treatment of the different straight run naphthas may be slightly different depending upon their composition due to crude source.

Reformed naphtha or reformate generally requires no furthertreatment except perhaps distillation or solvent extraction for valuable aromatic product removal.

Reformed naphthas have essentially no sulfur contaminants due to the severity of their pretreatment for the process and the process itself.

Cracked naphtha as it comes from the catalytic cracker has a relatively high octane number as a result of the olefinic and aromatic compounds contained therein.

In some cases this fraction may contribute as much as half of the gasoline in the refinery pool together with a significant portion of the octane.

Catalytically cracked naphtha gasoline boiling range material currently forms a significant part (z 1/3) of the gasoline product pool in the United States and it provides the largest portion of the sulfur. The sulfur impurities may require removal, usually by hydrotreating, in order to comply with product specifications or to ensure compliance with environmental regulations.

The most common method of removal of the sulfur compounds is by hydrodesulfurization (HDS) in which the petroleum distillate is passed over a solid particulate catalyst comprising a hydrogenation metal supported on an alumina base.

Additionally copious quantities of hydrogen are included in the feed. The following equations illustrate the reactions in a typical HDS unit: (1) RSH + H2 « RH + H2S (2) RCI + H2--- RH + HCI (3) RN + 2H2---> RH + NH3 (4) ROOH + 2H2 RH + 2H20 Typical operating conditions for the HDS reactions are: Temperature, °F 600-780 Pressure, psig 600-3000 H2 recycle rate, SCF/bbl 1500-3000 Fresh H2 makeup, SCF/bbl 700-1000 The reaction of organic sulfur compounds in a refinery stream with hydrogen over a catalyst to form H2S is typically called hydrodesulfurization. Hydrotreating is a broader term which includes saturation of olefins and aromatics and the reaction of organic nitrogen compounds to form ammonia. However hydrodesulfurization is included and is sometimes simply referred to as hydrotreating.

After the hydrotreating is complete, the product may be fractionated or simply flashed to release the hydrogen sulfide and collect the now desulfurized naphtha.

In addition to supplying high octane blending components the cracked naphthas are often used as sources of olefins in other processes such as etherifications. The conditions of hydrotreating of the naphtha fraction to remove sulfur will also saturate some of the olefinic compounds in the fraction reducing the

octane and causing a loss of source olefins.

Various proposals have been made for removing sulfur while retaining the more desirable olefins. Since the olefins in the cracked naphtha are mainly in the low boiling fraction of these naphthas and the sulfur containing impurities tend to be concentrated in the high boiling fraction the most common solution has been prefractionation prior to hydrotreating. The prefractionation produces a light boiling range naphtha which boils in the range of C5 to about 250°F and a heavy boiling range naphtha which boils in the range of from about 250-475°F.

The predominant light or lower boiling sulfur compounds are mercaptans white the heavier or higher boiling compounds are thiophenes and other heterocyclic compounds. The separation by fractionation alone will not remove the mercaptans.

However, in the past the mercaptans were frequently removed by oxidative processes involving caustic washing. A combination oxidative removal of the mercaptans followed by fractionation and hydrotreating of the heavier fraction is disclosed in U. S. patent 5,320, 742. In the oxidative removal of the mercaptans the mercaptans are converted to the corresponding disulfides.

In addition to treating the lighter portion of the naphtha to remove the mercaptans the lighter fraction traditionally has been used as feed to a catalytic reforming unit to increase the octane number if necessary. Also the lighter fraction may be subjected to further separation to remove the valuable C5 olefins (amylenes) which are useful in preparing ethers.

Simultaneous treatment and fractionation of petroleum products, including naphtha, especially fluid catalytically cracked naphtha (FCC naphtha) is disclosed in U. S. patents 5,510, 568; 5,597, 476; 5,779, 883; 5,807, 477 and 6,083, 378.

U. S. Pat. No. 5,510, 568 for example discloses full boiling range FCC naphtha hydrotreated in a splitter which contains a thioetherification catalyst in the upper portion. Mercaptans in the light fraction react with the diolefins contained therein (thioetherification) to produce higher boiling sulfides which are removed as bottoms along with the heavy (higher boiling) FCC naphtha.

It has now been found that the light FCC naphtha cut in the splitter just below the light fraction also contains mercaptans and a significant amount of thiophenes.

The mercaptans in this cut may be removed by the thioetherification. The total sulfur

content of the thiophene cut is relatively low and more significantly does not require as severe treatment as the sulfur compounds in the heavy fraction to convert the thiophene to H2S, thus the olefins in the thiophene cut are less likely to be hydrogenated.

It is an advantage of the present invention that the sulfur may be removed from the light olefin portion of the stream to a heavier portion of the stream without any substantial loss of olefins. Substantially all of the sulfur in the heavier portion is converted to H2S by hydrodesulfurization and easily distilled away from the hydrocarbons. Also, the sulfur in the middle cut will also be lowered.

SUMMARY OF THE INVENTION Briefly the present invention is a process for removal of sulfur from a full boiling range fluid cracked naphtha stream to meet higher standards for sulfur removal, by splitting the light portion of the stream and treating the components of the naphtha feed with the process that preserves the olefinic while most expediently removing the sulfur compounds.

Preferably the process comprises the steps of: (a) separating the full boiling range cracked naphtha stream into three fractions comprising a light cracked naphtha fraction, preferably boiling in the range of C5 to about 150°F, an intermediate cracked naphtha fraction preferably boiling in the range of about 150 to about 250°F and a heavy cracked naphtha preferably boiling in the range of about 250 to 450°F ; (b) subjecting the heavy cracked naphtha to hydrodesulfurization in a first hydrodesulfurization reactor containing a hydrodesulfurization catalyst ; and (c) combining the effluent from the first hydrodesulfurization reactor with the intermediate cracked naphtha and subjecting the combined stream to hydrodesulfurization in a second hydrodesulfurization reactor.

The advantage of this system is that the size and capital investment of the hydrodesulfurization distillation column reactor are reduced. The level of recombinant mercaptans coming for the hydrodesulfurization distillation column is reduced. Finally there is a potential savings in octane due to the milder treatment of the olefin rich thiophene cut.

BRIEF DESCRIPTION OF THE DRAWINGS FIG. 1 is a simplified flow diagram of one embodiment of the invention.

FIG. 2 is a simplified flow diagram of an alternative embodiment having a having a thioetherification pretreatment.

DETAILED DESCRIPTION OF THE INVENTION The feed to the process comprises a sulfur-containing petroleum fraction which boils in the gasoline boiling range. Feeds of this type include light naphthas having a boiling range of about C5 to 330 °F and full range naphthas having a boiling range of C5 to 420 °F. Generally the process is useful on the naphtha boiling range material from catalytic cracker products because they contain the desired olefins and unwanted sulfur compounds. Straight run naphthas have very little olefinic material, and unless the crude source is"sour", very little sulfur.

The sulfur content of the catalytically cracked fractions will depend upon the sulfur content of the feed to the cracker as well as the boiling range of the selected fraction used as feed to the process. Lighter fractions will have lower sulfur contents than higher boiling fractions. The front end of the naphtha contains most of the high octane olefins but relatively little of the sulfur. The sulfur components in the front end are mainly mercaptans and typical of those compounds are: methyl mercaptan (b. p.

43°F), ethyl mercaptan (b. p. 99°F), n-propyl mercaptan (b. p. 154°F), iso-propyl mercaptan (b. p. 135-140°F), iso-butyl mercaptan (b. p. 190°F), tert-butyl mercaptan (b. p. 147°F), n-butyl mercaptan (b. p. 208°F), sec-butyl mercaptan (b. p. 203°F) and 3-mercapto hexane (b. p. 135°F). Typical sulfur compounds found in the heavier boiling fraction include the heavier mercaptans, thiophenes sulfides and disulfides.

The reaction of these mercaptans with diolefins contained within the naphtha is called thioetherification and the products are higher boiling sulfides. A suitable catalyst for the reaction of the diolefins with the mercaptans is 0.4 wt. % Pd on 7 to 14 mesh Al203 (alumina) spheres, supplied by Sud-Chemie, designated as G-68C-1.

Typical physical and chemical properties of the catalyst as provided by the manufacturer are as follows : TABLE I Designation G-68C-1 Form Spheres

Nominal size 7x12 mesh Pd. wt. % 0.4 0. 03 Support High purity alumina (99.0-99. 5) Another catalyst useful for the mercaptan-diolefin reaction is Ni silica/alumina extrudates, supplied by Sud-Chemie, designated as C46-7-03RS. Typical physical and chemical properties of the catalyst as provided by the manufacturer are as follows : TABLE II Designation C46-7-03 RS Form Extrudate Nominal size 1/16" Ni wt. % 524 Support Silica/Alumina The hydrogen rate to the reactor must be sufficient to maintain the reaction, but which is understood to be the"effectuating amount of hydrogen"as that term is used herein. The mole ratio of hydrogen to diolefins and acetylenes in the feed is at least 1.0 to 1.0 and preferably 2.0 to 1.0.

Another method suitable for removing mercaptans from a light naphtha is the wet caustic washing process. In such a process the light naphtha is contacted with caustic. The mercaptans are solublized into the aqueous caustic phase. The mercaptans are then reacted to form disulfides. The amount of mercaptan extracted is limited by the solubility of the mercaptan in the caustic solution.

Catalyst which are useful for the hydrodesulfurization reaction include Group VIII metals such as cobalt, nickel, palladium, alone or in combination with other metals such as molybdenum or tungsten on a suitable support which may be alumina, silica-alumina, titania-zirconia orthe like. Normallythe metals are provided as the oxides of the metals supported on extrudates or spheres and as such are not generally useful as distillation structures.

The catalysts contain components from Group V, VIB, VIII metals of the Periodic Table or mixtures thereof. The use of the distillation system reduces the deactivation and provides for longer runs than the fixed bed hydrogenation units of the prior art. The Group VIII metal provides increased overall average activity.

Catalysts containing a Group VIB metal such as molybdenum and a Group VI I I such as cobalt or nickel are preferred. Catalysts suitable for the hydrodesulfurization reaction include cobalt-molybdenum, nickel-molybdenum and nickel-tungsten. The metals are generally present as oxides supported on a base such as alumina, silica- alumina or the like. The metals are reduced to the sulfide either in use or priorto use by exposure to sulfur compound containing streams. The catalyst may also catalyze the hydrogenation of the olefins and polyolefins contained within the light cracked naphtha and to a lesser degree the isomerization of some of the mono-olefins. The hydrogenation, especially of the mono-olefins in the lighter fraction may not be desirable.

Typical preferred conditions for the thiothetherification reaction in a standard down flow fixed bed reactor include temperatures in the range of 170 to 400°F, pressures of 145 to 290 psia and liquid hourly space velocities of 1 to 10 vol. of naphtha/volume of catalyst/hr.

The properties of a typical hydrodesulfurization catalyst are shown in Table I below.

TABLE III Manufacture Criterion Catalyst Co.

Designation C-448 Form Tri-lobe Extrudate Nominal size 1.2 mm diameter Metal, Wt. % Cobalt 2-5% Molybdenum 5-20% Support Alumina The catalyst typically is in the form of extrudates having a diameter of 1/8, 1/16 or 1/32 inches and an L/D of 1.5 to 10. The catalyst also may be in the form of spheres having the same diameters. They may be directly loaded into standard straight pass fixed bed reactors which include supports and reactant distribution structures.

Reaction conditions for sulfur removal only in a standard straight pass fixed bed reactor are in the range of 500-700°F at pressures of between 400-1000 psig.

Residence times expressed as liquid hourly space velocity are generally typically between 1.0 and 10. The naphtha in the straight pass fixed bed reaction may be in the liquid phase or gaseous phase depending on the temperature and pressure, with total pressure and hydrogen gas rate adjusted to attain hydrogen partial pressures in the 100-700 psia range. The operation of the straight pass fixed bed hydrodesulfurization is otherwise well known in the art.

Referring now to the FIG 1 a simplified flow diagram in schematic form of one embodiment is shown. The naphtha feed enters a naphtha splitter 10 via flow line 101. A light naphtha containing mostly C5's is taken as overheads via flow line 102.

The light naphtha also contains most of the mercaptans and little other organic sulfur compounds. An intermediate naphtha boiling in the range of C6 to about 300°F is taken via flow line 104 as a side draw. The intermediate naphtha containing predominantly thiophenes along with some mercaptans. A heavy naphtha boiling in the range of 300-450°F is taken as bottoms via flow line 106. The heavy naphtha may contain some thiophene but basically contains the heavier boiling organic sulfur compounds which for a better term are called other organic sulfur compounds.

The light naphtha in flow line 102 is treated by a wet caustic wash to in reactor 20 remove the mercaptans and taken as product via flow line 103 to be used primarily as feed to a tertiary amyl methyl ether process. The bottoms in flow line 106 is subjected to hydrodesulfurization in reactor 40 with hydrogen for the process being added via flow line 107. In reactor 40 substantially all of the thiophene and most of the other organic sulfur compounds are converted to hydrogen sulfide which can easily be removed by flashing or distillation. The effluent from the reactor 40 is combined with the intermediate naphtha in flow line 104 and fed to a second hydrodesulfurization reactor 30 where hydrogen is added via flow line 105 for polishing. Basically the thiophene in the intermediate naphtha and the remaining organic sulfur compounds in the heavy naphtha are converted to hydrogen sulfide.

A combined naphtha product is taken from reactor 30 via flow line 109 Referring now to FIG. 2 a second embodiment is shown. The entire naphtha feed is fed via flow line 101 to a thioetherification reactor 20 where the diolefins in the naphtha react with the mercaptans to sulfides. The effluent from the reactor 20 is fed via flow line 102 to the naphtha splitter 10 where the naphtha is split into three

fractions. A light naphtha containing mostly C5's is taken as overheads via flow line 103. Because the mercaptans have been removed in the thioetherification reactor the light naphtha contains very little organic sulfur. An intermediate naphtha boiling in the range of C6 to about 300° is taken via flow line 104 as a side draw. The intermediate naphtha containing predominantly thiophenes along with some mercaptans. A heavy naphtha boiling in the range of 300-450° is taken as bottoms via flow line 106. The heavy naphtha may contain some thiophene but basically contains the heavier boiling organic sulfur compounds which for a better term are called other organic sulfur compounds.

The bottoms in flow line 106 is subjected to hydrodesulfurization in reactor 40 with hydrogen for the process being added via flow line 107. In reactor 40 substantially all of the thiophene and most of the other organic sulfur compounds are converted to hydrogen sulfide which can easily be removed by flashing or distillation.

The effluent from the reactor 40 is combined with the intermediate naphtha in flow line 104 and fed to a second hydrodesulfurization reactor 30 where hydrogen is added via flow line 105 for polishing. Basically the thiophene in the intermediate naphtha and the remaining organic sulfur compounds in the heavy naphtha are converted to hydrogen sulfide. A combined naphtha product is taken from reactor 30 via flow line 109.