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Publication numberUS3349027 A
Publication typeGrant
Publication dateOct 24, 1967
Filing dateFeb 8, 1965
Priority dateFeb 8, 1965
Publication numberUS 3349027 A, US 3349027A, US-A-3349027, US3349027 A, US3349027A
InventorsCarr Norman L, Horne William A, Offutt William C, Somers Allen E
Original AssigneeGulf Research Development Co
Export CitationBiBTeX, EndNote, RefMan
External Links: USPTO, USPTO Assignment, Espacenet
Multi-stage hydrodesulfurization process
US 3349027 A
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Description  (OCR text may contain errors)

4 Sheets-Sheet 1 Filed. Feb. 8, 1965 a; W Z. a 1m in w Z a Z m f m INVENTORS Jprnaml J 1122622 Zffiuners.

Oct. 24 1967 CARR ETAL 3,349,027

MULT I-STAGE HYDRODESULFUR I ZATION PROCES 5 Filed Feb. 8, 1965 Y 4 Sheets-Sheet 2 dZZezz 251 flowers,

Oct 24;, 1967 N. L. CARR ETAL 3,349,027

MULTI-STAGE HYDRODESULFURI ZATION PROCES 5 N. L. CARR ETAL MULTI-STAGE HYDRODESULFUR I ZATION PROCESS Filed Feb. 8, 1965 4 Sheets-$heet 4 fl rmra Z. 'arr WZZZzdnd./%rae WiZZz'am 6f fijzii AZZem 235022675:

United States Patent Ofifice 3,349,027 Patented Oct. 24, 1967 3,349,027 MULTI-STAGE HYDRODESULFURIZATION PROCESS Norman L. Carr, Allison Park, William A. Horne, Oakmont, and William C. Olfutt and Allen E. Somers, Pittsburgh, Pa., assiguors to Gulf Research & Development, Company, Pittsburgh, Pa., a corporation of Delaware Filed Feb. 8, 1965, Ser. No. 430,907 5 Claims. (Cl. 208210) This invention relates to improved procedures for the catalytichydrodesulfurization of light petroleum gases and distillate hydrocarbons boiling below about 650 F.

It has been known to remove sulfur compounds from petroleum hydrocarbons by contacting these petroleum hydrocarbons with hydrogen and hydrodesulfurization catalysts. This desulfurization of petroleum hydrocarbons bearing sulfur compounds is necessary to make marketable furnace oils and other fuels and to prevent deterioration of sulfur sensitive catalysts upon subsequent processing of the petroleum hydrocarbons.

Reaction conditions for catalytic hydrodesulfurization typical of those taught in the prior art are temperatures of from 300 to 800 F., pressures of from 100 to 1000 p.s.i., space velocities of from less than 1 to about 5 liquid hourly space velocity (LHSV), and hydrogen re- .cycle rates of up to 2000 standard cubic feet of hydrogen per barrel of hydrocarbon charge. The prior art teaches two-stage hydrodesulfurization with removal of sulfur compounds between the stages. However, the use of unusually high space velocities, in general, and use of unusually high space velocities in a multi-stage process with removal of sulfur compounds at a specific point between stages is not taught in the prior art.

This invention has for its object the use of unusually high space velocities in a multi-stage catalytic hydrodesulfurization process, so that the judicious removal of gaseous sulfur compounds (primarily H 8) between the stages permits use of a much smaller catalyst bed as compared with catalyst beds necessary for the processes taught in the prior' art.

Another more specific object of this invention is to accomplish essentially complete removal of sulfur compounds from light petroleum gases, naphthas, and other distillate oils using a multi-stage catalytic hydrodesulfurization process with unusually high space velocities.

The objects of our invention are accomplished by subjecting light petroleum gases or distillate hydrocarbons boiling below about 650 F. to a continuous, multi-stage, catalytic hydrodesulfurization process. This continues hydrodesulfurization process partially desulfurizes the hydrocarbon in the first stage, then the hydrodesulfurization is interrupted before hydrogen sulfide can substantially .inhibit further catalytic reaction and hydrogen sulfide is removed from the reaction product, then this partially hydrodesulfurized reaction product is again contacted with hydrogen and hydrodesulfurization catalyst under hydrodesulfur-ization conditions.

The charge stocks suitable for catalytic desulfurization by this'invention are light petroleum gases and hydrocarbon distillates boiling below 650 F. Natural gasoline,

naphthas,-furnace oils and natural gas are examples of suitable feed stocks. Feeds will ordinarily contain .05 to 1.0% sulfur.

Each of the hydrodesulfurization units of the multistage process operates at essentially the same conditions and with the same catalyst. However, it is within the scope of this invention to operate the successive units at differing conditions, if necessary. Suitable operating ranges for our invention would be 400 to 750 F., 400 to 700 p.s.i.g., 30 to 200 LWHSV, 200 to 4000 s.c.f./bbl. of hydrogen, and a hydrogen purity of 50 to 100%. Preferred operating ranges are 500 to 600 F., 550 to 650 p.s.i.g., 50 to 100 LWHSV, 600 to 3000 s.c.f./bbl. of hydrogen and a hydrogen purity greater than 75%.

The catalysts suitable for the hydrofining in this invention may include the oxides and sulfides of Group VI and Group VIII (nonplatinum) metals alone or in ad- 7 mixture with each other deposited upon a nonacidic support or carrier such as activated alumina, bauxite, etc. Nickel-cobalt-molybdenum, cobalt molybdate or mixtures of cobalt oxide and molybdenum oxide on alumina are preferred and most often used because of their good activity, selectivity, long life, insensitiveness to poisons, strength and low cost.

The most important element of our invention, selection of the precise point of separation of sulfur impurities in the form of H 8 and mercaptans from the catalyst bed, was determined by extensive experimental work. It was found that the initial hydrodesulfurization reaction rates were extremely fast, resulting, for example, in a conversion of to 99% at a LWHSV of 100. In addition, it was found that the presence of H 8 in the reacting mixture has a large deleterious effect on the desired conversion of sulfur compounds in the feed. By using a multistage process with unusually high space velocities, the H 5 can be removed from the catalyst bed before the deleterious effect of H 8 in the reacting mixture can proceed to any appreciable extent.

In the following examples two sets of experimental runs were made. One set (Example 1) shows the adverse effect of the reverse reaction of H 8 and hydrocarbon upon the desired hydrodesulfurization reaction. The second set (Example 2) shows the improvement obtained by removing H S at a carefully selected point between stages.

Example 1 A study of conversion as aiunction of space-time, which is the reciprocal of space velocity, was made on a simulated naphtha charge having the sulfur content shown in the first column of Table I at 600 F., 650 p.s.i.g., 0.78 hydrogen ratio, and space velocitie which varied between 5 and 400 LWHSV. The experimental results are listed in Table I. The nonmercaptan sulfur concentration decreased from 1330 p.p.m. to 10 p.p.m. as the space velocity decreased. However, the hydrogen sulfide content built up to a constant level of 360 to 390 p.p.m. In the accompanying drawings the nonmercaptan and mercaptan conversions were plotted versus spacetime (the reciprocal of space velocity) to give the results shown in FIGURE 1. Note the extreme nonlinear behavior for both nonmercaptan and mercaptan sulfur inin a simulation of a first desulfurization stage (Run 1) to 3 dicating that a similar reaction mechanism is operative for both types of compounds. The complete composition TABLE I.SPACE VELOCITY VERSUS SULFUR DISTRIBUTION IN HYDRODESULFURIZATION OF NAPHTHA [Catalystz 10-20 mesh NiCoMo on filtrol alumina; Feed: Naphtha] Run No. Feed Temperature, F 602 602 602 601 600 602 Pressure, p.s.i.a. 665 665 665 665 665 665 Hz Ratio, Mole/Mole Ov 77 0. 78 0.77 0.77 0.77 0.80 Liquid Hourly Space Velocity, r. 399 198 101 50 21 5 Total Sulfur in H1 Stripped Liquid Product,

p.p.m 730 500 260 90 40 Mercaptan Sulfur in Liquid Pro as Tested on Hg Stripped Product. p.p.m 330 80 20 10 5 0. 5 Hydrogen Sulfide in Liquid Product, p.p.m 228 313 394 396 358 Nonmcrcaptan Sulfur in Liquid Product (by difference), p.p.m 1,330 650 470 240 80 9.7 Conversion of Mereaptan Sulfur, percent by wt. 75. 6 90.8 93. 9 96. 9 98v 4 99. 9 Conversion of Nonmercaptan Sulfur, percent by By difference between total sulfur and mercaptan in the stripped product. Conversion of mercaptan (originally present and/or formed from nonmercaptan).

sulfurization stage. Afterthe hydrocarbon product from the first stage (Run 1) was strippedwith hydrogen tov profiles are plotted in FIGURE 2 as moles (or weight) of sulfur as the individual sulfur compounds per mole (or TABLE II.EFFECT OF REMOVING HaS AND LOW-BOILING IVIERCAPTANS IN HYDRODESULFURIZATION OF NAPHTHA [Catalystz 10-20 mesh NiCoMo on filtrol alumina; Feed: Naphtha] Run N 0. Feed Temperature, F 599 605 603 600 Pressure, p.s.i.a. 665 665 665 665 Hg Ratio, Mole/Mole 0.78 0. 78 0.77 0.76 Liquid Hourly Space Velocity, wt./wt./hr 101 51 15 Over-All Liquid Hourly SpaceVeloeity,

wt./wt./hr 50 34 25 12 Mercaptan Sulfur in Liquid Product,

p.p.m 330 10 0.9 0.9 0. 5 (0.3) Total Sulfur in Liquid Product .e 1, 660 90 39 22 9 Nonmercaptan Sulfur in Liquid Product (byditference), p.p.m 1, 330 80 38 21 8.7 Conversion of Mercaptan Sulfur, percent by Wei ht 97.0 99. 7 99. 7 99.9 Conversion of Nonmercaptan Sulfur,

percent by Weight 94. 0 97.1 98. 4 99. 3

The feed was the Ii -stripped product from Run 1.

remove H 8 and ethyl mercaptan, it was rerun at essentially the same temperature, pressure and hydrogen ratio as in the first stage but at space velocities of about 100,

weight) of sulfur charge versus space-time (defined as grams of catalyst-hour per gram of total liquid feed charged). These profiles show that the non-mercaptan and mercaptan reaction rates (slopes of the curves) are initially high and then decrease rapidly as the hydrogen sulfide builds up. A kinetic analysis shows that the partial stage at three different space velocities. These data are set forth in Table II as Runs 2, 3 and 4 respectively.

provide sufiicient charge stock for a simulated second de- 50 and 15 LWHSV to simulate a second desulfurization pressure of hydrogen sulfide must inhibit the nonmercaptan and mercaptan hydrodesulfurization reaction rate constants.

Example 2 Another set of tests was made to show the advantage of using a two-stage hydrodesulfurization with removal of H 8 between stages. The charge stock was a simulated naphtha charge consisting of 7.8% coker naphtha, 5.9% visbreaker naphtha and 86.3% virgin naphtha. It contained 1660 p.p.m. total sulfur of which 330 p.p.m..were mercaptan sulfur and 1330 p.p.m. were nonmercaptan sulfur. The catalyst used was 10 to 20 mesh nickel-cobaltmolybdenum on Filtrol alumina consisting of an alumina base impregnated with 2.3% nickel, 1.2% cobalt and 11.0%of molybdenum.

The results from these tests are set forth in Table II. The charge naphtha was hydrodesulfurized at 599 F., 650 p.s.i.g., 50 LWHSV and 0.78 hydrogen ratio (mole/mole) The data from these runs were used to plot the points shown by squares labeled Second Reactor in FIGURES 3 and 4, FIGURE 3 concerns the conversion of mercaptan sulfur and FIGURE 4 the conversion of nonmercaptan sulfur compounds. .In each graph, conversion is plotted against space-time. Those points shown by circle and called First Reactor are based on the data given in Runs 1, 4 and 5, Table 1. Note that Run 1, Table II, is nearly identical to Run 4, Table I. Thus, the comparison in FIGURES 3 and 4 is permissible to show simulated first and second reactor runs. Run 1, Table II, was necessary only to produce sufficient charge stock for simulated second reactor runs.

the leveling off of the curve. However, by removing H 8 between stages, in this instance at 0.02 spacetime, desulfurization in the second reactor increases sharply in FIGURE 3 from 97.0 to 99.6% in about 0.01 spacetime. This shows the judicious removal of H 8 at a precise point between the reactor units does have a very beneficial effect on the reaction. However, since this point cannot be found so precisely that no reverse reaction occurs, the mercaptans formed, it any, may be removed along with the H 8 at this point.

Another way to depict the advantage of interstage H 5 removal is by Activity Ratio. For example, on FIGURE 3, choose the degree of mercaptan conversion as 99.6% by weight. To reach this desulfurization level with one reactor, a space-time of 0.163 is needed. However, with the high space velocity, multi-stage system, the space-time is only 0.026. Thus, the Activity Ratio is 0.163/0026 or 6.3. From FIGURE 1 it will be evident that 0.01 to 0.07 space-time and preferably 0.02 to 0.05 space-time is an advantageous range in which to remove H 8.

The closest direct experimental data comparison of a single reactor with a two-reactor system at similar operating conditions is Run 5 in Table I and Run 3 in Table II. These tests were made at essentially the same operating conditions except Run 5 was made at 21 LWHSV and Run 3 was at an overall space velocity of 25 LWHSV. Run 3 product, the two-stage operation with H S removal between stages, contained 0.9 p.p.m. mercaptan sulfur with 99.7% by weight over-all conversion of feed mercaptan sulfur. Run 5 product contained 5 p.p.m. mercaptan sulfur with 92.4% by weight conversion of feed mercaptans.

Thus, the data given in the tables and plotted on the graphs show that equivalent desulfurization and nearly complete desulfurization is possible using unusually high space velocities and much smaller reactors by removal of H 5 between the reactors.

The unusually high space velocity of this invention makes possible the use of much smaller reactors than those now in conventional use. For example, a cylindrical reactor for each unit of about 2 cubic feet would be sufficient for a 1000 barrel per day unit.

To adsorb the H 8 and mercaptans between stages, either of the following alternatives is satisfactory. Both methods use parallel multi-bed, preferably dual-bed units, containing materials which have an aflinity for removing sulfur compounds, especially H S from hydrocarbon streams. One of the alternative methods uses regenerable adsorbent, while the other uses a disposable adsorbent. The reactor efiluent vapors including hydrogen are contacted with the adsorbents at about 500 to 600 F about 550 to 650 p.s.i.g., and about 0.2 to 6.0 LHSV. The preferred adsorber temperatures and pressures are the same as those for the previous hydrodesulfun'zation unit to avoid the need for heat exchangers prior to or after the H S adsorber and also to avoid the need for compressors or pressure reducing equipment.

The preferred regenerable method is use of copper or copper oxide impregnated on a silicon carbide support as the adsorbent. Other possible regenerable adsorbents are nickel, iron, molybdenum, their oxides and compounds such as copper molybdate, cobalt molybdate or nickel molybdate supported on silica, silica-alumina, or alumina. These regenerable adsorbents are reactivated at given intervals. Regeneration is necessary only when the efiiuent from the adsorber shows sulfur content above that permissible. The sulfur content can be monitored by some automatic detecting unit such as a thermal conductivity cell to switch the reactor efiluent from one of the parallel adsorbents to the other. For example, a mercaptan analyzer for process use has been developed by the Gulf Physical Sciences Division. This permits regeneration of one of the adsorbent beds while the hydrodesulfuriza-tion continues.

Regeneration should take place when 30 to 60% of the metallic content of the catalyst has been converted to the metal sulfide. Before regeneration the adsorbent bed is purged with an inert gas to recover hydrocarbons in the bed. Then an oxygen containing gas is admitted to the adsorbent bed. The oxygen content of this gas is controlled to maintain a temperature between about 1000 and 1300 F. at a pressure of atmospheric to about 500 p.s.i.g. The diluent inert gas to air ratio varies from none to about 20 volumes per volume. Another purge with inert gas is necessary to remove any oxygen from the bed prior to contact with reactor etfiuent. If the adsorbent is a metal or metal mixed with metal oxide, a reducing treatment is necessary to restore the metal to its original form. The preferred nonregenerable adsorbent is zinc oxide or iron oxide. Operation of the parallel adsorbent bed would be the same as discussed above except that the spent adsorbent is replaced with fresh adsorbent rather than regenerated. The adsorbent beds to be used with a 2 cubic foot reactor would be about cubic feet in volume. Although we have at times mentioned removal of both hydrogen sulfide and mercaptans, this invention is not limited to removal of both. Any mercaptans or other sulfur impurities formed during hydrodesulfurization may be removed at the same time that H S is removed. Therefore, removal of sulfur compounds other than H 5 is not essential to this invention although it may advantageous in some cases.

What we claim is: 1. A continuous, multi-stage, catalytic process for the hydrodesulfurization of a hydrocarbon stream boiling below about 650 F. which comprises treating said hydrocarbon stream with hydrogen in a first reactor in the presence of a hydrodesulfurization catalyst at hydrodesulfurization conditions of pressure and temperature and at a weight hourly space velocity of between about 21 and 200,

separating gaseous sulfur compounds from the hydrocarbon efiinent stream from the first reactor, and

treating the hydrocarbon efiluent stream with hydrogen in a second reactor in the presence of a hydrodesulfurization catalyst at hydrodesulfurization conditions of pressure and temperature and at a weight hourly space velocity of between about 21 and 200.

2. A process in accordance with claim 1 in which the weight hourly space velocity in said reactor is between about 30 and 100.

3. A process in accordance with claim 1 in which the weight hourly space velocity in said second reactor is between about 30 and 100.

4. A process in accordance with claim 3 in which the weight hourly space velocity in said reactor is between about 30 and 100.

5. A process in accordance with claim 1 in which hydrogen sulfide is removed from the hydrocarbon eflluent stream from the first reactor.

References Cited UNITED STATES PATENTS 3,155,608 11/1964 Hopper et al 20889 3,175,970 3/1965 Bercik et al 20889 3,228,993 1/1966 Kozlowski et al 208-210 3,236,764 2/1966 Den Herder et a1. 208210 3,239,454 3/1966 Streed et al 208-210 DELBERT E. GANTZ, Primary Examiner. SAMUEL P. JONES, Examiner.

UNITED STATES PATENT OFFICE CERTIFICATE OF CORRECTION Patent No. 3,349,027 October 24, 1967 Norman L. Carr et a1.

It is hereby certified that error appears in the above numbered patent requiring correction and that the said Letters Patent should read as corrected below.

Column 1, line 50, for "continues" read continuous column 5, line 29, for "92.4%" read 98.4% column 6, lines 48 and 54, for "said reactor", each occurrence, read said first reactor Signed and sealed this 5th day of November 1968.

EAL)

ttest:

EDWARD J. BRENNER Commissioner of Patents [ward M. Fletcher, Jr.

testing Officer

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Referenced by
Citing PatentFiling datePublication dateApplicantTitle
US3519557 *Aug 15, 1969Jul 7, 1970Sun Oil CoControlled hydrogenation process
US3905893 *Aug 22, 1973Sep 16, 1975Gulf Research Development CoPlural stage residue hydrodesulfurization process
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US3926784 *Aug 22, 1973Dec 16, 1975Gulf Research Development CoPlural stage residue hydrodesulfurization process with hydrogen sulfide addition and removal
US3936370 *Aug 22, 1973Feb 3, 1976Gulf Research & Development CompanyProcess for producing a zeolite riser cracker feed from a residual oil
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US6416659Aug 17, 2000Jul 9, 2002Catalytic Distillation TechnologiesHydrodesulfurization of diesel stream in a distillation column reactor; liquid diesel oil is fed above the catalyst bed and the hydrogen is fed below
US6531054 *Mar 30, 1998Mar 11, 2003Akzo Nobel, N.V.Process for effecting deep HDS of hydrocarbon feedstocks
US6592750Jun 21, 2001Jul 15, 2003Catalytic Distillation TechnologiesTwo staged process wherein hydrogen sulfide is removed between the stages to prevent recombinant mercaptans formation; milder conditions can be used in the second stage
US7374667 *Mar 12, 2002May 20, 2008Bp Corporation North America, Inc.Process for the production of gasoline with a low sulfur content comprising a stage for transformation of sulfur-containing compounds, an acid-catalyst treatment and a desulfurization
US7754068Nov 21, 2006Jul 13, 2010Petroleo Brasileiro S.A.-Petrobrastwo-stage hydrodesulfurization and H2S removal from the first stage effluent, with the first reaction stage catalyst being a more active hydrodesulfurization catalyst than the second reaction stage catalyst
US7785461Apr 6, 2005Aug 31, 2010Petroleo Brasileiro S.A. - Petrobraswhich minimizes the hydrogenation of the olefins; two stage; flow of hydrogen and added non-reactive compound; H2S is removed from the effluent of the first reaction stage; fluidized catalytic cracking naphthas (FCC naphthas)
EP0239310A1 *Mar 18, 1987Sep 30, 1987Exxon Research And Engineering CompanyProcess for manufacturing process oil
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Classifications
U.S. Classification208/210, 208/246, 208/244, 208/216.00R, 208/245, 208/243
International ClassificationC07C7/00, C10G65/12, C10G67/06, C10G65/00, C07C7/163, C10G67/00
Cooperative ClassificationC10G67/06, C10G65/12, C07C7/163
European ClassificationC10G67/06, C10G65/12, C07C7/163