US3775303A - Production of low sulfur asphaltic fuel oil - Google Patents

Production of low sulfur asphaltic fuel oil Download PDF

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US3775303A
US3775303A US00205791A US3775303DA US3775303A US 3775303 A US3775303 A US 3775303A US 00205791 A US00205791 A US 00205791A US 3775303D A US3775303D A US 3775303DA US 3775303 A US3775303 A US 3775303A
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sulfur
percent
line
oil
aromatics
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J Mckinney
J Paraskos
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Chevron USA Inc
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Gulf Research and Development Co
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    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G65/00—Treatment of hydrocarbon oils by two or more hydrotreatment processes only
    • C10G65/02—Treatment of hydrocarbon oils by two or more hydrotreatment processes only plural serial stages only
    • C10G65/04—Treatment of hydrocarbon oils by two or more hydrotreatment processes only plural serial stages only including only refining steps
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/10—Feedstock materials
    • C10G2300/107—Atmospheric residues having a boiling point of at least about 538 °C

Definitions

  • PRODUCTION 01 LOW SULFUR ASPHALTIC FUEL OIL 4 Sheets-Sheet z 750 770 792 825 AVERAGE REACTOR TEMPERATURE; F.
  • This invention relates to a process for the production of crude or residual oils having an especially low sulfur content. More particularly, this invention relates to a hydrodesulfurization process .for producing an asphaltic fuel oil having a low sulfur content.
  • Asphalt is a generally low-grade material that has been isolated from the crude oil and utilized in road construction.
  • asphalt has been proposed to treat the asphaltic fraction of crude oil in some manner so as to upgrade this material into a more valuable product such as a fuel oil.
  • asphalt when isolated, is highly viscous and is diflicult to process over a catalyst.
  • Sulfur is a major contributor to air pollution. Accordingly, certain municipalities, both local and foreign, have placed an upper limit on the sulfur content of fuel oils. In the past, such locales have placed a one percent by weight sulfur limit on heavy fuel oils, but the trend has been to a lower maximum sulfur content, such as 0.5 percent. Such limitations have provided a major impediment to the use of heavy asphaltic hydrocarbon oil fractions as fuel oil, since an asphaltic fuel oil having a 0.5 percent sulfur content is not easily obtained from some high sulfur crudes merely by passing the crude oil over a desulfurization catalyst.
  • a particular heavy fuel oil containing an asphalt fraction may be produced having a sulfur content below one percent by weight by means of the present invention which comprises a process which involves passing an asphalt-containing or asphaltic, hydrocarbon oil, such as a crude oil or residual oil (a reduced crude) containing more than about one percent sulfur to a first hydrodesulfurization zone in the presence of hydrogen, withdrawing a first effluent from the first hydrodesulfurization zone having a reduced sulfur content relative to the feedstock, said first effluent comprising hydrogen sulfide, a light gas fraction, an oil fraction containing aromatics and saturates, and a higher boiling asphaltic fraction.
  • the oil fraction is referred to as light oil to contrast it to the higher boiling asphaltic fraction.
  • the hydrogen sulfide, the light gas fraction, and a low boiling portion of the light oil fraction are separated from the first eflluent, and the remaining portion of the first efiluent comprising the asphaltic fraction and a higher boiling portion of the oil fraction is passed to a second hydrodesulfurization zone in the presence of hydrogen.
  • Each hydrodesulfurization zone is provided with a hydrodesulfurization catalyst that is disposed on a non-cracking support.
  • An asphaltic hydrocarbon oil is withdrawn from the second hydrodesulfurization zone which oil provides a heavy, asphaltic fuel oil containing less than one percent by weight sulfur.
  • Another aspect of the present invention involves a process which comprises passing an asphaltic, hydrocarbon feed containing more than about one percent sulfur to a hydrodesulfurization zone in the presence of hydrogen and a light oil fraction comprising aromatics and saturates having a boiling point below the asphaltic portion of the feedstock to said hydrodesulfurization zone, and controlling the amount of said light oil, and thus the amount of aromatics and saturates that are passed to the hydrodesulfurization zone to increase the desulfurization rate and permit the recovery of a heavy, asphaltic hydrocarbon fuel containing less than about one percent sulfur.
  • the present invention provides an asphalt-containing heavy fuel oil, which is practically sulfur free, without the need for blending the asphaltic fuel oil with a sulfur-free middle distillate oil in order to obtain an oil having a low sulfur content although such blending is not precluded in accordance with the present invention.
  • a still further aspect of the present invention relates to a process for controlling the hydrodesulfurization of an asphaltic, heavy oil, which process comprises passing a crude oil or residual oil, for example, which oil contains an asphaltic fraction, through a hydrodesulfurization zone in the presence of hydrogen, the oil increasing in aromatic hydrocarbon content as it passes through the hydrodesulfurization zone, controlling the aromatic content of the oil as the oil passes through said hydrodesulfurization zone, and then withdrawing the oil from said hydrodesulfurization zone at substantially the point at which the aromatic content of the oil no longer increases.
  • asphalt or asphaltic as employed in the present specification is intended to include the resins and asphaltenes present in crude oil.
  • Asphalt can constitute approximately to 30 percent by volume or more of crude oil and has an initial boiling point of about 1040 F. It is obtained in refineries by a propane deasphalting process (solvent extraction), or from the residues obtained from distillation.
  • Asphaltenes are highly aromatic and consist of large molecules of fused aromatic rings and normally contain the greatest sulfur concentration of any constituent of the full range crude. Unlike other crude fractions, asphalt also contains metals, principally nickel and vanadium.
  • the asphaltenes and resins may be distinguished from the remainder of the crude oil, which material comprises saturates and aromatics, by virtue of the solubility of these aromatics and saturates in propane and the insolubility of the asphaltenes and resins in propane.
  • the propane-soluble aromatics include benzenes, naphthalenes, thiophenes, benzothiophenes, and dibenzothiophenes as the predominant molecular species, while the saturates include the non-aromatic, propane-soluble species, such as the naphthenes, e.g., cyclohexanes, and the parafiins, e.g., dodecane, and sulfur-containing compounds, such as s-butyl mercaptan.
  • the material commonly referred to as asphalt comprises the residue of a propane extraction.
  • resins and asphaltenes are themselves separable by a pentane extraction, by virtue of the fact that asphaltenes are insoluble in pentane, while both resins and oils are soluble in pentane.
  • the point at which the sulfur remaining in the crude oil becomes refractory may vary with the nature of the particular type of crude oil. This point may be easily determined experimentally.
  • the asphaltenes consist of large molecules of fused aromatic rings and contain sulfur in the interior of the large molecules, thereby rendering the sulfur extremely difiicult to remove.
  • the asphalt contains all of the metals, such as nickel and vanadium that are present in the crude, and these metals readily deposit on the catalyst tending to deactivate the catalyst and reduce its effectiveness.
  • FIG. 1 is a flow diagram illustrating the desulfurization of an asphaltic, reduced crude in two stages
  • FIG. 2 illustrates graphically the percent yield of materials boiling above the initial boiling point of the feed to a desulfurization reactor as the average reactor temperature increases
  • FIG. 3 graphically illustrates the change in concentration of the aromatic, saturate, asphaltene and resin fractions of an asphalt-containing reduced crude as the degree of desulfurization increases;
  • FIG. 4 graphically illustrates volume percentages of aromatics and saturates that are removed at various interstage flash points
  • FIGS. 5 to 9 are diagrammatic schemes for obtaining a low sulfur, light aromatic-rich fraction from one portion of the feedstock to solubilize and reduce the viscosity of the solution of asphaltenes and resins present in the residual portion of the feed prior to desulfurization of the asphaltenes and resins.
  • a reduced crude such as a 50 percent reduced Kuwait crude which contains the entire asphalt content of the full crude and therefore also contains all of the nickel and vanadium and most refractory sulfur content of the full crude is charged to the process through line 10 and is pumped through line 14, preheater 16, line 18, solids filter 20 and line 22 to drum 24. From drum 24 the liquid oil charge is passed through line 26 to feed pump 30.
  • Liquid from pump 30 is admixed with hydrogen from line 32 and passed through line 34, valve 36, line 38 and furnace 40.
  • Liquid flow valve 36 is disposed in a non-fully preheated liquid hydrocarbon line.
  • Recycled hydrogen along with make-up hydrogen are introduced into the liquid charge to the reactor prior to the preheating thereof.
  • Recycled hydrogen is passed through line 42 and valve 44, while make-up hydrogen may be charged through line 46, compressor 48 and valve 50.
  • the recycled hydrogen and any make-up hydrogen are introduced to the relatively cool liquid charge through line 32.
  • a preheated mixture of liquid charge and hydrogen in line 54 may be passed through a guard reactor (not shown), if desired.
  • An efiluent stream from the guard reactor is charged to the main reactor 60 containing catalyst beds 62, 64 and 66. This stream may have a 650 F boiling range, for example.
  • the hydrodesulfurization catalyst employed in the process of the present invention is conventional and comprises, for example, Group VI and Group VHI metals on a non-cracking support.
  • the catalyst may comprise nickel-cobalt-molybdenum or cobalt-molybdenum on an alumina support.
  • the alumina may be stabilized with 1 to 5 percent by weight of silica.
  • the preferred catalyst is a nickel-cobalt-molybdenuin on alumina containing less than 1 percent silica which catalyst may or may not be sulfided.
  • Magnesia is also a non-cracking support.
  • An especially preferred catalyst comprises a particulate catalyst comprising particles between about 6 and ,4 inch in diameter, such as described in U.S. Pat. 3,562,800 to Carlson et al., which patent is hereby incorporated by reference.
  • the same or a different hydrodesulfurization catalyst can be employed in each stage.
  • An essential feature of the present invention is that the catalyst is provided on a non-cracking support, since the process of the present invention is essentially a noncracking process in that very little material is produced having a boiling point below the initial boiling point of the feed. However, high boiling material in the feed may be cracked to produce lower boiling products still in the 'boiling range of the feed. Thus, whereas prior processes have employed techniques involving, for example, high silica-containing catalysts, e.g.
  • the process of the present invention involves mainly the severance of carbon-sulfur bonds of the asphaltenes and resins in order to desulfurize the difficulty desulfurizable asphalt, rather than cracking carbon-carbon bonds, which results in lower molecular weight materials.
  • sulfur is removed from oils during the present process, but this type of sulfur removal is relatively easy to accomplish.
  • the cracking of carbon-carbon bonds as in prior processes employing cracking produces a material other than a heavy fuel oil and is outside the scope of the present invention.
  • a relatively minor amount of material is produced having a boiling point below the initial boiling point of the feed to the hydrodesulfurization unit.
  • hydrogen is introduced along with the feedstock by means of line 32.
  • Conventional reaction conditions in the hydrodesulfurization reactor are employed, for example, a hydrogen partial pressure of 1000 to 5000 pounds per square inch, preferably 1000 to 3000 pounds per square inch, is employed.
  • a hydrogen partial pressure of 1500 to 2500 pounds per square inch is especially preferred.
  • the gas circulation rate may be between about 200 and 20,000 standard cubic feet per barrel, generally, or preferably about 3000 to 10,000 standard cubic feet per barrel of feed, and preferably containing 85 percent or more of hydrogen.
  • the mol ratio of hydrogen to oil may be between about 8:1 and 80:1.
  • a hydrogen partial pressure of at least 1000 pounds per square inch is provided. This is necessary in order to desulfurize the asphaltic oil of the present invention to the necessary extent and in order to get the hydrogen to the reactive surface of the asphaltene molecule. It is the chemical activity as expressed by the partial pressure of hydrogen rather than total reactor pressure which determines hydrodesulfurization activity.
  • Hydrodesulfurization reactor temperatures may range between about 650 and about 900 F., and preferably between about 680 and 800 F.
  • each succeeding catalyst bed 62, 64 and 66 may have a larger volume than the bed just prior to it. If desired, there may be 4 to 6 catalyst beds in the reactor and, if desired, each reactor bed may have 25 percent, 50 percent, 100 percent or more catalyst than the bed just prior to it.
  • reaction mixture passes through catalyst bed 66 and then leaves the reactor with, for example, about a one percent by weight sulfur content.
  • the process of the present invention permits the eflicient removal of greater than 75 percent sulfur from an asphaltic oil and overcomes the refractory nature of such oils.
  • the eflluent in line 88 is passed to a high pressure flash chamber 90 wherein light hydrocarbon gases, hydrogen sulfide, hydrogen and a controlled portion of the relatively highly desulfurized saturates and aromatics are removed by means of line 92.
  • This interstage flash chamber 90 constitutes a critical feature of the present invention.
  • FIG. 3 the composition of a 650 F.+ hydrocarbon oil containing various proportions of aromatics, saturates, resins and asphaltenes is presented, as the oil is passed through a hydrodesulfurization reactor, such as reactor 60 of FIG. 1.
  • a hydrodesulfurization reactor such as reactor 60 of FIG. 1.
  • the resins and asphaltenes content of the feed steadily decreases with increasing sulfur removal due to the severing of carbon-sulfur bonds thereby breaking off molecular fragments.
  • the accumulation of these molecular fragments is reflected in the build-up of lower molecular saturates and aromatics and particularly aromatics.
  • aromatics content in the liquid is beneficial because the aromatics constitute a solvent for the highly viscous resins and asphaltenes, whereas the resins and asphaltenes are not solvated by saturates.
  • the desulfurization of each fraction continues until about 75 percent sulfur removal, and at that point the resins and aromatics curves reach a plateau which indicates no further cracking of fragments therefrom.
  • the total aromatics and saturates content does not increase further, but an increase in saturates level is acornpanied by a decrease in aromatics level.
  • the sulfur becomes refractory to further desulfurization so that further desulfurization is accompanied by a loss in aromatics and a sharp increase in saturates. Both of these factors are detrimental in regard to removing further sulfur and overcoming the refractory nature of the oil at this point, since at the 75 percent sulfur-removal level most of the unremoved sulfur is concentrated in the resins and asphaltenes. Thus, a loss of aromatics deprives the viscous resins and asphaltenes of some solvation, while the formation of saturates imparts an excessive dispersion to the system tending to excessively dilute the remaining sulfur and thereby lower the reaction rate.
  • the aromatic content of the oil can be'measured as it passes through the reactor, and the oil should be withdrawn from the reactor when the aromatic content of the oil is no longer increased. This was the situation at 75 percent desulfurization in FIG. 3.
  • the aromatic content can increase 25 to 40 percent by weight or more as it passes through the reactor. Even a small increase in aromatics concentration is beneficial, e.g. 2 to 5 or percent by weight. Of course, the aromatics concentration should not increase to such a great extent that it unduly dilutes the sulfur which is to be removed.
  • the interstage flash point is as high as 800 F.
  • the oil fed to the second stage will have a higher ratio of aromatics to saturates which is desirable in order to accomplish high solvation with minimum diluent.
  • the total amount of aromatics which enter the second stage may not be great enough to dissolve the resins and asphaltenes and to sufficiently lower their viscosity to permit desulfurization. Accordingly, a proper balance of aromatics to saturates must be employed in order to obtain optimum desulfurization. This point may be easily experimentally determined for a particular stream undergoing desulfurization. For example, employing as a feed the residue represented by the overhead designated by the solid lines of FIG.
  • the dashed lines of FIG. 4 designate another possible overhead saturates and aromatics distribution in which aromatics begin to predominate in a 550 F. overhead fraction. However, since a 550 F. flash includes all the lighter material, the total overhead will still predominate in saturates over aromatics.
  • a predetermined amount of liquid is flashed and removed by means of line 92.
  • the flashed material in line 92 may contain, for example, between about 5 and about 60 percent by weight of the liquid eflluent from the desulfurization reactor 60, preferably between about 10 and about 35 percent by weight.
  • Suitable flash temperatures include, for example, between about 500 and about 800 F., preferably between about 600 and about 700 F. (These temperatures refer to atmospheric pressure and of course will be different at the process pressure).
  • An especially preferred flash point for the interstage flash is 650 F.
  • the most desirable amount of liquid to be flashed or otherwise separated from the desulfurization effluent stream may be easily determined experimentally.
  • the flashed material in line 92 is passed to a high pressure flash chamber unit 94 wherein hydrogen sulfide and light hydrocarbon gases are separated from a liquid hydrocarbon fraction.
  • the gases are withdrawn by means of line 96 and are subjected to purifica tion and separation, including various scrubbing operations and the like, in recycle gas recovery unit 97.
  • Substantially all of the hydrogen sulfide that is produced in reactor 60 is recovered by means of line 93.
  • Hydrogen now free from hydrogen sulfide and light hydrocarbon gases is recovered from unit 97 and is passed by means of line 99 to recycle gas compressor 101 and recycled for utilization in the process by means of line 103.
  • the non-flashed liquid fraction is discharged from flash unit 94 by means of line 98.
  • the bottoms fraction from the flash unit is discharged by means of line 10 and is admixed with makeup hydrogen, which is provided by means of line 102, valve 105 and line 107.
  • makeup hydrogen may be added to the make-up hydrogen in line 107 from line 103 by means of line 109, valve and line 113.
  • make-up hydrogen may be passed from line 103 directly to line 108 by appropriate valving (not shown).
  • the combined stream may be charged to a furnace 106 in order to raise the temperature of this stream if desired.
  • furnace 106 is optional, as the stream 104 may be already at the desired desulfurization temperature for introduction by means of line 108 to the second bydrosulfurization reactor 110.
  • the temperatures and pressures employed in reactor 110 may be the same as those described for the hydrodesulfurization reactor 60.
  • the desulfurization catalyst which is employed in reactor 110 may be identical to that described previously for reactor 60. It is noted at this point that the hydrodesulfurization catalysts is even more active for removal of nickel and vanadium than it is for removal of sulfur. Most of these metals will be removed in the first hydrodesulfurization reactor 60. The heaviest laydown of such metals is at the inlet to reactor 60.
  • the second desulfurization reactor 110 will act as a metals clean-up stage, and the catalyst therein will not collect as much metals as does the catalyst in reactor 60. Hence, the first stage catalyst will remove most of the metals and will become deactivated by metals much faster than the second stage catalyst.
  • the desulfurized efiluent from reactor 110 is discharged by means of line 114 and is passed to a flash unit 116 for removal of light gases including hydrogen, hydrogen sulfide and light hydrocarbons.
  • This gaseous stream is sent by means of line 118 to high pressure flash unit 94.
  • a bottoms fraction including the asphaltic product stream of the present invention is passed by means of line 120 to a distillation column 122.
  • a sulfur containing stream comprising sour gas and sour water is removed from column 122 by means of line 124.
  • the stream is passed to a gas treatment plant (by a means not shown) to recover sulfur therefrom.
  • a naphtha fraction is withdrawn from the column 122 by means of line 132.
  • This naphtha stream may be employed as a wash liquid for the separation of the light hydrocarbons from the hydrogen in line 96 (by a means not shown).
  • a furnace oil or heavier fraction may be withdrawn through line 133 and be employed in' a manner hereinafter descibed to provide additional aromatics to the second stage desulfurization reactor 110.
  • a product stream 134 is discharged from the distillation column 122.
  • This desulfurized oil stream contains asphaltenes and resins, and is especially useful, without further blending, as a fuel oil, particularly since less than one percent by weight sulfur is contained therein.
  • this heavy, asphaltic fuel oil contains, for example, between about 0.3 and about 0.5 percent by weight sulfur or less, which is well within the requirements of even the strictest oridinances for sulfur content of heavy fuel oils.
  • the process of the present invention provides a percent yield of not less than 40 or 50 and up to 80 or 90 percent 'by weight of material having a boiling point greater than the initial boiling point (I.B.P.) of the feed to the first desulfurization reactor. Therefore, very little hydrocracking occurs in accordance with the present invention and the hydrogen consumption will be generally in the range of only 150 to 1500 and preferably in the range of 300 to 1000 standard cubic feet per barrel of feed,
  • the feed to the hydrodesulfurization reactor can have an I.B.P. of not less than 375 F., and will preferably have an I.B.P. of at least 620 or 650 F.
  • the amount of material obtained from the second hydrodesulfurization zone whose boiling point is lower than 375 F., or 650' F. will not exceed 50 or 60 percent, generally, or preferably tor 20 Weight percent.
  • a feed having an I.B.P greater than 650 F. e.g. vacuum tower bottoms having an I.B.P. in the range of 750. F. to 900 F. or more may be employed in the process of the present invention.
  • the amount of material obtained from the second hydrodesulfurization zone whose boiling point is below 650 F. will not exceed 10 or 20 weight percent.
  • the process of this invention may be characterized as an essentially non-cracking process.
  • the fuel oil product from each hydrodesulfurization unit has a total asphaltenes plus resins content of at least 10 or 20 and can have 30 or 40 up to 80 percent by weight of that present in the feed to the first hydrodesulfurization unit.
  • the fuel oil product from the .second hydrodesulfurization unit has a preferred total content of resins plus asphaltenes of at least 40, 50 or 70 up to percent by weight of that present in the feed to the second hydrodesulfurization zone. This is a further indication that the resins, and particularly the asphaltenes may be desulfurized Without their complete destruction, as was previously proposed.
  • FIG. 5 is a simplified schematic diagram.
  • a reduced crude oil is introduced by means of line 220 to an atmospheric distillation unit 222 wherein a light asphalt-free distillate fraction having a 630-650 F. end point (ER) is withdrawn by means of line 224, while a heavy asphalt-containing 630-650 F.+ fraction containing 4 percent sulfur is discharged by means of line 226 from the distillation column 222.
  • the asphalt-containing bottoms fraction 226 is passed to a vacuum distillation unit 228 wherein additional light oil is discharged b means of line 230 and is admixed with the lighter fraction in line 224 and introduced along with hydrogen from line 233 into a hydrodesulfurization zone 232 by means of the line 234.
  • Zone 232 may be operated with a conventional gas oil desulfurization catalyst at a temperature, for example, in the range of between about 400 and about 800 F., but at a lower hydrogen partial pressure (e.g., below 1000 psi), than is employed for the desulfurization of an asphaltic oil.
  • the asphalt-free distillate is easily completely desulfurized in the zone 232 and is discharged by means of line 236 and passed to distillation unit 238 from which an overhead fraction containing hydrogen, hydrogen sulfide and light gases is removed by line 240 and processed as previously described to recover hydrogen and light hydrocarbons.
  • An aromatic-rich, furnace oil and higher fraction is discharged from the distillation unit 238 by means of line 244.
  • an asphalt-containing oil is withdrawn from the vacuum distillation unit 228 by means of a line 246.
  • This stream may have, for example, an initial boiling point of about 1000 F. and contain about 5.5 percent by weight sulfur.
  • the stream 246 is passed through a blending zone 250 wherein the asphalt-containing stream is admixed with a controlled portion of the aromatic-rich fraction from the line 244 in order to obtain the desired viscosity and solvency for the asphaltenes and resins contained in the stream.
  • hydrogen is added through line 248.
  • the heaviest product from distillation unit 242 can be blended with the product 268, if desired.
  • the asphaltic fraction containing solubilized resins and asphaltenes is passed by means of line 252 to a first hydrodesulfurization zone 254 and subjected to desulfurization under the conditions previously described in regard to the reactor 60 of FIG. 1.
  • the eflluent from zone 254 has a reduced sulfur content and is passed by means of line 256 to an interstage flash unit 258 wherein hydrogen, hydrogen sulfide, light hydrocarbon gases, and a controlled portion of aromatics and saturates is discharged by means of line 260.
  • a flash point is selected so as to optimize the amount of aromatic solvent available for solubilizing the asphaltenes and resins in the feed to the second hydrodesulfurization zone.
  • An efiluent stream 262 is discharged from the flash unit 258 and is admixed with hydrodesulfurization unit 266 wherein the sulfur content of the asphaltic oil is reduced to below one percent by weight.
  • the heavy oil product stream is discharged from the second hydrodesulfurization unit 266, which unit is operated in the manner described for unit in FIG. 1, and is withdrawn by means of the line 268 and treated as previously described for separation of hydrogen sulfide, light gases and the like.
  • the system of FIG. 5 provides a parallel mode of operation wherein an initially-separated lighter portion of the crude is desulfurized and is utilized to provide the desired viscosity and solvency for desulfurization of the heavy, asphaltic portion of the crude oil.
  • FIG. 6 Another modification of the FIG. 1 process is illustrated in FIG. 6.
  • an asphaltic oil is introduced by means of line 320 to a distillation unit 322 for separation into an aromatic-poor fraction on which is withdrawn from unit 322 by means of line 324 and an aromatic-rich fraction containing 4 percent sulfur.
  • An aromatic-rich asphaltic oil is discharged from unit 322 by means of a line 326.
  • distillation unit 322 may be operated to provide an asphaltic fraction having an initial boiling point of about 650 F.
  • the asphaltic stream in line 326 is admixed with hydrogen which is introduced by means of line 328 and the combined stream is passed by means of line 330 into a hydrodesulfurization unit 332 which is operated in the manner previously described.
  • the effluent from zone 332 is withdrawn by means of line 334 and is introduced into a high pressure flash unit 336 where, for example, material boiling below 800 F. is discharged by means of line 338. Accordingly, an asphaltic oil having a boiling point of 800 F.+ is discharged from the flash unit 336 by means of the line 340.
  • the efliuent from zone 346 is removed by means of line 348 and is introduced into distillation unit 350 where an aromatic-rich fraction is separated and recovered by means of line 352.
  • a controlled portion of the material in stream 352 is recycled by means of line 342 for admixture with the asphaltic stream in line 340 as previously described.
  • the light gases are discharged from distillation unit 350 by means of line 354, while a substantially sulfur-free, asphaltic, heavy fuel oil is recovered from line 356.
  • Substantially all of the asphaltenes and resins fed to distillation unit 350 are recovered in line 356 with the asphaltic fuel oil.
  • the recycle stream 342 is devoid of asphaltenes.
  • the asphaltenes are not recycled to the first hydrodesulfurization zone, since they would deactivate the catalyst prematurely. They are not recycled to the second hydrodesulfurization zone, since they have already been desulfurized, and such recycle would serve no useful purpose.
  • FIG. 7 Still another modification of the present invention is shown in FIG. 7, wherein an asphaltic feed stream is introduced by means of a line 420 to a distillation unit 422 to reduce the feed and prepare a hydrodesulfurization feed for passage through line 426.
  • the asphaltic fraction is discharged by means of the line 426 from unit 422 and is admixed with a controlled portion of an aromatic-rich stream which is introduced by means of line 428.
  • the stream in line 428 can be an aromatic-rich fraction boiling within the range of between about 400 and about 1050 F., preferably between about 650 F. and about 900 F.
  • the combined stream is admixed with hydrogen,
  • An asphaltic stream having a boiling point of, for example, 650 F.+ is admixed with hydrogen which is introduced by means of line 442 and introduced by means of line 444 into second hydrodesulfurization zone 446, which may be also operated at about 690 to 790 or 800 F.
  • the eflluent from the second desulfurization zone 446 has a sulfur content of less than one percent and is passed by means of line 448 to distillation unit 450.
  • An aromatic-rich, asphaltene-free fraction is withdrawn from unit 450 by means of line 452 and is recycled by means of line 428 for admixture to the asphaltic oil feedstock to the first desulfurization zone 434.
  • Hydrogen sulfide and light gases are withdrawn from the distillation unit 450 by means of line 454, While a low sulfur asphaltic fuel oil is recovered by means of line 456. Excess from stream 452 not recycled can be blended with product in line 456 to reduce the sulfur content of the product.
  • FIG. 7 utilized a low sulfur aromatic-rich product stream for solubilizing the asphaltenes and resins in a heavy desulfurization feedstock having a relatively high I.B.P.
  • FIG. 8 A modification of the system of FIG. 7 is shown in FIG. 8.
  • FIG. 8 The process of FIG. 8 is similar to FIG. 7, however, as shown in FIG. 8, the effluent from flash unit 438 that is withdrawn by means of line 440 is passed to a flash unit which is provided with cooling coils. Hydrogen sulfide and light gases are withdrawn by means of line 443. The remaining heavier eflluent is withdrawn from the flash unit 441 by means of the line 445 and is passed by means of pump 447 for admixture with stream 444 for introduction into the second stage desulfurization unit 446.
  • FIG. 8 permits the employment of a flash temperature for unit 438, which temperature may be the same as that employed in the hydrodesulfurization units 434 and 446.
  • the lower temperature flash unit 441 which is provided with cooling coils permits the separation of hydrogen sulfide and light gases and the reintroduction of a material having the optimum aromatics content and initial boiling point.
  • the flash unit 438 may also be operated at 700 F.
  • the lower temperature flash unit 441 is operated at 650 F. and thus permits the return by means of the 650 F.+ material by means of line 449.
  • an asphaltic, sulfur-containing, hydrocarbon oil is introduced by means of line 520 to distillation unit 522 for separation of the feed into light gases, which are withdrawn by means of line 524, and an aromatic-rich fraction, which is discharged by line 526, which is to be employed in a manner hereinafter described.
  • This aromatic-rich fraction may have a 650 F. E.P.
  • An asphaltic bottoms fraction having an initial boiling point of, for example, about 650 F. is discharged by means of line 528 and is admixed with hydrogen from line 530 prior to introduction into first desulfurization zone 532.
  • the desulfurized effluent from zone 532 is introduced by means of line 534 into flash unit 536.
  • the optimum flash point has been previously determined and a light oil fraction containing saturates and aromatics is flashed off along with light gases and content of the feed has gone from 55.45 weight percent to hydrogen sulfide by means of line 538. 60.45 weight percent after the first stage flashing, and
  • the asphaltic oil is passed from the flash unit 436 finally up to 61.91 weight percent aromatics in the prodand mixed with hydrogen from line 540 and introduced uct.
  • the weight ratio of aromatics to by means of line 542 to the second stage desulfurization resins plus asphaltenes increases from about 2 to 1 to zone 546.'In addition, the asphaltic feed to the zone 546 about 4 to 1.
  • Table I clearly illustrates the critiis admixed with the aromatic-rich stream 526.
  • the cality of providing sufficient aromatics in the asphaltic distillation operation unit 522 is conducted under condistream in order to solubilize the resins and asphaltenes tions so that the stream 526 has a selected boiling range and to deagglomerate any asphaltene aggregates so as to and aromatics content which provides maximum solvapermit desulfurization thereof.
  • this table shows tion for the asphaltenes present in the feed to the second the criticality of avoiding an excess of liquid including desulfurization zone 546.
  • the weight ratio of aromatics **d a hydrodeshlfhnzehoh eohtalhmg a to resins plus asphaltenes to accomplish solvation should hiekel'eehah'melyhdehum catalyst dlspesed on e be at least 1 to 1 and is preferably 1.5 or 2 to 1, and can eraeklhg, h e Support-
  • the hydrodeshlfhnzahoh be 4 or 5 to 1.
  • the aromatics can be present in the feed, operation 15 eohdheted at temperatures of about 5 can be introduced by recycle or can be produced in situ.
  • a 22 percent reduced Kuwait crude containing an A heavyfllel 011 18 Obtamed havlflg 1 Content asphalt fraction and 5.43 percent by weight sulfur is of 0- Wfilght Percent Sulfllr- The dlstrlbutlon of Sulfur subjected to desulfurization.
  • the initial boiling point of An asphalt'containing, reduced crude oil containing in each of the various fractions of the oil undergoing deth crude i 556 d th boiling range t d to 1400 sulfurization is set forth in Table I, below: F.+. After the sulfur content is reduced to 4.77, the
  • This reaction rate constant can also be expressed as 1 1 R-( LHSV where S is pounds of sulfur per pound of oil in the product; S is pounds of sulfur per pound of oil in the feed; and LHSV is volume of oil per hour per volume of catalyst.
  • a desulfurized furnace oil 7 having a boiling point in the range of 400 to 650 F. and containing 0.07 weight percent sulfur is added to the residue of the 650 F. flash operation.
  • the furnace oil is comprised of about one-half saturates and one-half aromatics.
  • EXAMPLE 4 In order to determine the efiect of adequate, as contrasted to excessive solubilization of an asphalt-containing feed, a residual, high-boiling feed having an initial boiling point of about 800 F. is charged to a hydrodesulfurization process, and 76.2 percent by weight desulfurization is accomplished. Next, a second sample of the feed is diluted with 30 volume percent of a lower boiling gas oil which had been previously desulfurized to the extent of to percent by weight. The addition of the gas oil, which comprises a high proportion of aromatics, increases the desulfurization to 80.3 percent by weight.
  • EXAMPLE 5 A test is performed utilizing in the first and second stages a one-thirty-second inch nickel-cobalt-molybdenum on alumina catalyst.
  • the catalyst exhibits a six month life with a start-of-run temperature of 690 F. and an end-of-run temperature of about 790 F. in hydrodesulfurizing a Kuwait reduced crude from 4 to 1 weight percent sulfur at a LHSV of about 0.8.
  • the catalyst life in the second stage is even longer.
  • the one weight percent sulfur eflluent from the first stage is flashed to remove 650 F. end point material based on atmospheric pressure and is charged to the second stage with hydrogen to reduce the sulfur level to 0.5 weight percent.
  • the second stage start-of-run temperature is 690 F. and the temperature at days is only 763 F. The test can continue until the temperature is 790 F. Therefore, the first and second stages of this invention can operate for 3, 4, 5, 6 or even 7, 8 or 12 months at a LHSV generally range between 0.1 and 10 or preferably between 0.3 and 1.25. The life of the second stage catalyst is longer than the life of the first stage catalyst.
  • a process for the hydrodesulfurization at a hydrogen partial pressure between 1,000 and 5,000 p.s.i. in a two-zone reaction of a heavy asphaltic feed oil to produce a heavy asphaltic fuel oil product containing propaneand pentene-insoluble asphaltenes and propane-insoluble but pentane-soluble resins comprising passing a sulfur containing asphaltic hydrocarbon oil feed downflow with hydrogen through a first zone containing at least one bed of hydrodesulfurization catalyst particles to 4 inch in diameter at a temperature between 680 and 800 F., the temperature being increased during the reaction to compensate for loss of hydrodesulfurization reaction rate due to catalyst aging, said catalyst particles comprising a Group VI and a Group VIII metal on alumina containing less than one percent silica, withdrawing a first efiluent stream from said first hydrodesulfurization zone having a reduced sulfur content, said first efliluent stream comprising a light gas fraction including hydrogen sulfide, a light oil fraction containing saturates and aromatic

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Cited By (12)

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Publication number Priority date Publication date Assignee Title
US3876530A (en) * 1973-08-22 1975-04-08 Gulf Research Development Co Multiple stage hydrodesulfurization with greater sulfur and metal removal in initial stage
US4317711A (en) * 1980-09-12 1982-03-02 Mobil Oil Corporation Coprocessing of residual oil and coal
US4334976A (en) * 1980-09-12 1982-06-15 Mobil Oil Corporation Upgrading of residual oil
US4565620A (en) * 1984-05-25 1986-01-21 Phillips Petroleum Company Crude oil refining
EP0207721A2 (fr) 1985-06-27 1987-01-07 A/G Technology Corporation Membranes anisotropes pour la séparation de gaz
US4713221A (en) * 1984-05-25 1987-12-15 Phillips Petroleum Company Crude oil refining apparatus
US4944776A (en) * 1989-10-05 1990-07-31 Andrew Corporation Dehumidifier for waveguide system
US5118327A (en) * 1989-10-05 1992-06-02 Andrew Corporation Dehumidifier for supplying gas having controlled dew point
US5288304A (en) * 1993-03-30 1994-02-22 The University Of Texas System Composite carbon fluid separation membranes
US5681368A (en) * 1995-07-05 1997-10-28 Andrew Corporation Dehumidifier system using membrane cartridge
US5762690A (en) * 1992-11-25 1998-06-09 Andrew Corporation Dehumidifier for supplying air using variable flow rate and variable pressure in a membrane dryer
US20120160487A1 (en) * 2009-07-09 2012-06-28 Shell Oil Company Method and composition for enhanced hydrocarbon recovery from a formation containing a crude oil with specific solubility groups and chemical families

Families Citing this family (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3775304A (en) * 1971-12-08 1973-11-27 Gulf Research Development Co Increasing the ratio of aromatics to saturates in hydrodesulfurization of heavy asphaltic feed oil
JPH0391591A (ja) * 1989-09-05 1991-04-17 Cosmo Oil Co Ltd 重質炭化水素油の水素化処理方法
RU2578150C1 (ru) * 2014-09-18 2016-03-20 Сергей Владиславович Дезорцев Способ получения экологически чистого жидкого ракетного топлива

Family Cites Families (3)

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Publication number Priority date Publication date Assignee Title
US3429801A (en) * 1965-12-06 1969-02-25 Universal Oil Prod Co Two-stage hydrorefining of asphaltene-containing oils
US3409538A (en) * 1967-04-24 1968-11-05 Universal Oil Prod Co Multiple-stage cascade conversion of black oil
US4165064A (en) * 1978-03-13 1979-08-21 Fip, S.A. De C.V. Gate valve

Cited By (15)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3876530A (en) * 1973-08-22 1975-04-08 Gulf Research Development Co Multiple stage hydrodesulfurization with greater sulfur and metal removal in initial stage
US4317711A (en) * 1980-09-12 1982-03-02 Mobil Oil Corporation Coprocessing of residual oil and coal
US4334976A (en) * 1980-09-12 1982-06-15 Mobil Oil Corporation Upgrading of residual oil
US4565620A (en) * 1984-05-25 1986-01-21 Phillips Petroleum Company Crude oil refining
US4713221A (en) * 1984-05-25 1987-12-15 Phillips Petroleum Company Crude oil refining apparatus
EP0207721A2 (fr) 1985-06-27 1987-01-07 A/G Technology Corporation Membranes anisotropes pour la séparation de gaz
US4944776A (en) * 1989-10-05 1990-07-31 Andrew Corporation Dehumidifier for waveguide system
US5118327A (en) * 1989-10-05 1992-06-02 Andrew Corporation Dehumidifier for supplying gas having controlled dew point
US5762690A (en) * 1992-11-25 1998-06-09 Andrew Corporation Dehumidifier for supplying air using variable flow rate and variable pressure in a membrane dryer
US5885329A (en) * 1992-11-25 1999-03-23 Andrew Corporation Dehumidifier for supplying air using variable flow rate and variable pressure in a membrane dryer
US5288304A (en) * 1993-03-30 1994-02-22 The University Of Texas System Composite carbon fluid separation membranes
US5681368A (en) * 1995-07-05 1997-10-28 Andrew Corporation Dehumidifier system using membrane cartridge
US20120160487A1 (en) * 2009-07-09 2012-06-28 Shell Oil Company Method and composition for enhanced hydrocarbon recovery from a formation containing a crude oil with specific solubility groups and chemical families
US9187688B2 (en) * 2009-07-09 2015-11-17 Shell Oil Company Method and composition for enhanced hydrocarbon recovery from a formation containing a crude oil with specific solubility groups and chemical families
US9732267B2 (en) 2009-07-09 2017-08-15 Shell Oil Company Composition for enhanced hydrocarbon recovery from a formation

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IT973934B (it) 1974-06-10
CA976902A (en) 1975-10-28
FR2162519B1 (fr) 1978-10-27
GB1414492A (en) 1975-11-19
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JPS5547077B2 (fr) 1980-11-27
FR2162519A1 (fr) 1973-07-20

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