US3901792A - Multi-zone method for demetallizing and desulfurizing crude oil or atmospheric residual oil - Google Patents

Multi-zone method for demetallizing and desulfurizing crude oil or atmospheric residual oil Download PDF

Info

Publication number
US3901792A
US3901792A US482322A US48232274A US3901792A US 3901792 A US3901792 A US 3901792A US 482322 A US482322 A US 482322A US 48232274 A US48232274 A US 48232274A US 3901792 A US3901792 A US 3901792A
Authority
US
United States
Prior art keywords
stage
ppm
catalyst
metals
reaction zone
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Expired - Lifetime
Application number
US482322A
Inventor
Ronald H Wolk
Govanon Nongbri
William C Rovesti
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
HRI Inc
Original Assignee
Hydrocarbon Research Inc
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Hydrocarbon Research Inc filed Critical Hydrocarbon Research Inc
Priority to US482322A priority Critical patent/US3901792A/en
Application granted granted Critical
Publication of US3901792A publication Critical patent/US3901792A/en
Assigned to HRI, INC., A DE CORP. reassignment HRI, INC., A DE CORP. ASSIGNMENT OF ASSIGNORS INTEREST. Assignors: HYDROCARBON RESEARCH, INC.
Anticipated expiration legal-status Critical
Expired - Lifetime legal-status Critical Current

Links

Images

Classifications

    • 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
    • C10G45/00—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds
    • C10G45/02—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbons; Hydrofinishing
    • C10G45/14—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbons; Hydrofinishing with moving solid particles
    • C10G45/16—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbons; Hydrofinishing with moving solid particles suspended in the oil, e.g. slurries
    • 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

  • the catalyst in the second stage has little UNITED STATES PATENTS macroporosity with no more than 0.l0 cc/gram in 3,322,666 5/1967 Beuthcr et al. 208/[12 pores greater than 125A in diameter so as to exclude 3.413.234 /1 68 Ch rv nak t all.v 208/210 most of the metal containing molecules which were 3.530.066 9 u ala el a 203/251 H not contacted in the first stage.
  • the vanadium con taining molecules left after the first stage treatment are excluded from entering the pores of the second stage catalyst.
  • vanadium compounds contained in the virgin residuum differ in character in terms of their ability to be removed from the oil. What is done is to take out most of the easily removed vanadium compounds and leave just a few of the more difficult to remove compounds in the feed to the catalytic stage. This reduces the poisoning rate in that catalytic stage to almost a trivial amount.
  • FIG. I is a schematic view of a multiple stage hydrogenation process.
  • FIG. 2 is a graph of sulfur removal against catalyst age for both virgin and demetallized light Venezuelan atmospheric residuum, and a graph of sulfur removal against catalyst age for both virgin and demetallized heavy Venezuelan atmospheric residuum.
  • FIG. 3 is a graph showing the amount of desulfurization as a function of the vanadium content of the feed.
  • a heavy hydrocarbon charge such as a metals containing Venezuelan residuum at 10, together with hydrogen at 12 is introduced into a reactor 14 of the type shown in the US. Pat. No. 25,770.
  • a reactor 14 will be suitably charged with a demetallization contact material such as porous alumina, the particles being of an average size between about 60 mesh and 270 mesh.
  • a small makeup of fresh contact particles is combined with the feed at 16.
  • contact particles in the form of extrudates of 4 inch to 1/32 inch diameter may be used, or granules of 10 to 60 mesh may be used.
  • the liquid and gas upflow through the bed of contact particles should be such that it will tend to expand the bed at least 10% based on the bed volume without fluid flow, and such that the particles are all in a random motion in the liquid. Such conditions are described as ebullated in the aforementioned Johanson patent.
  • Recycle of liquid effluent from above the contact particle interface 15 to below the distributor deck 38 is usually desirable to give proper temperature control and to establish a sufficient upflow velocity to assist in maintaining the particles in random motion in the case of particles in the form of 1/32 to 4 inch diameter ex trudates.
  • This recycle may be accomplished either externally utilizing pump 40, or internally as described in Johanson, supra.
  • a vapor effluent is removed at 18 and a liquid effluent is removed at 20 from the upper portion 22 of the reaction zone 14. The liquid is then conducted to the second stage reactor 24.
  • the liquid feed at 20 joins with additional hydrogen at 26 and passes upwardly through a bed of desulfurization catalyst from the group of nickel, cobalt, molybdenum and tungsten on a carrier from the group of silica, alumina and mixtures thereof. Small amounts of desulfurization makeup catalyst may also be added at 28.
  • a gaseous effluent is removed at 30, and a liquid is removed at 32 from the upper portion 34 of the reactor 24.
  • the catalyst loading used in the second stage reactor 24 is about the same as that used for the contact particles in the first stage reactor 14.
  • EXAMPLE 1 Desulfurization of Demetallized Feeds Catalyst Deactivation
  • Demetallized Light Venezuelan atmospheric resid (17.3API, 2.09% S, 235 ppm V and 28 ppm Ni) was prepared by passing this feed over porous alumina having more than 0.15 cc/gram of pores greater than A in diameter, operating temperature was 760F and hydrogen partial pressure was 2000 psi.
  • Demetallized feed prepared in this manner was subsequently run over 1/32 inch cobalt molybdate on alumina catalyst having a pore size distribution such that the pore volume in pores having a diameter greater than 125A is less than 0.10 cc/gram.
  • the demetallized Light Vene zuelan stock had an average metals content of about 55 ppm (40 ppm V and 15 ppm Ni).
  • FIG. 2 Results of the desulfurization runs are presented in FIG. 2.
  • the line A in FIG. 2 represents the deactivation curve for a high activity cobalt molybdate on alumina catalyst wherein the feed has been pretreated for demetallization while line A represents the same high activity cobalt molybdate on alumina catalyst when un- Light Venezuelan atmospheric resid was run over H32 inch cobalt molybdenum extrudates where only 1.03 and L97 weight percent, respectively, on a fresh catalyst basis at catalyst age of 9.0 bbl/lb.
  • Table I presents data on the amount of demetallization that occurs when desulfurizing the residuums indicated to 75%. When desulfurizing the virgin feed about 60% demetallization occurs. However, if the feed is demetallized according to our invention before desulfurization, then the amount of dcmetallization that occurs in the desulfurization step is a function ofthc vanadium content of the feed.
  • the scale is from O to L0.
  • the abscissae is the vanadium content of the feed in parts per million to the desulfurization stage and the scale is from 0 to I000.
  • Lines 50, 52, 54 and 56 represent experimental runs on feeds as folows:
  • Lines 60, 62, 64 and 66 are mathematical calculations showing the parts per million of vanadium removed from the feed in the second or desulfurization stage as follows:
  • 60 shows 10 ppm vanadium removal.
  • Atmospheric Bottoms 'lhc preferred operating conditions for the two stages are 1st 2nd Temperature "F 730 v 825 700 K00 Preferred 760 780 720 760 Hydrogen Partial Pressure (psi) 1000 2500 l000 2500 Preferred I500 2000 i500 2000 Space Velocity V/hr/V 0.20 l5 0.3 i 5 Preferred 0.3 0.) 0.5 l l) While we have shown and described a preferred form of embodiment of our invention, we are aware that modifications may be made thereto within the scope and spirit of the description herein and of the claims appended hereinafter.
  • a multi-zone method for desulfurizing a crude pe troleum charge or atmospheric residual charge containing at least lUO ppm of metals from the group consisting of vanadium and nickel wherein said charge, in liquid phase, is passed upwardly with hydrogen-rich gas through a first reaction zone containing a particulate contact material and the effluent from said first reaction zone is then passed with hydrogen-rich gas upwardly through a second reaction zone containing a particulate hydrodesulfurization catalyst; under conditions in which said contact material and said hydrodesulfurization catalyst are maintained in random motion in the liquid, and wherein the temperature in said first reaction zone is maintained in the range of 730 to 825F and the hydrogen partial pressure is in the range of lO002500 psi and space velocity in the order of 0.2-1.5 volume of feed/hr/volume of reaction zone, the improvement which comprises:

Landscapes

  • Chemical & Material Sciences (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Engineering & Computer Science (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • General Chemical & Material Sciences (AREA)
  • Organic Chemistry (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)

Abstract

The high level desulfurization of petroleum residuums normally having at least 100 ppm of metals from the groups of vanadium and nickel is accomplished by an initial contact stage with a contact material such as Porocel, having extensive macroporosity with more than 0.15 cc/gram pore volume in pores greater than 125A in diameter operating as an ebullated bed under optimum demetallization conditions in the range of 730*-825*F (preferably 760*-780*F), and hydrogen partial pressure of 1000-2500 psi (preferably 1500-2000 psi), followed by a removal of effluent vapors and a further ebullated bed contact of the liquid with a highly active hydrodesulfurization catalyst which would ordinarily be rapidly poisoned by these residuums. By control of the first stage reaction conditions including space velocity, in the range of 0.20 to 1.5 volume of feed per hour per volume of reactor, and obtaining a high degree of demetallization in the order of 50-80% or more deposit of metals on the first stage contact particles, so that the amount of vanadium removed from the oil and taken up on the catalyst in the second stage was no more than 20 ppm, the life of the catalyst in the second stage was very greatly lengthened. The catalyst in the second stage has little macroporosity with no more than 0.10 cc/gram in pores greater than 125A in diameter so as to exclude most of the metal containing molecules which were not contacted in the first stage. This combination of the reaction steps makes it possible to achieve in excess of 75% desulfurization of these residuums.

Description

United States Patent (1 1 Wolk et al.
[ Aug. 26, 1975 MULTLZONE METHOD FOR Primary ExaminerDelbert E. Gantz DEMETALLIZIN AND E L UB N Assistant Examiner-G. J. Crasanakis CRUDE OIL R ATMOSPHERIC RESIDUAL 57 T T OIL The high level desulfurization of petroleum residuums [75] lnventorsi Rflnald wolk, Lawrence P, normally having at least 100 ppm of metals from the Mercer n y, GOYaIIOIl groups of vanadium and nickel is accomplished by an g Levitlow"; William initial contact stage with a contact material such as NeWtOWn, both 0f Porocel, having extensive macroporosity with more [73] Assigneez Hydrocarbon Research, Inc" New than 0.l5 cc/gram pore volume in pores greater than York N Y lA in diameter operating as an ebullated bed under optimum demetallization conditions in the range of [22] File Jun 24, 1 4 730825F (preferably 760780F), and hydrogen 2] A L N 482,322 partial pressure of l0OO-2500 psi (preferably 1 pp 0 1500-2000 psi), followed by a removal of effluent vapors and a further ebullated bed contact of the liquid Relmed Application Data with a highly active hydrodesulfurization catalyst [63] Continuation of Ser. No. 255,452, May 22, 1972, which would ordinarily be rapidly poisoned by these abandoned, residuums. By control of the first stage reaction conditions including space velocity, in the range of 0.20 to [52] S. Cl- 208/210; 208/2l3; 208/216; 1.5 volume of feed per hour per volume of reactor, 208/25] H and obtaining a high degree of demetallization in the [5 l Int. Cl ClOg 23/02 order of -80% or more deposit of metals on the first Fifld Search 25! stage contact particles, so that the amount of vana- 21 1 dium removed from the oil and taken up on the catalyst in the second stage was no more than 20 ppm, the [56] References Cited life of the catalyst in the second stage was very greatly lengthened. The catalyst in the second stage has little UNITED STATES PATENTS macroporosity with no more than 0.l0 cc/gram in 3,322,666 5/1967 Beuthcr et al. 208/[12 pores greater than 125A in diameter so as to exclude 3.413.234 /1 68 Ch rv nak t all.v 208/210 most of the metal containing molecules which were 3.530.066 9 u ala el a 203/251 H not contacted in the first stage. This combination of the reaction steps makes it possible to achieve in exe e a c v 3,788,973 H1974 wolk ct a]. I g I 208/25] H cess of desulfurization of these residuums. 3,844,933 l0/l974 Wolk et al. 208/25l H 4 Claims, 3 Drawing Figures Gas Products,
Heavy 24 32 Products Contact Portlcles Catalyst i ll I6 2 l0 Feed g- 25 Hydrogen Hydrogen Fraction of PATENTEDAUBZBIQYB 2.901192 Gas Products Heavy 32 Prod ucts Contact Particles l0 Feed l2- Hydrogen 25 Hydrogen Demetulized Feed l I J- o 2 4 s B IO Catalyst Age, Bbl/Lb E 20 'E C 00.9 296 gee 62 Fe?) e 3 :15 U a s 2%" 03in u.|
V ,Vonodium Content of Feed ppm MULTI-ZONE METHOD FOR DEMETALLIZING AND DESULFURIZING CRUDE OIL OR ATMOSPHERIC RESIDUAL OIL This is a continuation of application Ser. No. 255,452, filed May 22, 1972 and now abandoned.
BACKGROUND OF THE INVENTION The ebullated bed hydrodesulfurization of petroleum residuum is disclosed in the Chervenak et a1. U.S. Pat. No. 3,418,234. It is also known that many residuum stocks contain substantial amounts of metals.
However, it has also been observed that in an ebullated bed hydrodesulfurization of a high metals containing residuum, the desulfurization catalyst was rapidly rendered inactive by the deposit of metals on and in the catalyst. This requires a frequent and expensive replacement of the catalyst which is otherwise expressed as low average catalyst life. Previous disclosures of two stage operations in which the second stage was a hydroconversion do not satisfactorily meet the requirements when the object is a desulfurization of high metals containing residuum in that the catalyst replacement cost for the first stage is too high. The maximum vanadium loading without severe activity loss on a catalyst is on the order of 0.3 lbs. vanadium per pound of fresh catalyst. This would be equivalent to limiting the catalyst life on a 400 ppm vanadium feed to less than 3 bbl/lb which is economically prohibitive.
SUMMARY OF THE INVENTION It has now been determined that extremely long catalyst life can be obtained by careful maintenance of the metals content in the feed to a second stage catalyst desulfurization zone below a level in which the amount of vanadium that the second stage catalyst will remove is less than 20 ppm when obtaining desulfurization levels of 75% or more.
By selecting the pore size distribution of the first stage contact particles to be of a larger average size than the second stage catalyst then the vanadium con taining molecules left after the first stage treatment are excluded from entering the pores of the second stage catalyst.
It appears that the vanadium compounds contained in the virgin residuum differ in character in terms of their ability to be removed from the oil. What is done is to take out most of the easily removed vanadium compounds and leave just a few of the more difficult to remove compounds in the feed to the catalytic stage. This reduces the poisoning rate in that catalytic stage to almost a trivial amount.
DESCRIPTION OF THE DRAWING FIG. I is a schematic view of a multiple stage hydrogenation process.
FIG. 2 is a graph of sulfur removal against catalyst age for both virgin and demetallized light Venezuelan atmospheric residuum, and a graph of sulfur removal against catalyst age for both virgin and demetallized heavy Venezuelan atmospheric residuum.
FIG. 3 is a graph showing the amount of desulfurization as a function of the vanadium content of the feed.
DESCRIPTION OF THE PREFERRED EMBODIMENT In accordance with the disclosed invention, a heavy hydrocarbon charge such as a metals containing Venezuelan residuum at 10, together with hydrogen at 12 is introduced into a reactor 14 of the type shown in the US. Pat. No. 25,770. Such a reactor will be suitably charged with a demetallization contact material such as porous alumina, the particles being of an average size between about 60 mesh and 270 mesh. A small makeup of fresh contact particles is combined with the feed at 16. Alternately, contact particles in the form of extrudates of 4 inch to 1/32 inch diameter may be used, or granules of 10 to 60 mesh may be used.
The liquid and gas upflow through the bed of contact particles should be such that it will tend to expand the bed at least 10% based on the bed volume without fluid flow, and such that the particles are all in a random motion in the liquid. Such conditions are described as ebullated in the aforementioned Johanson patent.
Recycle of liquid effluent from above the contact particle interface 15 to below the distributor deck 38 is usually desirable to give proper temperature control and to establish a sufficient upflow velocity to assist in maintaining the particles in random motion in the case of particles in the form of 1/32 to 4 inch diameter ex trudates. This recycle may be accomplished either externally utilizing pump 40, or internally as described in Johanson, supra.
Under the preferred conditions of temperature, pressure, throughput and product composition as hereinafter set forth, a vapor effluent is removed at 18 and a liquid effluent is removed at 20 from the upper portion 22 of the reaction zone 14. The liquid is then conducted to the second stage reactor 24.
In the second stage reactor the liquid feed at 20 joins with additional hydrogen at 26 and passes upwardly through a bed of desulfurization catalyst from the group of nickel, cobalt, molybdenum and tungsten on a carrier from the group of silica, alumina and mixtures thereof. Small amounts of desulfurization makeup catalyst may also be added at 28. A gaseous effluent is removed at 30, and a liquid is removed at 32 from the upper portion 34 of the reactor 24. The catalyst loading used in the second stage reactor 24 is about the same as that used for the contact particles in the first stage reactor 14.
EXAMPLE 1 Desulfurization of Demetallized Feeds Catalyst Deactivation Demetallized Light Venezuelan atmospheric resid (17.3API, 2.09% S, 235 ppm V and 28 ppm Ni) was prepared by passing this feed over porous alumina having more than 0.15 cc/gram of pores greater than A in diameter, operating temperature was 760F and hydrogen partial pressure was 2000 psi. Demetallized feed prepared in this manner was subsequently run over 1/32 inch cobalt molybdate on alumina catalyst having a pore size distribution such that the pore volume in pores having a diameter greater than 125A is less than 0.10 cc/gram. The demetallized Light Vene zuelan stock had an average metals content of about 55 ppm (40 ppm V and 15 ppm Ni).
Results of the desulfurization runs are presented in FIG. 2. The line A in FIG. 2 represents the deactivation curve for a high activity cobalt molybdate on alumina catalyst wherein the feed has been pretreated for demetallization while line A represents the same high activity cobalt molybdate on alumina catalyst when un- Light Venezuelan atmospheric resid was run over H32 inch cobalt molybdenum extrudates where only 1.03 and L97 weight percent, respectively, on a fresh catalyst basis at catalyst age of 9.0 bbl/lb.
EXAMPLE 2 Demetallized Heavy Venezuelan atmospheric resid (12.6APl, 2.8% S, 375 ppm V and 57 ppm Ni) was prepared by passing this feed over porous alumina at 780F and 2000 psi. The resulting demetallized feed,
line B in FIG. 2, having a metals content of 139 ppm 104 ppm V and 35 ppm Ni) was run over 1/32 inch cobalt molybdate on alumina extrudates in order to compare the catalyst deactivation rate of this 139 ppm metals feed with the virgin feed line B. Results of the two desulfurization runs over the same catalyst as used in Example 1 are presented in FIG. 2.
Despite the considerably higher metals level, the de metallized Heavy Venezuelan run up to an age of 2.75 B/lb showed no sign of rapid deactivation. Furthermore, the vanadium removed in this run was only about l8-22 ppm out of 104 ppm compared to 22 ppm out of 36 ppm in the case of Kuwait atmospheric resid over the same catalyst and at the same level of desulfurization.
This last observation is extremely important since it demonstrates that high metals-feeds need not be demetallized to the level of Kuwait atmospheric residuum (an economically prohibitive requirement in many cases) in order to effect a rate of vanadium deposition that will not rapidly deactivate a nonporous high activity desulfurization catalyst.
Table I presents data on the amount of demetallization that occurs when desulfurizing the residuums indicated to 75%. When desulfurizing the virgin feed about 60% demetallization occurs. However, if the feed is demetallized according to our invention before desulfurization, then the amount of dcmetallization that occurs in the desulfurization step is a function ofthc vanadium content of the feed.
The graph of FIG. 3, on log-log scale, for the ordinate, shows the fraction ofvanadium removed from the feed when undergoing a 75% desulfurization. The scale is from O to L0.
The abscissae is the vanadium content of the feed in parts per million to the desulfurization stage and the scale is from 0 to I000.
Lines 50, 52, 54 and 56 represent experimental runs on feeds as folows:
is for a Kuwait atmospheric residuum originally having 36 ppm of vanadium after undergoing demetallization in the first stage.
52 is for a Khafji atmospheric residuum originally having lOO ppm of vanadium after undergoing demetallization in the first stage.
54 is for a Light Venezuelan atmospheric residuum originally having 200 ppm of vanadium after undergoing demetallization in the first stage.
56 is for a Heavy Venezuelan atmospheric residuum originally having 398 ppm of vanadium after undergo ing demetallization in the first stage.
Lines 60, 62, 64 and 66 are mathematical calculations showing the parts per million of vanadium removed from the feed in the second or desulfurization stage as follows:
60 shows 10 ppm vanadium removal.
62 shows 20 ppm vanadium removal.
64 shows 40 ppm vanadium removal.
66 shows 100 ppm vanadium removal.
It is thus possible to determine the extent of demetallization in the first stage necessary to permit second stage demetallization at the rate without depositing more than 20 ppm of vanadium on the catalyst.
For example, it would be necessary to demetallize Heavy Venezuelan atmospheric residuum from 398 ppm to 92 ppm vanadium (Point Z) in a demetallization step in order not to exceed 20 ppm of vanadium deposition on the desulfurization stage catalyst. Analogous values would be 72 for Light Venezuelan atmospheric (Point Y), 53 for Khafii atmospheric residuum (Point X) and 34 Kuwait atmospheric residuum. Since the value for Kuwait atmospheric residuum is so close to the feed value of 36 ppm, it would not be practical to put in a demetallization step for this feed.
TABLE I Vanadium Removal Vanadium When Undergoing 75% Feed Content Desulfurivation Virgin Heavy Venezuelan AB. 400 ppm 45.5 Dcmetallized I72 326 l04 28.8 Virgin Light Venezuelan AB. 200 60.0 Demetal lized 98 26.1 56 32.1 42 166 Virgin Khafji AB. I00 6L0 Virgin Kuwait AB. 36 6 l .3
AB. Atmospheric Bottoms 'lhc preferred operating conditions for the two stages are 1st 2nd Temperature "F 730 v 825 700 K00 Preferred 760 780 720 760 Hydrogen Partial Pressure (psi) 1000 2500 l000 2500 Preferred I500 2000 i500 2000 Space Velocity V/hr/V 0.20 l5 0.3 i 5 Preferred 0.3 0.) 0.5 l l) While we have shown and described a preferred form of embodiment of our invention, we are aware that modifications may be made thereto within the scope and spirit of the description herein and of the claims appended hereinafter.
We claim:
1. A multi-zone method for desulfurizing a crude pe troleum charge or atmospheric residual charge containing at least lUO ppm of metals from the group consisting of vanadium and nickel wherein said charge, in liquid phase, is passed upwardly with hydrogen-rich gas through a first reaction zone containing a particulate contact material and the effluent from said first reaction zone is then passed with hydrogen-rich gas upwardly through a second reaction zone containing a particulate hydrodesulfurization catalyst; under conditions in which said contact material and said hydrodesulfurization catalyst are maintained in random motion in the liquid, and wherein the temperature in said first reaction zone is maintained in the range of 730 to 825F and the hydrogen partial pressure is in the range of lO002500 psi and space velocity in the order of 0.2-1.5 volume of feed/hr/volume of reaction zone, the improvement which comprises:
a. maintaining porous alumina as said contact material in said first reaction zone, said alumina having a pore volume of more than 0.15 cc/gram of pores having a diameter in excess of l25A;
b. maintaining reaction conditions in said second reaction zone substantially at the same pressure as in said first reaction zone with a maximum hydrogen rate of 5000 SCF/barrel, the temperature being between 700 and 800F, the space velocity being between 0.3
and 1.5 volume of feed/hour/volume of reaction space wherein no more than 20 ppm of vanadium is removed in said second zone while a desulfurization of at least percent is achieved in said second zone, said catalyst in said second reaction zone comprising a Group Vl-B metal and iron group metal on alumina, said catalyst having a pore structure with less than 010 cc/gram in pores larger than 125A.
2. The method as claimed in claim 1 wherein said atmospheric residual charge is a heavy Venezuelan atmospheric bottoms containing in the order of 400 ppm of metals and the first stage operation is conducted under conditions to remove approximately 75% of the metals.
3. The method as claimed in claim 1 wherein said atmospheric residual charge is a light Venezuelan atmospheric bottoms containing in the order of 200 ppm of metals and the first stage operation is conducted under conditions to remove approximately 70% of the metals.
4. The method as claimed in claim 1 wherein said atmospheric residual charge is a Khatji atmospheric bottoms having in the order of ppm of metals and the first stage operation is conducted under conditions to remove approximately 60% of the metals.

Claims (4)

1. A MULTI-ZONE METHOD FOR DESULFURIZING A CRUDE PETROLEUM CHARGE OR ATMOSPHERIC RESIDUAL CHARGE CONTAINING AT LEAST 100 PPM OF METALS FROM THE GROUP CONSISTING OF VANADIUM AND NICKEL WHEREIN SAID CHARGE, IN LIQUID PHASE, IS PASSED UPWARDLY WITH HYDROGEN-RICH GAS THROUGH A FIRST REACTION ZONE CONTAINING A PARTICULATE CONTACT MATERIAL AND THE EFFUENT FROM SAID FIRST REACTION ZONE IN THEN PASSED WITH HYDROGEN-RICH GAS UPWARDLY THROUGH A SECOND REACTION ZONE CONTAINING A PARTICULATE HYDRODESULFURIZATION CATALYST, UNDER CONDITIONS IN WHICH SAID CONTACT MATERIAL AND SAID HYDRODESULFURIZATION CATALYST ARE MAINTAINED IN RANDOM MOTION IN THE LIQUID AND WHEREIN THE TEMPERATURE IN SAID FIRST REACTION ZONE IS MAINTAINED IN THE RANGE OF 730* TO 825*F AND THE HYDROGEN PARTIAL PRESSURE IS IN THE RANGE OF 1000-2500 PSI AND SPACE VELOCITY IN THE ORDER OF 0.2-1.5 VOLUME OF FEED/HR/ VOLUME OF REACTION ZONE, THE IMPROVEMENT WHICH COMPRISES: A. MAINTAINING POROUS ALUMINA AS SAID CONTACT MATERIAL IN SAID FIRST REACTION ZONE SAID ALUMINA HAVING A PORE VOLUME OF MORE THAN 0.15 CC/GRAM OF PORES HAVING A DIAMETER IN EXCESS OF 125A, B. MINTINING REACTION CONDITIONS IN SAID SECOND REACTION ZONE SUBSTANTIALLY AT THE SAME PRESSURE AS IN SAID FIRST REACTION ZONE WITH A MAXIMUM HYDROGEN RATE OF 5000 SCF/BARREL, THE TEMPERATURE BEING BETWEEN 700* AND 800*F, THE SPACE VELOCITY BEING BETWEEN 0.3 AND 1.5 VOLUME OF FEED/HOUR/VOLUME OF REACTION SPACE WHEREIN NO MORE THAN 20 PPM OF VANADIUM IS REMOVED IN SAID SECOND ZONE WHILE A DESULFURIZATION OF AT LEAST 75 PERCENT IS ACHIEVED IN SAID SECOND ZONE, SAID CATALYST IN SAID SECOND REACTION ZONE COMPRISING A GROUP VI-B METAL AND IRON GROUP METAL ON ALUMINA, SAD CATALYST HAVING A PORE STRUCTURE WITH LESS THAN 0.10 CC/GRAM IN PORES LARGER THAN 125A.
2. The method as claimed in claim 1 wherein said atmospheric residual charge is a heavy Venezuelan atmospheric bottoms containing in the order of 400 ppm of metals and the first stage operation is conducted under conditions to remove approximately 75% of the metals.
3. The method as claimed in claim 1 wherein said atmospheric residual charge is a light Venezuelan atmospheric bottoms containing in the order of 200 ppm of metals and the first stage operation is conducted under conditions to remove approximately 70% of the metals.
4. The method as claimed in claim 1 wherein said atmospheric residual charge is a Khafji atmospheric bottoms having in the order of 100 ppm of metals and the first stage operation is conducted under conditions to remove approximately 60% of the metals.
US482322A 1972-05-22 1974-06-24 Multi-zone method for demetallizing and desulfurizing crude oil or atmospheric residual oil Expired - Lifetime US3901792A (en)

Priority Applications (1)

Application Number Priority Date Filing Date Title
US482322A US3901792A (en) 1972-05-22 1974-06-24 Multi-zone method for demetallizing and desulfurizing crude oil or atmospheric residual oil

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US25545272A 1972-05-22 1972-05-22
US482322A US3901792A (en) 1972-05-22 1974-06-24 Multi-zone method for demetallizing and desulfurizing crude oil or atmospheric residual oil

Publications (1)

Publication Number Publication Date
US3901792A true US3901792A (en) 1975-08-26

Family

ID=26944709

Family Applications (1)

Application Number Title Priority Date Filing Date
US482322A Expired - Lifetime US3901792A (en) 1972-05-22 1974-06-24 Multi-zone method for demetallizing and desulfurizing crude oil or atmospheric residual oil

Country Status (1)

Country Link
US (1) US3901792A (en)

Cited By (43)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3964995A (en) * 1972-07-24 1976-06-22 Hydrocarbon Research, Inc. Hydrodesulfurization process
US3980551A (en) * 1975-12-18 1976-09-14 Hydrocarbon Research, Inc. Refining of waste lube oil to prepare usable lubestock
US4217206A (en) * 1977-07-20 1980-08-12 Hydrocarbon Research, Inc. Extending life of demetallization catalyst
US4301037A (en) * 1980-04-01 1981-11-17 W. R. Grace & Co. Extruded alumina catalyst support having controlled distribution of pore sizes
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
US4378308A (en) * 1980-11-26 1983-03-29 Mobil Oil Corporation Poison-resistant hydrodesulfurization catalyst
US4431526A (en) * 1982-07-06 1984-02-14 Union Oil Company Of California Multiple-stage hydroprocessing of hydrocarbon oil
US4452911A (en) * 1983-08-10 1984-06-05 Hri, Inc. Frangible catalyst pretreatment method for use in hydrocarbon hydrodemetallization process
US4457831A (en) * 1982-08-18 1984-07-03 Hri, Inc. Two-stage catalytic hydroconversion of hydrocarbon feedstocks using resid recycle
US4460707A (en) * 1982-12-28 1984-07-17 Union Oil Company Of California Hydroprocessing catalyst and method for preparing it
FR2542754A1 (en) * 1983-03-15 1984-09-21 Raffinage Cie Francaise METHOD OF HYDRODEMETALLIZING HYDROCARBON LOADS AND CATALYST FOR IMPLEMENTING SAID METHOD
US4498972A (en) * 1982-12-31 1985-02-12 Institut Francais Du Petrole Hydrotreatment process for converting a heavy hydrocarbon fraction containing sulfur impurities and metal impurities to a lighter oil, in at least two steps
FR2550544A1 (en) * 1983-08-10 1985-02-15 Hydrocarbon Research Inc Catalyst for hydro-demetallisation and hydroconversion
US4548710A (en) * 1982-12-28 1985-10-22 Union Oil Company Of California Hydrocarbon processing
US4564439A (en) * 1984-06-29 1986-01-14 Chevron Research Company Two-stage, close-coupled thermal catalytic hydroconversion process
US4576710A (en) * 1982-09-03 1986-03-18 Hri, Inc. Catalyst desulfurization of petroleum residua feedstocks
US4761220A (en) * 1984-10-31 1988-08-02 Chevron Research Company Hydroprocessing catalyst fines as a first-stage catalyst in a two-stage, close-coupled thermal catalytic hydroconversion process
AU576083B2 (en) * 1984-06-29 1988-08-11 Chevron Research Company Two-stage, close-coupled thermal catalytic hydroconversion process
US4802974A (en) * 1987-03-12 1989-02-07 Phillips Petroleum Company Hydrofining employing treated alumina material in fixed beds
US4828683A (en) * 1987-02-06 1989-05-09 Phillips Petroleum Company Hydrofining employing a support material for fixed beds
US4846962A (en) * 1987-02-12 1989-07-11 Exxon Research And Engineering Company Removal of basic nitrogen compounds from extracted oils by use of acidic polar adsorbents and the regeneration of said adsorbents
US4870044A (en) * 1987-03-12 1989-09-26 Phillips Petroleum Company Treated alumina material for fixed hydrofining beds
US4895816A (en) * 1987-02-06 1990-01-23 Gardner Lloyd E Support material containing catalyst for fixed hydrofining beds
US4925554A (en) * 1988-02-05 1990-05-15 Catalysts & Chemicals Industries Co., Ltd. Hydrotreating process for heavy hydrocarbon oils
US5320741A (en) * 1992-04-09 1994-06-14 Stone & Webster Engineering Corporation Combination process for the pretreatment and hydroconversion of heavy residual oils
US5417846A (en) * 1990-03-29 1995-05-23 Institut Francais Du Petrole Hydrotreatment method for a petroleum residue or heavy oil with a view to refining them and converting them to lighter fractions
US20030229583A1 (en) * 2001-02-15 2003-12-11 Sandra Cotten Methods of coordinating products and service demonstrations
WO2005005581A1 (en) * 2003-07-09 2005-01-20 Instituto Mexicano Del Petróleo Method for the catalytic hydroprocessing of heavy petroleum hydrocarbons
US20050167323A1 (en) * 2003-12-19 2005-08-04 Wellington Scott L. Systems and methods of producing a crude product
US20060006556A1 (en) * 2004-07-08 2006-01-12 Chen Hung Y Gas supply device by gasifying burnable liquid
US20060278039A1 (en) * 2005-06-13 2006-12-14 Zhufang Liu Process for removing metal species in the presence of hydrogen and a porous material and polyester polymer containing reduced amounts of metal species
CN100352893C (en) * 2005-02-05 2007-12-05 中国石油化工股份有限公司 Cut-fracted oil oxidation desulfurizing method
US7534342B2 (en) 2003-12-19 2009-05-19 Shell Oil Company Systems, methods, and catalysts for producing a crude product
US20090139902A1 (en) * 2007-11-28 2009-06-04 Saudi Arabian Oil Company Process for catalytic hydrotreating of sour crude oils
US20100018904A1 (en) * 2008-07-14 2010-01-28 Saudi Arabian Oil Company Prerefining Process for the Hydrodesulfurization of Heavy Sour Crude Oils to Produce Sweeter Lighter Crudes Using Moving Catalyst System
US20100025293A1 (en) * 2008-07-14 2010-02-04 Saudi Arabian Oil Company Process for the Sequential Hydroconversion and Hydrodesulfurization of Whole Crude Oil
US20100025291A1 (en) * 2008-07-14 2010-02-04 Saudi Arabian Oil Company Process for the Treatment of Heavy Oils Using Light Hydrocarbon Components as a Diluent
US7678264B2 (en) 2005-04-11 2010-03-16 Shell Oil Company Systems, methods, and catalysts for producing a crude product
US7745369B2 (en) 2003-12-19 2010-06-29 Shell Oil Company Method and catalyst for producing a crude product with minimal hydrogen uptake
US7749374B2 (en) 2006-10-06 2010-07-06 Shell Oil Company Methods for producing a crude product
US7918992B2 (en) 2005-04-11 2011-04-05 Shell Oil Company Systems, methods, and catalysts for producing a crude product
US20110083996A1 (en) * 2009-06-22 2011-04-14 Saudi Arabian Oil Company Alternative Process for Treatment of Heavy Crudes in a Coking Refinery

Citations (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3322666A (en) * 1964-08-25 1967-05-30 Gulf Research Development Co Chemical process for hydrocracking and hydrorefining of hydrocarbon oils
US3418234A (en) * 1967-02-16 1968-12-24 Hydrocarbon Research Inc High conversion hydrogenation
US3530066A (en) * 1967-07-29 1970-09-22 Nippon Oil Co Ltd Catalytic hydrotreating process of petroleum hydrocarbons containing asphaltenes
US3623974A (en) * 1969-12-10 1971-11-30 Cities Service Res & Dev Co Hydrotreating a heavy hydrocarbon oil in an ebullated catalyst zone and a fixed catalyst zone
US3725251A (en) * 1971-11-08 1973-04-03 Hydrocarbon Research Inc Two-stage hydrodesulfurization of a high metal content hydrocarbon feed
US3788973A (en) * 1971-12-23 1974-01-29 Hydrocarbon Research Inc High conversion hydrogenation
US3844933A (en) * 1972-10-16 1974-10-29 Hydrocarbon Research Inc Hydroconversion of coal-derived oils

Patent Citations (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3322666A (en) * 1964-08-25 1967-05-30 Gulf Research Development Co Chemical process for hydrocracking and hydrorefining of hydrocarbon oils
US3418234A (en) * 1967-02-16 1968-12-24 Hydrocarbon Research Inc High conversion hydrogenation
US3530066A (en) * 1967-07-29 1970-09-22 Nippon Oil Co Ltd Catalytic hydrotreating process of petroleum hydrocarbons containing asphaltenes
US3623974A (en) * 1969-12-10 1971-11-30 Cities Service Res & Dev Co Hydrotreating a heavy hydrocarbon oil in an ebullated catalyst zone and a fixed catalyst zone
US3725251A (en) * 1971-11-08 1973-04-03 Hydrocarbon Research Inc Two-stage hydrodesulfurization of a high metal content hydrocarbon feed
US3788973A (en) * 1971-12-23 1974-01-29 Hydrocarbon Research Inc High conversion hydrogenation
US3844933A (en) * 1972-10-16 1974-10-29 Hydrocarbon Research Inc Hydroconversion of coal-derived oils

Cited By (89)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3964995A (en) * 1972-07-24 1976-06-22 Hydrocarbon Research, Inc. Hydrodesulfurization process
US3980551A (en) * 1975-12-18 1976-09-14 Hydrocarbon Research, Inc. Refining of waste lube oil to prepare usable lubestock
US4217206A (en) * 1977-07-20 1980-08-12 Hydrocarbon Research, Inc. Extending life of demetallization catalyst
US4301037A (en) * 1980-04-01 1981-11-17 W. R. Grace & Co. Extruded alumina catalyst support having controlled distribution of pore sizes
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
US4378308A (en) * 1980-11-26 1983-03-29 Mobil Oil Corporation Poison-resistant hydrodesulfurization catalyst
US4431526A (en) * 1982-07-06 1984-02-14 Union Oil Company Of California Multiple-stage hydroprocessing of hydrocarbon oil
US4457831A (en) * 1982-08-18 1984-07-03 Hri, Inc. Two-stage catalytic hydroconversion of hydrocarbon feedstocks using resid recycle
US4576710A (en) * 1982-09-03 1986-03-18 Hri, Inc. Catalyst desulfurization of petroleum residua feedstocks
US4548710A (en) * 1982-12-28 1985-10-22 Union Oil Company Of California Hydrocarbon processing
US4460707A (en) * 1982-12-28 1984-07-17 Union Oil Company Of California Hydroprocessing catalyst and method for preparing it
US4498972A (en) * 1982-12-31 1985-02-12 Institut Francais Du Petrole Hydrotreatment process for converting a heavy hydrocarbon fraction containing sulfur impurities and metal impurities to a lighter oil, in at least two steps
FR2542754A1 (en) * 1983-03-15 1984-09-21 Raffinage Cie Francaise METHOD OF HYDRODEMETALLIZING HYDROCARBON LOADS AND CATALYST FOR IMPLEMENTING SAID METHOD
FR2550544A1 (en) * 1983-08-10 1985-02-15 Hydrocarbon Research Inc Catalyst for hydro-demetallisation and hydroconversion
US4452911A (en) * 1983-08-10 1984-06-05 Hri, Inc. Frangible catalyst pretreatment method for use in hydrocarbon hydrodemetallization process
US4564439A (en) * 1984-06-29 1986-01-14 Chevron Research Company Two-stage, close-coupled thermal catalytic hydroconversion process
AU576083B2 (en) * 1984-06-29 1988-08-11 Chevron Research Company Two-stage, close-coupled thermal catalytic hydroconversion process
US4761220A (en) * 1984-10-31 1988-08-02 Chevron Research Company Hydroprocessing catalyst fines as a first-stage catalyst in a two-stage, close-coupled thermal catalytic hydroconversion process
US4895816A (en) * 1987-02-06 1990-01-23 Gardner Lloyd E Support material containing catalyst for fixed hydrofining beds
US4828683A (en) * 1987-02-06 1989-05-09 Phillips Petroleum Company Hydrofining employing a support material for fixed beds
US4846962A (en) * 1987-02-12 1989-07-11 Exxon Research And Engineering Company Removal of basic nitrogen compounds from extracted oils by use of acidic polar adsorbents and the regeneration of said adsorbents
US4870044A (en) * 1987-03-12 1989-09-26 Phillips Petroleum Company Treated alumina material for fixed hydrofining beds
US4802974A (en) * 1987-03-12 1989-02-07 Phillips Petroleum Company Hydrofining employing treated alumina material in fixed beds
US4925554A (en) * 1988-02-05 1990-05-15 Catalysts & Chemicals Industries Co., Ltd. Hydrotreating process for heavy hydrocarbon oils
US5417846A (en) * 1990-03-29 1995-05-23 Institut Francais Du Petrole Hydrotreatment method for a petroleum residue or heavy oil with a view to refining them and converting them to lighter fractions
US5320741A (en) * 1992-04-09 1994-06-14 Stone & Webster Engineering Corporation Combination process for the pretreatment and hydroconversion of heavy residual oils
US20030229583A1 (en) * 2001-02-15 2003-12-11 Sandra Cotten Methods of coordinating products and service demonstrations
WO2005005581A1 (en) * 2003-07-09 2005-01-20 Instituto Mexicano Del Petróleo Method for the catalytic hydroprocessing of heavy petroleum hydrocarbons
US7651604B2 (en) 2003-07-09 2010-01-26 Instituto Mexicano Del Petroleo Process for the catalytic hydrotreatment of heavy hydrocarbons of petroleum
US20070187294A1 (en) * 2003-07-09 2007-08-16 Jorge Ancheyta Juarez Process for the catalytic hydrotretment of heavy hydrocarbons of petroleum
US7628908B2 (en) 2003-12-19 2009-12-08 Shell Oil Company Systems, methods, and catalysts for producing a crude product
US7828958B2 (en) 2003-12-19 2010-11-09 Shell Oil Company Systems and methods of producing a crude product
US8663453B2 (en) 2003-12-19 2014-03-04 Shell Oil Company Crude product composition
US8613851B2 (en) 2003-12-19 2013-12-24 Shell Oil Company Crude product composition
US7402547B2 (en) 2003-12-19 2008-07-22 Shell Oil Company Systems and methods of producing a crude product
US7413646B2 (en) 2003-12-19 2008-08-19 Shell Oil Company Systems and methods of producing a crude product
US7416653B2 (en) 2003-12-19 2008-08-26 Shell Oil Company Systems and methods of producing a crude product
US7534342B2 (en) 2003-12-19 2009-05-19 Shell Oil Company Systems, methods, and catalysts for producing a crude product
US8608938B2 (en) 2003-12-19 2013-12-17 Shell Oil Company Crude product composition
US7588681B2 (en) 2003-12-19 2009-09-15 Shell Oil Company Systems, methods, and catalysts for producing a crude product
US7591941B2 (en) 2003-12-19 2009-09-22 Shell Oil Company Systems, methods, and catalysts for producing a crude product
US7615196B2 (en) 2003-12-19 2009-11-10 Shell Oil Company Systems for producing a crude product
US7625481B2 (en) 2003-12-19 2009-12-01 Shell Oil Company Systems and methods of producing a crude product
US8608946B2 (en) 2003-12-19 2013-12-17 Shell Oil Company Systems, methods, and catalysts for producing a crude product
US7648625B2 (en) 2003-12-19 2010-01-19 Shell Oil Company Systems, methods, and catalysts for producing a crude product
US20050167323A1 (en) * 2003-12-19 2005-08-04 Wellington Scott L. Systems and methods of producing a crude product
US8506794B2 (en) 2003-12-19 2013-08-13 Shell Oil Company Systems, methods, and catalysts for producing a crude product
US8475651B2 (en) 2003-12-19 2013-07-02 Shell Oil Company Systems, methods, and catalysts for producing a crude product
US8394254B2 (en) 2003-12-19 2013-03-12 Shell Oil Company Crude product composition
US7674368B2 (en) 2003-12-19 2010-03-09 Shell Oil Company Systems, methods, and catalysts for producing a crude product
US7674370B2 (en) 2003-12-19 2010-03-09 Shell Oil Company Systems, methods, and catalysts for producing a crude product
US8268164B2 (en) 2003-12-19 2012-09-18 Shell Oil Company Systems and methods of producing a crude product
US7736490B2 (en) 2003-12-19 2010-06-15 Shell Oil Company Systems, methods, and catalysts for producing a crude product
US7745369B2 (en) 2003-12-19 2010-06-29 Shell Oil Company Method and catalyst for producing a crude product with minimal hydrogen uptake
US8241489B2 (en) 2003-12-19 2012-08-14 Shell Oil Company Systems, methods, and catalysts for producing a crude product
US7763160B2 (en) 2003-12-19 2010-07-27 Shell Oil Company Systems and methods of producing a crude product
US7780844B2 (en) 2003-12-19 2010-08-24 Shell Oil Company Systems, methods, and catalysts for producing a crude product
US7807046B2 (en) 2003-12-19 2010-10-05 Shell Oil Company Systems, methods, and catalysts for producing a crude product
US7811445B2 (en) 2003-12-19 2010-10-12 Shell Oil Company Systems and methods of producing a crude product
US8163166B2 (en) 2003-12-19 2012-04-24 Shell Oil Company Systems and methods of producing a crude product
US7837863B2 (en) 2003-12-19 2010-11-23 Shell Oil Company Systems, methods, and catalysts for producing a crude product
US7854833B2 (en) 2003-12-19 2010-12-21 Shell Oil Company Systems and methods of producing a crude product
US7879223B2 (en) 2003-12-19 2011-02-01 Shell Oil Company Systems and methods of producing a crude product
US8070937B2 (en) 2003-12-19 2011-12-06 Shell Oil Company Systems, methods, and catalysts for producing a crude product
US8070936B2 (en) 2003-12-19 2011-12-06 Shell Oil Company Systems and methods of producing a crude product
US7955499B2 (en) 2003-12-19 2011-06-07 Shell Oil Company Systems, methods, and catalysts for producing a crude product
US7959796B2 (en) 2003-12-19 2011-06-14 Shell Oil Company Systems, methods, and catalysts for producing a crude product
US7959797B2 (en) 2003-12-19 2011-06-14 Shell Oil Company Systems and methods of producing a crude product
US20110192762A1 (en) * 2003-12-19 2011-08-11 Scott Lee Wellington Crude product composition
US8025794B2 (en) 2003-12-19 2011-09-27 Shell Oil Company Systems, methods, and catalysts for producing a crude product
US8025791B2 (en) 2003-12-19 2011-09-27 Shell Oil Company Systems and methods of producing a crude product
US20060006556A1 (en) * 2004-07-08 2006-01-12 Chen Hung Y Gas supply device by gasifying burnable liquid
CN100352893C (en) * 2005-02-05 2007-12-05 中国石油化工股份有限公司 Cut-fracted oil oxidation desulfurizing method
US8481450B2 (en) 2005-04-11 2013-07-09 Shell Oil Company Catalysts for producing a crude product
US7678264B2 (en) 2005-04-11 2010-03-16 Shell Oil Company Systems, methods, and catalysts for producing a crude product
US7918992B2 (en) 2005-04-11 2011-04-05 Shell Oil Company Systems, methods, and catalysts for producing a crude product
US20060278039A1 (en) * 2005-06-13 2006-12-14 Zhufang Liu Process for removing metal species in the presence of hydrogen and a porous material and polyester polymer containing reduced amounts of metal species
US7390869B2 (en) * 2005-06-13 2008-06-24 Eastman Chemical Company Process for removing metal species in the presence of hydrogen and a porous material and polyester polymer containing reduced amounts of metal species
US7749374B2 (en) 2006-10-06 2010-07-06 Shell Oil Company Methods for producing a crude product
US8632673B2 (en) 2007-11-28 2014-01-21 Saudi Arabian Oil Company Process for catalytic hydrotreating of sour crude oils
US20090139902A1 (en) * 2007-11-28 2009-06-04 Saudi Arabian Oil Company Process for catalytic hydrotreating of sour crude oils
US20100025291A1 (en) * 2008-07-14 2010-02-04 Saudi Arabian Oil Company Process for the Treatment of Heavy Oils Using Light Hydrocarbon Components as a Diluent
US20100018904A1 (en) * 2008-07-14 2010-01-28 Saudi Arabian Oil Company Prerefining Process for the Hydrodesulfurization of Heavy Sour Crude Oils to Produce Sweeter Lighter Crudes Using Moving Catalyst System
US20100025293A1 (en) * 2008-07-14 2010-02-04 Saudi Arabian Oil Company Process for the Sequential Hydroconversion and Hydrodesulfurization of Whole Crude Oil
US8372267B2 (en) 2008-07-14 2013-02-12 Saudi Arabian Oil Company Process for the sequential hydroconversion and hydrodesulfurization of whole crude oil
US9260671B2 (en) 2008-07-14 2016-02-16 Saudi Arabian Oil Company Process for the treatment of heavy oils using light hydrocarbon components as a diluent
US8491779B2 (en) 2009-06-22 2013-07-23 Saudi Arabian Oil Company Alternative process for treatment of heavy crudes in a coking refinery
US20110083996A1 (en) * 2009-06-22 2011-04-14 Saudi Arabian Oil Company Alternative Process for Treatment of Heavy Crudes in a Coking Refinery

Similar Documents

Publication Publication Date Title
US3901792A (en) Multi-zone method for demetallizing and desulfurizing crude oil or atmospheric residual oil
US4306964A (en) Multi-stage process for demetalation and desulfurization of petroleum oils
US4054508A (en) Demetalation and desulfurization of residual oil utilizing hydrogen and trickle beds of catalysts in three zones
US3809644A (en) Multiple stage hydrodesulfurization of residuum
US3870623A (en) Hydroconversion process of residuum oils
US4016067A (en) Process for demetalation and desulfurization of petroleum oils
US4328127A (en) Residua demetalation/desulfurization catalyst
US8372267B2 (en) Process for the sequential hydroconversion and hydrodesulfurization of whole crude oil
US3501396A (en) Hydrodesulfurization of asphaltene-containing black oil
US3964995A (en) Hydrodesulfurization process
US4534852A (en) Single-stage hydrotreating process for converting pitch to conversion process feedstock
US3114701A (en) Catalytic hydrodenitrification process
US4404097A (en) Residua demetalation/desulfurization catalyst and methods for its use
US4340466A (en) Process for hydrotreating heavy oils containing metals
US3732155A (en) Two-stage hydrodesulfurization process with hydrogen addition in the first stage
JPS6326157B2 (en)
EP0285233B1 (en) Method for hydrocracking heavy fraction oil
US4576710A (en) Catalyst desulfurization of petroleum residua feedstocks
JPH0753967A (en) Hydrotreatment of heavy oil
US4108761A (en) Denitrification of carbonaceous feedstocks
US3155608A (en) Process for reducing metals content of catalytic cracking feedstock
US4165274A (en) Process for the preparation of synthetic crude oil
EP0239056A2 (en) Catalytic hydrofining of oil
US3725251A (en) Two-stage hydrodesulfurization of a high metal content hydrocarbon feed
US3893911A (en) Demetallization of high metals feedstocks using regenerated catalyst

Legal Events

Date Code Title Description
AS Assignment

Owner name: HRI, INC., 1313 DOLLEY MADISON BLVD, MC LEANN, VA.

Free format text: ASSIGNMENT OF ASSIGNORS INTEREST.;ASSIGNOR:HYDROCARBON RESEARCH, INC.;REEL/FRAME:004180/0621

Effective date: 19830331