US3910834A - Moving bed reactor conversion process for particulate containing hydrocarbons such as shale oil and tar-sands oil - Google Patents

Moving bed reactor conversion process for particulate containing hydrocarbons such as shale oil and tar-sands oil Download PDF

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US3910834A
US3910834A US284689A US28468972A US3910834A US 3910834 A US3910834 A US 3910834A US 284689 A US284689 A US 284689A US 28468972 A US28468972 A US 28468972A US 3910834 A US3910834 A US 3910834A
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reactor
catalyst
oil
moving bed
charged
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Robert F Anderson
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Honeywell UOP LLC
Universal Oil Products Co
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Universal Oil Products Co
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Priority to US284689A priority Critical patent/US3910834A/en
Priority to CA179,322A priority patent/CA1008386A/en
Priority to GB4046473A priority patent/GB1440523A/en
Priority to IT52213/73A priority patent/IT990342B/it
Priority to DE19732343211 priority patent/DE2343211A1/de
Priority to FR7331295A priority patent/FR2197968B1/fr
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Assigned to UOP, DES PLAINES, IL, A NY GENERAL PARTNERSHIP reassignment UOP, DES PLAINES, IL, A NY GENERAL PARTNERSHIP ASSIGNMENT OF ASSIGNORS INTEREST. Assignors: KATALISTIKS INTERNATIONAL, INC., A CORP. OF MD
Assigned to UOP, A GENERAL PARTNERSHIP OF NY reassignment UOP, A GENERAL PARTNERSHIP OF NY ASSIGNMENT OF ASSIGNORS INTEREST. Assignors: UOP INC.
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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
    • 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
    • C10G45/18—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 according to the "moving-bed" technique

Definitions

  • the invention pertains to the hydroprocessing of petroleum feed stocks for the removal of sulfur, nitrogen and metals and the hydrocracking of heavy fractions of the petroleum. It is directly concerned with the use of a moving bed reactor for the duel-functional role of reactor and filter, particularly with feed stocks containing large amounts of abrasive or catalyst fouling material.
  • a basic problem in fixed bed hydroprocessing is the plugging of the catalyst bed due to the accumulation of foreign matter entrained in the feed.
  • Filtration of charge stocks for fixed bed reactors has been performed with replaceable cartridge filters in the charge lines or with dirt traps located within the reactor as described in US. Pat. No. 3,255,159.
  • Other methods used inside the reactor include increasing the surface area over which the clogging occurs and impingement baffles to deflect solid material away from the catalyst bed.
  • Panel bed filters utilize flow of the process media horizontally through a thin layer of particles similar to radial flow reactors and include a means to remove built up filter cake either mechanically or by expelling the particles horizontally through openings in the filter apparatus.
  • a moving bed hydroprocessing reactor is used as a first contacting zone to remove entrained material from the charge stock by the filtration action of the catalyst.
  • the catalyst flow through the reactor removes the accumulated material from the reactor and therefore prevents the build up of excessive pressure drops.
  • Optimum filtration is obtained when the oil flows countercurrent to a descending catalyst bed traveling in a piston-like manner.
  • a broad range petroleum fraction such as a raw tar sand origin oil containing a large amount of particulate matter, is passed through a moving bed hydroprocessing reactor in contact with hydrogen.
  • the efi'luent is then separated into a light fraction which is passed through a fixed bed hydroprocessing reactor, and a heavy fraction which is comingled with fresh hydrogen and passed through a hydrorefining or hydrocracking reactor.
  • the countercurrent flow of oil and catalyst aids in preventing the escape of entrained particulate matter from the reactor when the catalyst bed moves as the catalyst is transferred. Material released from the lower part of the bed must then move through the upper part and is more likely to be recaptured.
  • the flow of oil may also be downward through the reactor in the more conventional manner.
  • the partially hydrotreated and filtered reactor effluent leaves by lines 7 and is passed directly into separator 8.
  • This separator may be a hot flash Zone or a fractionator with a small number of trays to perform a rough split of the effluent into a heavy oil fraction and a light oil fraction.
  • the light oil fraction including hydrogen, hydrogen sulfide, and light gases is withdrawn through line 9 for passage through fixed bed reactor I0, which due to the light character of the charged material would be operated at hydrotreating conditions to complete removal of sulfur and nitrogen before the charged material exits through line I].
  • the heavy hydrocarbon fraction produced in separator 8 is withdrawn through line 12 and commingled with fresh hydrogen entering the process through line 13 prior to passage by line 14 into fixed bed hydrocracking reactor 15.
  • the reactor effluent leaves by line 16 for appropriate fractionation into the desired products.
  • This invention relates to the field of hydroprocessing in general and is particularly directed to those hydroprocessing operations troubled by the accumulation on the catalyst bed of solid or semi-solid foreign material entrained in the feed stream.
  • the invention is also concerned with the necessity of removing small highly abrasive sulfated ash from the crude oil produced from tar sands.
  • Such foreign matter is introduced from one or more various sources and may comprise, for example, mill scale torn loose from plant equipment carrying the feed stream, corrosion products, iron sulfide, and various pieces of solid materials such as sand or oil shale particles.
  • a technique presently resorted to in order to avoid total shut downs of the complete process because of reactor plugging or catalyst deactivation consists of operating two or more reactors in parallel and removing one of the reactors at a time to replace or regenerate the catalyst.
  • This method requires a higher initial capital expenditure, involves a more complicated process flow and does not provide continuously uniform products.
  • the use of a moving bed reactor provides the means to avoid these problems encountered in the prior art.
  • a moving bed reactor is defined as a reactor wherein a non-fluidized bed of catalyst is slowly transferred from one end of the reactor to the other end in a flow similar to plug flow of reactants by the intermittent addition of catalyst at the first end and removal at the second.
  • the time between these catalyst movements will depend on process results and the amount of catalyst transferred on each occasion. Intermittent may therefore range in meaning from about every hour to about every week or two.
  • the advantages of the moving bed system has lead to its use in the light oil process of reforming as described in US. Pat. Nos. 3,470,090 and 3,647,680. This application of moving bed technology is carried out at low pressures of from l00 to 300 psig. with all of the hydrocarbon maintained in a vapor phase.
  • the broad field of hydroprocessing is divided into three main subdivisions.
  • the first is hydrotreating wherein material such as sulfur, nitrogen, and metals contained in various organic molecular structures are removed from the charge stock with very little molecular cracking.
  • the second subdivision is hydrocracking, wherein a substantial part of the charge stock is cracked into smaller molecular weight components, such as in the production of a naphtha from a heavy distillate. Hydrorefining is between these two extremes and results in molecular changes to up to l0% of the feed together with impurity removal.
  • suitable catalysts and flow schemes for these different operations they are basically alike in most aspects and may in fact be performed simultaneously in one operation using different reactors or more than one catalyst in a single reactor. In every instance, the hydrocarbon is mixed with hydrogen and raised to an elevated temperature and pressure and passed over a catalyst having a tendency to promote the desired reactions.
  • Catalysts used in these processes are typically composed of a base metal, which is defined to be a metal selected from the group consisting of nickel, iron and cobalt, supported on an inorganic oxide carrier.
  • a suitable catalyst may contain from about 0. ⁇ to l0% nickel or other metal or a combination of metals from base metal group, or other metals not in the group such as molybdenum or vanadium or oxides of these metals.
  • the base material in the catalyst will normally be a refractory inorganic oxide such as alumina, silica, zirconia, or boria, or combinations of any of these materials, particularly alumina in combination with one or more of the other oxides.
  • the alumina is usually the predominant component with a weight ratio in the catalyst of from l.5:l to about 9:] and preferably from about l.5:l to about 3zl of alumina to other support materials.
  • Inclusion of a small amount of silica is the common method to increase the cracking activity of the catalyst since silica is an effective cracking catalyst by itself. Details of suitable catalyst production are given in US. Pat. Nos. 3,525,684 and 3,471,399.
  • the processing conditions necessary for any hydrorefining operation are determined by the charge stock. the catalyst used and the desired result of the process.
  • a broad range of conditions includes a temperature of from 500F. to l000F., a pressure of from 300 psig. to 4000 psig., and a liquid hourly space velocity of 0.5 to about 5.0.
  • the liquid hourly space velocity is defined as the hourly volume at 60F. of the hydrocarbon charged to the reactor divided by the volume in the catalyst in the reactor.
  • the exact reactor temperature re quired is determined by the initial activity and prior use of catalyst. As a general rule, the preferred operating pressure will increase with the boiling point of the material being processed.
  • hydrogen is circulated through the process at a rate of about 1,000 to 2,5000 scf/bbl of charge. This is to increase the vaporization of the oil, thereby resulting in better yields, and to provide hydrogen needed for the formation of ammonia and hydrogen sulfide from the nitrogen and sulfur removed from the charge stock and for the saturation of olefinic hydrocarbons formed by the cracking of large complex molecules. Hydrogen consumed in this manner must be replaced at a rate equal to its consumption, which will vary from about scf/bbl to about 200 scf/bbl during hydrotreating and up to about L000 scf/bbl during hydrocracking.
  • Canadian tar sands produce a synthetic crude oil having a composition which includes approximately 250 ppm. metals (mainly nickel and vanadium), about 5% sulfur, and from 10 ppm. to about 2,000 ppm. particulates. These crudes are very heavy in composition, have about 7 APl gravity, contain approximately l l7r heptane insolubles, and are only about 50% distillable.
  • the particulate matter comprises sulfated ash which consists mostly of alumina silicate particles of l to 10 microns in diameter. These particles have sharp edges and are quite abrasive and must be removed early in the processing of the crude oil to prevent excessive erosion of processing equipment. Coking the oil, the simplest method to deal with this trouble, is used by the Great Canadian Tar Sand Company in the major tar sand refinery now in existence.
  • Shale oil compositions vary with the method of extracting the oil but will normally include a high amount of sulfur, nitrogen and metals. The amount of rock dust and particles may not be excessive if the oil is produced by retorting the shale.
  • the method of the present invention is to intentionally remove substantial amounts of particulate matter by the filter action of a bed of catalyst while simultaneously utilizing the catalyst to hydroprocess the charged material, and intermittently withdrawing portions of the catalyst bed and entrained particulate matter from the reactor to prevent the build up of excessive pressure drops in the reactor.
  • neither long catalyst life nor highly uniform distribution patterns are the controlling criteria.
  • the central objective is the removal of large proportions of the particulate matter and metals from the charge stock as a clean up operation prior to further processing.
  • the flow chosen through the reactor therefore will be that which provides the best removal of the particulate matter and still, if possible, provides a good degree of hydroprocessing and may be either upflow or downflow.
  • Upflow operation is not normally used in fixed bed operations with a charge stock heavy as that derived from the tar sands, because the heavy liquid would not be vaporized and there would result two phase flow through the reactor. Two phase flow is thought to hinder the diffusion of hydrogen to activate catalyst sites and results in an increased carbon forma tion rate, quicker deactivation of the catalyst, channelling of reactants and inferior yields and operation.
  • catalyst particles are relatively large and loose fitting compared to normal filter media, a certain degree of fine material will pass through the catalyst bed. As time progresses, the material that is removed from the liquid stream accumulates on a filter and itself acts as filter medium. With a wide particle size distribution, the course particles initially removed will partially plug the larger holes through the catalyst bed and increase its filtration efficiency. This natural phenomenon can be used to the best advantage with an upward flow of oil in the reactor, that is, one countercurrent to the downward moving catalyst.
  • Catalyst particles are normally about l/16 inch to 3/8 inch extruded pellets or spheres.
  • the use of a smaller size catalyst will increase the effectiveness of the catalyst bed as a filter medium, since it is in effect a step toward a true filter medium.
  • the minimum size the catalyst used will be a great extent determined by the physical restraints of designing equipment to prevent the catalyst from exiting from the reactor effluent and to transport the catalyst into and out of the reactor.
  • Other very important design considerations include the increase in pressure drop inherent with a smaller catalyst (approximately 50 velocity heads per diameter), and the tendency of catalyst (depending on catalyst size and density and the fluids characteristics) to become fluidized in countercurrent flow. Large pressure drops in upflow reactors can raise the catalyst bed as a whole and thereby cause difficulty in attempts to transport catalyst into and out of the reactor by gravity.
  • One method available for preventing the lifting or fluidization of the catalyst bed is the use of a hydraulic ram formed by material circulated downward through the top of reactor and exiting at a midpoint of the vessel.
  • the ram exerts a downward force composed of the weight of the solids above the reactor effluent opening plus the drag of the fluid being circulated downward over these solids.
  • a hydraulic ram is used advantageously as a reaction zone in a specific embodiment of the present invention
  • a mixed phase reactant stream such as heavy material recycled from the reactor effluent, may be used and a common effluent opening provided, or a vapor phase reactant stream may be used in conjunction with sepa rate effluent openings for the two reactant streams to minimize mixing.
  • the vapor phase reactant stream may be light material separated from the lower reactor zone effluent and which would be contaminated if comingled with the rising heavier reactants from the treating and filtration zone.
  • These effluent openings could be separated by a layer of catalyst to prevent mixing rather than a physical separator, such as a conventional plate deck, which would restrict catalyst movement.
  • the moving bed reactor is intended to perform significant hydroprocessing
  • a specific embodiment of the present invention has the rate of catalyst addition controlled solely by the pressure drop or the filtration in the reactor rather than the rate of conversion.
  • the pressure drop between the reactant inlet and outlet may be correlated with experimentally determined degrees of filtration to provide a means to optimize processing. A less than normally desired removal of sulfur, nitrogen and metals may be the overall optimum case.
  • the moving bed reactor would hold from 10 to 25% of the total catalyst used in the process and would be operated at a liquid hourly space velocity of from 2 to l() based on a space velocity of 0.5 to L0 for the process as a whole.
  • the moving bed reactor would be operated at high severity conditions to result in approximately 50% metals removal, about 50 to 60% sulfur removal and at least 90% removal of the particulate matter. Due to the high severity operation envisioned and the inherent rapid build up of coke on the catalyst, the catalyst removed from the reactor could be substantially regen erated by contact with oxygen to burn off the carbon and reused in the reactor.
  • the catalyst regeneration may be a two-stop operation with initial removal of entrained charge stock and particulate matter from the catalyst in a cleaning zone to form a more free flowing catalyst which in a second step would be contacted with air or some other oxygen containing gas stream.
  • rate of carbon deposition is relatively low, as in the processing of a light. fully vaporized oil fraction, a portion of the catalyst may be returned to the reactor without regeneration,
  • the high metals content of a crude tar sand derived charge stock would result in rather quick, permanent deactivation of the catalyst due to deposition of metals on the catalyst surface. This metals poisioning of catalyst is irreversible and not affected by the removal of the carbon. Hence, there would be required a constant replacement of the used catalyst with fresh catalyst.
  • the preferred embodiment utilizes a moving bed reactor followed by a fractionation step to divide the wide boiling range crude oil produced from the tar sand into two separate fractions.
  • the lighter fraction is hydrotreated for the removal of residual metals, sulfur and nitrogen, while the heavier fraction is treated or cracked in a second fixed bed reactor operated at higher severity conditions.
  • the hydrogen that is not consumed in the moving bed reactor is passed through to the fixed bed reactor processing the lighter fraction of the charge stock.
  • a higher purity hydrogen stream is charged to the second moving bed reactor processing the heavy fraction of the moving bed reactor effluent to maintain a higher hydrogen partial pressure for more effective desulfurization of this heavier material.
  • the reactors may be operated at different conditions of pressure and temperature as dictated by product slate, feed composition, and economics.
  • a moving bed reactor may be used to process this heavier fraction.
  • the light fraction removed from the separation zone may also be ei ther processed in a fixed bed or moving bed reactor may be fractionated prior to any further treatment. Either of these fractions may be recycled to the initial moving bed reactor as a second stream charged to the top of the reactor to prevent fluidization or lifting of the catalyst bed by the charge stream entering the bottom of the reactor.
  • a process for the filtration and hydroprocessing of a particulate-containing tar-sand oil or shale oil which comprises the steps of:
  • a process for the filtration and hydroprocessing of a particulate-containing tar-sand oil or shale oil which comprises the steps of:
  • catalyst removed from said second reactor is regenerated by contacting it with an oxygen-containing gas so to remove carbon deposits and is then charged to the initial moving bed reactor.

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  • 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)
  • Organic Low-Molecular-Weight Compounds And Preparation Thereof (AREA)
US284689A 1972-08-29 1972-08-29 Moving bed reactor conversion process for particulate containing hydrocarbons such as shale oil and tar-sands oil Expired - Lifetime US3910834A (en)

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Application Number Priority Date Filing Date Title
US284689A US3910834A (en) 1972-08-29 1972-08-29 Moving bed reactor conversion process for particulate containing hydrocarbons such as shale oil and tar-sands oil
CA179,322A CA1008386A (en) 1972-08-29 1973-08-21 Moving bed reactor conversion process for particulate containing hydrocarbons
IT52213/73A IT990342B (it) 1972-08-29 1973-08-28 Procedimento per la conversione di idrocarburi del petrolio a letto mo bile
DE19732343211 DE2343211A1 (de) 1972-08-29 1973-08-28 Kohlenwasserstoffumwandlungsverfahren
GB4046473A GB1440523A (en) 1972-08-29 1973-08-28 Moving-bed reactor conversion process for hydrocarbons containing particulate matter
FR7331295A FR2197968B1 (enrdf_load_stackoverflow) 1972-08-29 1973-08-29

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CA (1) CA1008386A (enrdf_load_stackoverflow)
DE (1) DE2343211A1 (enrdf_load_stackoverflow)
FR (1) FR2197968B1 (enrdf_load_stackoverflow)
GB (1) GB1440523A (enrdf_load_stackoverflow)
IT (1) IT990342B (enrdf_load_stackoverflow)

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US4029571A (en) * 1975-02-25 1977-06-14 Atlantic Richfield Company Method of removing contaminant from hydrocarbonaceous fluid
US4298458A (en) * 1980-02-25 1981-11-03 Mobil Oil Corporation Low pressure hydrotreating of residual fractions
US4344840A (en) * 1981-02-09 1982-08-17 Hydrocarbon Research, Inc. Hydrocracking and hydrotreating shale oil in multiple catalytic reactors
US4393264A (en) * 1979-10-19 1983-07-12 Standard Oil Company (Indiana) Continuous non-catalytic pyrolysis of aqueous slurry of oxygen-containing derivatives of benzene and toluene
US4409092A (en) * 1980-04-07 1983-10-11 Ashland Oil, Inc. Combination process for upgrading oil products of coal, shale oil and crude oil to produce jet fuels, diesel fuels and gasoline
JPS5945390A (ja) * 1982-08-18 1984-03-14 エツチア−ルアイ・インコ−ポレ−テツド 炭化水素原料油の接触水添転化方法
US4968409A (en) * 1984-03-21 1990-11-06 Chevron Research Company Hydrocarbon processing of gas containing feed in a countercurrent moving catalyst bed
US5041209A (en) * 1989-07-12 1991-08-20 Western Research Institute Process for removing heavy metal compounds from heavy crude oil
US5736108A (en) * 1995-08-04 1998-04-07 Softard Industries Co., Ltd. Refrigerant unit in hydrogen treating plant
US6372123B1 (en) 2000-06-26 2002-04-16 Colt Engineering Corporation Method of removing water and contaminants from crude oil containing same
US6536523B1 (en) 1997-01-14 2003-03-25 Aqua Pure Ventures Inc. Water treatment process for thermal heavy oil recovery
US6579443B1 (en) * 1998-12-07 2003-06-17 Exxonmobil Research And Engineering Company Countercurrent hydroprocessing with treatment of feedstream to remove particulates and foulant precursors
DE4231718C2 (de) * 1991-09-26 2003-07-31 Inst Francais Du Petrole Verfahren zur Wasserstoffbehandlung einer schweren Kohlenwasserstofffraktion
CN1322097C (zh) * 2000-12-11 2007-06-20 法国石油公司 使用可置换反应器和可短路反应器加氢处理重烃馏分的方法
US20100200465A1 (en) * 2009-02-12 2010-08-12 Todd Dana Carbon management and sequestration from encapsulated control infrastructures
US20100200467A1 (en) * 2009-02-12 2010-08-12 Todd Dana Methods of recovering hydrocarbons from hydrocarbonaceous material using a constructed infrastructure and associated systems maintained under positive pressure
US20110094952A1 (en) * 2007-02-09 2011-04-28 Red Leaf Resources, Inc. System For Recovering Hydrocarbons From Water-Containing Hydrocarbonaceous Material Using a Constructed Infrastructure
WO2012095565A2 (fr) 2011-01-10 2012-07-19 IFP Energies Nouvelles Procédé d'hydrotraitement de charges lourdes d'hydrocarbures avec des reacteurs permutables incluant au moins une etape de permutation progressive
WO2012095566A2 (fr) 2011-01-10 2012-07-19 IFP Energies Nouvelles Procede d'hydrotraitement de charges lourdes d'hydrocarbures avec des reacteurs permutables incluant au moins une etape de court-circuitage d'un lit catalytique
US8961652B2 (en) 2009-12-16 2015-02-24 Red Leaf Resources, Inc. Method for the removal and condensation of vapors
US9242190B2 (en) 2009-12-03 2016-01-26 Red Leaf Resources, Inc. Methods and systems for removing fines from hydrocarbon-containing fluids
US20170066983A1 (en) * 2015-09-09 2017-03-09 Sundrop Fuels, Inc. Integrated Process Plant Having a Biomass Reforming Reactor Using a Fluidized Bed
US11795406B2 (en) 2017-02-12 2023-10-24 Magemä Technology LLC Multi-stage device and process for production of a low sulfur heavy marine fuel oil from distressed heavy fuel oil materials
US11884883B2 (en) 2017-02-12 2024-01-30 MagêmãTechnology LLC Multi-stage device and process for production of a low sulfur heavy marine fuel oil
US12025435B2 (en) 2017-02-12 2024-07-02 Magēmã Technology LLC Multi-stage device and process for production of a low sulfur heavy marine fuel oil
US12071592B2 (en) 2017-02-12 2024-08-27 Magēmā Technology LLC Multi-stage process and device utilizing structured catalyst beds and reactive distillation for the production of a low sulfur heavy marine fuel oil
US12281266B2 (en) 2017-02-12 2025-04-22 Magẽmã Technology LLC Heavy marine fuel oil composition
US12404462B2 (en) 2021-05-26 2025-09-02 Magēmā Technology LLC Multi-stage process and device utilizing structured catalyst beds and reactive distillation for the production of a low sulfur heavy marine fuel oil

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FR2969648B1 (fr) 2010-12-24 2014-04-11 Total Raffinage Marketing Procede de conversion de charge hydrocarbonee comprenant une huile de schiste par hydroconversion en lit bouillonnant, fractionnement par distillation atmospherique, et hydrocraquage

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US3712861A (en) * 1970-10-19 1973-01-23 Mobil Oil Corp Upgrading a hydrocarbon utilizing a catalyst of metal sulfides dispersed in alumina

Cited By (39)

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US4029571A (en) * 1975-02-25 1977-06-14 Atlantic Richfield Company Method of removing contaminant from hydrocarbonaceous fluid
US4393264A (en) * 1979-10-19 1983-07-12 Standard Oil Company (Indiana) Continuous non-catalytic pyrolysis of aqueous slurry of oxygen-containing derivatives of benzene and toluene
US4298458A (en) * 1980-02-25 1981-11-03 Mobil Oil Corporation Low pressure hydrotreating of residual fractions
US4409092A (en) * 1980-04-07 1983-10-11 Ashland Oil, Inc. Combination process for upgrading oil products of coal, shale oil and crude oil to produce jet fuels, diesel fuels and gasoline
US4344840A (en) * 1981-02-09 1982-08-17 Hydrocarbon Research, Inc. Hydrocracking and hydrotreating shale oil in multiple catalytic reactors
JPS5945390A (ja) * 1982-08-18 1984-03-14 エツチア−ルアイ・インコ−ポレ−テツド 炭化水素原料油の接触水添転化方法
US4457831A (en) * 1982-08-18 1984-07-03 Hri, Inc. Two-stage catalytic hydroconversion of hydrocarbon feedstocks using resid recycle
JPH0765056B2 (ja) 1982-08-18 1995-07-12 エッチアールアイ インコーポレーテッド 炭化水素原料油の接触水添転化方法
US4968409A (en) * 1984-03-21 1990-11-06 Chevron Research Company Hydrocarbon processing of gas containing feed in a countercurrent moving catalyst bed
US5041209A (en) * 1989-07-12 1991-08-20 Western Research Institute Process for removing heavy metal compounds from heavy crude oil
DE4231718C2 (de) * 1991-09-26 2003-07-31 Inst Francais Du Petrole Verfahren zur Wasserstoffbehandlung einer schweren Kohlenwasserstofffraktion
US5736108A (en) * 1995-08-04 1998-04-07 Softard Industries Co., Ltd. Refrigerant unit in hydrogen treating plant
US6536523B1 (en) 1997-01-14 2003-03-25 Aqua Pure Ventures Inc. Water treatment process for thermal heavy oil recovery
US20030127400A1 (en) * 1997-01-14 2003-07-10 Steve Kresnyak Water treatment process for thermal heavy oil recovery
US6984292B2 (en) 1997-01-14 2006-01-10 Encana Corporation Water treatment process for thermal heavy oil recovery
US6579443B1 (en) * 1998-12-07 2003-06-17 Exxonmobil Research And Engineering Company Countercurrent hydroprocessing with treatment of feedstream to remove particulates and foulant precursors
US6372123B1 (en) 2000-06-26 2002-04-16 Colt Engineering Corporation Method of removing water and contaminants from crude oil containing same
CN1322097C (zh) * 2000-12-11 2007-06-20 法国石油公司 使用可置换反应器和可短路反应器加氢处理重烃馏分的方法
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US8109047B2 (en) 2007-02-09 2012-02-07 Red Leaf Resources, Inc. System for recovering hydrocarbons from water-containing hydrocarbonaceous material using a constructed infrastructure
US20100200465A1 (en) * 2009-02-12 2010-08-12 Todd Dana Carbon management and sequestration from encapsulated control infrastructures
US20100200467A1 (en) * 2009-02-12 2010-08-12 Todd Dana Methods of recovering hydrocarbons from hydrocarbonaceous material using a constructed infrastructure and associated systems maintained under positive pressure
US8323481B2 (en) 2009-02-12 2012-12-04 Red Leaf Resources, Inc. Carbon management and sequestration from encapsulated control infrastructures
US8349171B2 (en) 2009-02-12 2013-01-08 Red Leaf Resources, Inc. Methods of recovering hydrocarbons from hydrocarbonaceous material using a constructed infrastructure and associated systems maintained under positive pressure
US9242190B2 (en) 2009-12-03 2016-01-26 Red Leaf Resources, Inc. Methods and systems for removing fines from hydrocarbon-containing fluids
US8961652B2 (en) 2009-12-16 2015-02-24 Red Leaf Resources, Inc. Method for the removal and condensation of vapors
US9482467B2 (en) 2009-12-16 2016-11-01 Red Leaf Resources, Inc. Method for the removal and condensation of vapors
WO2012095565A2 (fr) 2011-01-10 2012-07-19 IFP Energies Nouvelles Procédé d'hydrotraitement de charges lourdes d'hydrocarbures avec des reacteurs permutables incluant au moins une etape de permutation progressive
WO2012095566A2 (fr) 2011-01-10 2012-07-19 IFP Energies Nouvelles Procede d'hydrotraitement de charges lourdes d'hydrocarbures avec des reacteurs permutables incluant au moins une etape de court-circuitage d'un lit catalytique
US20170066983A1 (en) * 2015-09-09 2017-03-09 Sundrop Fuels, Inc. Integrated Process Plant Having a Biomass Reforming Reactor Using a Fluidized Bed
US10995288B2 (en) * 2015-09-09 2021-05-04 Sundrop Ip Holdings, Llc Integrated process plant having a biomass reforming reactor using a fluidized bed
US11795406B2 (en) 2017-02-12 2023-10-24 Magemä Technology LLC Multi-stage device and process for production of a low sulfur heavy marine fuel oil from distressed heavy fuel oil materials
US11884883B2 (en) 2017-02-12 2024-01-30 MagêmãTechnology LLC Multi-stage device and process for production of a low sulfur heavy marine fuel oil
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US12071592B2 (en) 2017-02-12 2024-08-27 Magēmā Technology LLC Multi-stage process and device utilizing structured catalyst beds and reactive distillation for the production of a low sulfur heavy marine fuel oil
US12139672B2 (en) 2017-02-12 2024-11-12 Magēmā Technology LLC Multi-stage device and process for production of a low sulfur heavy marine fuel oil
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US12404462B2 (en) 2021-05-26 2025-09-02 Magēmā Technology LLC Multi-stage process and device utilizing structured catalyst beds and reactive distillation for the production of a low sulfur heavy marine fuel oil

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Publication number Publication date
IT990342B (it) 1975-06-20
FR2197968A1 (enrdf_load_stackoverflow) 1974-03-29
CA1008386A (en) 1977-04-12
GB1440523A (en) 1976-06-23
FR2197968B1 (enrdf_load_stackoverflow) 1979-01-19
DE2343211A1 (de) 1974-04-11

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