US20030089636A1 - Process for the conversion of heavy charges such as heavy crude oils and distillation residues - Google Patents

Process for the conversion of heavy charges such as heavy crude oils and distillation residues Download PDF

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Publication number
US20030089636A1
US20030089636A1 US10/188,785 US18878502A US2003089636A1 US 20030089636 A1 US20030089636 A1 US 20030089636A1 US 18878502 A US18878502 A US 18878502A US 2003089636 A1 US2003089636 A1 US 2003089636A1
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process according
deasphalting
distillation
catalyst
charge
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Inventor
Mario Marchionna
Alberto Delbianco
Nicoletta Panariti
Romolo Montanari
Sergio Rosi
Sebastiano Correra
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SnamProgetti SpA
Eni Tecnologie SpA
Eni SpA
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Eni SpA
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Assigned to ENI S.P.A., ENITECNOLOGIE S.P.A., SNAMPROGETTI S.P.A. reassignment ENI S.P.A. ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: CORRERA, SEBASTIANO, DELBIANCO, ALBERTO, MARCHIONNA, MARIO, MONTANARI, ROMOLO, PANARITI, NICOLETTA, ROSI, SERGIO
Publication of US20030089636A1 publication Critical patent/US20030089636A1/en
Priority to US11/404,746 priority Critical patent/US20060186021A1/en
Priority to US12/248,163 priority patent/US20090101540A1/en
Priority to US12/725,915 priority patent/US20100300934A1/en
Priority to US13/169,950 priority patent/US20110253594A1/en
Priority to US13/532,004 priority patent/US20120261309A1/en
Priority to US14/083,237 priority patent/US9598652B2/en
Abandoned legal-status Critical Current

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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
    • C10G67/00—Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one process for refining in the absence of hydrogen only
    • C10G67/02—Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one process for refining in the absence of hydrogen only plural serial stages only
    • C10G67/04—Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one process for refining in the absence of hydrogen only plural serial stages only including solvent extraction as the refining step in the absence of hydrogen
    • C10G67/0454—Solvent desasphalting
    • 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
    • C10G67/00—Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one process for refining in the absence of hydrogen 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
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/10—Feedstock materials
    • C10G2300/1033—Oil well production fluids
    • 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
    • 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
    • C10G2300/1077—Vacuum residues
    • 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
    • C10G2300/20—Characteristics of the feedstock or the products
    • C10G2300/201—Impurities
    • C10G2300/205—Metal content
    • 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
    • C10G2300/20—Characteristics of the feedstock or the products
    • C10G2300/201—Impurities
    • C10G2300/205—Metal content
    • C10G2300/206—Asphaltenes
    • 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
    • C10G2300/20—Characteristics of the feedstock or the products
    • C10G2300/201—Impurities
    • C10G2300/207—Acid gases, e.g. H2S, COS, SO2, HCN
    • 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
    • C10G2300/40—Characteristics of the process deviating from typical ways of processing
    • C10G2300/4081—Recycling aspects
    • 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
    • C10G2300/40—Characteristics of the process deviating from typical ways of processing
    • C10G2300/44—Solvents
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
    • Y02P30/00—Technologies relating to oil refining and petrochemical industry
    • Y02P30/20—Technologies relating to oil refining and petrochemical industry using bio-feedstock

Definitions

  • the present invention relates to a process for the conversion of heavy charges, among which heavy crude oils, tars from oil sands and distillation residues, by the use of three process units: hydroconversion of the charge using catalysts in dispersed phase, distillation and deasphalting, suitably connected and fed with mixed streams consisting of fresh charge and conversion products.
  • Hydrogenating processes consist in treating the charge in the presence of hydrogen and suitable catalysts.
  • Slurry technologies are characterized by the presence of particles of catalyst having very small average dimensions and effectively dispersed in the medium: for this reason hydrogenation processes are easier and more immediate in all points of the reactor. The formation of coke is considerably reduced and the upgrading of the charge is high.
  • the catalyst can be charged as powder with sufficiently reduced dimensions (U.S. Pat. No. 4,303,634) or as oil-soluble precursor (U.S. Pat. No. 5,288,681).
  • the active form of the catalyst generally the metal sulfide
  • the catalyst is formed in-situ by thermal decomposition of the compound used, during the reaction itself or after suitable pretreatment (U.S. Pat. No. 4,470,295).
  • the metallic constituents of the dispersed catalysts are generally one or more transition metals (preferably Mo, W, Ni, Co or Ru). Molybdenum and tungsten have much more satisfactory performances than nickel, cobalt or ruthenium and even more than vanadium and iron (N. Panariti et al., Appl. Catal. A: January 2000, 204, 203).
  • the catalyst can be used at a low concentration (a few hundreds of ppm) in a “once-through” configuration, but in this case the upgrading of the reaction products is generally insufficient (N. Panariti et al., Appl. Catal. A: January 2000, 204, 203 and 215).
  • extremely active catalysts for example molybdenum
  • concentrations of catalyst for example molybdenum
  • the catalyst leaving the reactor can be recovered by separation from the product obtained from hydro-treatment (preferably from the bottom of the distillation column, downstream of the reactor) using conventional methods such as, for example, decanting, centrifugation or filtration (U.S. Pat. No. 3,240,718; U.S. Pat. No. 4,762,812). Part of the catalyst can be recycled to the hydrogenation process without further treatment.
  • the catalyst recovered using known hydro-treatment processes normally has a reduced activity with respect to fresh catalyst and a suitable regeneration step must therefore be effected to restore the catalytic activity and recycle at least part of the catalyst to the hydro-treatment reactor.
  • Hydrocarbons which can be precipitated by a crude oil or oil residue by treatment with n-heptane under standard conditions established by regulation IP-143, are conventionally defined as asphaltenes.
  • the optimum operating conditions (mainly reaction temperature and residence time) are simply determined on the basis of the stability data of the reactor effluent by means of direct measurements on the non-converted residue (P value, Hot Filtration Test, Spot Test, etc.).
  • This process comprises the following steps:
  • the process, object of the present invention for the conversion of heavy charges by means of the combined use of the following three process units: hydroconversion with catalysts in slurry phase (HT), distillation or flash (D), deasphalting (SDA), is characterized in that the three units operate on mixed streams consisting of fresh charge and recycled streams, using the following steps:
  • the heavy charges treated can be of different kinds: they can be selected from heavy crude oils, distillation residues, heavy oils coming from catalytic treatment, for example heavy cycle oils from catalytic cracking treatment, thermal tars (coming for example from visbreaking or similar thermal processes), tars from oil sands, various kinds of coals and any other high-boiling charge of a hydrocarbon origin generally known in the art as “black oils”.
  • the catalysts can be selected from those obtained from easily decomposable oil-soluble precursors (metallic naphthenates, metallic derivatives of phosphonic acids, metalcarbonyls, etc.) or from preformed compounds based on one or more transition metals such as Ni, Co, Ru, W and Mo: the latter is preferred due to its high catalytic activity.
  • the concentration of catalyst defined on the basis of the concentration of metal or metals present in the hydroconversion reactor, ranges from 350 to 10000 ppm, preferably from 1000 to 8000 ppm, more preferably from 1500 to 5000 ppm.
  • the hydro-treatment step is preferably carried out at a temperature ranging from 370 to 480° C., preferably from 380 to 440° C., and at a pressure ranging from 3 to 30 MPa, preferably from 10 to 20 MPa.
  • the hydrogen is fed to the reactor, which can operate either under down-flow or, preferably up-flow conditions.
  • the gas can be fed to different sections of the reactor.
  • the distillation step is preferably carried out at reduced pressure, at a pressure ranging from 0.001 to 0.5 MPa, preferably from 0.05 to 0.3 MPa.
  • the hydro-treatment step can consist of one or more reactors operating within the range of conditions indicated above. Part of the distillates produced in the first reactor can be recycled to the subsequent reactors.
  • the deasphalting step effected by an extraction with a solvent, which may or may not be hydrocarbon, (for example with paraffins having from 3 to 6 carbon atoms), is generally carried out at temperatures ranging from 40 to 200° C. and at a pressure ranging from 0.1 to 7 MPa. It can also consist of one or more sections operating with the same solvent or with different solvents; the solvent can be recovered under supercritical conditions thus allowing further fractionation between asphalt and resins.
  • a solvent which may or may not be hydrocarbon, (for example with paraffins having from 3 to 6 carbon atoms)
  • the stream consisting of deasphalted oil (DAO) can be used as such as synthetic crude oil (syncrude), optionally mixed with the distillates, or it can be used as charge for fluid bed Catalytic Cracking treatment or Hydrocracking.
  • DAO deasphalted oil
  • the recycling ratio between fresh charge and tar to be sent to the deasphalting section preferably varies from 0.1 to 100, more preferably from 0.1 to 10;
  • the recycling ratio between fresh charge and asphalts to be sent to the hydro-treatment section can vary in relation to the variation in the previous ratios
  • the recycling ratio between tar and asphalts to be sent to the hydro-treatment section can vary in relation to the variation in the previous ratios.
  • the fractions of fresh charge to be fed to the deasphalting and hydro-treatment sections can be modulated in the best possible way.
  • the process, object of the present invention can be further improved, as far as the compatibility of the streams to be mixed is concerned, by controlling that the recycling between the streams containing asphaltenes, or fresh charge, tar and asphalt, has such a ratio that:
  • ⁇ mix is the molar volume of the maltene component (i.e. non-asphaltene) of the mixture (cm 3 /mole);
  • ⁇ mix is the solubility parameter of the maltene component of the mixture (cal/cm 3 ) 1/2 ;
  • ⁇ asph is the solubility parameter of the asphaltenes of the mixture (the highest value among the values of the two components of the mixture is considered)(cal/cm 3 ) 1/2 ;
  • R Gas Constant (1.987 cal/mol° K);
  • T temperature expressed in Kelvin degrees.
  • the asphaltenes used as reference for determining the properties indicated above are the insoluble n-heptane fraction (C 7 asphaltenes).
  • ⁇ mix molar average of the molar volumes of the maltene components
  • ⁇ mix volumetric average of the solubility parameters of the maltene components
  • k constant whose value ranges from 0.2 to 0.5.
  • the investment cost of the whole complex can also be minimized as, with respect to the scheme described in patent application IT-95A001095, for the same charge unit treated, the dimensions of the deasphalting section are increased whereas those of the hydro-treatment section (and downstream distillation column) are reduced; as the deasphalting unit involves lower investment costs than the hydro-treatment unit, there is a consequent saving on the investment cost of the whole complex.
  • FIG. 1 A preferred embodiment of the present invention is now provided with the help of FIG. 1 enclosed, which however should not be considered as limiting the scope of the invention itself.
  • the heavy charge ( 1 ), or at least a part thereof ( 1 a ), is sent to the deasphalting unit (SDA), an operation which is effected by means of extraction with solvent.
  • SDA deasphalting unit
  • Two streams are obtained from the deasphalting unit (SDA): one ( 2 ) consisting of deasphalted oil (DAO), the other consisting of asphalts and resins ( 3 ); the latter can be further separated into the two groups of compounds of which it is formed, and the fraction of resins ( 4 ) can be divided between DAO and asphalt.
  • DAO deasphalted oil
  • resins 3
  • the stream consisting of asphalt and resins (or a fraction of these) is mixed with fresh make-up catalyst ( 5 ) necessary for reintegrating that used up with the flushing stream ( 14 ), with the part of heavy charge ( 1 b ) not fed to the deasphalting section and optionally with the stream ( 15 ) (which will be described further on in the text) coming from the bottom of the distillation column (D) to form a stream ( 6 ) which is fed to the hydro-treatment reactor (HT) into which hydrogen (or a mixture of hydrogen and H 2 S) ( 7 ), is charged.
  • HT hydro-treatment reactor
  • a stream ( 8 ) containing the hydrogenation product and catalyst in dispersed phase leaves the reactor and is fractionated in a distillation column (D) from which the lighter fractions ( 9 ) and distillable products ( 10 ), ( 11 ) and ( 12 ) are separated from the distillation residue containing the dispersed catalyst and coke.
  • This stream, called tar, ( 13 ) is completely or for the most part, except for a flushing ( 14 ), recycled to the deasphalting reactor (SDA).
  • a part of this ( 15 ) can be optionally sent to the hydro-treatment unit (HT).
  • Deasphalting agent 2000 cc of liquid propane (extraction repeated 3 times)
  • Reactor 3000 cc, steel, suitably shaped and equipped with magnetic stirring
  • Catalyst 3000 ppm of Mo/charge added using molybdenum naphthenate as precursor
  • Atmospheric gas oil (AGO 170-350° C.):17%
  • the asphaltene stream recovered at the end of the test contains all the catalyst initially fed, sulfides of the metals Ni and V produced during the 10 recycles from the hydro-treatment and a quantity of coke in the order of about 1% by weight with respect to the total quantity of Ural residue fed. In the example indicated, there was no need to effect any flushing of the recycled stream.
  • Table 2 provides the characterization of the product obtained. TABLE 2 characteristics of test reaction products according to Example 1. Sulfur Nitrogen RCC Ni + V w % (ppm) Sp.Gr. (w %) (ppm) Naphtha C 5 -170° C. 0.06 450 0.768 — — AGO 170-350° C. 0.52 2100 0.870 — — VGO + DAO 1.45 2500 0.938 3 1
  • Atmospheric gas oil (AGO 170-350° C.):24%
  • VGO+DAO 56%
  • Table 3 provides the characterization of the product obtained. TABLE 3 characteristics of test reaction products according to Example 2. Sulfur Nitrogen RCC Ni + V w % (ppm) Sp.Gr. (w %) (ppm) Naphtha C 5 -170° C. 0.05 300 0.759 — — AGO 170-350° C. 0.51 1950 0.864 — — VGO + DAO 1.45 2200 0.922 2.5 1
  • the parameter k values were calculated in all the possible mixture situations of the two streams: from 0% of the first component and 100% of the second component up to the reverse situation, i.e. 100% of the first component and 0% of the second component.
  • the temperature to which reference was made for determining the properties is 140° C.

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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)
US10/188,785 2001-07-06 2002-07-05 Process for the conversion of heavy charges such as heavy crude oils and distillation residues Abandoned US20030089636A1 (en)

Priority Applications (6)

Application Number Priority Date Filing Date Title
US11/404,746 US20060186021A1 (en) 2001-07-06 2006-04-17 Process for the conversion of heavy charges such as heavy crude oils and distillation residues
US12/248,163 US20090101540A1 (en) 2001-07-06 2008-10-09 Process for the conversion of heavy charges such as heavy crude oils and distillation residues
US12/725,915 US20100300934A1 (en) 2001-07-06 2010-03-17 Process for the conversion of heavy charges such as heavy crude oils and distillation residues
US13/169,950 US20110253594A1 (en) 2001-07-06 2011-06-27 Process for the conversion of heavy charges such as heavy crude oils and distillation residues
US13/532,004 US20120261309A1 (en) 2001-07-06 2012-06-25 Process for the conversion of heavy charges such as heavy crude oils and distillation residues
US14/083,237 US9598652B2 (en) 2001-07-06 2013-11-18 Process for the conversion of heavy charges such as heavy crude oils and distillation residues

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
ITMI2001A001438 2001-07-06
IT2001MI001438A ITMI20011438A1 (it) 2001-07-06 2001-07-06 Procedimento per la conversione di cariche pesanti quali i graggi pesanti e i residui di distillazione

Related Child Applications (1)

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US11/404,746 Continuation US20060186021A1 (en) 2001-07-06 2006-04-17 Process for the conversion of heavy charges such as heavy crude oils and distillation residues

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US20030089636A1 true US20030089636A1 (en) 2003-05-15

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Application Number Title Priority Date Filing Date
US10/188,785 Abandoned US20030089636A1 (en) 2001-07-06 2002-07-05 Process for the conversion of heavy charges such as heavy crude oils and distillation residues
US11/404,746 Abandoned US20060186021A1 (en) 2001-07-06 2006-04-17 Process for the conversion of heavy charges such as heavy crude oils and distillation residues
US12/248,163 Abandoned US20090101540A1 (en) 2001-07-06 2008-10-09 Process for the conversion of heavy charges such as heavy crude oils and distillation residues
US12/725,915 Abandoned US20100300934A1 (en) 2001-07-06 2010-03-17 Process for the conversion of heavy charges such as heavy crude oils and distillation residues
US13/169,950 Abandoned US20110253594A1 (en) 2001-07-06 2011-06-27 Process for the conversion of heavy charges such as heavy crude oils and distillation residues
US13/532,004 Abandoned US20120261309A1 (en) 2001-07-06 2012-06-25 Process for the conversion of heavy charges such as heavy crude oils and distillation residues
US14/083,237 Expired - Lifetime US9598652B2 (en) 2001-07-06 2013-11-18 Process for the conversion of heavy charges such as heavy crude oils and distillation residues

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Application Number Title Priority Date Filing Date
US11/404,746 Abandoned US20060186021A1 (en) 2001-07-06 2006-04-17 Process for the conversion of heavy charges such as heavy crude oils and distillation residues
US12/248,163 Abandoned US20090101540A1 (en) 2001-07-06 2008-10-09 Process for the conversion of heavy charges such as heavy crude oils and distillation residues
US12/725,915 Abandoned US20100300934A1 (en) 2001-07-06 2010-03-17 Process for the conversion of heavy charges such as heavy crude oils and distillation residues
US13/169,950 Abandoned US20110253594A1 (en) 2001-07-06 2011-06-27 Process for the conversion of heavy charges such as heavy crude oils and distillation residues
US13/532,004 Abandoned US20120261309A1 (en) 2001-07-06 2012-06-25 Process for the conversion of heavy charges such as heavy crude oils and distillation residues
US14/083,237 Expired - Lifetime US9598652B2 (en) 2001-07-06 2013-11-18 Process for the conversion of heavy charges such as heavy crude oils and distillation residues

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US (7) US20030089636A1 (it)
CN (1) CN100467575C (it)
CA (1) CA2392669C (it)
DE (1) DE10230403B4 (it)
EG (1) EG23196A (it)
IT (1) ITMI20011438A1 (it)
MX (1) MXPA02006667A (it)
RU (1) RU2298579C9 (it)
SA (1) SA02230247B1 (it)

Cited By (46)

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US20110253594A1 (en) 2011-10-20
CN1398953A (zh) 2003-02-26
CA2392669C (en) 2012-01-03
ITMI20011438A1 (it) 2003-01-06
RU2002117936A (ru) 2004-02-20
US20100300934A1 (en) 2010-12-02
MXPA02006667A (es) 2004-08-19
US20060186021A1 (en) 2006-08-24
US20140197070A1 (en) 2014-07-17
SA02230247B1 (ar) 2006-11-28
EG23196A (en) 2004-07-31
RU2298579C2 (ru) 2007-05-10
US20090101540A1 (en) 2009-04-23
DE10230403A1 (de) 2003-02-06
DE10230403B4 (de) 2007-08-16
ITMI20011438A0 (it) 2001-07-06
RU2298579C9 (ru) 2007-09-27
CN100467575C (zh) 2009-03-11
CA2392669A1 (en) 2003-01-06

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