EP0683218B1 - Verfahren zur Verwandlung von Rückstand Kohlenwasserstofföls - Google Patents

Verfahren zur Verwandlung von Rückstand Kohlenwasserstofföls Download PDF

Info

Publication number
EP0683218B1
EP0683218B1 EP19950201314 EP95201314A EP0683218B1 EP 0683218 B1 EP0683218 B1 EP 0683218B1 EP 19950201314 EP19950201314 EP 19950201314 EP 95201314 A EP95201314 A EP 95201314A EP 0683218 B1 EP0683218 B1 EP 0683218B1
Authority
EP
European Patent Office
Prior art keywords
dao
fraction
hydrocracking
upgraded
deasphalting
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
EP19950201314
Other languages
English (en)
French (fr)
Other versions
EP0683218A3 (de
EP0683218A2 (de
Inventor
Johan Willem Gosselink
Anneke Van Der Heijden
Tom Huizinga
Hennie P/A Shell Int.Petr.Maatsch.B.V. Schaper
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.)
Shell Internationale Research Maatschappij BV
Original Assignee
Shell Internationale Research Maatschappij BV
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 Shell Internationale Research Maatschappij BV filed Critical Shell Internationale Research Maatschappij BV
Priority to EP19950201314 priority Critical patent/EP0683218B1/de
Publication of EP0683218A2 publication Critical patent/EP0683218A2/de
Publication of EP0683218A3 publication Critical patent/EP0683218A3/de
Application granted granted Critical
Publication of EP0683218B1 publication Critical patent/EP0683218B1/de
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
    • 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

Definitions

  • the present invention relates to a process for the conversion of a residual hydrocarbon oil. More specifically, the present invention relates to a process for the conversion of a residual hydrocarbon oil involving the hydrocracking of upgraded deasphalted oil.
  • residual hydrocarbon oils such as those obtained in the distillation of crude oils at atmospheric or reduced pressure, contain considerable amounts of non-distillable compounds having a high molecular weight.
  • specific examples of such compounds are asphaltenes and metal compounds, in particular vanadium and nickel compounds.
  • demetallisation catalysts are known. They usually consist of oxidic carriers such as alumina, silica or silica-alumina, on which one or more metals or metal compounds having hydrogenation activity are optionally deposited. Metals from Groups VIB and VIII of the Periodic Table of Elements are widely known to be suitable for this purpose. Examples of suitable demetallisation catalysts are disclosed in inter alia U.S. Patents Nos.
  • U.S. Patent No. 4,564,439 discloses a two-stage catalytic hydroconversion process, wherein a heavy hydrocarbonaceous feedstock containing more than 100 parts per million by weight (ppmw) of metallic contaminants is first hydrodemetallised and then hydrocracked. Hydrodemetallisation is carried out by mixing the heavy hydrocarbonaceous feedstock, which might be a deasphalted tar or oil, with up to 10% by weight based on feedstock of solid particles which have sufficient catalytic activity to suppress the adverse coke formation and which induce substantial demetallisation. The resulting slurry, suitably in the form of a dispersion, is subsequently introduced into a first-stage hydrothermal zone, wherein hydrogen is introduced as well.
  • ppmw parts per million by weight
  • the reactant mixture is heated and as a result, demetallisation as well as conversion of hydrocarbons having a boiling point above 1000 °F (538 °C) into lower boiling hydrocarbons occurs.
  • the effluent is then, without substantial reduction of pressure, rapidly passed through a cooling zone into a second-stage hydrocatalytic reaction zone, where hydrogenation and cracking occurs.
  • a major disadvantage of the process according to U.S. Patent No. 4,564,439 is the fact that the contaminated solid particles resulting from the first stage of the process are passed into the hydrocatalytic reaction zone together with the demetallised feedstock. This will usually cause a more rapid and highly unwanted decrease of the activity of the hydrocracking catalyst. Moreover, in said U.S. patent a clear preference for heavy hydrocarbonaceous feedstocks containing very high amounts of metallic contaminants is expressed. Since a deasphalting treatment generally causes a substantial amount of the metallic contaminants present in the feed as high-molecular weight complexes to accumulate in the asphaltic bitumen fraction rather than in the deasphalted oil fraction, the metals content of a deasphalted oil is usually lower than 100 ppmw.
  • the present invention relates to a process for the conversion of a residual hydrocarbon oil, preferably a vacuum hydrocarbon oil residue, comprising the following steps:
  • the residual hydrocarbon oil feed and the flashed distillate fraction(s) used in step (c) may originate from different sources and may be supplied as separate feedstocks. It is, however, preferred that said residual hydrocarbon oil and said flashed distillate fraction(s) used in step (c) are both produced in a vacuum distillation step prior to step (a). Accordingly, in a preferred embodiment of the present invention a hydrocarbon oil, suitably an atmospheric residue, is converted via the subsequent steps of:
  • Vacuum distillation can be carried out by any conventional technique known in the art. Suitable techniques then, include high vacuum distillation using steam ejectors and vacuum flash distillation.
  • the deasphalting of the heavy residual fraction obtained from the vacuum distillation may be carried out in any conventional manner.
  • a well known and suitable deasphalting method is solvent deasphalting, wherein the hydrocarbon feed is treated counter-currently with an extracting medium which is usually a light hydrocarbon solvent containing paraffinic compounds.
  • Commonly applied paraffinic compounds include C 3-8 paraffinic hydrocarbons, such as propane, butane, isobutane, pentane, isopentane, hexane or mixtures of two or more of these.
  • C 3 -C 5 paraffinic hydrocarbons most preferably butane, pentane or a mixture thereof, are used as the extracting solvent.
  • the extraction depth increases at increasing number of carbon atoms of the extracting solvent.
  • the higher the extraction depth the larger the amount of hydrocarbons being extracted from the hydrocarbon feed, the smaller and more viscous the asphaltene fraction and the heavier the asphaltenes being present in said asphaltene fraction.
  • a rotating disc contactor or a plate column can be used with the hydrocarbon feed entering at the top and the extracting solvent entering at the bottom.
  • the lighter hydrocarbons which are present in the residual hydrocarbon oil dissolve in the extracting solvent and are withdrawn at the top of the apparatus.
  • the asphaltenes which are insoluble in the extracting solvent are withdrawn at the bottom of the apparatus.
  • deasphalting is carried out at a total extracting solvent to residual hydrocarbon oil ratio of 1.5 to 8 wt/wt, a pressure of from 1 to 50 bar and a temperature of from 160 to 230 °C.
  • Demetallisation of the DAO in accordance with step (b) of the process according to the present invention can be achieved by any well known demetallisation process wherein the hydrocarbon feed to be demetallised is passed at elevated temperature and pressure and in the presence of hydrogen in an upward, downward or radial direction, through one or more vertically disposed reactors containing a fixed or moving bed of demetallisation catalyst particles.
  • Well known demetallisation operations are the bunker flow operation, the fixed bed operation, the fixed bed swing operation and the movable bed operation.
  • suitable demetallisation catalyst usually consist of oxidic carriers such as alumina, silica or silica-alumina, on which one or more Group VIB or Group VIII metals or metal compounds may be deposited.
  • oxidic carriers such as alumina, silica or silica-alumina, on which one or more Group VIB or Group VIII metals or metal compounds may be deposited.
  • Such demetallisation catalysts are commercially available from many catalyst suppliers.
  • Particularly suitable demetallisation catalysts are those having as the active agent one of the combinations nickel/molybdenum (NiMo) or cobalt/molybdenum (CoMo), optionally promoted with phosphorus (P), on an alumina (Al 2 O 3 ) carrier.
  • catalysts are CoMo/Al 2 O 3 , CoMoP/Al 2 O 3 and NiMo/Al 2 O 3 and NiMoP/Al 2 O 3 catalysts. It is well known that the type of catalysts described hereinbefore in practice will also exhibit some upgrading activity in terms of hydrodenitrification and/or hydrodesulphurization, removal of heavy hydrocarbons and conversion of hydrocarbons having a boiling point above 520 °C into lower boiling components. For this reason the DAO leaving the hydrodemetallisation zone is referred to as "upgraded DAO" instead of demetallised DAO.
  • Hydrodemetallisation is usually carried out at a hydrogen partial pressure of 20-250 bar, a temperature of 300-470 °C, preferably 310-440 °C, and a space velocity of 0.1-10 l.l -1 hr -1 , preferably 0.2 to 7 l.l -1 hr -1 .
  • the blending ratio of the upgraded DAO and the flashed distillate fractions is not particularly critical and is mainly determined by factors such as hydrocracking catalyst choice, viscosity specification of the hydrocracking equipment and desired product distribution in the hydrocarbon effluent.
  • the weight ratio flashed distillates to upgraded DAO is in the range of from 10/90 to 90/10, preferably 25/75 to 75/25 and even more preferably 40/60 to 70/30.
  • the hydrocracking performed in step (c) of the process according to the present invention may be conducted in any way known in the art, provided that at least one of the catalysts used in the hydrocracking zone is acidic. Generally, such process is carried out in the presence of hydrogen and a suitable hydrocracking catalyst at elevated temperature and pressure.
  • Hydrocracking catalysts usually consist of one or more metals from nickel, tungsten, cobalt and molybdenum in elemental, oxidic or sulphidic form on a suitable carrier such as alumina, silica, silica-alumina or a zeolite.
  • a suitable carrier such as alumina, silica, silica-alumina or a zeolite.
  • hydrocracking catalysts which can be suitably applied in the process of the present invention.
  • At least one of the catalysts used in the hydrocracking zone must be acidic, i.e. must contain a silica-alumina and/or zeolitic component.
  • the hydrocracking process can be a single- or multiple-staged process.
  • a stacked bed of a hydrodenitrification/first-stage hydrocracking catalyst on top of a conversion catalyst can suitably be used.
  • Particularly suitable hydrodenitrification/first-stage hydrocracking catalysts are NiMo/Al 2 O 3 and CoMo/Al 2 O 3 , optionally promoted with phosphorus and/or fluor.
  • Preferred conversion catalysts are those based on NiW/zeolite or NiW/zeolite/silica-alumina.
  • Common hydrocracking conditions are an operating pressure of 80-250 bar, preferably 100-200 bar, and a temperature of 300-500 °C, preferably 350-475 °C.
  • the hydrodemetallisation of the DAO in step (b) is carried out at a hydrogen partial pressure which is at most 30 bar and suitably less than 20 bar higher than the operating pressure of the hydrocracking in step (c).
  • the hydrogen partial pressure in step (b) is from 0 to about 10 bar higher than the operating pressure in step (c).
  • the operation pressure in the hydrocracking zone is suitably in the range of from 120 to about 200 bar, preferably from 140 to 180 bar.
  • a heavy fraction in the hydrocracking of step (c) can suitably be recycled in order to be subjected to hydrocracking and/or hydrodemetallisation once again.
  • said heavy fraction could also be suitably applied as a feed for a fluidised bed catalytic cracking (FCC) unit or as a feedstock for lubricating oil manufacture.
  • FCC fluidised bed catalytic cracking
  • a combination of these options is possible as well.
  • the asphaltic fraction resulting from the solvent deasphalting treatment in step (a) of the process according to the present invention may be used in several ways. It can for instance be combusted for cogeneration of power and steam. Alternatively, it can be partially combusted for clean fuel gas production, cogeneration of power and steam, hydrogen manufacture or hydrocarbon synthesis. Still another option is application in bitumen, emulsion fuels or solid fuels by means of pelletizing. A preferred option is to subject the asphaltic fraction resulting from the deasphalting treatment in step (a) to partial combustion.
  • Figure 1 depicts a preferred embodiment of the process according to the present invention, wherein the vacuum distillation step has been integrated.
  • Figure 2 depicts a further preferred embodiment of the process according to the present invention.
  • Figure 3 shows how the process according to the present invention can be suitably integrated in a complex hydrocracker refinery line-up.
  • an atmospheric hydrocarbon oil residue (105) is passed into vacuum distillation zone (101), where it is separated in one or more flashed distillate fractions (106) and a vacuum residue fraction (107). At least a part of the flashed distillate fractions (106) is routed to upgraded DAO stream (110).
  • the vacuum residue fraction (107) is deasphalted in deasphalting zone (102), resulting in an asphaltic fraction (109) and a DAO (108) which is subsequently hydrodemetallised in hydrodemetallisation zone (103).
  • the upgraded DAO (110) is blended with at least a part of the flashed distillate fraction(s) (106) and the resulting blendstream is then passed into hydrocracking zone (104), thus producing one or more distillate fractions (111) and optionally a heavy fraction (112).
  • Figure 2 is in fact an extension of Figure 1 in three aspects. Firstly, in that at least a part of the heavy fraction (212) produced in hydrocracking zone (204) is recirculated by routing it to upgraded DAO (210) and blending it therewith prior to being led into hydrocracking zone (204). Secondly, part of the heavy fraction (212) routed to upgraded DAO (210) is routed to DAO (208) and blended therewith in order to be subjected to hydrodemetallisation in hydrodemetallisation zone (203) once again. This option is indicated by a dotted line in figure 2. The third aspect, finally, is also indicated with a dotted line and embodies the option of routing part of the flashed distillate fractions (206) to DAO (208) and blending it therewith. The other reference numbers used in Figure 2 correspond with those used in Figure 1 having the same last two numbers.
  • Figure 3 shows the line-up of a hydrocracker refinery.
  • a crude oil (307) is passed into atmospheric distillation zone (301), where a first separation into one or more distillate fractions (308) and a residual fraction or "long residue” (309).
  • This long residue (309) is further separated in vacuum distillation zone (302) into one or more flashed distillate fractions (310), at least part of which is blended with upgraded DAO (317), and a vacuum residue fraction or "short residue” (311), which is deasphalted in deasphalting zone (303).
  • a part of the flashed distillate fractions (310) is blended with DAO (312).
  • the DAO (312) is passed into hydrodemetallisation zone (304) and the upgraded DAO is led into hydrocracking zone (305).
  • the asphaltic fraction (313) resulting from the deasphalting treatment is passed into gasification zone (306) where it is partially oxidised using oxygen, supplied via stream (314), eventually producing clean fuel gas (315) and hydrogen (316).
  • This hydrogen can for instance be passed into hydrodemetallisation zone (304) and/or hydrocracking zone (305) in order to increase the overall process efficiency.
  • Hydrocracking in hydrocracking zone (305) results in one or more distillate fractions (318) and a heavy fraction (319), which is at least partially recirculated into hydrocracking zone (305) via blending with upgraded DAO (317).
  • a part of the heavy fraction (319) is blended with DAO (312).
  • the invention is further illustrated by the following example.
  • a crude oil feed was subjected to conventional crude distillation; the long residue produced was subjected to conventional vacuum flashing, producing a flashed distillate (FD) and short residue (SR).
  • the SR was subsequently subjected to solvent deasphalting using butane as extracting solvent to produce a DAO at a yield of 70% by weight based on SR.
  • the DAO and FD were coprocessed in an integrated hydro-demetallization/hydrocracking (HDM/HCU) pilot plant for about 5000 hours.
  • the DAO was upgraded in the HDM reactor over a conventional NiMoP/alumina catalyst.
  • Upgraded DAO and FD were subsequently coprocessed in the HCU reactor over a catalyst system including an acidic catalyst, producing hydrowax, gasoil, kerosene, naphtha and gaseous products. Both HDM and HCU reactors were operated at the same pressure.

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)

Claims (8)

  1. Verfahren zur Umwandlung eines Kohlenwasserstoffrückstandsöls, vorzugsweise eines Vakuum-Kohlenwasserstoffrückstandsöls, das die folgenden Stufen umfaßt:
    (a) Entasphaltieren des Kohlenwasserstoffrückstandsöls, unter Ausbildung einer Asphaltfraktion und eines entasphaltierten Öls (DAO);
    (b) Führen des DAO durch ein Bett aus einem Hydroentmetallisierungskatalysator in Gegenwart von Wasserstoff unter Entmetallisierungsbedingungen, unter Ausbildung eines aufgebesserten DAO; und unmittelbar anschließend
    (c) Vermischen des aufgebesserten DAO mit einer oder mit mehreren Flashdestillatfraktionen und Ausführen einer Hydrocrackbehandlung an dem resultierenden Gemischstrom in Gegenwart eines sauren Katalysators, unter Ausbildung einer oder mehrerer Destillatfraktionen.
  2. Verfahren nach Anspruch 1, worin das Kohlenwasserstoffrückstandsöl und die in Stufe (c) verwendete(n) Flashdestillatfraktion(en) in einer Vakuumdestillationsstufe (a') vor der Stufe (a) gebildet werden.
  3. Verfahren nach Anspruch 1 oder 2, worin das Entasphaltieren in Stufe (a) durch eine Lösungsmittelentasphaltierungsbehandlung vorgenommen wird, wobei als Extraktionslösungsmittel ein oder mehrere C3-C5 Paraffinkohlenwasserstoffe, vorzugsweise Butan, Pentan oder ein Gemisch hievon, verwendet werden.
  4. Verfahren nach einem der vorstehenden Ansprüche, worin die Stufe (b) bei einem Wasserstoffpartialdruck ausgeführt wird, der höchstens 30 bar und vorzugsweise weniger als 20 bar über dem Betriebsdruck des Hydrocrackens in Stufe (c) liegt.
  5. Verfahren nach Anspruch 4, worin der Wasserstoffpartialdruck in Stufe (b) im Bereich von 150 bis 200 bar liegt.
  6. Verfahren nach einem der vorstehenden Ansprüche, worin in Stufe (c) auch eine schwere Fraktion gebildet wird, von der wenigstens ein Teil wiederum dem Hydrocracken unterworfen wird.
  7. Verfahren nach einem der vorstehenden Ansprüche, worin die aus der Entasphaltierungsbehandlung in Stufe (a) resultierende Asphaltfraktion einer partiellen Verbrennung unterworfen wird.
  8. Hydrocrackerraffinerie, in die ein Verfahren zur Umwandlung eines Rückstandsöls nach einem der Ansprüche 1 bis 7 einbezogen worden ist, die umfaßt: eine Vakuumdestillationszone (101), die zur Aufnahme eines Kohlenwasserstoffrückstandsöls (105) und zu dessen Auftrennung in eine oder mehrere Flashdestillatfraktionen (106) und in eine Vakuumrückstandsfraktion (107) befähigt ist, eine Entasphaltierungszone (102), die zum Entasphaltieren der Vakuumrückstandsfraktion (107) und zur Ausbildung einer Asphaltfraktion (109) und eines DAO (108) befähigt ist, eine Hydroentmetallisierungszone (103), die zum Entmetallisieren des DAO (108) und zur Ausbildung eines aufgebesserten DAO (110) befähigt ist und die direkt mit einem Mischpunkt verbunden ist, der zur Aufnahme wenigstens eines Teiles der Flashdestillatfraktionen (106) aus der Vakuumdestillationszone (101) und des aufgebesserten DAO (110) befähigt ist, und eine Hydrocrackzone (104), die zum Hydrocracken des Gemisches aus wenigstens einem Teil der Flashdestillatfraktionen (106) und dem aufgebesserten DAO (110) und zum Ausbilden einer oder mehrerer Destillatfraktionen (111) und gewünschtenfalls einer schweren Fraktion (112) befähigt ist.
EP19950201314 1994-05-19 1995-05-18 Verfahren zur Verwandlung von Rückstand Kohlenwasserstofföls Expired - Lifetime EP0683218B1 (de)

Priority Applications (1)

Application Number Priority Date Filing Date Title
EP19950201314 EP0683218B1 (de) 1994-05-19 1995-05-18 Verfahren zur Verwandlung von Rückstand Kohlenwasserstofföls

Applications Claiming Priority (3)

Application Number Priority Date Filing Date Title
EP94201423 1994-05-19
EP94201423 1994-05-19
EP19950201314 EP0683218B1 (de) 1994-05-19 1995-05-18 Verfahren zur Verwandlung von Rückstand Kohlenwasserstofföls

Publications (3)

Publication Number Publication Date
EP0683218A2 EP0683218A2 (de) 1995-11-22
EP0683218A3 EP0683218A3 (de) 1996-03-20
EP0683218B1 true EP0683218B1 (de) 2001-04-11

Family

ID=26136276

Family Applications (1)

Application Number Title Priority Date Filing Date
EP19950201314 Expired - Lifetime EP0683218B1 (de) 1994-05-19 1995-05-18 Verfahren zur Verwandlung von Rückstand Kohlenwasserstofföls

Country Status (1)

Country Link
EP (1) EP0683218B1 (de)

Cited By (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN103059998A (zh) * 2011-10-21 2013-04-24 中国石油化工股份有限公司 一种处理渣油的组合工艺方法
US8960651B2 (en) 2008-12-04 2015-02-24 Shell Oil Company Vessel for cooling syngas
US9051522B2 (en) 2006-12-01 2015-06-09 Shell Oil Company Gasification reactor

Families Citing this family (11)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CO5040119A1 (es) * 1997-09-11 2001-05-29 Atlantic Richfield Co Metodo para convertir un crudo de petroleo pesado producido via un sondeo de un yacimiento subterraneo en una corriente de producto de destilado usando un procedimiento de desasfaltado con disolvente
DE69920489T2 (de) * 1998-07-29 2005-12-01 Texaco Development Corp. Integriertes lösungsmittelentasphaltierungs- und vergasungsverfahren
EP1731588A1 (de) * 2005-06-08 2006-12-13 Shell Internationale Researchmaatschappij B.V. Verfahren zur verberrerung von rohöl
US20080190026A1 (en) * 2006-12-01 2008-08-14 De Jong Johannes Cornelis Process to prepare a mixture of hydrogen and carbon monoxide from a liquid hydrocarbon feedstock containing a certain amount of ash
US8052864B2 (en) 2006-12-01 2011-11-08 Shell Oil Company Process to prepare a sweet crude
US8475546B2 (en) 2008-12-04 2013-07-02 Shell Oil Company Reactor for preparing syngas
CN101633848B (zh) * 2009-08-31 2012-11-21 中煤能源黑龙江煤化工有限公司 一种中低温煤焦油深加工方法
CN102453545B (zh) * 2010-10-15 2013-11-06 中国石油化工股份有限公司 一种渣油轻质化的方法
CN102453541B (zh) * 2010-10-15 2013-11-20 中国石油化工股份有限公司 一种处理渣油的联合加工方法
CN103540358B (zh) * 2012-07-12 2016-05-11 中国石油天然气股份有限公司 渣油转化-芳烃抽提组合工艺
US10703998B2 (en) * 2018-10-22 2020-07-07 Saudi Arabian Oil Company Catalytic demetallization and gas phase oxidative desulfurization of residual oil

Family Cites Families (13)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
FR1423627A (fr) * 1963-04-11 1966-01-07 Inst Francais Du Petrole Procédé de conversion d'hydrocarbures lourds
NL159135B (nl) * 1967-12-27 1979-01-15 Shell Int Research Werkwijze voor de bereiding van lager kokende koolwaterstoffen of fracties, die deze bevatten, uit residuale olien door deze te ontasfalteren en de ontasfalteerde olie te hydrokraken in aanwezigheid van waterstof, die is verkregen door partiele verbranding van de bij de ontasfaltering afgescheiden asfaltenen.
NL175732C (nl) 1972-07-07 Shell Int Research Werkwijze voor het katalytisch demetalliseren van residuale koolwaterstofolien en het verder katalytisch omzetten van de hierbij verkregen olie.
US3891541A (en) 1973-08-29 1975-06-24 Mobil Oil Corp Process for demetalizing and desulfurizing residual oil with hydrogen and alumina-supported catalyst
US3876523A (en) 1973-08-29 1975-04-08 Mobil Oil Corp Catalyst for residua demetalation and desulfurization
NL7412337A (nl) 1974-09-18 1976-03-22 Shell Int Research Werkwijze voor de bereiding van nieuwe kata- lysatoren.
GB1550684A (en) 1975-08-28 1979-08-15 Mobil Oil Corp Demetalation-desulphurisation catalyst and the preparation and use thereof
NL7510465A (nl) 1975-09-05 1977-03-08 Shell Int Research Werkwijze voor het omzetten van koolwaterstoffen.
NL187026C (nl) 1976-07-08 1991-05-01 Shell Int Research Werkwijze voor het ontmetalliseren van koolwaterstofolien.
NL7607551A (nl) 1976-07-08 1978-01-10 Shell Int Research Werkwijze voor het ontmetalliseren van koolwater- stofolien.
US4177163A (en) 1978-03-08 1979-12-04 Mobil Oil Corporation Supported catalyst for demetalation and desulfurization of hydrocarbon oils
US4165274A (en) * 1978-06-13 1979-08-21 Shell Oil Company Process for the preparation of synthetic crude oil
US4564439A (en) 1984-06-29 1986-01-14 Chevron Research Company Two-stage, close-coupled thermal catalytic hydroconversion process

Cited By (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US9051522B2 (en) 2006-12-01 2015-06-09 Shell Oil Company Gasification reactor
US8960651B2 (en) 2008-12-04 2015-02-24 Shell Oil Company Vessel for cooling syngas
CN103059998A (zh) * 2011-10-21 2013-04-24 中国石油化工股份有限公司 一种处理渣油的组合工艺方法
CN103059998B (zh) * 2011-10-21 2014-08-20 中国石油化工股份有限公司 一种处理渣油的组合工艺方法

Also Published As

Publication number Publication date
EP0683218A3 (de) 1996-03-20
EP0683218A2 (de) 1995-11-22

Similar Documents

Publication Publication Date Title
US8123932B2 (en) Process for the conversion of heavy feedstocks such as heavy crude oils and distillation residues
KR101829113B1 (ko) 잔사유 수소첨가분해 및 용매 탈아스팔트화의 통합
RU2360944C2 (ru) Комплексный способ конверсии содержащего уголь сырья в жидкие продукты
RU2352616C2 (ru) Способ переработки тяжелого сырья, такого как тяжелая сырая нефть и кубовые остатки
EP0434799B1 (de) Hydrobehandlung von restöl mittels lösungsmittel-extrahierten und desalsphaltierten harzen
US7691256B2 (en) Process for the conversion of heavy charges such as heavy crude oils and distillation residues
KR101831039B1 (ko) 잔사유 수소첨가분해 및 수소첨가처리의 통합
KR101716989B1 (ko) 잔유물의 하이드로크랙킹
US20090127161A1 (en) Process and Apparatus for Integrated Heavy Oil Upgrading
CA2897212C (en) Residue hydrocracking processing
EP0683218B1 (de) Verfahren zur Verwandlung von Rückstand Kohlenwasserstofföls
WO2013019687A1 (en) Integration of solvent deasphalting with resin hydroprocessing
EP0697455B1 (de) Verfahren zur Herstellung eines Hydrowachs
EP1731588A1 (de) Verfahren zur verberrerung von rohöl
WO2015097199A1 (en) Process for producing middle distillates
CA2149595C (en) Process for the conversion of a residual hydrocarbon oil
CA2154313C (en) Process for producing a hydrowax
AU2011346959B2 (en) Method for converting hydrocarbon feedstock comprising a shale oil by decontamination, hydroconversion in an ebullating bed, and fractionation by atmospheric distillation
CN110776953B (zh) 包括固定床加氢处理、两次脱沥青操作和沥青的加氢裂化的用于处理重质烃原料的方法
CN109988624B (zh) 一种渣油加氢处理与加氢精制组合工艺
WO2023227639A1 (en) Process for producing middle distillates

Legal Events

Date Code Title Description
PUAI Public reference made under article 153(3) epc to a published international application that has entered the european phase

Free format text: ORIGINAL CODE: 0009012

AK Designated contracting states

Kind code of ref document: A2

Designated state(s): DE FR GB IT NL

PUAL Search report despatched

Free format text: ORIGINAL CODE: 0009013

AK Designated contracting states

Kind code of ref document: A3

Designated state(s): DE FR GB IT NL

17P Request for examination filed

Effective date: 19960712

17Q First examination report despatched

Effective date: 19980629

GRAG Despatch of communication of intention to grant

Free format text: ORIGINAL CODE: EPIDOS AGRA

GRAG Despatch of communication of intention to grant

Free format text: ORIGINAL CODE: EPIDOS AGRA

GRAH Despatch of communication of intention to grant a patent

Free format text: ORIGINAL CODE: EPIDOS IGRA

GRAH Despatch of communication of intention to grant a patent

Free format text: ORIGINAL CODE: EPIDOS IGRA

GRAA (expected) grant

Free format text: ORIGINAL CODE: 0009210

AK Designated contracting states

Kind code of ref document: B1

Designated state(s): DE FR GB IT NL

ITF It: translation for a ep patent filed
REF Corresponds to:

Ref document number: 69520616

Country of ref document: DE

Date of ref document: 20010517

ET Fr: translation filed
REG Reference to a national code

Ref country code: GB

Ref legal event code: IF02

PLBE No opposition filed within time limit

Free format text: ORIGINAL CODE: 0009261

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: NO OPPOSITION FILED WITHIN TIME LIMIT

26N No opposition filed
PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: IT

Payment date: 20080421

Year of fee payment: 14

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: FR

Payment date: 20080331

Year of fee payment: 14

REG Reference to a national code

Ref country code: FR

Ref legal event code: ST

Effective date: 20100129

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: FR

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20090602

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: IT

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20090518

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: NL

Payment date: 20110517

Year of fee payment: 17

Ref country code: GB

Payment date: 20110415

Year of fee payment: 17

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: DE

Payment date: 20110519

Year of fee payment: 17

REG Reference to a national code

Ref country code: NL

Ref legal event code: V1

Effective date: 20121201

GBPC Gb: european patent ceased through non-payment of renewal fee

Effective date: 20120518

REG Reference to a national code

Ref country code: DE

Ref legal event code: R119

Ref document number: 69520616

Country of ref document: DE

Effective date: 20121201

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: NL

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20121201

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: GB

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20120518

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: DE

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20121201