EP0400743B1 - Conversion d'huile lourde - Google Patents

Conversion d'huile lourde Download PDF

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Publication number
EP0400743B1
EP0400743B1 EP90201336A EP90201336A EP0400743B1 EP 0400743 B1 EP0400743 B1 EP 0400743B1 EP 90201336 A EP90201336 A EP 90201336A EP 90201336 A EP90201336 A EP 90201336A EP 0400743 B1 EP0400743 B1 EP 0400743B1
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EP
European Patent Office
Prior art keywords
catalyst
process according
hydrogen
coke
bar
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
EP90201336A
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German (de)
English (en)
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EP0400743A1 (fr
Inventor
Eduard Philip Kieffer
Dirk Bode
Diederik Visser
Gerrit Bargeman
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Shell Internationale Research Maatschappij BV
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Shell Internationale Research Maatschappij BV
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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
    • C10G47/00—Cracking of hydrocarbon oils, in the presence of hydrogen or hydrogen- generating compounds, to obtain lower boiling fractions

Definitions

  • the present invention relates to a process for the conversion of a heavy hydrocarbon oil by contacting the hydrocarbon oil with a hydrogen containing gaseous stream and a catalyst at elevated temperature and moderate pressure.
  • oil refining heavy hydrocarbon oils or residues are usually processed in either carbon-rejection type processes such as thermal cracking and fluidized catalytic cracking or hydrogen-addition type processes such as hydrocracking.
  • Thermal cracking of residual material is usually performed at a relatively low or moderate pressure (usually 5 to 30 bar) and at a relatively high temperature (420-520 °C) without catalysts and in the absence of hydrogen.
  • the thermal cracking reactions take place in a cracking furnace, which is usually followed by a soaker vessel, in which the cracking reactions continue further.
  • the middle distillates obtained from thermal cracking of high boiling residues are of good quality as far as the ignition properties are concerned.
  • the high content of olefins and heteroatoms especially sulphur and nitrogen), however, make a hydrofinishing treatment necessary for many applications.
  • thermal cracking An intrinsic problem of thermal cracking, however, is the occurrence of condensation reactions which lead to the forming of poly-aromatics.
  • the cracked residue from thermal cracking therefore, is as such of a moderate quality (high viscosity and high carbon residue after evaporation and pyrolysis, expressed for instance by its Conradson Carbon Residue (CCR) content).
  • CCR Conradson Carbon Residue
  • the cracking severity in the thermal cracking unit is normally controlled in such a way, however, that a residue is obtained of sufficient quality to be blended to commercial fuels or bitumen.
  • Fluidized catalytic cracking is usually performed at a relatively low pressure (1.5 to 3 bar), and at relatively high temperatures (480-600 °C) in the presence of an acid catalyst (for instance zeolite containing catalysts).
  • the reaction is carried out in the absence of hydrogen and the residence time of the feed is very short (0.1-10 seconds).
  • a rather large amount of carbonaceous materials hereinafter to be referred to as coke, is deposited onto the catalyst (on average 3 to 8 %wt of the feed). Continuous regeneration of the catalyst by burning-off coke is therefore necessary.
  • the products obtained in this process contain relatively large quantities of olefins, iso-paraffins and aromatics boiling in the gasoline range. Further, light cycle oils boiling in the kerosene range and some heavy cycle oils boiling in the gas oil range and above are obtained, both of a moderate to low quality for use as kerosene and gas oil.
  • Hydrocracking is usually performed at a relatively high hydrogen partial pressure (usually 100-140 bar) and a relatively low temperature (usually 300 to 400 °C ).
  • the catalyst used in this reaction has a dual function: acid catalyzed cracking of the hydrocarbon molecules and activation of hydrogen and hydrogenation.
  • a long reaction time is used (usually 0.3 to 2 l/l/h liquid hourly space velocity). Due to the high hydrogen pressure only small amounts of coke are deposited on the catalyst which makes it possible to use the catalyst for 0.5 to 2 years in a fixed bed operation without regeneration.
  • the product slates obtained in this process are dependent on the mode of operation. In one mode of operation, predominantly naphtha and lighter products are obtained.
  • the naphtha fraction contains paraffins with a high iso/normal ratio, making it a valuable gasoline blending component.
  • kerosene and gas oil are mainly obtained.
  • the quality of these products is rather moderate, due to the presence of remaining aromatics together with an undesired high iso/normal ratio of the paraffins among others.
  • Object of the present invention is to provide a catalytic process wherein the production of liquid hydrocarbons together with substantial amounts of coke can be controlled and optimized. Moreover it would be highly advantageous when part or all of the coke produced could be converted into energy or hydrogen containing streams for further use in e.g. refineries.
  • a process has now been found which is especially suitable for the catalytic conversion of heavy hydrocarbon oils into valuable middle distillates of good quality.
  • the process combines the favourable aspects of carbon-rejection and hydrogen-addition in one process step.
  • the process is carried out at a relatively high temperature and under a moderate hydrogen pressure in the presence of a catalyst. Formation of coke is suitably controlled, whilst a large amount of heavy material is converted into lighter products and moreover upgraded distillates are also obtained.
  • the present invention thus relates to a process for the conversion of a heavy hydrocarbon oil comprising contacting a hydrocarbon oil which comprises at least 35 %wt of material boiling above 520 °C with a hydrogen containing gaseous stream and a catalyst at a temperature of 450-850 °C and a hydrogen partial pressure of 10-80 bar, whereby coke-bearing catalyst is withdrawn continuously from the reactor and replaced at least partially by regenerated catalyst in which process the catalyst has a residence time of below 2.0 hours and the coke make expressed as Conradson Carbon content of the feedstock varies between 0.4 and 1.0 weight/weight.
  • a method for upgrading crude petroleum oil by employing a moving bed of catalyst is disclosed in GB-A-831 247.
  • petroleum residual oils, hydrogen and catalyst particles are contacted to form a suspension in a riser reactor thereby producing lower boiling components.
  • US-A-3 183 180 is directed to the catalytic hydrogenation of heavy hydrocarbon oils in an ebullated bed.
  • Dynacracking Process described for example in Hydrocarbon Processing, May 1981 pp. 86-92, which is in essence a thermal hydroconversion process carried out in a moving particles system.
  • the feed is thermally hydrocracked in the upper part of the system in the presence of synthesis gas producing substantial amounts of coke which are deposited on inert carrier material.
  • coke on the inert material is gasified to synthesis gas with steam and oxygen.
  • ART Asphalt Residue Treating
  • a further process is the Fluid Thermal Cracking (FTC) process which is, for instance, described in United States patent specification No. 4,668,378.
  • the process is carried out in a fluidized system in which residual feedstock is contacted with fine porous catalytically inactive particles, which particles are fluidised by steam or a hydrogen-containing gas at a rather low (hydrogen) partial pressure.
  • the molecular weight reduction in the present process is essentially determined by catalytically induced control of coke make and liquid hydrocarbon production. Due to the presence of hydrogen at a pressure which may vary between 10 and 80 bar the coke make expressed as Conradson Carbon Content of the feedstock varies respectively between 0.4 and 1.0 weight/weight.
  • the activated hydrogen apparently participates in the radical reaction mechanisms and contributes to the saturation of the larger hydrocarbyl radicals resulting in less condensed aromatic structures and finally a lower coke make.
  • the middle distillates obtained in the present process are of good quality due to the high amount of n-paraffins and the low amount of olefins although they may contain a certain amount of aromatic compounds.
  • the hydrogen consumption of the process is relatively low compared to pure hydrogen-addition processes, as the aromatic components are not substantially hydrogenated.
  • a further advantage resides in the fact that the sulphur present in the feed can be converted for a substantial part into hydrogen sulphide, thus resulting in a product containing a relatively small amount of sulphur.
  • a large part of the metals and nitrogen components present in the feed are deposited in the coke on the catalyst leaving a high quality distillate with a low metal(s) and nitrogen content, which makes it very suitable for product blending or as a feedstock for further upgrading in, for instance, catalytic cracking or hydrocracking units.
  • the present process does not entirely depend on the presence of acidic sites on the catalyst.
  • the residual feeds which normally contain substantial amounts of basic nitrogen and/or sulphur containing compounds can be processed without difficulties. Due to the presence of activated hydrogen less coke is deposited on the catalyst, than would be deposited on the catalyst in case the same feedstock would be processed in a fluidized catalytic cracking process, which implies that the present process can handle considerable heavier feeds than the heaviest feeds which can be processed in catalytic cracking of residual feedstocks.
  • the present process is relatively insensitive to feedstock impurities, especially nitrogen and Conradson Carbon Residue, which are detrimental in hydrocracking processes.
  • the present process has the important advantage that a considerable desulphurization and hydrogenation takes place in the presence of a hydrogen activating catalyst at relatively elevated hydrogen partial pressures. This results both in a higher middle distillate yield of a higher quality and a lower and controllable coke production on feed.
  • Feedstocks which can suitably be applied in the present process comprise heavy hydrocarbon oils which contain at least 35 %wt of material boiling above 520 °C, and usually more than 15 %wt of material boiling above 620 °C.
  • Atmospheric or vacuum distillates, catalytically cracked cycle oils and slurry oils, deasphalted oils, atmospheric and vacuum residues, thermally cracked residues, asphalts originating from various kinds of deasphalting processes, synthetic residues and hydrocarbon oils originating from tar sands and shale oils of any source can suitably converted as such or in mixtures in the process according to the present invention, provided that the feedstocks comprise at least 35 %wt of material boiling above 520 °C.
  • feedstocks which comprise at least 50 %wt of material boiling above 520 °C, in particular feedstocks comprising at least 90 %wt of material boiling above 520 °C.
  • Feedstocks comprising more than 3 %wt of asphaltenic constituents, in particular more than 10 %wt, can suitably be processed.
  • C7-asphaltenes are meant, i.e. the asphaltenic fraction removed from the oil fraction by precipitation with heptane.
  • Feedstocks containing substantial amounts of sulphur and nitrogen can suitably be applied in the process according to the present invention. Good results have been obtained using feedstocks containing no less than 4000 ppmw nitrogen and 5 %wt of sulphur.
  • the process according to the present invention is suitably carried out at a reaction temperature of 450-850 °C and a hydrogen partial pressure of 10-80 bar.
  • the process according to the present invention can suitably be carried out in various types of moving bed reactors: a wet fluidized bed reactor, a slurry-type reactor and a riser-type of reactor.
  • Each type of moving bed reactor has its specific preferred reaction conditions.
  • a suitable reaction temperature is 450-650 °C, preferably 470-600 °C.
  • the hydrogen partial pressure is then suitably chosen between 10-80 bar, preferably between 12-50 bar, more preferably between 15-40 bar.
  • the catalyst/oil ratio can suitably be chosen between 1-20 weight/weight, preferably between 2-12 weight/weight, more preferably between 2-8 weight/weight.
  • the catalyst residence time in the wet fluidized bed reactor is chosen between 0.2-2.5 minutes, preferably between 0.4-2.0 minutes.
  • a hydrogen containing gaseous stream is supplied to the wet fluidized bed reactor to provide the hydrogen required for the desired reactions and to maintain a good fluidization, this is suitably achieved at a superficial gas velocity between 0.01-3.50 m/s.
  • the feed may be pretreated in a mixing zone to produce a slurry of feed and hot catalyst particles which can suitably be introduced into the hydroconversion zone at a temperature of 450-600 °C, preferably 470-550 °C.
  • the hydrogen partial is then suitably chosen between 10-80 bar, preferably between 12-50 bar, most preferably between 15-40 bar.
  • the catalyst/oil ratio in the slurry-type reactor is suitably chosen between 0.01-2.0 weight/weight.
  • the catalyst residence time in the slurry-type reactor is suitably chosen between 0.3-2.0 hours.
  • the slurry of feed and catalyst is introduced into the reactor at a space velocity of 0.1-10.0 l/l/hr, preferably between 0.25-5.0 l/l/hr.
  • the hydrogen containing gaseous stream can suitably be supplied to the slurry-type reactor at a superficial gas velocity of between 0.05-4.0 m/s to supply the hydrogen required for the desired process reactions and to provide a sufficient high superficial gas velocity to ensure catalyst particulate fluidization.
  • a "slurry reactor" in this description also includes a three phase fluid bed reactor.
  • the reaction temperature is suitably between 450-850 °C, preferably between 500-750 °C.
  • the hydrogen partial pressure is suitably chosen between 10-80 bar, preferably between 12-50 bar, most preferably between 15-40 bar.
  • the catalyst/oil ratio is suitably chosen between 1-20 weight/weight, preferably between 2-12 weight/weight, most preferably between 2-8 weight/weight.
  • the catalyst residence time in the riser reactor is below 2 minutes, preferably between 0.1-10.0 seconds.
  • the hydrogen containing gaseous stream is suitably supplied to the riser reactor at a superficial gas velocity of 0.6-3.5 m/s to provide the hydrogen required for the desired process reactions and to maintain a good fluidization and aeration.
  • the catalysts to be used in the process according to the present invention should contain a hydrogen activating function.
  • the catalysts may also contain a moderate acidic function.
  • Suitable catalysts comprise one or more components of a Group IVa, VIb or VIII metal. Good results have been obtained using Ni, V, Mo, Co and/or mixtures thereof.
  • the metal component(s) can be incorporated into various support materials. Suitable support materials comprise silica, alumina, alumina-silica, aluminophosphates, zeolitic compounds, spinel compounds, titania, zirconia and/or mixtures thereof.
  • the hydrogen containing gaseous stream used in the process according to the present invention suitably comprises molecular hydrogen.
  • Hydrogen containing refinery streams can be applied. They may also contain lower hydrocarbons, steam and/or mixtures thereof. If desired, synthesis gas can also be used as hydrogen source.
  • Catalyst regeneration can suitably be carried out by burning off or gasifying the coke deposited on the catalyst using an oxygen and/or steam containing gas.
  • the synthesis gas obtained in the gasification of the coke can suitably be used as a refinery fuel gas or as a hydrogen source for hydroprocesses in the refinery, or as a feedstock for hydrocarbon synthesis processes.
  • the regeneration process can be suitably carried out by supplying the heat required for gasification via hot particles which preferably have a larger diameter and a higher density than the catalyst particles to be regenerated.
  • the use of relatively large particles e.g. 3-20 times the diameter of the catalyst particles) allows easy separation by fluidization and/or centrifugation in a cyclone.
  • the hot particles which provide the external heat for the regeneration procedure are suitably brought to the desired temperature by heating in a combustive atmosphere (e.g. in an air/fuel gas sytem).
  • At least 90% of the coke-bearing catalyst being withdrawn is replaced by regenerated catalyst.
  • Suitable sulphidation procedures comprise heating the catalyst together with a sulphur-containing feedstock and hydrogen at appropriate conditions or the use of H2S and hydrogen.
  • the reactions were carried out at 459-525 °C and a hydrogen partial pressure of 5-50 bar.
  • the feedstock and the liquid product were analyzed for the boiling point distribution using a TBP-GLC method up to 620 °C. Moreover GLC analysis of the off-gas was carried out. On the basis of these analyses conversions and product yields were calculated.
  • the 520 °C+ conversion has been defined as the amount of 520 °C+ material present in the feedstock minus the amount of 520 °C+ material present in the total liquid product, divided by the amount of 520 °C+ material present in the feedstock.
  • the product slate was split up into gas (C1-C4), the total liquid product (C5+) and the coke deposited on the catalyst. The respective fractions have been calculated as the amount of product in question, divided by the total amount of products.

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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)

Claims (13)

  1. Procédé pour la conversion d'une huile d'hydrocarbures lourds, procédé selon lequel on met en contact une huile d'hydrocarbures qui renferme au moins 35% en poids de produit bouillant au-dessus de 520°C avec un courant gazeux renfermant de l'hydrogène et un catalyseur à une température de 450-850°C sous une pression partielle d'hydrogène de 10 à 80 bars, le catalyseur sur lequel se dépose du coke étant prélevé en continu du réacteur et remplacé au moins partiellement par du catalyseur regénéré, procédé dans lequel le catalyseur a un temps de séjour inférieur à 2,0 heures et la production de coke exprimée en tant que la teneur en carbone Conradson de la charge brute varie entre 0,4 et 1,0 poids/poids.
  2. Procédé selon la revendication 1, dans lequel l'huile d'hydrocarbures lourds présente une teneur en constituants asphalténiques d'au moin 3% en poids, de préférence d'au moins 10% en poids.
  3. Procédé selon la revendication 1 ou 2, dans lequel l'huile d'hydrocarbures lourds comporte au moins 50% en poids d'un matériau bouillant au-dessus de 520°C, de préférence au moins 90% en poids du matériau bouillant au-dessus de 520°C.
  4. Procédé selon l'une quelconque des revendications 1 à 3, dans lequel la réaction est mise en oeuvre dans un réacteur à lit fluidisé humide à une température de 450 à 650°C, et dans lequel le catalyseur a un temps de séjour compris entre 0,2 et 2,5 minutes.
  5. Procédé selon l'une quelconque des revendications 1 à 3, dans lequel la réaction est mise en oeuvre dans un réacteur du type à suspension à une température de 450 à 600°C, et dans lequel le catalyseur a un temps de séjour compris entre 0,3 et 2,0 heures.
  6. Procédé selon l'une quelconque des revendications 1 à 3, dans lequel la réaction est mise en oeuvre dans un réacteur ascendant à une température de 450 à 850°C, et dans lequel le catalyseur a un temps de séjour inférieur à 2 minutes.
  7. Procédé selon l'une quelconque des revendications 1 à 6, dans lequel la pression partielle d'hydrogène se situe entre 12 et 50 bars, de préférence entre 15 et 40 bars.
  8. Procédé selon l'une quelconque des revendications 1 à 7, dans lequel le catalyseur comporte un ou plus d'un composant d'un métal des groupes IVa, VIb ou VIII, en particulier Ni, V, Mo, Co et/ou des mélanges de ceux-ci.
  9. Procédé selon l'une quelconque des revendications 1 à 8, dans lequel le catalyseur comprend de la silice, de l'alumine, de l'alumine-silice, des composés zéolitiques, des composés du type spinelle, des aluminophosphates, du dioxyde de titane, de la zircone et/ou des mélanges de ceux-ci.
  10. Procédé selon la revendication 8 ou 9, dans lequel les composants métalliques sont sous leur forme sulfurée.
  11. Procédé selon l'une quelconque des revendications 1 à 10, dans lequel le courant gazeux renfermant de l'hydrogène comprend de l'hydrogène moléculaire, du gaz de synthèse, ou un courant de raffinage comportant des hydrocarbures inférieurs, de la vapeur et/ou des mélanges de ceux-ci.
  12. Procédé selon l'une quelconque des revendications 1 à 11, dans lequel le catalyseur est régénéré par combustion ou gazéification du coke déposé sur le catalyseur.
  13. Procédé selon l'une quelconque des revendications 1 à 12, dans lequel au moins 90% du catalyseur portant du coke est remplacé par du catalyseur régénéré.
EP90201336A 1989-06-02 1990-05-23 Conversion d'huile lourde Expired - Lifetime EP0400743B1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
GB8912698 1989-06-02
GB898912698A GB8912698D0 (en) 1989-06-02 1989-06-02 Heavy oil conversion process

Publications (2)

Publication Number Publication Date
EP0400743A1 EP0400743A1 (fr) 1990-12-05
EP0400743B1 true EP0400743B1 (fr) 1994-08-03

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EP90201336A Expired - Lifetime EP0400743B1 (fr) 1989-06-02 1990-05-23 Conversion d'huile lourde

Country Status (6)

Country Link
EP (1) EP0400743B1 (fr)
JP (1) JPH03163194A (fr)
CA (1) CA2018013A1 (fr)
DE (1) DE69011217T2 (fr)
ES (1) ES2058755T3 (fr)
GB (1) GB8912698D0 (fr)

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US7811445B2 (en) 2003-12-19 2010-10-12 Shell Oil Company Systems and methods of producing a crude product

Families Citing this family (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB9025818D0 (en) * 1990-11-28 1991-01-09 Shell Int Research Heavy oil conversion process
US6043288A (en) * 1998-02-13 2000-03-28 Exxon Research And Engineering Co. Gas conversion using synthesis gas produced hydrogen for catalyst rejuvenation and hydrocarbon conversion
NL1027783C2 (nl) * 2003-12-19 2006-08-23 Shell Int Research Systemen en werkwijzen voor het bereiden van een ruw product.
MX2008016075A (es) * 2006-06-22 2009-01-15 Shell Int Research Metodos para la obtencion de un producto total con minimo consumo de hidrogeno.
EP2029699A1 (fr) * 2006-06-22 2009-03-04 Shell Internationale Research Maatschappij B.V. Systèmes et procédés de production d'un produit total avec récupération de sels inorganiques
EP2029697A1 (fr) * 2006-06-22 2009-03-04 Shell Internationale Research Maatschappij B.V. Procédés de fabrication d'un produit total avec fabrication sélective d'hydrocarbures

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GB831247A (en) * 1957-08-28 1960-03-23 Exxon Research Engineering Co Improvements in upgrading crude petroleum oils
US3183180A (en) * 1964-02-18 1965-05-11 Hydrocarbon Research Inc Hydrogenation of oils
US4298458A (en) * 1980-02-25 1981-11-03 Mobil Oil Corporation Low pressure hydrotreating of residual fractions
US4316794A (en) * 1980-03-06 1982-02-23 Mobil Oil Corporation Direct conversion of residual oils

Non-Patent Citations (1)

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Title
Annual Book of ASTM Standards, vol.05.01 (1992), page 99 *

Cited By (13)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US7811445B2 (en) 2003-12-19 2010-10-12 Shell Oil Company Systems and methods of producing a crude product
US7828958B2 (en) 2003-12-19 2010-11-09 Shell Oil Company Systems and methods of producing a crude product
US7854833B2 (en) 2003-12-19 2010-12-21 Shell Oil Company Systems and methods of producing a crude product
US7879223B2 (en) 2003-12-19 2011-02-01 Shell Oil Company Systems and methods of producing a crude product
US7959797B2 (en) 2003-12-19 2011-06-14 Shell Oil Company Systems and methods of producing a crude product
US8025791B2 (en) 2003-12-19 2011-09-27 Shell Oil Company Systems and methods of producing a crude product
US8070936B2 (en) 2003-12-19 2011-12-06 Shell Oil Company Systems and methods of producing a crude product
US8163166B2 (en) 2003-12-19 2012-04-24 Shell Oil Company Systems and methods of producing a crude product
US8268164B2 (en) 2003-12-19 2012-09-18 Shell Oil Company Systems and methods of producing a crude product
US8394254B2 (en) 2003-12-19 2013-03-12 Shell Oil Company Crude product composition
US8608938B2 (en) 2003-12-19 2013-12-17 Shell Oil Company Crude product composition
US8613851B2 (en) 2003-12-19 2013-12-24 Shell Oil Company Crude product composition
US8663453B2 (en) 2003-12-19 2014-03-04 Shell Oil Company Crude product composition

Also Published As

Publication number Publication date
JPH03163194A (ja) 1991-07-15
EP0400743A1 (fr) 1990-12-05
GB8912698D0 (en) 1989-07-19
DE69011217T2 (de) 1995-01-26
ES2058755T3 (es) 1994-11-01
CA2018013A1 (fr) 1990-12-02
DE69011217D1 (de) 1994-09-08

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