WO1997038066A1 - Procede de separation inverse dans des systemes de chambres d'hydrotraitement - Google Patents

Procede de separation inverse dans des systemes de chambres d'hydrotraitement Download PDF

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Publication number
WO1997038066A1
WO1997038066A1 PCT/US1997/004270 US9704270W WO9738066A1 WO 1997038066 A1 WO1997038066 A1 WO 1997038066A1 US 9704270 W US9704270 W US 9704270W WO 9738066 A1 WO9738066 A1 WO 9738066A1
Authority
WO
WIPO (PCT)
Prior art keywords
zone
hydrotreating
passing
denitrification
liquid
Prior art date
Application number
PCT/US1997/004270
Other languages
English (en)
Inventor
Dennis R. Cash
Original Assignee
Chevron U.S.A. Inc.
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Chevron U.S.A. Inc. filed Critical Chevron U.S.A. Inc.
Priority to SK1661-97A priority Critical patent/SK166197A3/sk
Priority to BR9706578-1A priority patent/BR9706578A/pt
Priority to EP97915144A priority patent/EP0851907A1/fr
Priority to AU22159/97A priority patent/AU2215997A/en
Priority to JP53621097A priority patent/JP2001523277A/ja
Publication of WO1997038066A1 publication Critical patent/WO1997038066A1/fr

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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
    • C10G65/00—Treatment of hydrocarbon oils by two or more hydrotreatment processes only
    • C10G65/02—Treatment of hydrocarbon oils by two or more hydrotreatment processes only plural serial stages only
    • C10G65/04—Treatment of hydrocarbon oils by two or more hydrotreatment processes only plural serial stages only including only refining steps
    • 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
    • C10G65/02—Treatment of hydrocarbon oils by two or more hydrotreatment processes only plural serial stages only
    • C10G65/12—Treatment of hydrocarbon oils by two or more hydrotreatment processes only plural serial stages only including cracking steps and other hydrotreatment steps

Definitions

  • the present invention relates to the field of hydroprocessing.
  • the present invention relates to hydroprocessing to obtain high conversions, product selectivity and selective hydrotreating of specific boiling range products.
  • High conversions includes sulfur removal, nitrogen removal, hydrocracking, ramsbottom carbon reduction, and the like.
  • the two conventional processes include (a) a long residence time or low space velocity reactors, or (b) a separate reactor loop for the high conversion step after feed impurities are reduced in an initial reactor loop.
  • Selectivity includes obtaining a preferential yield of certain boiling range materials. These conventional processes include (a) recycling the undesirable products for reprocessing with the fresh feed, or (b) reprocessing the undesirable products in a separate reaction loop. Typical approaches in the art to selective hydrotreating of specific boiling range products include (a) overtreating of the entire feed to the point where the most difficult product specification is met, or (b) treating of the whole feed to a lesser extent followed by a separate hydrotreating of particular product cuts to meet the most difficult specifications.
  • the present invention serves to accomplish these objectives in a single reaction loop including lower costs than multiple loops, while maintaining the advantages of a multiple loop system including higher reaction rates or catalysts tailored for pretreated feeds.
  • the present invention includes a process for reverse staging to obtain high conversion, selective hydrotreating and product selectivity in a hydroprocessing reactor system including performing in a single reactor loop a higher conversion or deeper treating processing in a top bed(s) of a reactor or in the lead reactor in a series reactor loop and performing the general feed processing in the reactor zones that follow.
  • FIG. 1 depicts one embodiment of a flow diagram of the process of the invention utilizing a common vessel for housing the different treatment zones.
  • FIG. 2 depicts an alternate embodiment of a flow diagram of the process of the invention utilizing separate vessels for housing the different treatment zones.
  • the invention is a method of reverse stage hydrotreating a hydrocarbon feed to obtain high conversion, selective hydrotreating and product selectivity in a hydroprocessing reactor system.
  • the method includes passing a hydrocarbon feed to a first hydrotreating zone, e.g., a denitrification and desulfurization zone.
  • a hydrotreating zone e.g., a denitrification and desulfurization zone.
  • hydrotreating conditions e.g., denitrification and desulfurization conditions
  • a hydrotreating catalyst e.g., a denitrification and desulfurization catalyst.
  • the denitrification and desulfurization zone effluent is then passed to a purification/cooling zone (or termed a "NH 3 and H 2 S and cooling zone").
  • Ammonia and H 2 S are removed, typically by water scrubbing.
  • the effluent is cooled by any conventional means, e.g., by heat exchanger.
  • Recovered from the purification/cooling zone is a hydrogen/light hydrocarbon stream from the top and a liquid stream containing dissolved gases from the bottom.
  • the hydrogen/light hydrocarbon stream is optionally passed to a second H 2 S removal zone, typically using an amine adsorbent for H S removal.
  • the recovered effluent from the optional H 2 S removal zone is optionally passed to a second hydrotreating zone, e.g., the hydrocracking zone discussed below.
  • the liquid stream containing dissolved gases is passed to a separation zone. Any conventional separation may be used, typically distillation.
  • a light product and other fractions selected from a liquid bottoms, one or more side- or mid-cuts, and mixtures thereof, are recovered.
  • the other fractions, i.e., liquid bottoms and/or one or more side- or mid-cuts are passed to a second hydrotreating zone, e.g., a hydrocracking zone.
  • the liquid bottoms and/or one or more side- or mid-cuts are contacted with a hydrocracking catalyst.
  • a hydrocracking zone effluent is then recovered.
  • the hydrocracking zone effluent is then passed to the first hydrotreating zone, in one embodiment, a denitrification and desulfurization zone.
  • the first and second hydrotreating or reaction zone may each be a hydrocracking zone or a denitrification and desulfurization zone.
  • the lower zone which the fresh feed first contacts is a denitrification and desulfurization zone.
  • the upper feed is a hydrocracking zone.
  • each zone may both be either a hydrocracking zone or each a denitrification and desulfurization zone.
  • Each may also be a combination or mixture of a hydrocracking zone and a denitrification and desulfurization zone.
  • the present invention provides a single reaction loop. This single reaction loop method lowers costs as compared to the use of multiple reaction loops. Yet, the single reaction loop of the invention maintains the advantages of higher reaction rates or catalyst tailored for pretreated feeds of a multiple reaction loop system.
  • the present invention accomplishes the final processing in the upper reaction zone or top bed or beds of a reactor or reactors in series while performing the general feed processing in the lower reaction zones that follow.
  • Another advantage of a series configuration rather than a parallel reactor configuration for the initial conversion and one for the high conversion step is that gas circulation is minimized thereby reducing both investment and operating costs.
  • the capital cost is lower due to smaller equipment and piping. Operating costs are lower due to less compressor power to recirculate gas.
  • the gas circulation is reduced relative to initial processing in a separate loop or parallel reactor of the same loop because (a) the high conversion effluent from the top reaction zone serves as a partial heat sink and thereby reduces the quench requirements for the initial processing in the zones which follow, (b) the unused hydrogen in the high conversion effluent from the top zone serves as a partial source of hydrogen for the initial processing in the zones which follow, and (c) the high conversion effluent from the top reaction zone helps to provide good distribution of the fresh feed and hydrogen for reaction on the catalyst in the zones which follow.
  • the advantages of using a single loop are reduced investment cost and operating costs by not duplicating similar pieces of equipment in two separate loops, i.e., one for the initial processing and one for the high conversion step.
  • Advantages of processing the pretreated hydrocarbon in upper reaction zone or top bed separate from the fresh feed include (a) the top bed catalysts are not contaminated with feed impurities, (b) the reaction rate in the top beds is not inhibited by substantial quantities of hydrotreating byproducts, e.g., NH 3 and H 2 S, and (c) hydrogen partial pressures are maximized for the finishing processes.
  • the present process can also provide benefits in the lower reaction zones which includes reduced pulsation tendency.
  • Feedstocks suitable for use in the invention and desired products obtained include any conventional or known hydrocracking/hydroprocessing feedstocks and products.
  • the feedstocks and desired products for the instant process include those disclosed in U.S. Patent Nos. 5,277,793; 5,232,577; 5,073,530; 4,430,203; and 4,404,088 which are incorporated herein by reference.
  • the hydrocarbon feed is selected from a residuum, a vacuum gas oil, middle-distillates, and mixtures thereof.
  • Suitable hydrocracking and hydroprocessing catalysts and reaction conditions include any conventional or known catalysts and reaction conditions.
  • the catalysts and reaction conditions suitable for the instant process include those disclosed in U.S. Patent Nos. 5,277,793; 5,232,577; 5,073,530; 4,430,203; and 4,404,088 which are incorporated herein by reference.
  • the reaction zone is a denitrification and/or desulfurization zone
  • the contacting occurs at denitrification and/or desulfurization conditions.
  • the reaction zone is a hydrocracking zone
  • the contacting occurs at hydrocracking conditions.
  • reaction temperature 400°F-900°F
  • pressure 500 to 5000 psig
  • LHSV 0.5 to 20
  • overall hydrogen consumption 300 to 2000 scf per barrel of liquid hydrocarbon feed The hydrotreating catalyst for the beds will typically be a composite of a Group VI metal or compound thereof, and a Group VIII metal or compound thereof supported on a porous refractory base such as alumina.
  • hydrotreating catalysts are alumina supported cobalt-molybdenum, nickel sulfide, tungsten-nickel sulfide, cobalt molybdate and nickel molybdate.
  • reaction temperature 400°F-950°F
  • reaction pressure 500 to 5000 psig
  • LHSV 0.1 to 15
  • hydrogen consumption 500 to 2500 scf per barrel of liquid hydrocarbon feed.
  • the hydrocracking catalysts used for the beds will typically be a Group VI, Group VII, or Group VIII metal or oxides or sulfides thereof supported on a porous refractory base such as silica or alumina.
  • Examples of hydrocracking catalysts are oxides or sulfides of Mo, W, V, and Cr supported on such bases.
  • the catalyst is any catalyst which will catalyze denitrification and/or desulfurization at denitrification and/or desulfurization conditions.
  • the catalyst is any catalyst which will catalyze hydrocracking at hydrocracking conditions.
  • Vessel 2 houses both reaction zones 3 and 10.
  • the initial processing is carried out in the second zone 10 and the high conversion processing carried out in the first zone 3.
  • the flow scheme optionally includes other features which are common in hydroprocessing units such as preheating of liquid and gas feeds to the reactors (preheaters not shown), NH 3 and H 2 S removal and effluent cooling and separation zone 20, optional recycle gas purification zone 31 , and recirculation streams 30 and 32, and product separation and distillation zone 40.
  • Liquid bottoms stream 50, and/or side- or mid-cut 52, from distillation zone 40 are joined as stream 54.
  • Stream 54 is passed to reaction zone 3.
  • Make-up hydrogen stream 60 is added to gas recirculation stream 32 (also termed "hydrogen/light hydrocarbon stream 30" or “H 2 S removal zone effluent 32").
  • make-up hydrogen stream 70 is added to feed stream 1 instead of, or in addition to, adding make-up hydrogen to stream 32.
  • reaction zone 3 Hydrocracking or deeper hydrotreating takes place in reaction zone 3 depending on the type of catalyst used in that zone.
  • the effluent 65 from reaction zones passes to reaction zone 10.
  • Fresh feed 1 is introduced at an intermediate point between reactor beds 3 and 10. It is processed in the presence of the effluent 65 from the upper reaction zone 3.
  • Effluent 65 assists in distribution of feed stream 1 through reaction zone 10.
  • Effluent 65 also acts as a heat-sink for the exothermic reaction in reaction zone 10.
  • Zone 20 is also a cooling and separation zone producing a gas stream 30 and a liquid stream containing dissolved gases 35. Conventional processing is used for the interrelationships of the NH 3 and H 2 S removal and cooling and separation processes in zone 20. Zone 20 may include multiple units or sub-zones according to conventional means for accomplishing the NH 3 and H S removal and cooling and separation.
  • a hydrogen rich gas stream 32 is recycled back to the reactors and then mixed with make-up hydrogen stream 60.
  • make-up hydrogen stream 70 is mixed with oil feed stream 1.
  • the recycle gas in stream 30 is optionally purified, e.g., by amine adsorbent for H 2 S removal, in zone 31 before recirculation to the reactors.
  • the recycle gas of stream 30 (or stream 32 if further purified in zone 31 ) is optionally fed to stream 54 for feeding to first reaction zone 3 or is passed, as stream 34, to feed stream 1 for feeding to second reaction zone 10.
  • FIG. 2 The description of FIG. 2 is the same as for Figure 1 above, except for the following differences.
  • a common vessel houses the reaction zones.
  • separate vessels 2 and 9 house reaction zones 3 and 10, respectively.

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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)

Abstract

L'invention concerne un procédé de séparation inverse dans des systèmes de chambres d'hydrotraitement, qui comprend les étapes suivantes: a) envoi d'hydrocarbure (1) dans une zone de dénitrification et de désulfuration; b) envoi des effluents issus de ladite zone de dénitrification et de désulfuration dans une zone (20) de purification/refroidissement pour éliminer NH3 et H2S et refroidissement, et récupération, à partir de ladite zone de purification/refroidissement, d'un courant (30) d'hydrogène/hydrocarbure léger et d'un courant liquide contenant des gaz dissous (35); c) envoi du dit courant liquide contenant des gaz dissous dans une zone (40) de séparation, et récupération d'un produit léger (45), de dépôts liquides (50) et d'au moins un produit latéral (52); d) envoi desdits dépôts liquides (50), dudit produit latéral (52) et dudit courant hydrogène/hydrocarbure léger (30) de l'étape b) dans une zone d'hydrocraquage ou d'hydrotraitement; e) évacuation des effluents (65) issus de ladite zone d'hydrocraquage ou d'hydrotraitement dans ladite zone (10) de dénitrification ou désulfuration.
PCT/US1997/004270 1996-04-09 1997-03-19 Procede de separation inverse dans des systemes de chambres d'hydrotraitement WO1997038066A1 (fr)

Priority Applications (5)

Application Number Priority Date Filing Date Title
SK1661-97A SK166197A3 (en) 1996-04-09 1997-03-19 Process for reverse staging in hydroprocessing reactor systems
BR9706578-1A BR9706578A (pt) 1996-04-09 1997-03-19 Processos de hidrotratamento de estágio reverso de uma alimentação de hidrocarboreto, de escalonamento reverso, para obter alta conversão, hidrotratamento seletivo e seletividade de produto, em um sistema de reator de hidroprocessamento e de tratamento de uma alimentacao de hidrocarboneto.
EP97915144A EP0851907A1 (fr) 1996-04-09 1997-03-19 Procede de separation inverse dans des systemes de chambres d'hydrotraitement
AU22159/97A AU2215997A (en) 1996-04-09 1997-03-19 Process for reverse staging in hydroprocessing reactor systems
JP53621097A JP2001523277A (ja) 1996-04-09 1997-03-19 ハイドロプロセシング反応器系の逆順操作法

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
US1507496P 1996-04-09 1996-04-09
US60/015,074 1996-04-09
US80016397A 1997-02-13 1997-02-13
US08/800,163 1997-02-13

Publications (1)

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WO1997038066A1 true WO1997038066A1 (fr) 1997-10-16

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EP (1) EP0851907A1 (fr)
JP (1) JP2001523277A (fr)
KR (1) KR19990022632A (fr)
AU (1) AU2215997A (fr)
BR (1) BR9706578A (fr)
CA (1) CA2223285A1 (fr)
CZ (1) CZ374697A3 (fr)
ID (1) ID19791A (fr)
PL (1) PL323925A1 (fr)
SK (1) SK166197A3 (fr)
WO (1) WO1997038066A1 (fr)

Cited By (17)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO1999047626A1 (fr) * 1998-03-14 1999-09-23 Chevron U.S.A. Inc. Procede integre d'hydroconversion a flux d'hydrogene inverse
US5980729A (en) * 1998-09-29 1999-11-09 Uop Llc Hydrocracking process
US6096190A (en) * 1998-03-14 2000-08-01 Chevron U.S.A. Inc. Hydrocracking/hydrotreating process without intermediate product removal
US6179995B1 (en) 1998-03-14 2001-01-30 Chevron U.S.A. Inc. Residuum hydrotreating/hydrocracking with common hydrogen supply
US6190535B1 (en) 1999-08-20 2001-02-20 Uop Llc Hydrocracking process
US6200462B1 (en) 1998-04-28 2001-03-13 Chevron U.S.A. Inc. Process for reverse gas flow in hydroprocessing reactor systems
US6224747B1 (en) 1998-03-14 2001-05-01 Chevron U.S.A. Inc. Hydrocracking and hydrotreating
EP1103592A2 (fr) * 1999-11-23 2001-05-30 Uop Llc Procédé d'hydrocraquage
US6361683B1 (en) 2000-02-22 2002-03-26 Uop Llc Hydrocracking process
WO2002026917A1 (fr) * 2000-09-26 2002-04-04 Uop Llc Processus d'hydrocraquage
US6379532B1 (en) 2000-02-17 2002-04-30 Uop Llc Hydrocracking process
US6379535B1 (en) 2000-04-25 2002-04-30 Uop Llc Hydrocracking process
US6387245B1 (en) 2000-09-26 2002-05-14 Uop Llc Hydrocracking process
US6451197B1 (en) 2001-02-13 2002-09-17 Uop Llc Process for hydrocracking a hydrocarbonaceous feedstock
US6596155B1 (en) 2000-09-26 2003-07-22 Uop Llc Hydrocracking process
US6787025B2 (en) 2001-12-17 2004-09-07 Chevron U.S.A. Inc. Process for the production of high quality middle distillates from mild hydrocrackers and vacuum gas oil hydrotreaters in combination with external feeds in the middle distillate boiling range
US6797154B2 (en) 2001-12-17 2004-09-28 Chevron U.S.A. Inc. Hydrocracking process for the production of high quality distillates from heavy gas oils

Families Citing this family (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5865987A (en) * 1995-07-07 1999-02-02 Mobil Oil Benzene conversion in an improved gasoline upgrading process

Citations (5)

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US3256178A (en) * 1965-05-25 1966-06-14 Union Oil Co Hydrocracking process
US3328290A (en) * 1965-03-30 1967-06-27 Standard Oil Co Two-stage process for the hydrocracking of hydrocarbon oils in which the feed oil ispretreated in the first stage
US3657110A (en) * 1970-01-05 1972-04-18 Standard Oil Co Process for hydrocracking nitrogen-containing feedstocks
US3926784A (en) * 1973-08-22 1975-12-16 Gulf Research Development Co Plural stage residue hydrodesulfurization process with hydrogen sulfide addition and removal
US4059503A (en) * 1976-08-05 1977-11-22 The Lummus Company Stripping ammonia from liquid effluent of a hydrodenitrification process

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3328290A (en) * 1965-03-30 1967-06-27 Standard Oil Co Two-stage process for the hydrocracking of hydrocarbon oils in which the feed oil ispretreated in the first stage
US3256178A (en) * 1965-05-25 1966-06-14 Union Oil Co Hydrocracking process
US3657110A (en) * 1970-01-05 1972-04-18 Standard Oil Co Process for hydrocracking nitrogen-containing feedstocks
US3926784A (en) * 1973-08-22 1975-12-16 Gulf Research Development Co Plural stage residue hydrodesulfurization process with hydrogen sulfide addition and removal
US4059503A (en) * 1976-08-05 1977-11-22 The Lummus Company Stripping ammonia from liquid effluent of a hydrodenitrification process

Cited By (21)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6096190A (en) * 1998-03-14 2000-08-01 Chevron U.S.A. Inc. Hydrocracking/hydrotreating process without intermediate product removal
US6179995B1 (en) 1998-03-14 2001-01-30 Chevron U.S.A. Inc. Residuum hydrotreating/hydrocracking with common hydrogen supply
US6224747B1 (en) 1998-03-14 2001-05-01 Chevron U.S.A. Inc. Hydrocracking and hydrotreating
WO1999047626A1 (fr) * 1998-03-14 1999-09-23 Chevron U.S.A. Inc. Procede integre d'hydroconversion a flux d'hydrogene inverse
US6200462B1 (en) 1998-04-28 2001-03-13 Chevron U.S.A. Inc. Process for reverse gas flow in hydroprocessing reactor systems
US6296758B1 (en) 1998-09-29 2001-10-02 Uop Llc Hydrocracking process
US5980729A (en) * 1998-09-29 1999-11-09 Uop Llc Hydrocracking process
US6190535B1 (en) 1999-08-20 2001-02-20 Uop Llc Hydrocracking process
US6402935B1 (en) 1999-11-23 2002-06-11 Uop Llc Hydrocracking process
EP1103592A3 (fr) * 1999-11-23 2002-02-06 Uop Llc Procédé d'hydrocraquage
EP1103592A2 (fr) * 1999-11-23 2001-05-30 Uop Llc Procédé d'hydrocraquage
US6379532B1 (en) 2000-02-17 2002-04-30 Uop Llc Hydrocracking process
US6361683B1 (en) 2000-02-22 2002-03-26 Uop Llc Hydrocracking process
US6379535B1 (en) 2000-04-25 2002-04-30 Uop Llc Hydrocracking process
US6858128B1 (en) 2000-04-25 2005-02-22 Uop Llc Hydrocracking process
WO2002026917A1 (fr) * 2000-09-26 2002-04-04 Uop Llc Processus d'hydrocraquage
US6387245B1 (en) 2000-09-26 2002-05-14 Uop Llc Hydrocracking process
US6596155B1 (en) 2000-09-26 2003-07-22 Uop Llc Hydrocracking process
US6451197B1 (en) 2001-02-13 2002-09-17 Uop Llc Process for hydrocracking a hydrocarbonaceous feedstock
US6787025B2 (en) 2001-12-17 2004-09-07 Chevron U.S.A. Inc. Process for the production of high quality middle distillates from mild hydrocrackers and vacuum gas oil hydrotreaters in combination with external feeds in the middle distillate boiling range
US6797154B2 (en) 2001-12-17 2004-09-28 Chevron U.S.A. Inc. Hydrocracking process for the production of high quality distillates from heavy gas oils

Also Published As

Publication number Publication date
BR9706578A (pt) 1999-12-28
SK166197A3 (en) 1998-04-08
KR19990022632A (ko) 1999-03-25
CZ374697A3 (cs) 1998-03-18
CA2223285A1 (fr) 1997-10-16
ID19791A (id) 1998-07-30
AU2215997A (en) 1997-10-29
JP2001523277A (ja) 2001-11-20
PL323925A1 (en) 1998-04-27
EP0851907A1 (fr) 1998-07-08

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