WO2016069435A1 - Procédé pour convertir un courant de queues de distillation de tour sous vide - Google Patents

Procédé pour convertir un courant de queues de distillation de tour sous vide Download PDF

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Publication number
WO2016069435A1
WO2016069435A1 PCT/US2015/057293 US2015057293W WO2016069435A1 WO 2016069435 A1 WO2016069435 A1 WO 2016069435A1 US 2015057293 W US2015057293 W US 2015057293W WO 2016069435 A1 WO2016069435 A1 WO 2016069435A1
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WO
WIPO (PCT)
Prior art keywords
stream
cracking zone
zone
reactor
visbreaking
Prior art date
Application number
PCT/US2015/057293
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English (en)
Inventor
Christopher Lepine Standing
Ping Sun
Grant YOKOMIZO
James Malcolm Robert Wilson
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Uop Llc
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Filing date
Publication date
Application filed by Uop Llc filed Critical Uop Llc
Publication of WO2016069435A1 publication Critical patent/WO2016069435A1/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
    • C10G69/00—Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one other conversion process
    • C10G69/02—Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one other conversion process plural serial stages only
    • C10G69/06—Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one other conversion process plural serial stages only including at least one step of thermal cracking in the absence of hydrogen
    • 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
    • C10G47/24—Cracking of hydrocarbon oils, in the presence of hydrogen or hydrogen- generating compounds, to obtain lower boiling fractions with moving solid particles
    • C10G47/26—Cracking of hydrocarbon oils, in the presence of hydrogen or hydrogen- generating compounds, to obtain lower boiling fractions with moving solid particles suspended in the oil, e.g. slurries
    • 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
    • C10G7/00—Distillation of hydrocarbon oils
    • C10G7/06—Vacuum distillation
    • 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
    • C10G9/00—Thermal non-catalytic cracking, in the absence of hydrogen, of hydrocarbon oils
    • C10G9/007—Visbreaking

Definitions

  • This invention relates generally to a process for converting a stream from the bottom of a vacuum tower, and more particular to a process using two cracking zones to increase the recovery from the stream and improve the handling of same.
  • Thermal cracking of hydrocarbons can achieve a high conversion of heavy feed stocks, such as vacuum residues, to lower boiling, more valuable distillate products. However, a portion of the product can remain after vacuum distillation. The remaining portion typically comprises unconverted pitch that may have a boiling point greater than 500 °C. The pitch can be sent to a slurry hydrocracking unit to recovery some of the hydrocarbons therefrom.
  • refiners seek to achieve the maximum conversion of the vacuum residues. To meet the desired conversion levels, as well as to provide mesophase (or coke and coke precursor) free conditions, refiners often utilize a large reactor, or integrate the slurry hydrocracker with an existing fluid catalytic cracking unit (for clarified slurry oil).
  • a vacuum column bottoms stream from a Light Arabian crude oil may have a viscosity of 0.0019 m/s (1900 cSt) at 100 °C
  • a vacuum column bottom stream from a Heavy Arabian crude oil may have a viscosity of 0.047000 m/s 2 (47000 cSt) at 100 °C.
  • the present invention may be characterized as a process for processing a bottom stream from a vacuum tower, the process comprising: passing a bottoms stream from a vacuum tower to a first cracking zone to produce a converted stream and an unconverted stream; and, passing the unconverted stream of the first cracking zone to a second cracking zone to produce a second converted stream and a pitch stream, wherein the second cracking zone is operated with a pressure that is higher than the first cracking zone.
  • conversion can be monitored as the net disappearance of 524 °C+ (975 °F+) normal boiling range materials as measured in a standard gas chromatograph method, such as ASTM 2887 and ASTM D7169.
  • the first cracking zone comprises a visbreaking reactor. It is further contemplated that the second cracking zone comprises a slurry hydrocracking reactor.
  • the first cracking zone is free from hydrocracking catalyst. It is also contemplated that the second cracking zone includes a hydrocracking catalyst.
  • the converted stream from the first cracking zone includes gas oil.
  • the process further includes passing at least a portion of the gas oil to the second cracking zone. It is contemplated that the second cracking zone has a combined feed ratio of at least 1.2.
  • the "combined feed ratio" is the ratio of the mass flow rate of the feed stream and any recycle streams passed to a particular zone to the mass flow rate of the feed stream passed to that particular zone.
  • between 90 to 95% of the bottom stream from the vacuum tower is recovered in the first converted stream and the second converted stream.
  • the present invention may be characterized as a process for reducing a viscosity of a bottoms stream from a vacuum tower in which the process includes: passing a bottoms stream from a vacuum tower to a cracking zone including a visbreaking reactor, the cracking zone providing a converted stream and an unconverted stream; and, passing the unconverted stream from the cracking zone to a hydrocracking zone, wherein the unconverted stream from the cracking zone has a lower viscosity than the bottoms stream from the vacuum tower.
  • the hydrocracking zone may include a slurry hydrocracking reactor.
  • the hydrocracking zone includes a catalyst.
  • the invention further includes separating the converted stream from the cracking zone into at least a gas oil stream. It is also contemplated that the process further includes passing the gas oil stream to the hydrocracking zone.
  • the hydrocracking zone may provide a second converted product stream.
  • the process may further include separating the second converted product stream into at least a second gas oil stream, and, recycling at least a portion of the second gas oil stream to the hydrocracking zone.
  • the hydrocracking zone may have a combined feed ratio of at least 1.2. It is contemplated that the cracking zone is a thermal cracking zone operated to convert 10 to 40% of 349 °C+ (660 °F+) material from the bottoms stream of the vacuum tower.
  • the hydrocracking zone is operated to convert between 90 to 95% of the unconverted stream from the cracking zone.
  • the invention may be characterized as a process for increasing a conversion of a bottoms stream from a vacuum tower in which the process includes: passing a bottoms stream from a vacuum tower to a visbreaking reactor, the visbreaking reactor recovering 25 to 55% of the 521 °C+ (970 °F+) material from the bottoms stream in a converted stream and the remaining portion comprising an unconverted stream; and, passing the unconverted stream from the visbreaking reactor to a slurry hydrocracking reactor, wherein the unconverted stream from the visbreaking reactor has a lower viscosity than the bottoms stream from the vacuum tower.
  • the process further includes converting 10 to 20% of the bottoms stream from the vacuum tower into a gas oil stream. It is also contemplated that the process includes passing a portion of the gas oil stream to the slurry hydrocracking reactor.
  • a first zone includes a visbreaking reactor and a second zone includes a slurry hydrocracker reactor downstream from the visbreaking reactor.
  • visbreaking reactors are relatively inexpensive. Thus, it would be less costly for a refiner to include a visbreaking reactor. Additionally, such process may provide for higher overall conversion of the feedstock without increasing the severity of the slurry hydrocracker operation.
  • a slurry hydrocracker unit downstream of a visbreaking reactor (operating at 25% conversion, as discussed below,) would have to operate at 90% conversion.
  • Such process may also enable the design of a smaller slurry hydrocracking reactor.
  • the feed rate to the hydrocracking unit would be less.
  • Upstream visbreaking would also reduce the vapor production within the hydrocracking reactor, since it would remove molecules which were easier to crack under milder visbreaking conditions.
  • a feed 10, such as a crude oil is first passed to an atmospheric fractionation zone 12.
  • the atmospheric fractionation zone 12 can produce one or more overhead streams 14 and an atmospheric bottom stream 16.
  • the one or more overhead streams 14 can include a variety of products, such as light gases, gasoline, diesel, and kerosene. These one or more overhead streams 14 can exit the atmospheric fractionation zone 12 separately or in combination.
  • the atmospheric bottom stream 16 can typically include a heavy hydrocarbon boiling at or above 340°C.
  • the atmospheric bottom stream 16 can be provided to a vacuum fractionation zone 18 having at least one vacuum column 19.
  • the vacuum column 19 separates the atmospheric bottom stream 16 into an overhead stream 20 and a vacuum column bottom stream 22.
  • the overhead stream 20 can include one or more compounds boiling above 300 °C.
  • the vacuum column bottom stream 22 can include material boiling above 500 °C.
  • a vacuum column may comprise a distillation column with a three-stage eductor at the overhead to provide the vacuum in the column. Each stage of the eductor is co-fed with a gas stream such as steam to pull a vacuum upstream of the eductor in the vacuum column. Pressure is greater on the downstream side of each eductor stage, causing the overhead stream to condense in an accumulator to liquid products that can be recovered.
  • a vacuum column may be maintained at a pressure between 1 and 10 kPaa.
  • the vacuum column bottom stream 22 is passed to a first cracking zone 24 where a first portion 26 will be the converted and the remaining portion 28 will comprise the unconverted hydrocarbons which can be passed to a second cracking zone 30.
  • the two cracking zones 24, 30 are preferably operated at different pressures. Additionally, it is preferred that the first cracking zone 24 is catalyst free, while the second cracking zone 30 includes a catalyst.
  • the first cracking zone 24 comprises a thermal cracking zone such as with no or low hydrogen gas pressure, with, for example, a visbreaking reactor 25 and the second cracking zone 30 comprises a hydrocracking zone such as with a desired addition of hydrogen gas pressure, with, for example, a slurry hydrocracking reactor 31.
  • Visbreaking is a mild thermal cracking type of hydrocarbon conversion process which is normally employed to reduce the viscosity and/or pour point of various heavy petroleum-derived hydrocarbonaceous liquids. The visbreaking operation may be employed to decrease the amount of low value residual material produced in a petroleum refinery by upgrading a portion of the charge stock to a salable fuel oil product.
  • the visbreaking process may employ a single fractionation column as the initial separation zone or may be integrated with a vacuum fractionation column to recover additional amounts of light and heavy gas oils.
  • the visbreaking operation typically comprises the basic steps of heating the feed stream to the relatively high temperature required for the mild thermal cracking operation and maintaining the feed stream at this temperature for a predetermined time, which is inversely proportional to the temperature employed. The material treated in this manner may then be quenched to a temperature low enough to terminate the thermal cracking reactions and passed into the separation facilities.
  • the inherent inefficiency of heat recovery requires an input of heat.
  • the vacuum column bottom stream 22 passed to the visbreaking reactor 25 may be first heated by indirect heat exchange in various heat recovery steps. After being heated, the vacuum column bottom stream 22 is then passed into a visbreaking zone which comprises the visbreaking reactor 25. Steam may be admixed with the feed stream to minimize coking within the heater tubes of the visbreaking reactor 25.
  • the visbreaking reactor 25 is maintained at visbreaking conditions. Visbreaking conditions in general include a temperature within the general range of 426 °C to 523 °C (800 °F to 975 °F). Normal visbreaking conditions also comprise a pressure between 172 and 2758 kPag (25 to 400 psig) although higher pressures to 689 kPag (1000) psig have been described in the literature.
  • the vacuum column bottom stream 22 is preferably subjected to these visbreaking conditions for a period of 20 to 65 equivalent seconds at a temperature above 480 °C (900 °F) while within the visbreaking reactor 25.
  • the effluent of the visbreaking reactor 25 may be quenched, as with a gas oil, to reduce its temperature by 21 °C to 60 °C (70 °F to 140 °F).
  • a common variation in visbreaking is the use of a soaker drum in which the still-hot effluent of the visbreaking reactor 25 is retained for a preselected time prior to quenching.
  • the thermal conversion reactions continue within the drum thereby allowing a reduction in the temperature required for the same degree of conversion.
  • the exact conditions of temperature and pressure which are preferred will vary with such factors as the characteristics of the feed material and the degree of thermal cracking desired.
  • the visbreaking reactor 25 will crack hydrocarbons into the first stream 26 comprising converted hydrocarbons and the second stream 28 which comprises unconverted hydrocarbons, or the remaining portion of the vacuum column bottom stream 22.
  • the first stream 26 can be separated into various components (or cuts) such as naphtha, distillate, gas oil, etc. which may be passed to downstream processing.
  • a gas oil stream 32 can be used with the second stream 28 from the first cracking zone 24 to provide a combined feed ratio of at least 1.2 for the feed stream to the second cracking zone 30.
  • the second cracking zone 30 comprises a slurry hydrocracking reactor 31.
  • a slurry hydrocracking reactor 31 utilizes a catalyst and is operated under hydrocracking conditions to hydrocrack the longer hydrocarbons in the second stream 28 from the first cracking zone 24.
  • exemplary catalyst compounds can include a catalytically effective amount of one or more compounds having iron.
  • the one or more compounds can include at least one of an iron oxide, an iron sulfate, and an iron carbonate.
  • Other forms of iron can include at least one of an iron sulfide, a pyrrhotite, and a pyrite.
  • the catalyst can contain materials other than an iron, such as at least one of molybdenum, nickel, and manganese, and/or a salt, an oxide, and/or a mineral thereof.
  • the one or more compounds may include an iron sulfate, and, more specifically, at least one of an iron sulfate monohydrate and an iron sulfate heptahydrate.
  • Oxidic iron-containing compounds obtained from sources such as a limonite, a laterite, a wrought iron, a clay, a magnetite, a hematite, a gibbsite, or a Kisch iron can also be used.
  • One particularly such material is ferrous sulfate.
  • the ferrous sulfate can either be a monohydrate or a heptahydrate.
  • One or more catalyst particles can include 2 to 45 wt% iron oxide and
  • Iron-containing bauxite is such material having these proportions.
  • Bauxite can have 10 to 40 wt% iron oxide (Fe 2 O 3 ), and 54 to 84 wt% alumina and may have 10 to 35 wt% iron oxide and 55 to 80 wt% alumina.
  • Bauxite also may include silica (SiO 2 ) and titania (TiO 2 ) in amounts of usually no more than 10 wt% and typically in amounts of no more than 6 wt%. Volatiles such as water and carbon dioxide may also be present, but the foregoing weight proportions exclude such volatiles.
  • Iron oxide is also present in bauxite in a hydrated form, but again the foregoing proportions exclude water in the hydrated composition.
  • Such a supported catalyst can be relatively resilient and maintain its particle size after being processed through the slurry hydrocracking reactor.
  • a catalyst can include a support of alumina, silica, titania, one or more aluminosilicates, magnesia, bauxite, coal and/or petroleum coke.
  • Such a supported catalyst can include a catalytically active metal, such as at least one of iron, molybdenum, nickel, and vanadium, as well as sulfides of one or more of these metals.
  • the catalyst can have 0.01 to 30 wt% of the catalytic active metal based on the total weight of the catalyst.
  • the slurry hydrocracking reactor 31 can receive the second stream 28 from the first cracking zone 24, the gas oil stream 32 and a recycle stream 34 (also preferably gas oil, discussed below). Since the process allows for two gas oil streams 32, 34 to be combined with the feed stream 28, the combined feed ratio can be at least 1.2.
  • Hydrogen may be provided (not shown) to the second stream 28 from the first cracking zone 24 to before being passed into the second cracking zone 30.
  • the hydrogen can include recycled and/or make-up hydrogen, and as such can include other light hydrocarbon molecules, such as methane and ethane.
  • the hydrocracking reactor 31 can operate either in up-flow or down- flow manner.
  • One exemplary hydrocracking reactor 31 can be a tubular reactor through which the feed, catalyst, and gas pass upwardly.
  • the temperature can be 400 °C to 500 °C (752 °F to 932 °F), preferably 440 °C 465 °C (824 °F to 869 °F), and a pressure between 3 to 28 MPa (435 to 4000 psig), preferably between 10 to 18 MPa (1450 to 2610 psig).
  • the liquid hourly space velocity is typically below 4 hr "1 .
  • the second cracking zone 30 may also include or more separators to separate lighter hydrocarbons 36 from a stream 38 of unconverted hydrocarbons, catalyst, coke, and some trace amounts of converted hydrocarbons. Additionally, due to the higher combined feed ratio, the viscosity of the stream 38 of the unconverted portion is improved as well. In some instances it is believed that stream 38 can comprise 5 to 20% of the original feed stock. The improved viscosity will allow for a lower grading of pipeline tracing and tankage heating to be installed.
  • a theoretical modeling of a slurry hydrocracking unit processing a vacuum column bottoms stream from a Light Arabian crude oil distillation was performed.
  • the slurry hydrocracking unit was operated at a 90% conversion of the vacuum column bottoms stream (521 °C+ (970 °F+) material (materials with a boiling point of 521 °C or greater)) is expected to produce 5.0 wt% C 4 - hydrocarbon stream, 22.0 wt% naphtha, and 35.0 wt% distillate.
  • the slurry hydrocracking unit will also produce 28.0 wt% gas oil, some of which can be recycled to provide a combined feed ratio of 1.1 for the slurry hydrocracking unit.
  • 10.0 wt% of the slurry hydrocracking product vacuum column bottoms stream will comprise unconverted material.
  • a vacuum column bottoms stream from a Light Arabian crude oil distillation was first passed to a visbreaking unit operating with 25% conversion (typical for visbreaking units) of the 349 °C+ (660 °F+) material (materials with a boiling point of 349 °C+ or greater) and with 40% conversion of 521 °C+ (970 °F+) material.
  • the visbreaking unit is expected to produce 6.0 wt% naphtha and 15.5 wt% distillate, both of which can be sent to downstream hydro treating. There will also be 16.0 wt% gas oil yield.
  • 11.0 wt% of the gas oil can be sent to a downstream hydrocracking reactor, and 5 wt% can be used to increase the combined feed ratio of the stream passed to the slurry hydrocracking unit.
  • the uncovered 60 wt% of the 521 °C+ (970 °F+) material from the visbreaking unit can be passed to the slurry hydrocracking unit.
  • a slurry hydrocracking unit downstream of the visbreaking unit is believed to produce 3.0 wt% of a C 4 - hydrocarbons stream, 13.2 wt% naphtha, 21.0 wt distillate, 16.8 wt% gas oil, and 6.0 wt% unconverted material.
  • a combined feed ratio of 1.2 can be utilized.
  • the amount of diesel produced is increased.
  • the recovery of distillate is improved by utilizing both the visbreaking reactor and the slurry hydrocracking reactor.
  • the recovery from the vacuum column bottoms stream can be improved.
  • the amount of unconverted hydrocarbons boiling over 521 °C is reduced, lowering the amount of pitch that needs to be disposed of. It is believed that by adjusting the cut point to 524°C, the recovery will reach 95% (shown in Table 1 as 94% with a 521°C cut point). It is also believed that by utilizing such a process, a feed stream with an initial viscosity of 0.00093 m/s would have an improved viscosity of around 0.00011 m/s , James G.
  • a first embodiment of the invention is a process for increasing a recovery from a bottom stream from a vacuum tower, the process comprising passing a bottoms stream from a vacuum tower to a first cracking zone to produce a converted stream and an unconverted stream; and, passing the unconverted stream of the first cracking zone to a second cracking zone to produce a second converted stream and a pitch stream, wherein the second cracking zone is operated with a pressure that is higher than the first cracking zone.
  • An embodiment of the invention is one, any or all of prior embodiments in this paragraph up through the first embodiment in this paragraph wherein the first cracking zone includes a visbreaking reactor.
  • An embodiment of the invention is one, any or all of prior embodiments in this paragraph up through the first embodiment in this paragraph wherein the second cracking zone includes a slurry hydrocracking reactor.
  • An embodiment of the invention is one, any or all of prior embodiments in this paragraph up through the first embodiment in this paragraph wherein the first cracking zone is free from hydrocracking catalyst.
  • An embodiment of the invention is one, any or all of prior embodiments in this paragraph up through the first embodiment in this paragraph wherein the second cracking zone includes a hydrocracking catalyst.
  • An embodiment of the invention is one, any or all of prior embodiments in this paragraph up through the first embodiment in this paragraph wherein the converted stream from the first cracking zone includes gas oil, and the process further comprising passing at least a portion of the gas oil to the second cracking zone.
  • An embodiment of the invention is one, any or all of prior embodiments in this paragraph up through the first embodiment in this paragraph wherein the second cracking zone has a combined feed ratio of at least 1.2.
  • An embodiment of the invention is one, any or all of prior embodiments in this paragraph up through the first embodiment in this paragraph wherein at least 87% of the bottom stream from the vacuum tower is recovered converted product.
  • a second embodiment of the invention is a process for reducing a viscosity of a bottoms stream from a vacuum tower, the process comprising passing a bottoms stream from a vacuum tower to a cracking zone including a visbreaking reactor, the cracking zone providing a converted stream and an unconverted stream; and, passing the unconverted stream from the cracking zone to a hydrocracking zone, wherein the unconverted stream from the cracking zone has a lower viscosity than the bottoms stream from the vacuum tower.
  • An embodiment of the invention is one, any or all of prior embodiments in this paragraph up through the second embodiment in this paragraph wherein the hydrocracking zone includes a slurry hydrocracking reactor.
  • An embodiment of the invention is one, any or all of prior embodiments in this paragraph up through the second embodiment in this paragraph wherein the hydrocracking zone includes a catalyst.
  • An embodiment of the invention is one, any or all of prior embodiments in this paragraph up through the second embodiment in this paragraph further comprising separating the converted stream from the cracking zone into at least a gas oil stream.
  • An embodiment of the invention is one, any or all of prior embodiments in this paragraph up through the second embodiment in this paragraph further comprising passing the gas oil stream to the hydrocracking zone.
  • An embodiment of the invention is one, any or all of prior embodiments in this paragraph up through the second embodiment in this paragraph wherein the hydrocracking zone provides a second converted product stream, and the process further comprising separating the second converted product stream into at least a second gas oil stream; and, recycling the second gas oil stream to the hydrocracking zone.
  • An embodiment of the invention is one, any or all of prior embodiments in this paragraph up through the second embodiment in this paragraph wherein the hydrocracking zone has a combined feed ratio of at least 1.2.
  • An embodiment of the invention is one, any or all of prior embodiments in this paragraph up through the second embodiment in this paragraph wherein the cracking zone is operated to convert 10 to 40% of material with a boiling point of 349 °C (660 °F) of higher from the bottoms stream of the vacuum tower.
  • An embodiment of the invention is one, any or all of prior embodiments in this paragraph up through the second embodiment in this paragraph wherein the hydrocracking zone is operated to convert at least 87% of the unconverted stream from the cracking zone.
  • a third embodiment of the invention is a process for increasing a conversion of a bottoms stream from a vacuum tower, the process comprising passing a bottoms stream from a vacuum tower to a visbreaking reactor, the visbreaking reactor converting 25 to 55% of material with a boiling point of 521 °C (970 °F) of higher from the bottoms stream into a converted stream and the remaining portion of the bottoms stream comprising an unconverted stream; and, passing the unconverted stream from the visbreaking reactor to a slurry hydrocracking reactor, wherein the unconverted stream from the visbreaking reactor has a lower viscosity than the bottoms stream from the vacuum tower.
  • An embodiment of the invention is one, any or all of prior embodiments in this paragraph up through the third embodiment in this paragraph further comprising converting 10 to 20% of the bottoms stream from the vacuum tower into a gas oil stream.
  • An embodiment of the invention is one, any or all of prior embodiments in this paragraph up through the third embodiment in this paragraph further comprising passing a portion of the gas oil stream to the slurry hydrocracking reactor.

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  • Chemical & Material Sciences (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Engineering & Computer Science (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • General Chemical & Material Sciences (AREA)
  • Organic Chemistry (AREA)
  • Physics & Mathematics (AREA)
  • Thermal Sciences (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)

Abstract

L'invention concerne un procédé pour améliorer la récupération d'un courant de queues de distillation d'une tour sous vide. Le courant de queue passe dans une première zone de craquage et le matériau non converti issu de la première zone de craquage passe dans une seconde zone de craquage. La première zone de craquage peut comprendre un réacteur de viscoréduction. La seconde zone de craquage peut comprendre un réacteur d'hydrocraquage de boues.
PCT/US2015/057293 2014-10-28 2015-10-26 Procédé pour convertir un courant de queues de distillation de tour sous vide WO2016069435A1 (fr)

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US14/525,522 2014-10-28
US14/525,522 US20160115404A1 (en) 2014-10-28 2014-10-28 Process for converting a vacuum tower bottoms stream

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WO2016069435A1 true WO2016069435A1 (fr) 2016-05-06

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Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4201659A (en) * 1978-07-07 1980-05-06 Shell Oil Company Process for the preparation of gas oil
EP0768363B1 (fr) * 1995-10-13 1999-12-29 AGIP PETROLI S.p.A. Procédé pour réduire la viscosité d'huiles résiduelles lourdes
US8168061B2 (en) * 2008-07-25 2012-05-01 Exxonmobil Research And Engineering Company Process for flexible vacuum gas oil conversion using divided wall fractionation

Family Cites Families (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20100122934A1 (en) * 2008-11-15 2010-05-20 Haizmann Robert S Integrated Solvent Deasphalting and Slurry Hydrocracking Process

Patent Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4201659A (en) * 1978-07-07 1980-05-06 Shell Oil Company Process for the preparation of gas oil
EP0768363B1 (fr) * 1995-10-13 1999-12-29 AGIP PETROLI S.p.A. Procédé pour réduire la viscosité d'huiles résiduelles lourdes
US8168061B2 (en) * 2008-07-25 2012-05-01 Exxonmobil Research And Engineering Company Process for flexible vacuum gas oil conversion using divided wall fractionation

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