WO2012050766A2 - Appareil d'hydrotraitement à deux phases et procédé comprenant un fractionnement commun - Google Patents

Appareil d'hydrotraitement à deux phases et procédé comprenant un fractionnement commun Download PDF

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Publication number
WO2012050766A2
WO2012050766A2 PCT/US2011/052473 US2011052473W WO2012050766A2 WO 2012050766 A2 WO2012050766 A2 WO 2012050766A2 US 2011052473 W US2011052473 W US 2011052473W WO 2012050766 A2 WO2012050766 A2 WO 2012050766A2
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WO
WIPO (PCT)
Prior art keywords
hydroprocessing
dividing wall
reaction zone
hydrogen
fractionation column
Prior art date
Application number
PCT/US2011/052473
Other languages
English (en)
Other versions
WO2012050766A3 (fr
Inventor
John A. Petri
Vedula K. Murty
Peter Kokayeff
Original Assignee
Uop Llc
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
Priority claimed from US12/894,199 external-priority patent/US8691082B2/en
Priority claimed from US12/894,202 external-priority patent/US8911694B2/en
Application filed by Uop Llc filed Critical Uop Llc
Priority to EA201300398A priority Critical patent/EA024500B1/ru
Priority to CN201180045698.3A priority patent/CN103119133B/zh
Publication of WO2012050766A2 publication Critical patent/WO2012050766A2/fr
Publication of WO2012050766A3 publication Critical patent/WO2012050766A3/fr

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Classifications

    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10L—FUELS NOT OTHERWISE PROVIDED FOR; NATURAL GAS; SYNTHETIC NATURAL GAS OBTAINED BY PROCESSES NOT COVERED BY SUBCLASSES C10G, C10K; LIQUEFIED PETROLEUM GAS; ADDING MATERIALS TO FUELS OR FIRES TO REDUCE SMOKE OR UNDESIRABLE DEPOSITS OR TO FACILITATE SOOT REMOVAL; FIRELIGHTERS
    • C10L1/00—Liquid carbonaceous fuels
    • C10L1/04—Liquid carbonaceous fuels essentially based on blends of hydrocarbons
    • C10L1/08—Liquid carbonaceous fuels essentially based on blends of hydrocarbons for compression ignition
    • 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
    • C10G45/00—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds
    • C10G45/02—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbons; Hydrofinishing
    • 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
    • C10G47/02—Cracking of hydrocarbon oils, in the presence of hydrogen or hydrogen- generating compounds, to obtain lower boiling fractions characterised by the catalyst used
    • C10G47/10—Cracking of hydrocarbon oils, in the presence of hydrogen or hydrogen- generating compounds, to obtain lower boiling fractions characterised by the catalyst used with catalysts deposited on a carrier
    • C10G47/12—Inorganic carriers
    • C10G47/16—Crystalline alumino-silicate carriers
    • 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
    • C10G47/02—Cracking of hydrocarbon oils, in the presence of hydrogen or hydrogen- generating compounds, to obtain lower boiling fractions characterised by the catalyst used
    • C10G47/10—Cracking of hydrocarbon oils, in the presence of hydrogen or hydrogen- generating compounds, to obtain lower boiling fractions characterised by the catalyst used with catalysts deposited on a carrier
    • C10G47/12—Inorganic carriers
    • C10G47/16—Crystalline alumino-silicate carriers
    • C10G47/18—Crystalline alumino-silicate carriers the catalyst containing platinum group metals or compounds thereof
    • 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
    • C10G47/02—Cracking of hydrocarbon oils, in the presence of hydrogen or hydrogen- generating compounds, to obtain lower boiling fractions characterised by the catalyst used
    • C10G47/10—Cracking of hydrocarbon oils, in the presence of hydrogen or hydrogen- generating compounds, to obtain lower boiling fractions characterised by the catalyst used with catalysts deposited on a carrier
    • C10G47/12—Inorganic carriers
    • C10G47/16—Crystalline alumino-silicate carriers
    • C10G47/20—Crystalline alumino-silicate carriers the catalyst containing other metals or compounds thereof
    • 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
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/10—Feedstock materials
    • C10G2300/1037—Hydrocarbon fractions
    • C10G2300/1048—Middle distillates
    • C10G2300/1055—Diesel having a boiling range of about 230 - 330 °C
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/20—Characteristics of the feedstock or the products
    • C10G2300/201—Impurities
    • C10G2300/202—Heteroatoms content, i.e. S, N, O, P
    • 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
    • C10G2400/00—Products obtained by processes covered by groups C10G9/00 - C10G69/14
    • C10G2400/04—Diesel oil

Definitions

  • the invention relates to hydroprocessing hydrocarbons in two stages with common fractionation.
  • Hydroprocessing is a process that contacts a selected feedstock and hydrogen- containing gas with suitable catalyst(s) in a reaction vessel under conditions of elevated temperature and pressure.
  • the hydrogen is conventionally a separate phase in a three-phase system (gas/liquid/solid catalyst).
  • Such hydroprocessing is commonly undertaken in a trickle- bed reactor where the continuous phase is gaseous and not liquid.
  • the continuous gas phase is far in excess of stoichiometry requiring gas recovery, clean-up, compression and recycle back to the hydroprocessing reaction vessel.
  • Hydrotreating is a type of hydroprocessing primarily active for the removal of heteroatoms, such as sulfur and nitrogen, and saturation of compounds in the hydrocarbon feedstock. Hydrotreating can typically increase the cetane number of a hydrocarbonaceous feed and prepare the feed for further hydroprocessing.
  • the present invention comprises an apparatus for hydroprocessing hydrocarbonaceous feedstock comprising a first hydroprocessing reaction zone for hydroprocessing the hydrocarbonaceous feedstock.
  • a dividing wall fractionation column includes a dividing wall extending to a bottom of the dividing wall fractionation column that divides the dividing wall fractionation column into a first side and a second side. The first side is in downstream communication with the first hydroprocessing reaction zone.
  • a second hydroprocessing reaction zone is in downstream communication with the first side of the dividing wall fractionation column. The second hydroprocessing reaction zone hydroprocesses a feed diesel stream from the first side of the dividing wall fractionation column.
  • a second side of the dividing wall fractionation column is in downstream communication with the second hydroprocessing reaction zone.
  • the present invention comprises an apparatus for producing low sulfur diesel comprising a first hydrotreating reaction zone for hydrotreating a hydrocarbonaceous feedstock to reduce its sulfur concentration and improve its cetane number.
  • a dividing wall fractionation column includes a dividing wall extending to a bottom of the column that divides the dividing wall fractionation column into a first side and a second side. The first side is in downstream communication with the first hydrotreating reaction zone.
  • a second hydroprocessing reaction zone is in downstream communication with the first side of the dividing wall column. The second hydroprocessing reaction zone hydroprocesses a feed diesel stream from the first side of the dividing wall fractionation column.
  • a second side of the dividing wall fractionation column is in downstream communication with the second hydroprocessing reaction zone.
  • the present invention comprises an apparatus for producing low sulfur diesel comprising a first hydrotreating reaction zone for
  • a dividing wall fractionation column includes a dividing wall that divides the dividing wall fractionation column into a first side and a second side. The first side is in downstream communication with the first hydrotreating reaction zone.
  • a second dividing wall that divides the dividing wall fractionation column into a first side and a second side. The first side is in downstream communication with the first hydrotreating reaction zone.
  • hydroprocessing reaction zone is in downstream communication with the first side of the dividing wall column.
  • the second hydroprocessing reaction zone hydroprocesses a feed diesel stream from the first side of the dividing wall fractionation column.
  • a second side of the dividing wall fractionation column is in downstream communication with the second hydroprocessing reaction zone.
  • a fractionator column is in downstream
  • the present invention comprises a process to
  • hydroprocess hydrocarbonaceous feedstock comprising hydroprocessing the
  • the first hydroprocessed effluent is fractionated on a first side of a dividing wall in a dividing wall fractionation column to provide a diesel stream recovered from a bottom of the dividing wall fractionation column.
  • a feed diesel stream is hydroprocessed with hydrogen in a second hydroprocessing reaction zone with hydroprocessing catalyst to produce a second
  • hydroprocessed effluent is fractionated on a second side of the dividing wall in the dividing wall fractionation column to produce a hydroprocessed diesel stream.
  • the feed diesel stream is at least a portion of the diesel stream.
  • the present invention comprises a process to hydroprocess hydrocarbonaceous feedstock comprising hydrotreating the hydrocarbonaceous feedstock boiling in a VGO boiling range with hydrogen in a hydrotreating reaction zone with a hydrotreating catalyst at conditions effective to produce a hydrotreated effluent having a lower sulfur concentration and an improved cetane number than that of the hydrocarbonaceous feedstock.
  • the hydrotreated effluent is fractionated on a first side of a dividing wall in a dividing wall fractionation column to provide a diesel stream.
  • the diesel stream is fractionated in a fractionator column to provide a feed diesel stream.
  • the feed diesel stream is hydroprocessed with hydrogen in a hydroprocessing reaction zone with hydroprocessing catalyst to produce a hydroprocessed effluent.
  • the hydroprocessed effluent is fractionated on a second side of the dividing wall in the dividing wall fractionation column to produce a hydroprocessed diesel stream.
  • the present invention comprises a process to produce low sulfur diesel comprising hydro treating a hydrocarbonaceous feedstock with hydrogen in a first hydrotreating reaction zone with a hydrotreating catalyst at conditions effective to produce a first hydrotreated effluent having a lower sulfur concentration and an improved cetane number than that of the hydrocarbonaceous feedstock.
  • hydrotreated effluent is fractionated on a first side of a dividing wall in a dividing wall fractionation column to provide a diesel stream.
  • a feed diesel stream which is at least a portion of the diesel stream is hydrotreated with hydrogen in a second hydrotreating reaction zone with hydrotreating catalyst to produce a second hydrotreated effluent.
  • the second hydrotreated effluent is fractionated on a second side of the dividing wall in the dividing wall fractionation column to produce ultra-low sulfur diesel stream.
  • downstream communication means that at least a portion of material flowing to the subject in downstream communication may operatively flow from the object with which it communicates.
  • upstream communication means that at least a portion of the material flowing from the subject in upstream communication may operatively flow to the object with which it communicates.
  • each column includes a condenser on an overhead of the column to condense and reflux a portion of an overhead stream back to the top of the column and a reboiler at a bottom of the column to vaporize and send a portion of a bottoms stream back to the bottom of the column. Feeds to the columns may be preheated.
  • the top pressure is the absolute pressure of the overhead vapor at the outlet of the column.
  • the bottom temperature is the liquid bottom outlet temperature.
  • Hydroprocessed effluent from a first hydroprocessing zone may be fed to a first side of a dividing wall in a dividing wall fractionation column.
  • a diesel stream from the first side of the dividing wall is either fed directly to a second hydroprocessing zone or fractionated in a fractionator column to remove hydrotreated VGO to feed a feed diesel stream to the second hydroprocessing zone.
  • a second effluent from the second hydroprocessing zone may be fed to a second side of the dividing wall in the dividing wall fractionation column to separate ULSD which may be recovered.
  • the apparatuses and processes described herein are particularly useful for hydroprocessing a hydrocarbonaceous feedstock containing diesel or VGO boiling range hydrocarbons.
  • hydrocarbon feedstocks include hydrocarbonaceous streams having components boiling above 288°C (550°F), such as atmospheric gas oils, vacuum gas oils, deasphalted, vacuum, and atmospheric residua, hydrotreated or mildly hydrocracked residual oils, coker distillates, straight run distillates, solvent-deasphalted oils, pyrolysis- derived oils, high boiling synthetic oils, cycle oils, cat cracker distillates, and the like.
  • These hydrocarbonaceous feed stocks may contain from 0.1 to 4 percent sulfur.
  • a preferred hydrocarbonaceous feedstock is a diesel stream or other hydrocarbon fraction having at least 50 percent by weight, and usually at least 75 percent by weight, of its components boiling at a temperature above 149°C (300°F).
  • a typical diesel stream normally has a boiling point range between 138°C (280°F) and 382°C (720°F).
  • Another preferred hydrocarbonaceous feedstock is a VGO or other hydrocarbon fraction having at least 50 percent by weight, and usually at least 75 percent by weight, of its components boiling at a temperature above 371°C (700°F).
  • a typical vacuum gas oil normally has a boiling point range between 315°C (600°F) and 565°C (1050°F).
  • FIG. 1 an exemplary integrated hydrocarbon processing unit will be described in more detail. It will be appreciated by one skilled in the art that various features of the above described process, such as pumps, instrumentation, heat-exchange and recovery units, condensers, compressors, flash drums, feed tanks, and other ancillary or miscellaneous process equipment that are traditionally used in commercial embodiments of hydrocarbon conversion processes have not been described or illustrated. It will be understood that such accompanying equipment may be utilized in commercial embodiments of the flow schemes as described herein. Such ancillary or miscellaneous process equipment can be obtained and designed by one skilled in the art without undue experimentation.
  • the FIGURE shows a process and apparatus 10 for producing low sulfur diesel.
  • a hydrocarbonaceous feedstock is introduced in line 12 and may be split between an initial stream 14 and a quench stream 16.
  • the initial stream is preheated and combined with a hydrogen gas stream 18.
  • the hydrogen gas stream may be provided from a make-up gas compressor (not shown).
  • hydrogen in line 18 is only provided via a make-up gas compressor supplied from a general refinery hydrogen supply.
  • the hydrogen gas stream from line 18 is admixed with the hydrocarbonaceous feedstock line 12 to provide an admixture of the hydrocarbonaceous feedstock and hydrogen in line 19.
  • the combined stream 19 is heated in a fired heater and fed to a first
  • the first hydroprocessing reaction zone 20 may have more than one hydroprocessing reactor 22.
  • the first hydroprocessing reaction zone 20 shown in the FIGURE has a first hydroprocessing reactor 22 and a second hydroprocessing reactor 24. More hydroprocessing reactors are contemplated.
  • Each of the hydroprocessing reactors 22, 24 may have just one bed of hydroprocessing catalyst 26 or have multiple hydroprocessing catalyst beds 26, 28.
  • the quench stream 16 may bypass feed heaters and be divided up and fed to the effluent from a hydroprocessing catalyst bed or hydroprocessing reactor to cool the hot hydroprocessed effluent.
  • a first hydroprocessed effluent exits the first hydroprocessing reaction zone 20 in line 30.
  • One or both of the hydroprocessing reactors 22, 24 in the hydroprocessing reaction zone 20 may be operated in a continuous liquid phase.
  • Continuous liquid phase hydroprocessing involves introducing a liquid phase hydrocarbonaceous feedstock and hydrogen into a hydroprocessing reactor.
  • the hydrogen should be present in a sufficiently low concentration to maintain a continuous liquid phase in the hydroprocessing reactor but high enough concentration to provide sufficient hydrogen for hydroprocessing of the hydrocarbonaceous feed.
  • a continuous plenum of hydrocarbon liquid should extend from a feed inlet to an effluent outlet of the reactor 22, 24.
  • Hydrogen gas may be present outside of the liquid plenum or inside of the liquid plenum in the forms of slugs or bubbles. At the very least, the volume of the liquid in the reactor will be greater than the volume of the gas in the reactor.
  • Hydrogen is necessarily consumed. Hydrogen may be provided to the reactor at a first feed inlet in excess or additionally replaced by one or more hydrogen inlet points located downstream of the first feed inlet (not shown). The flow rate of hydrogen added at these downstream locations is controlled to ensure that the reactor operates in a continuous liquid phase. The maximum flow rate of hydrogen that may be added to the reactor 22, 24 is less than the flow rate which would cause a transition from a continuous liquid phase to a continuous vapor phase.
  • the hydrocarbonaceous feedstock does not contain recycled product from a hydroprocessing reactor or other hydrocarbon diluent.
  • a recycle stream or diluent may be incorporated into the fresh
  • any recycled product or diluent typically is introduced into the feedstock in line 14 before a hydrogen stream in line 18 is mixed with the feedstock.
  • such recycled product may be previously stripped of a vaporous hydrogen sulfide, nitrogen or nitrogen containing compositions, and any other vapor phase materials.
  • the fresh hydrocarbonaceous feed in line 14 is provided and mixed with a hydrogen flow in line 18 from a make-up gas compressor or other similar hydrogen source.
  • the hydrogen flow is mixed into the fresh hydrocarbonaceous feed for the hydroprocessing reaction zone 20 and is provided at a rate at least sufficient to satisfy the hydrogen requirement of the first reactor 22 and the second reactor 24 if present.
  • the flow rate of added hydrogen will include an amount in excess of the predicted hydrogen requirements of the hydroprocessing reaction zone 20 as reserve in event the hydrogen consumption exceeds the expected amount at a particular bed 26, 28 or reactor 22, 24.
  • hydrogen is added to the fresh feed stream to provide sufficient hydrogen to exceed the saturation point of the hydrocarbonaceous liquid so that a small vapor phase is present throughout the substantially liquid phase.
  • sufficient additional hydrogen in the small vapor phase to provide additional dissolved hydrogen to the continuous liquid hydrocarbon phase as the reaction consumes hydrogen.
  • the amount of added hydrogen may be 10 to 20 wt-% greater than the expected collective hydrogen requirements of each hydroprocessing catalyst bed 26, 28.
  • it is expected that the amount of hydrogen may be up to 100 percent of saturation to 1000 percent of the saturated liquid phase hydrocarbon.
  • Excess hydrogen is carried in the effluent from the first hydroprocessing reactor 22 in either solution, a gaseous phase, or both in a gaseous phase and solution in the liquid effluent stream 23 carrying effluent from the first hydroprocessing reactor 22 to the second hydroprocessing reactor 24.
  • no other hydrogen is added to the hydroprocessing reaction zone 20.
  • supplemental hydrogen may be added to the hydroprocessing reactors 22, 24. It will be appreciated, however, that the amount of hydrogen added to the hydroprocessing reaction zone 20 can vary depending on the feed composition, operating conditions, desired output, and other factors.
  • the liquid hydrocarbonaceous feed may include 67 to 135 Nm3 hydrogen per m ⁇ oil (400 to 800 scf/bbl).
  • a continuous gas phase may exist along with the continuous liquid phase extending from feed inlet to product outlet or each reactor 22, 24.
  • 4 to 25 Nm ⁇ hydrogen per m ⁇ oil may exit the outlet from a catalyst bed 26, 28 or each outlet of a reactor 22, 24.
  • the hydroprocessing that takes place in the first hydroprocessing reaction zone can include, without limit, hydrotreating such as hydrodesulfurization or saturation, hydrocracking and hydroisomerization.
  • the first hydroprocessing reaction zone 20 is a hydrotreating reaction zone 20.
  • one or all of the hydroprocessing reactors 22, 24 are hydrotreating reactors 22, 24 with one bed 26 or more beds 26, 28 of hydrotreating catalyst.
  • the first hydroprocessed effluent may be a first hydrotreated effluent.
  • the first hydroprocessed effluent in line 30 may be flashed to separate gas from liquid and a relief valve installed on the gas line to relieve the
  • hydroprocessing reaction zone 20 in the event of over pressurization.
  • the gas and liquid stream may be recombined downstream of the relieve valve.
  • the fractionation zone 40 comprises a fractionation column 42.
  • the fractionating column 42 fractionates the first hydroprocessed effluent entering through inlet 31 to provide a light gas stream in the off-gas line 44 and a diesel stream in a bottoms stream 46.
  • an overhead line 48 removes vapor from a top of the fractionating column 42.
  • the vapor from line 48 is condensed and deposited in a receiver 50.
  • the off-gas line 44 removes light gas from a top of the receiver 50, and unstabilized naphtha from a bottom of the receiver in line 52.
  • An aqueous phase may be removed from a boot in the receiver 50.
  • At least a portion of the unstabilized naphtha may be refluxed to the fractionation column 42, while unstabilized naphtha may be recovered in line 54 for further processing.
  • the top pressure in the fractionation column 42 ranges between 450 and 1150 kPa and the bottom temperature in the dividing wall fractionation column 42 ranges between 204° and 260°C if the feed in line 12 is predominantly a diesel boiling range feed and between 232° and 315°C if the feed in line 12 is predominantly a VGO boiling range feed. Other bottom temperatures may be suitable for different feeds in line 12.
  • fractionation column 42 may be a dividing wall fractionation column 42.
  • a dividing wall 56 may divide the dividing wall column 42 into separate compartments on a first side 58 and a second side 60.
  • the first hydroprocessed effluent is fed to the first side 58 of the dividing wall fractionation column 42 through inlet 31, so the first side 58 is in downstream communication with the first hydroprocessing reaction zone 20.
  • the diesel stream is recovered at a bottom of the first side 58 of the dividing wall
  • the dividing wall 56 extends to the bottom of the dividing wall fractionation column 42 and is sealed to a bottom and inner walls of the dividing wall column to prevent fluid communication between compartments on the first side 58 and the second side 60 at any location below a top of the dividing wall 56.
  • the first hydroprocessed effluent is fed to the first side 58 at inlet 31 located below a top of the dividing wall 56.
  • the dividing wall column may be a dividing wall stripper 42 which utilizes inert gas injection into the bottom of the first side to strip gaseous components from the downflowing liquid instead of utilizing a reboiler.
  • the inert gas may be hydrogen or steam, but steam is preferred.
  • a diesel stream may exit the first side 58 through diesel outlet 43, which is located below the inlet 31 to the first side 58 at a bottom of the fractionation column 42.
  • the bottom temperature in the first side 58 of the dividing wall fractionation column 42 ranges between 204° and 260°C if the feed in line 12 is predominantly a diesel boiling range feed and between 232° and 315°C if the feed in line 12 is predominantly a VGO boiling range feed.
  • the diesel stream 46 which comprises diesel and may comprise heavier components may not qualify as an ULSD stream because it may comprise as much as 50 to 700 wppm sulfur. We have found this to be the case when the first hydroprocessing reaction zone 20 is a hydrotreating reaction zone that operates with a continuous liquid phase.
  • the diesel stream must be further hydrotreated. Additionally, the diesel stream in line 46 may require further hydroprocessing to achieve desired properties. In some cases, the diesel stream in line 46 may be further hydroprocessed directly in which case, line 46 carries a feed diesel stream. In an aspect, particularly when the feed 12 is heavier feed such as VGO, the fractionation zone 40 includes a fractionator column 70 and the diesel stream in line 46 may be fed to the fractionator column 70 via line 47.
  • the fractionator column 70 fractionates the diesel stream into a vapor line 72 which may be condensed and deposited in a receiver 74 to yield a naphtha stream 76. A portion of the naphtha stream may be refluxed to the fractionator column 70 and the other portion recovered as product in line 78. Hydrotreated heavy hydrocarbon such as VGO may be recovered from a bottom of the fractionator column in line 80 which may be an excellent feedstock to an FCC unit or a hydrocracking unit. A fractionated diesel stream in line 82 may be recovered as a side cut at outlet 81 from the fractionation column 70.
  • the outlet 81 for the side cut is taken at a location above where the diesel stream in line 46 is fed to the fractionator column 70 via line 47 at inlet 49 from the fractionation column 42.
  • the fractionated diesel stream in line 82 is collected as a liquid from a liquid collection device on a tray in the fractionator column 70.
  • the top pressure in the fractionator column 70 ranges between 110 and 200 kPa absolute and the bottom temperature in the fractionator column 70 ranges between 316 and 371°C.
  • the diesel stream in either line 46 or 82 is fed to a second hydroprocessing reaction zone 90 or stage in feed diesel line 84.
  • the second hydroprocessing reaction zone 90 or stage in feed diesel line 84 is fed to a second hydroprocessing reaction zone 90 or stage in feed diesel line 84.
  • the second hydroprocessing reaction zone 90 or stage in feed diesel line 84 is fed to a second hydroprocessing reaction zone 90 or stage in feed diesel line 84.
  • hydroprocessing reaction zone is in downstream communication with the first side 58 of the dividing wall fractionation column 42 and the first hydroprocessing reaction zone 20. If the diesel stream in line 46 is the feed diesel stream, a control valve on line 83 is open and control valves on lines 47 and 82 are closed. If the fractionated diesel stream in line 82 is the feed diesel stream, the control valve on line 83 is closed and the control valves on lines 82 and 47 are open. It is contemplated that some intermediate variation between these two conditions may be used.
  • the feed diesel stream carried in line 84 is at least a portion of the diesel stream in line 46 from a bottom of the fractionation column 42 which is fed directly to the second hydroprocessing reaction zone 90 or a cut produced from the fractionation column 70 in line 82.
  • the second hydroprocessing reaction zone 90 is in downstream communication with the fractionator column 70 through the side outlet 81. Moreover, the fractionator column 70 is in upstream communication with the second hydroprocessing reaction zone 90.
  • the feed diesel stream in line 84 is hydroprocessed with hydrogen in a second hydroprocessing reaction zone 90 with hydroprocessing catalyst to produce a second hydroprocessed effluent.
  • the feed diesel stream in line 84 is preheated and combined with a hydrogen gas stream in line 85.
  • the hydrogen gas stream may be provided from a make-up gas compressor (not shown).
  • hydrogen in line 85 is only provided via a make-up gas compressor supplied from a general refinery hydrogen supply.
  • the hydrogen gas stream from line 85 is admixed with the feed diesel stream in line 84 to provide an admixture of the feed diesel stream and hydrogen in line 86.
  • the combined stream 86 is heated in a fired heater and fed to the second hydroprocessing reaction zone 90.
  • the second hydroprocessing reaction zone 90 may have more than one hydroprocessing reactor 92.
  • the second hydroprocessing reaction zone 90 shown in the FIGURE has only one hydroprocessing reactor 92. More hydroprocessing reactors are contemplated.
  • the hydroprocessing reactors 92 may have just one bed of hydroprocessing catalyst 94 or have multiple hydroprocessing catalyst beds.
  • a second hydroprocessed effluent exits the second hydroprocessing reaction zone 90 in line 96.
  • the hydroprocessmg reactor 92 in the second hydroprocessmg reaction zone 90 may be operated in a continuous liquid phase as explained with respect to the first hydroprocessmg reaction zone 20.
  • Hydrogen may be added to the hydroprocessmg reactor 92 as explained with respect to the first hydroprocessmg reaction zone 20.
  • Product recycle or diluent may be supplied to the hydroprocessmg reactor 92 as explained with respect to the first hydroprocessmg reaction zone 20.
  • the hydroprocessmg that takes place in the second hydroprocessmg reaction zone can include, without limit, hydrotreating such as hydrodesulfurization, hydrocracking and hydroisomerization.
  • the hydroprocessmg reactions promoted in the second hydroprocessmg reaction zone 90 may be the same or different as the hydroprocessmg reactions promoted in the first hydroprocessmg reaction zone 20. If the second hydroprocessmg reaction zone 90 is a hydrotreating reaction zone 90 and the first hydroprocessmg reaction zone is a first hydrotreating reaction zone 20, the second hydroprocessmg zone 90 may be a second hydrotreating reaction zone 90.
  • one or more of the hydroprocessmg reactors 92 are hydrotreating reactors 92 with one bed 94 or more beds 94 of hydrotreating catalyst.
  • the second hydroprocessed effluent in line 96 is a second hydrotreated effluent in line 96.
  • hydroprocessmg zone 90 is much more effective in converting feed diesel into useable products. With nitrogen and sulfur species absent, the hydrotreating catalyst if used as the catalyst in the hydrotreating reactor 92 is effective in removing remaining sulfur species to produce ULSD.
  • a hydrotreated effluent which may be the second hydrotreated effluent comprising ULSD exits the second hydroprocessmg reaction zone 90 in line 96.
  • the second hydroprocessed effluent in line 96 may be flashed to separate gas from liquid and a relief valve installed on the gas line to relieve the hydroprocessmg reaction zone 90 in the event of overpressurization.
  • the gas and liquid stream may be recombined downstream of the relieve valve.
  • the second hydroprocessed effluent in line 96 may be fed to the fractionation column 42 to fractionate the second hydroprocessed effluent into off-gas and unstabilized naphtha and produce a hydroprocessed diesel stream in line 98 exiting a bottom of the second side 60 through an outlet 99 which is below the inlet 97.
  • the hydroprocessed diesel in line 98 may be an ultra-low sulfur diesel stream if one or both of the first and second hydroprocessing reaction zones 20 and 90 are hydrotreating reaction zones.
  • the fractionation column 42 is a dividing wall column and the second hydroprocessed effluent is fed to the second side 60 of the dividing wall 56 in the dividing wall fractionation column 42 through inlet 97, so the second side 60 of the dividing wall fractionation column is in downstream communication with the second hydroprocessing reaction zone 90.
  • the inlet 97 to the second side 60 is at an elevation lower than a top of said dividing wall 56.
  • the dividing wall 56 extends to the bottom of the dividing wall fractionation column 42 and is sealed to the bottom and sides of the dividing wall column to prevent communication between the first side 58 and the second side 60 at any location below a top of the dividing wall 56.
  • the second hydroprocessed effluent is fed to the second side 60 below a top of the dividing wall 56.
  • the dividing wall column may be a dividing wall stripper 42 which utilizes inert gas injection into the bottom of the first side to strip gaseous components from the downflowing liquid instead of utilizing a reboiler.
  • the inert gas may be hydrogen or steam, but steam is preferred.
  • the bottom temperature in the second side 60 of the dividing wall fractionation column 42 ranges between 204 and 260°C.
  • the hydroprocessed diesel stream is recovered at a bottom of the second side 60 of the dividing wall fractionation column 42 from outlet 99.
  • the hydroprocessed diesel may be ULSD if one or both hydroprocessing zones 20 and 90 are hydrotreating reaction zones.
  • hydroprocessing that may be performed in any of the hydroprocessing reactors 22, 24 or 92 may be “hydrotreating” which may also include saturation and catalytic dewaxing.
  • hydrotreating hydrogen gas is contacted with hydrocarbonaceous feedstock in the presence of suitable catalysts which are primarily active for the removal of heteroatoms, such as sulfur and nitrogen from the hydrocarbon feedstock.
  • suitable catalysts which are primarily active for the removal of heteroatoms, such as sulfur and nitrogen from the hydrocarbon feedstock.
  • unsaturated hydrocarbons are saturated.
  • Suitable hydrotreating catalysts for use in the present invention are any known conventional hydrotreating catalysts and include those which are comprised of at least one Group VIII metal, preferably iron, cobalt and nickel, more preferably cobalt and/or nickel and at least one Group VI metal, preferably molybdenum and tungsten, on a high surface area support material, preferably alumina.
  • Other suitable hydrotreating catalysts include zeolitic catalysts, as well as noble metal catalysts where the noble metal is selected from palladium and platinum. It is within the scope of the present invention that more than one type of hydrotreating catalyst be used in the same reaction vessel.
  • the Group VIII metal is typically present in an amount ranging from 2 to 20 wt-%, preferably from 4 to 12 wt-%.
  • the Group VI metal will typically be present in an amount ranging from 1 to 25 wt-%, preferably from 2 to 25 wt-%.
  • Preferred hydrotreating reaction conditions include a temperature from 204°C (400°F) to 482°C (900°F), a pressure from 3.5 MPa (500 psig) to 17.3 MPa (2500 psig), a liquid hourly space velocity of the fresh hydrocarbonaceous feedstock from 0.1 hr -1 to 10 hr -1 with a hydrotreating catalyst or a combination of hydrotreating catalysts.
  • hydrotreated effluent having a lower sulfur concentration and an improved cetane number than that of the hydrocarbonaceous feedstock exits the hydrotreating reaction zone 20 in line 30 and enters a fractionation zone 40.
  • hydroprocessing that may be performed in any of the hydroprocessing reactors 22, 24 or 92 may be “hydrocracking".
  • Hydrocracking refers to a process in which hydrocarbons crack in the presence of hydrogen to lower molecular weight hydrocarbons.
  • the hydrocracking zone may contain one or more beds of the same or different catalyst.
  • the preferred hydrocracking catalysts utilize amorphous bases or low-level zeolite bases combined with one or more Group VIII or Group VIB metal hydrogenating components.
  • the hydrocracking zone contains a catalyst which comprises, in general, any crystalline zeolite cracking base upon which is deposited a minor proportion of a Group VIII metal hydrogenating component. Additional hydrogenating components may be selected from Group VIB for incorporation with the zeolite base.
  • the zeolite cracking bases are sometimes referred to in the art as molecular sieves and are usually composed of silica, alumina and one or more exchangeable cations such as sodium, magnesium, calcium, rare earth metals, etc. They are further characterized by crystal pores of relatively uniform diameter between 4 and 14 Angstroms (10 ⁇ 10 meters). It is preferred to employ zeolites having a relatively high silica/alumina mole ratio between 3 and 12. Suitable zeolites found in nature include, for example, mordenite, stilbite, heulandite, ferrierite, dachiardite, chabazite, erionite and faujasite.
  • Suitable synthetic zeolites include, for example, the B, X, Y and L crystal types, e.g., synthetic faujasite and mordenite.
  • the preferred zeolites are those having crystal pore diameters between 8-12 Angstroms (10 ⁇ 10 meters), wherein the silica/alumina mole ratio is 4 to 6.
  • One example of a zeolite falling in the preferred group is synthetic Y molecular sieve.
  • the natural occurring zeolites are normally found in a sodium form, an alkaline earth metal form, or mixed forms.
  • the synthetic zeolites are nearly always prepared first in the sodium form.
  • Hydrogen or "decationized" Y zeolites of this nature are more particularly described in US 3,130,006.
  • Mixed polyvalent metal-hydrogen zeolites may be prepared by ion-exchanging first with an ammonium salt, then partially back exchanging with a polyvalent metal salt and then calcining.
  • the hydrogen forms can be prepared by direct acid treatment of the alkali metal zeolites.
  • the preferred cracking bases are those which are at least 10 percent, and preferably at least 20 percent, metal-cation-deficient, based on the initial ion-exchange capacity.
  • a desirable and stable class of zeolites is one wherein at least 20 percent of the ion exchange capacity is satisfied by hydrogen ions.
  • the active metals employed in the preferred hydrocracking catalysts of the present invention as hydrogenation components are those of Group VIII, i.e., iron, cobalt, nickel, ruthenium, rhodium, palladium, osmium, iridium and platinum.
  • other promoters may also be employed in conjunction therewith, including the metals of Group VIB, e.g., molybdenum and tungsten.
  • the amount of hydrogenating metal in the catalyst can vary within wide ranges. Broadly speaking, any amount between 0.05 percent and 30 percent by weight may be used. In the case of the noble metals, it is normally preferred to use 0.05 to 2 wt-%.
  • the method for incorporating the hydrogenating metal is to contact the zeolite base material with an aqueous solution of a suitable compound of the desired metal wherein the metal is present in a cationic form.
  • the resulting catalyst powder is then filtered, dried, pelleted with added lubricants, binders or the like if desired, and calcined in air at temperatures of, e.g., 371° to 648°C (700° to 1200°F) in order to activate the catalyst and decompose ammonium ions.
  • the zeolite component may first be pelleted, followed by the addition of the hydrogenating component and activation by calcining.
  • the foregoing catalysts may be employed in undiluted form, or the powdered zeolite catalyst may be mixed and copelleted with other relatively less active catalysts, diluents or binders such as alumina, silica gel, silica-alumina cogels, activated clays and the like in proportions ranging between 5 and 90 wt-%.
  • diluents may be employed as such or they may contain a minor proportion of an added hydrogenating metal such as a Group VIB and/or Group VIII metal.
  • Additional metal promoted hydrocracking catalysts may also be utilized in the process of the present invention which comprises, for example,
  • aluminophosphate molecular sieves crystalline chromosilicates and other crystalline silicates. Crystalline chromosilicates are more fully described in US 4,363,718.
  • the hydrocracking conditions may include a temperature from 232°C (450°F) to 468°C (875°F), a pressure from 3.5 MPa (500 psig) to 16.5 MPa (2400 psig) and a liquid hourly space velocity (LHSV) from 0.1 to 30 hr "1 .
  • the hydrocracking reaction provides conversion of the hydrocarbons in the process stream to lower boiling products, which may be the conversion of at least 5 vol-% of the process flow.
  • the per pass conversion in the hydrocracking zone may be in the range from 15 percent to 70 percent and, preferably, the per-pass conversion is in the range from 20 percent to 60 percent.
  • the processes herein are suitable for the production of naphtha, diesel or any other desired lower boiling hydrocarbons.
  • Hydroisomerization also includes catalytic dewaxing. Hydroisomerization is a process in which in one aspect at least 10 percent, in another aspect, at least 50 percent and, in yet another aspect, 10 to 90 percent of the n- paraffins of the hydrocarbon feedstock are converted into iso-paraffins effective to provide an effluent with at least one of a cloud point value of 0°C (32°F) or less, a pour point value of 0°C (32°F) or less, and/or a cold filter plugging point (CFPP) value of 0°C (32°F) or less.
  • a cloud point value of 0°C (32°F) or less a pour point value of 0°C (32°F) or less
  • CFPP cold filter plugging point
  • Suitable hydroisomerization catalysts are any known conventional hydroisomerization catalysts.
  • suitable catalysts can include zeolite components, hydrogenation/dehydrogenation components, and/or acidic components.
  • the catalysts can include at least one Group VIII metal such as a noble metal (i.e., platinum or palladium).
  • the catalyst may also include silico alumino phosphate and/or zeolite alumino silicate. Examples of suitable catalysts are disclosed in US 5,976,351;
  • a product from hydrotreated VGO boiling in the diesel range had the properties presented in Table 3. This diesel feed was selected to simulate diesel that had been subjected to hydrotreating and separation to remove hydrotreating products such as hydrogen sulfide and ammonia which can impede further hydrodesulfurization.

Abstract

Un hydrotraitement à deux phases utilise une colonne de fractionnement à cloison commune. Les effluents hydrotraités provenant des deux phases de l'hydrotraitement sont fournis à des côtés opposés de la cloison.
PCT/US2011/052473 2010-09-30 2011-09-21 Appareil d'hydrotraitement à deux phases et procédé comprenant un fractionnement commun WO2012050766A2 (fr)

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US10683459B2 (en) 2015-12-18 2020-06-16 Petrochina Company Limited Liquid-phase hydroisomerization system and process therefor and use thereof
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US10683459B2 (en) 2015-12-18 2020-06-16 Petrochina Company Limited Liquid-phase hydroisomerization system and process therefor and use thereof

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EA201300398A1 (ru) 2013-07-30
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AR083212A1 (es) 2013-02-06
CN103119133A (zh) 2013-05-22
EA024500B1 (ru) 2016-09-30

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