WO2023107815A1 - Procédés et systèmes de vapocraquage de charges d'hydrocarbures - Google Patents

Procédés et systèmes de vapocraquage de charges d'hydrocarbures Download PDF

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Publication number
WO2023107815A1
WO2023107815A1 PCT/US2022/080171 US2022080171W WO2023107815A1 WO 2023107815 A1 WO2023107815 A1 WO 2023107815A1 US 2022080171 W US2022080171 W US 2022080171W WO 2023107815 A1 WO2023107815 A1 WO 2023107815A1
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WO
WIPO (PCT)
Prior art keywords
decoking
radiant coils
hydrocarbon feed
feed
steam
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PCT/US2022/080171
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English (en)
Inventor
Mark A. Rooney
David Spicer
Philippe J. LE ROY
George Stephens
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Exxonmobil Chemical Patents Inc.
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Publication of WO2023107815A1 publication Critical patent/WO2023107815A1/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
    • C10G9/00—Thermal non-catalytic cracking, in the absence of hydrogen, of hydrocarbon oils
    • C10G9/34—Thermal non-catalytic cracking, in the absence of hydrogen, of hydrocarbon oils by direct contact with inert preheated fluids, e.g. with molten metals or salts
    • C10G9/36—Thermal non-catalytic cracking, in the absence of hydrogen, of hydrocarbon oils by direct contact with inert preheated fluids, e.g. with molten metals or salts with heated gases or vapours
    • 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
    • C10G75/00—Inhibiting corrosion or fouling in apparatus for treatment or conversion of hydrocarbon oils, in general
    • 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
    • C10G9/14—Thermal non-catalytic cracking, in the absence of hydrogen, of hydrocarbon oils in pipes or coils with or without auxiliary means, e.g. digesters, soaking drums, expansion means
    • C10G9/16—Preventing or removing incrustation
    • 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
    • C10G9/14—Thermal non-catalytic cracking, in the absence of hydrogen, of hydrocarbon oils in pipes or coils with or without auxiliary means, e.g. digesters, soaking drums, expansion means
    • C10G9/18—Apparatus
    • C10G9/20—Tube furnaces
    • C10G9/203—Tube furnaces chemical composition of the tubes
    • 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
    • C10G2300/40—Characteristics of the process deviating from typical ways of processing
    • C10G2300/4031—Start up or shut down operations

Definitions

  • Embodiments disclosed herein generally relate to processes for steam cracking hydrocarbons for the production of olefins, particularly low molecular weight olefins such as ethylene and propylene. More particularly, such embodiments relate to processes for removing coke deposits that form within radiant coils of a steam cracker and/or within one or more quench exchanger inlets during steam cracking of the hydrocarbons under a high conversion of ethane and/or propane to one or more other compounds.
  • Steam cracking is a primary means used to generate ethyl ene and propylene and other products from a variety' of feedstocks. Modem plants employ optimization models and controls to optimize profit. Neither ethane nor propane can be converted entirely to products in a steam cracking furnace due to the excessive formation of coke. Despite capital cost, utility cost, energy', and environmental benefits for increasing conversion, steam cracking furnace operators limit ethane conversion to 70% and limit propane conversion to 90%. Unconverted ethane and/or propane in the steam cracker effluent is separated therefrom, compressed, refrigerated, and recycled back to the steam cracker furnace for cracking to extinction. Coking constraints result in reduced run-lengths between decokes or mechanical cleanings, causing operational challenges.
  • the process for steam cracking hydrocarbons can include (A) providing an olefins production plant comprising a steam cracking furnace and an olefins product recovery section.
  • a first hydrocarbon feed comprising at least one of ethane and propane can be introduced into a plurality of radiant coils disposed within the steam cracking furnace under first steam cracking conditions that produce a first steam cracker effluent and deposit coke on an inner surface of the radiant coils.
  • a conversion of ethane, if present at a molar concentration in the first hydrocarbon feed equal to or greater than that of propane, to one or more other compounds is > 75%.
  • a conversion of propane, if present at a molar concentration in the first hydrocarbon feed higher than that of ethane feed, to one or more other compounds is > 93%.
  • the introduction of the first hydrocarbon feed into at least one of the radiant coils in the plurality of radiant coils can be periodically stopped.
  • a decoking feed comprising steam and optionally air can be introduced into the at least one of the radiant coils under decoking process conditions.
  • the decoking process conditions can comprise at least one of: (i) introducing the decoking feed into the at least one of the radiant coils to produce a decoking effluent having a coil outlet temperature of > 900°C; (ii) introducing the decoking feed into the at least one of the radiant coils or into one or more quench exchanger inlets in fluid communication with the at least one of the radiant coils at a mass flux rate at the quench exchanger inlet of > 39 kg m" - 2 second -1 ; and (iii) introducing the decoking feed into the at least one of the radiant coils while maintaining introduction of the first hydrocarbon feed into one or more of the radiant coils in the plurality of radiant coils.
  • process for steam cracking hydrocarbons may comprise introducing a hydrocarbon feed comprising ethane, propane, or a mixture thereof into a plurality of radiant coils disposed within a steam cracking furnace under steam cracking conditions that produce a steam cracker effluent and deposit coke on an inner surface of the radiant coils.
  • a conversion of at least one of ethane, if present at a molar concentration in the first hydrocarbon feed equal to or greater than that of propane (based on the total moles of molecules in the first hydrocarbon feed), to one or more other compounds is > 75%.
  • An inner surface of the radiant coils in the plurality of radiant coils may comprise a material that is non-catalytic to coke generation.
  • process for steam cracking hydrocarbons may comprise (1) providing an olefins production plant comprising a steam cracking furnace and an olefins product recovery section.
  • a first hydrocarbon feed comprising at least one of ethane and propane is introduced into a plurality of radiant coils disposed within the steam cracking furnace under first steam cracking conditions that produce a first steam cracker effluent and deposit coke on an inner surface of the radiant coils.
  • a conversion of ethane, if present at a molar concentration in the first hydrocarbon feed equal to or greater than that of propane, to one or more other compounds is > 75%.
  • a conversion of propane, if present at a molar concentration in the first hydrocarbon feed higher than that of ethane feed, to one or more other compounds is > 93%.
  • Online decoking in an online decoking interval of at least one of the radiant coils can be optionally conducted by introducing a decoking steam there into. Periodically introduction of the first hydrocarbon feed into at least one of the radiant coils in the plurality of radiant coils maybe stopped.
  • a reference process comprising the following may be provided: (a) in a reference cracking interval, introducing a reference steam cracker feed (preferably the same as the first hydrocarbon feed) into the plurality of radiant coils under reference steam cracking conditions that produce a reference steam cracker effluent and deposit coke on the inner surface of the radiant coils, having a reference conversion of ethane, if present at higher molar concentration in the reference steam cracker feed than propane, to one or more other compounds of ⁇ 75%, and a reference conversion of propane, if present, to one or more other compounds of ⁇ 93%; (b) periodically stopping introduction of a reference steam cracker feed into at least one of the radiant coils in the plurality of radiant coils; and (c) in a reference offline decoking interval, introducing the decoking feed into the at least one of the radiant coils under reference decoking conditions.
  • a decoking feed comprising steam and optionally air is introduced into the at least one of the radiant coils under decoking process conditions such that
  • AA Rl(ref)*Dl(ref) + R(ref)*delta(Dl) + delta(Rl)*(D1(ref) + delta(Dl)) - P1 - (P2 - P2(ref)); delta(R1 ) ::: R - R(ref), where R is average coke deposition rate in the radiant coils in the process during the cracking interval, in millimeter- day' 1 (mm- day 1 ), and R(ref) is average coke deposition rate in the radiant coils in the reference process during the reference cracking interval, in mm- day”’;
  • Dl(ref) is the duration of the reference cracking interval, in days
  • P2 is coke removed during the offline decoking interval, in mm.
  • P2(ref) is coke removed during the reference offline decoking interval, in mm.
  • the Figure depicts a schematic of an illustrative steam cracking furnace in operation to convert first and second hydrocarbon feeds within radiant coils disposed within a firebox in the stream cracking furnace, according to one or more embodiments described.
  • hydrocarbon means a class of compounds containing hydrogen bound to carbon.
  • hydrocarbon means hydrocarbon having n carbon atom(s) per molecule, where n is a positive integer.
  • hydrocarbon means hydrocarbon having at least n carbon atom(s) per molecule, where n is a positive integer.
  • C n - !! hydrocarbon means hydrocarbon having no more than n number of carbon atom(s) per molecule, where n is a positive integer.
  • Hydrocarbon encompasses (i) saturated hydrocarbon, (ii) unsaturated hydrocarbon, and (iii) mixtures of hydrocarbons, including mixtures of hydrocarbon compounds (saturated and/or unsaturated), including mixtures of hydrocarbon compounds having different values of n.
  • hydrocarbon feed means any feed that includes hydrocarbon and is suitable for producing unsaturated hydrocarbons, e.g., ethylene and/or propylene, by pyrolysis, such as by steam cracking.
  • Typical hydrocarbon feeds include > 10% hydrocarbon (weight basis, based on the weight of the first hydrocarbon feed), e.g., > 50%, such as > 90%, or > 95%, or > 99%.
  • “Consisting essentially of” a given material means comprising the given material at a concentration of > 50 wt%, preferably > 60 wt%, preferably > 80 wt%, preferably 90 wt%, preferably > 95 wt%, based on the total weight of an identified mixture comprising the given material in question.
  • a hydrocarbon feed consisting essentially of C5+ hydrocarbons is a hydrocarbon feed comprising C5+ hydrocarbons, in total, at an aggregate concentration of > 50 wt%, based on the total weight of the hydrocarbon feed.
  • An olefins production plant useful in the processes of this disclosure can comprise one or more steam cracker furnaces and an olefins product recovery section,
  • a steam cracker furnace can comprises a radiant section and a convection section,
  • a steam cracker feed comprising hydrocarbons, after optional combining with dilution steam, upon pre-heating in heat exchangers, e.g., in the convection section of the steam cracker furnace, is fed into a plurality of radiant tubes (also known as ‘'radiant coils”) located in the radiant section of the steam cracker furnace.
  • the radiant coils are heated by the thermal energy produced by combustion of a steam cracker fuel to an elevated temperature.
  • the first hydrocarbon feed is subjected to steam cracking conditions including various steam cracking temperatures and various residence times, whereby the hydrocarbons undergo pyrolysis reactions to produce a steam cracker effluent exiting the steam cracker furnace comprising desirable olefins such as ethylene and propylene.
  • a steam cracker effluent exiting the steam cracker furnace comprising desirable olefins such as ethylene and propylene.
  • coke may be formed and deposited on the inner surface of the radiant coils.
  • the steam cracker effluent can be immediately quenched to stop additional undesirable reactions.
  • the quenched cracker effluent can be separated into fractions, including a process gas stream rich in hydrogen and C1-C4 hydrocarbons.
  • the process gas stream can be supplied to the olefins product recovery section, where the various components are separated to produce the desirable products, e.g,, an ethylene product stream, a propylene product stream, and the like.
  • An ethane stream and/or a propane stream may be produced from the process gas stream as well, which may be recycled to the stream cracker as a portion of the steam cracker hydrocarbon feed.
  • the steam cracker furnace may be designed to crack a hydrocarbon feed rich in ethane, propane, naphtha, gas oil, or even crude oil. Switching a steam cracker designed to crack a C5+-hydrocarbon-rich steam cracker feed to crack an ethane-rich steam cracker feed or a propane-rich steam cracker feed is not easy.
  • one or more hy drocarbon feeds containing ethane and/or propane can be subjected to steam cracking conditions within one or more radiant coils disposed within a steam cracking furnace to produce a steam cracker effluent, where a conversion of at least one of ethane, if present at a molar concentration in the first hydrocarbon feed equal to or greater than that of propane, to one or more other compounds can be > 75%, or a conversion of propane, if present at a molar concentration in the first hydrocarbon feed higher than that of ethane feed, to one or more other compounds can be > 93%, while coke produced during the steam cracking can be sufficiently removed during a decoking process such that the coke does not appreciably build-up so that the steam cracker does not require frequent (if at all) shut downs due to coke build-up that necessitates the mechanical removal of tire coke build-up from within the radiant coils and/or
  • steam cracking the one or more hydrocarbon feeds can be carried out within the plurality of radiant coils such that a steam cracker effluent can be produced for months, e.g., > 1 month, > 2 months, > 3 months, > 4 months, > 5 months, > 6 months, > 8 months, or > 12 months, with periodic decoking operations occurring within ah of the radiant coils at the same time or with periodic decoking operations occurring within at least one of the radiant coils while maintaining steam cracking of the first hydrocarbon feed within at least one other of the radiant coils without the need to shut down the steam cracker to mechanically remove coke built up on the inner surfaces of the radiant coils and/or the inner surfaces of one or more quench exchangers.
  • the runlength between offline decoking of the entire furnace can be substantially extended.
  • the one or more hydrocarbon feeds can include one or more relatively low' molecular weight hydrocarbon (light feedstocks), particularly those aspects where relatively high yields of C2 unsaturates, e.g., ethylene and acetylene, and/or C3 unsaturates, e.g., propylene and methylacetylene, can be desired.
  • Light feedstocks can include substantially saturated hydrocarbon molecules having fewer than five carbon atoms, e.g. , ethane, propane, and mixtures thereof (e.g. , ethane-propane mixtures or “E/P mix”).
  • a concentration of ethane in the first hydrocarbon feed can be, e.g., > 50 wt%, > 60 w't.%, > 70 wt%, > 75 wt%, > 80 w4.%, > 85%, > 90 wt%, > 95 wt%, up to 100 wt%.
  • a concentration of propane in the first hydrocarbon feed can be, e.g., > 50 wt%, > 60 wt%, > 70 wt%, > 75 wt%, > 80 wt%, > 85%, > 90 wt%, > 95 wt%, up to 100 wt%.
  • a total concentration of ethane plus propane of > 50 wt%, > 60 wt%, > 70 wt%, > 75 wt%, > 80 wt%, > 85%, > 90 wt%, > 95 wt%, up to 100 wt% can be used, the amount of ethane in the E/P mix can be > 20 wt% based on the weight of the E/P mix, e.g., of about 25 wt% to about 75 wt%.
  • the amount of propane in the E/P mix can be, e.g., > 20 wt%, based on the weight of the E/P mix, such as of about 25 wt% to about 75 wt%.
  • the first hydrocarbon feed can be or can include, but is not limited to, a refinery gas stream that can include one or more C2 to C5, saturated or unsaturated hydrocarbons.
  • a first hydrocarbon feed can include primarily ethane, propane, or a mixture thereof, and a second hydrocarbon feed can include a refinery gas stream.
  • the steam cracking conditions can include a residence time of, e.g., from 0.01 seconds (s), 0,02 s, 0.03 s, 0.04 s, to 0.05 s, 0.06 s, 0,07 s, 0,08 s, 0,09 s, to 0.1 s, 0.2 s, 0,3 s, 0.4 s, to 0.5 s.
  • the steam cracking conditions can include heating the first hydrocarbon feed within the radiant coils sufficiently to produce a steam cracker effluent that can have a coil outlet temperature of, e.g., from 815 °C, 820 °C, 825 °C, 830 °C, to 840 °C, 850 °C, 860°C, 870 °C, 880 °C, to 890 °C, 900°C, 910 °C, 920 °C, or 925 °C.
  • a coil outlet temperature e.g., from 815 °C, 820 °C, 825 °C, 830 °C, to 840 °C, 850 °C, 860°C, 870 °C, 880 °C, to 890 °C, 900°C, 910 °C, 920 °C, or 925 °C.
  • introduction of the first hydrocarbon feed into at least one of the radiant coils in the plurality of radiant coils can be stopped periodically.
  • a decoking feed that includes steam or a mixture of air and steam can be introduced into the at least one of the radiant coils under decoking process conditions to remove at least a portion of any coke disposed on the inner walls of the at least one radiant coil and/or at least a portion of any coke disposed on an inner wall of one or more quench exchanger inlets in fluid communication with the at least one radiant coil.
  • the decoking feed can include, e.g., from 50 wt%, 55 wt%, 60 wt%, 65 wt%, to 70 wt%, 75 wt%, 80 wt%, 85 wt%, to 90 wt%, 95 wt%, or 100 wt% of steam, based on a combined weight of steam and the optional air.
  • the decoking process conditions can include introducing the decoking feed (e.g., a decoking feed comprising a mixture of steam and air) into the at least one of the radiant coils to produce a decoking effluent that can have a coil outlet temperature of > 900 °C.
  • the decoking effluent can have a temperature of, e.g.
  • the decoking process conditions can include introducing the decoking feed (e.g., a decoking feed comprising steam and air) into the at least one of the radiant coils or into one or more quench exchanger inlets in fluid communication with the at least one of the radiant coils at a mass flux rate at the quench exchanger inlet of > 39 kg m" 2 second -1 .
  • the decoking feed e.g., a decoking feed comprising steam and air
  • the decoking feed can have a mass flux rate at the quench exchanger inlet of, e.g., from 40, 42, 44, 45, to 46, 48, 50, to 52, 54, 55, to 56, 58, 60, kg m" - 2 second -1 , when introduced into the at least one of the radiant coils and/or into the one or more quench exchanger inlets.
  • the decoking process conditions can include introducing the decoking feed (e.g., steam only) into the at least one of the radiant coils while maintaining introduction of the first hydrocarbon feed into one or more of the other radiant coils in the plurality of radiant coils.
  • decoking process conditions can be referred to as “online decoking process conditions,” where steam cracking of the first hydrocarbon feed continues within one or more radiant coils while decoking conditions are present within one or more radiant coils.
  • the decoking effluent can have a coil outlet temperature of ⁇ 900°C. In other embodiments, the decoking effluent can have a coil outlet temperature of > 900°C.
  • the decoking feed can be at a pressure of > 690 kPa-gauge, > 750 kPa-gauge, > 800 kPa-gauge, > 850 kPa-gauge, > 900 kPa-gauge, or > 930 kPa-gauge when introduced into the radiant cods.
  • steam cracking the one or more hydrocarbon feeds can be earned out within the plurality of radiant coils disposed within a furnace of the steam cracker such that a steam cracker effluent can be continuously produced for months, e.g., > 1 month, > 2 months, > 3 months, > 4 months, > 5 months, > 6 months, > 10 months, > 20 months, > 40 months, > 60 months, > 80 months, or > 100 months, without the need to shut down the steam cracker to mechanically remove coke built up on the inner surfaces of the radiant coils and/or the inner surfaces of one or more quench exchangers.
  • the online decoking process can include the decoking process described in WO Publication No. WO 2020/191253.
  • the decoking process conditions can include a combination of introducing the decoking feed into the at least one of the radiant coils to produce a decoking effluent that can have a coil outlet temperature of > 900°C and introducing the decoking feed into the at least one of the radiant coils or into one or more quench exchanger inlets in fluid communication with the at least one of the radiant coils at a mass flux rate at the quench exchanger inlet of > 39 kg m' 2 - second' 1 .
  • the decoking process conditions can include a combination of introducing the decoking feed into the at least one of the radiant coils to produce a decoking effluent that can have a coil outlet temperature of > 900°C and introducing the decoking feed into the at least one of the radiant coils while maintaining introduction of the first hydrocarbon feed into one or more of the radiant coils in the plurality of radiant coils.
  • the decoking process conditions can include a combination of introducing the decoking feed into the at least one of the radiant coils or into one or more quench exchanger inlets in fluid communication with the at least one of the radiant coils at a mass flux rate at the quench exchanger inlet of > 39 kg- m" 2 - second -1 and introducing the decoking feed into the at least one of the radiant coils while maintaining introduction of the first hydrocarbon feed into one or more of the radiant coils in the plurality of radiant coils.
  • the decoking process conditions can include a combination of introducing the decoking feed into the at least one of the radiant coils to produce a decoking effluent that can have a coil outlet temperature of > 900°C, introducing the decoking feed into the at least one of the radiant coils or into one or more quench exchanger inlets in fluid communication with the at least one of the radiant coils at a mass flux rate at the quench exchanger inlet of > 39 kg-m -2 -second -1 , and introducing the decoking feed into the at least one of the radiant coils while maintaining introduction of the first hydrocarbon feed into one or more of the radiant coils in the plurality of radiant coils.
  • the steam cracking condition provides a coking seventy; and during the offline decoking interval under decoking conditions, the decoking conditions provide a decoking seventy.
  • the decoking severity exceeds the coking severity.
  • the process for steam cracking hydrocarbons can include (C) operating the olefins production plant by (Cl) first introducing a reference hydrocarbon feed (which may be the same as or different from the first hydrocarbon feed as described above) into the plurality of radiant coils under reference steam cracking conditions that produce a reference steam cracker effluent and convert ethane, if present at an equal or higher molar concentration than propane in the reference hydrocarbon feed, to one or more other compounds at ⁇ 75%, or propane, if present at higher concentration than ethane in the reference hydrocarbon feed, to one or more other compounds at ⁇ 93%; and (D) adjusting step (C) to cany 7 out step (B) by, e.g., adjusting the steam cracking conditions such that the conversion of at least one of ethane, if present at an equal or higher molar concentration than propane in the reference hydrocarbon feed, to one or more other compounds is > 75%, and propane, if present at higher concentration than
  • step (CI) the first hydrocarbon feed is introduced into the plurality of radiant coils at a first quantity
  • step (Bl) the reference hydrocarbon feed is introduced into the plurality of radiant coils at a second quantity, the first hydrocarbon feed and the reference hydrocarbon feed have the same composition, and the second quantity is higher than the first quantity.
  • the olefins production plant processes an increased quantity of the first hydrocarbon feed without decreasing the run-length of the steam cracker furnace between adjacent decoking events requiring costly mechanical cleaning, achieving a higher productivity and reducing the associated potential dangers of mechanical cleaning.
  • the first hydrocarbon feed may be different from the reference hydrocarbon feed, the quantity of ethane in the first hydrocarbon feed introduced into the plurality of radiant coils in step (Bl) is higher than the quantity of ethane in the reference hydrocarbon feed introduced into the plurality of radiant coils in step (C 1); and/or the quantity of propane in the first hydrocarbon feed introduced into the plurality of radiant coils in step (Bl) is higher than the quantity of propane in the reference hydrocarbon feed introduced into the plurality' of radiant coils in step (Cl).
  • the first hydrocarbon feed can comprise ethane and/or propane at a higher concentration than the reference hydrocarbon feed.
  • the olefins production plant can be adjusted from processing a reference hydrocarbon feed comprising a relatively low concentration of ethane/propane, such as a naphtha feed or a gas oil feed, to processing a gas feed such as ethane and/or propane, without being constrained by the capacity of the recovery section, if the recovery section was originally designed to receive process gas produced by cracking liquid feeds.
  • a reference hydrocarbon feed comprising a relatively low concentration of ethane/propane, such as a naphtha feed or a gas oil feed
  • a gas feed such as ethane and/or propane
  • the reference hydrocarbon feed may consist essentially of C5+ hydrocarbons such as naphtha, gas oil, and the like.
  • Liquid cracking steam cracker furnaces produce some recycle ethane ( ⁇ 4 wt%) that must be separated, while for the same amount of ethylene gas cracking plants produce more than double (-20-35 wt%) the recycle ethane. Therefore, a liquid cracker moving from all liquid feed to all gas feed will require a substantial reduction in recycle ethane from gas cracking. By increasing conversion, the recycle ethane rates are reduced and more gas cracking can be afforded to a recycle ethane or gas processing constraint.
  • step (B) may further comprises: (B4) separating a process gas stream comprising C1 -C4 hydrocarbons from the first steam cracker effluent; (B5) providing a second C 1 -C4-hydrocarbon ⁇ containmg stream separate from the process gas stream; and (B6) supplying the process gas stream and the second Cl -C4-hydrocarbon-containing stream into the olefins production recovery' section.
  • the second Cl-C4-hydrocarbon-containing stream may be obtained from, e.g,, a petroleum refinery' facility.
  • step (C) As a result of adjusting the reference cracking conditions in step (C) and implementing step (B), less ethane is present in the process gas stream fed into the recovery' section, freeing a portion of the capacity of the recovery' section to receive and process a second Cl-C4-hydrocarbon-containing stream, from which valuable products can be recovered.
  • adjusting the steam cracking conditions can provide an increased production capability' of ethylene, propylene, or a mixture thereof In other embodiments, adjusting the steam cracking conditions can provide a capability' of introducing or, if already introducing, increasing a throughput capability of one or more other hydrocarbons that produce ethane, propane, or a mixture thereof upon steam cracking for recycle into the plurality of radiant coils.
  • adjusting the steam cracking conditions can provide a capability of introducing or, if already introducing, increasing a throughput capability of one or more refinery gases that can include one or more saturated C1-C4 hydrocarbons, one or more unsaturated C1-C4 hydrocarbons, or a mixture thereof that can be introduced into the plurality of radiant coils.
  • adjusting the steam cracking conditions can provide any combination of these benefits.
  • an inner surface of the radiant coils in the plurality of radiant coils and/or an inner surface within one or more quench exchangers can include a material that is non-catalytic to coke generation.
  • the radiant coils can be alumina former tubes made of an alloy that can include > 1.5 wt% of aluminum that have an aluminum oxide layer disposed on the inner surfaces thereof.
  • the radiant coils can include a layer comprising silicon carbide, spinel, or a combination thereof disposed on the inner surfaces thereof.
  • the radiant coils can include a layer comprising a spinel-type oxide layer disposed on the inner surfaces thereof.
  • the spinel-type oxide layer can be or can include, but is not limited to, compounds having the chemical formula: Mn x Cr 3-x O 4 , wherein x is from 0.5 to 2, and from 60 wt% to 40 wt% of oxides of Mn and Si selected from the group consisting of MnO, MnSiOi, MH2S1O4 and mixtures thereof provided that the surface contains less than 5 wt% of Cr 2 O 3 .
  • the process of this disclosure can comprise: (1 ) providing an olefins production plant comprising a steam cracking furnace and an olefins product recovery section; (2) operating the olefins production plant by: (2a) in a cracking interval, introducing a first hydrocarbon feed comprising at least one of ethane and propane into a plurality of radiant coils disposed within the steam cracking furnace under first steam cracking conditions that produce a first steam cracker effluent and deposit coke on an inner surface of the radiant coils, wherein a conversion of ethane, if present at a molar concentration in the first hy drocarbon feed equal to or greater than that of propane, to one or more other compounds is > 75%, or a conversion of propane, if present at a molar concentration in the first hydrocarbon feed higher than that of ethane feed, to one or more other compounds is > 93%: (2b) optionally conducting online decoking in an online decoking
  • P2 is coke removed during the offline decoking interval, in mm.
  • P2(ref) is coke removed during the reference offline decoking interval, in mm
  • the reference process in step (3) may have been carried out at the olefins production plant prior to step (2).
  • P2(ref) can be measured.
  • Pl and P2 can be measured.
  • the reference hydrocarbon feed has substantially the same composition as the first hydrocarbon feed.
  • the process above can comprise, in addition to steps (1), (2), (3), and (4), the following: (5) during a plurality of quench exchanger decoking intervals, feeding a quench exchanger decoking feed into a quench exchanger inlet tube operated under quench exchanger decoking conditions; wherein: the reference process further comprises: during a plurality of reference quench exchanger decoking intervals, feeding the quench exchanger decoking feed into the quench exchanger inlet tube operated under reference quench exchanger decoking conditions; the process further comprises selecting the quench exchanger decoking conditions such that:
  • delta(R2) delta(D2(ref) + delta(D2)) - (P3 - P3(ref)) ⁇ 2 mm, where: delta(R2) ::: R2 - R2(ref), where R2 is average coke deposition rate in the quench exchanger inlet tube between two adjacent quench exchanger decoking intervals, in mm day' and R2(ref) is average coke deposition rate in the quench exchanger inlet tube in the reference process between two adjacent reference quench exchanger decoking intervals, in mm -day 1 ;
  • D2(ref) is the duration between two adjacent quench exchanger decoking intervals, in days; delta(D2) ::::: D2 - D2(ref), where D2 is the duration between two adjacent quench exchanger decoking intervals, in days;
  • P3 is average coke removed during the plurality of quench exchanger decoking intervals, in mm.
  • P3(ref) is average coke removed during the plurality of reference quench exchanger decoking intervals, in mm.
  • BB represents the change of coke deposition in the quench exchanger in step (5) relative to the reference process.
  • BB represents the change of coke deposition in the quench exchanger in step (5) relative to the reference process.
  • BB represents the change of coke deposition in the quench exchanger in step (5) relative to the reference process.
  • alow coke layer change BB in the quench exchanger -2 mm ⁇ B B ⁇ 2 mm, can be realized, thus achieving a prolonged run-length of the quench exchanger between adjacent mechanical cleaning of the quench exchanger, which can be costly and potentially dangerous.
  • step (5) can comprise one or more of the following: (i) introducing the decoking feed into the at least one of the radiant coils to produce a decoking effluent having a coil outlet temperature of > 900°C; (ii) introducing the decoking feed into the at least one of the radiant coils or into one or more quench exchanger inlets in fluid communication with the at least one of the radiant coils at a mass flux rate at the quench exchanger inlet of > 39 kg- nr 2 second' 1 ; and (iii) introducing the decoking feed into the at least one of the radiant coils while maintaining introduction of the first hydrocarbon feed into one or more of the radiant coils in the plurality of radiant coils.
  • the Figure depicts a schematic of an illustrative steam cracking furnace 100 in operation to convert a first hydrocarbon feed in line 1001 and a second hydrocarbon feed in line 1003, within one or more first radiant coils 1025 and within one or second radiant coils 1027, respectively, disposed within a radiant section 1029 of the steam cracking furnace 100, according to one or more embodiments.
  • a feed rate of the first hydrocarbon feed in line 1001 can be controlled via a first flow control device 1002 and a feed rate of the second hydrocarbon feed in line 1003 can be controlled via a second flow' control device 1004.
  • the composition of the first hydrocarbon feed in line 1001 and the composition of the second hydrocarbon feed in line 1003 can be the same or different with respect to one another.
  • at least one of the first hydrocarbon feed in line 1001 and the second hydrocarbon feed in line 1003 can include ethane, propane, or a mixture thereof.
  • the first hydrocarbon feed in line 1001 and the second hydrocarbon feed in line 1003 can each include ethane, propane, or a mixture thereof.
  • the first hydrocarbon feed in line 1001 and/or the second hydrocarbon feed in line 1003 can include 30 wt%, 40 wt%, 50 wt%, 60 wt%, 70 wt%, 75%, 80 wt%, 85 wt%, 90 wt%, 95 wt%, or more of ethane, based on a total weight of all hydrocarbons in the first hydrocarbon feed.
  • the first hydrocarbon feed in line 1001 and/or the second hydrocarbon feed in line 1003 can include 30 wt%, 40 wt%, 50 wt%, 60 wt%, 70 wt%, 75%, 80 wt%, 85 wt%, 90 wt%, 95 wt%, or more of propane, based on a total weight of all hydrocarbons in the first hydrocarbon feed.
  • the first hydrocarbon feed in line 1001 and the second hydrocarbon feed in line 1003 can include a mixture of ethane and propane.
  • a hydrocarbon feed that includes ethane and propane can include at least 75 wt% of a combined amount of ethane and propane, based on a total weight of the first hydrocarbon feed, where the amount of ethane in the ethane and propane mixture can be > 20 wt% based on the combined weight of the ethane and propane in the first hydrocarbon feed.
  • a hydrocarbon feed that includes ethane and propane can include at least 75 wt% of a combined amount of ethane and propane, based on a total weight of the first hydrocarbon feed, where the amount of propane in the ethane and propane mixture can be > 20 wt%, based on the combined weight of the ethane and propane in the first hydrocarbon feed.
  • the first hydrocarbon feed in line 1001 and the second hydrocarbon feed in line 1003 can be mixed, blended, combined, or otherwise contacted with steam in lines 1007 and 1009, respectively, to produce first and second hydrocarbon and steam mixtures tn lines 1011 and 1013, respectively.
  • the first and second hydrocarbon and steam mixtures can independently include steam in an amount in of about 10 wt% to about 95 wt%, based on the weight of the hydrocarbon and steam mixture.
  • the steam in lines 1007 and 1009 can be provided from a common source, e.g., steam in line 1005. In other embodiments, the steam in lines 1007 and 1009 can be provided from different sources.
  • a feed rate of the steam contacted with the first hydrocarbon feed in line 1001 can be controlled by a third flow control device 1008 and a feed rate of the steam contacted with the second hydrocarbon feed in line 1003 can be controlled by a fourth flow control device 1010.
  • Tire amount of steam contacted with the first and second hydrocarbon feeds in lines 1001 and 1003 can be the same or different with respect to one another.
  • the first and second mixtures in lines 1011 and 1013 can each be heated within one or more convection coils 1015 and 1017, respectively, disposed within the convection section 1019 of the steam cracking furnace 100 to produce first and second heated mixtures via lines 1021 and 1023, respectively.
  • the first and second mixtures in lines 1011 and 1013 can be heated to a temperature of 200°C, 300°C, 400°, or 450°C to 500°C, 600°C, 700°C, or 750°C within the convection section 1019.
  • the first and second heated mixtures in lines 1021 and 1023 can be further heated and subjected to steam cracking conditions within the one or more first radiant coils 1025 and within the one or more second radiant coils 1027, respectively, disposed within the radiant section 1029 of the steam cracking furnace 100 to produce first and second steam cracker effluents via lines 1031 and 1033, respectively.
  • the first radiant coil(s) 1025 and the second radiant coil(s) 1027 can be heated by a plurality of burners (four are shown - 1035, 1037, 1039, and 1041),
  • the burners 1035 and 1037 can be considered as being disposed within a first segment of the radiant section 1029 and the burners 1039 and 1041 can be considered as being disposed within a second segment of the radiant section 1029.
  • the first segment of the radiant section occupies the left half of the radiant section 1029 and the second segment of the radiant section 1029 occupies the light half of the radiant section 1029, as shown in the FIG.
  • the burners 1035, 1037, 1039, and 1041 can be operated at substantially the same firing rate such that the amount of heat produced by each burner in the first sand second segments is substantially the same. In other embodiments, during operation, one or more of the burners 1035, 1037, 1039, and 1041 can be operated at different firing rates with respect to one or more other burners such that the amount of heat produced by each burner is not substantially the same.
  • the first steam cracker effluent in line 1031 can have a first coil outlet temperature upon exiting the first radiant coil(s) 1025 and the second steam cracker effluent in line 1033 can have a second coil outlet temperature upon exiting the second radiant coil(s) 1027.
  • the first coil outlet temperature of the first steam cracker effluent in line 1031 can be measured with a first temperature measuring device, e.g., thermocouple, 1043 and the second coil outlet temperature of the second steam cracker effluent in line 1033 can be measured with a second temperature measuring device, e.g., thermocouple, 1045.
  • the feed rate of the first hydrocarbon feed in fine 1001 and the feed rate of the second hydrocarbon feed in line 1003 can be controlled based, at least in part, on the composition(s) of the first and second hydrocarbon feeds and/or the first and second coil outlet temperatures, respectively.
  • the feed rate of the first hydrocarbon feed in line 1001 can be reduced to increase the first coil outlet temperature of the first steam cracker effluent in line 1031.
  • the feed rate of the first hydrocarbon feed in line 1001 can be increased to reduce the first coil outlet temperature of the first steam cracker effluent in line 1031.
  • the feed rate of the second hydrocarbon feed in line 1003 can be controlled in a similar manner as the feed rate of the first hydrocarbon feed in line 1001.
  • the feed rate of the steam in line 1007 and the steam in line 1009 that can be contacted with the first hydrocarbon feed in line 1001 and the second hydrocarbon feed in line 1003, respectively can be controlled based, at leas t in part, on the composition(s) of the firs t and second hydrocarbon feeds and the first and second coil outlet temperatures, respectively.
  • the feed rate of the heated first and second hydrocarbon feeds introduced via lines 1021 and 1023, respectively can be increased or decreased as desired to control or otherwise adjust the first coil outlet temperature and the second coil outlet temperature as desired.
  • the feed rate of the first hydrocarbon feed in line 1001 and the feed rate of the second hydrocarbon feed in line 1003, which can be the same or different with respect to one another, can remain substantially constant during steam cracking.
  • the amount of heat produced via the burners 1035, 1037, 1039, and 1041 can be independently adjusted to control or otherwise adjust the coil-outlet-temperatures of the first and second steam cracker effluents in lines 1031 and 1033.
  • the feed rate of the steam in line 1007 and the steam in line 1009 that can be contacted with the first hydrocarbon feed in line 1001 and the second hydrocarbon feed in fine 1003, respectively, which can be the same or different with respect to one another, can also remain substantially the same or can be independently adjusted with respect to one another during steam cracking.
  • the steam cracking conditions can include, but are not limited to, one or more of: exposing the heated mixtures of the first hydrocarbon feed and steam in line (or a vapor phase product separated therefrom) to a temperature (as measured at a radiant outlet of the steam cracking furnace) of > 400°C, e.g, a temperature of about 700°C, about 800°C, or about 900 c C to about 950°C, about l,000°C, or about 1050°C, a pressure of about 10 kPa- absolute to about 500 kPa-absolute or more, and/or a steam cracking residence time of about 0.01 second to about 5 seconds, preferably from 0.01 second to 1 second, preferably from 0.01 second to 0.5 second.
  • the steam cracking conditions can be sufficient produce a steam cracker effluent and deposit coke on an inner surface of the radiant coils 1025, 102.7, where a conversion of at least one of ethane, if present at higher concentration than propane in the hydrocarbon feed, to one or more other compounds is > 75%, and a conversion of propane, if present at higher concentration than ethane in the hydrocarbon feed, to one or more other compounds is > 93%.
  • the introduction of the first hydrocarbon feed in line 1001 and/or introduction of the second hydrocarbon feed in line 1003 can be stopped by closing the flow control device 1002 and/or 1010, respectively,
  • a decoking feed that can include steam or a mixture of air and steam can be introduced into the first and/or second radiant coil(s) 1025, 1027 that does not have the first and/or second hydrocarbon feed being introduced thereto.
  • flow control device 1012 when the flow control device 1002 is closed, flow control device 1012 can be opened such that air (or other oxidant) in line 1006 can be mixed, blended, combined, or otherwise contacted with the steam in line 1007 to produce the decoking feed that can flow' through the radiant coil 1025 to produce a decoking effluent in line 1031.
  • the decoking effluent in line 1031 can be at a temperature of > 900°C, can be introduced into the radiant coil 1025 and/or a quench exchanger inlet 1049 of a quench exchanger 1051 at a mass flux at the quench exchanger inlet of > 39 kg m" 2 second 4 , introduced into the radiant coil 1025 while How of the first hydrocarbon feed in line 1003 is maintained, or any combination thereof.
  • flow control device 1018 when the flow control device 1004 is closed, flow control device 1018 can be opened such that air (or other oxidant) in line 1016 can be mixed, blended, combined, or otherwise contacted with the steam in line 1009 to produce the decoking feed that can flow- through the radiant coil 1027 to produce a decoking effluent in line 1033.
  • the decoking effluent in line 1033 can be at a temperature of > 900°C, can be introduced into the radiant coil 1027 and/or a quench exchanger inlet 1049 of the quench exchanger 1051 at a mass flux at the quench exchanger inlet of > 39 kg m' 2 -second -1 , introduced into the radiant coil 1027 while flow of the first hydrocarbon feed in line 1001 is maintained, or any combination thereof.
  • one or more quench mediums via line 1047 can be introduced into the inlet 1049 of the quench exchanger 1051 and can contact the decoking effluent, and if present, steam cracker effluent to produce a cooled effluent via line 1053.
  • the quench exchanger 1051 can be an indirect heat exchange stage such that heat can be indirection transferred from the decoking effluent, and if present, steam cracker effluent to produce the cooled effluent via line 1053.
  • the quench exchanger 1051 can include a direct contact exchange stage and an indirect heat exchange stage.
  • the quench medium in line 1047 that can be contacted with the steam cracker effluent and/or the decoking effluent can be or can include a utility fluid.
  • the utility fluid can be the same or similar to the utility fluids described in U.S. Patent Nos. 9,090,836; 9,637,694; and 9,777,227; and International Patent Application Publication No. WO 2018/111574.
  • Suitable steam crackers, process gas recovery configurations, other equipment, and process conditions can include those disclosed in U.S. Patent Nos,: 6,419,885; 7,560,019; 7,993,435; 8,105,479; 8,197,668; 8,882,991; 9,637,694; 9,777,227; U.S. Patent Application Publication Nos. : 2014/0061096; 2014/0357923; 2016/0376511; 2018/0170832;
  • Suitable dividing walls that can optionally be disposed between two or more segments can include those disclosed in U.S. Patent No. 7,718,052.
  • the first and/or second hydrocarbon feeds in lines 1001 and 1003, respectively can be or can include, but are not limited to, lighter hydrocarbons such as C 1 -C 5 alkanes, naphtha distillate, aromatic hydrocarbons, or any mixture thereof.
  • lighter hydrocarbons such as C 1 -C 5 alkanes, naphtha distillate, aromatic hydrocarbons, or any mixture thereof.
  • two or more hydrocarbon feeds can be introduced into the steam cracker and the two hydrocarbon feeds can be the same or different with respect to one another.
  • first and/or second hydrocarbon feeds in line 1001 and 1003, respectively can be or can include, but are not limited to, relatively high molecular weight hydrocarbons (“heavy feedstocks”), such as those that produce a relatively large amount of steam cracker tar (“SCT”) during steam cracking.
  • relatively high molecular weight hydrocarbons such as those that produce a relatively large amount of steam cracker tar (“SCT”) during steam cracking.
  • heavy feedstocks can include one or more of steam cracked gas oil and residues, gas oils, heating oil, j et fuel, diesel, kerosene, coker naphtha, steam cracked naphtha, catalytically cracked naphtha, hydrocrackate, reformate, raffinate reformate, Fischer-Tropsch liquids, Fischer-Tropsch gases, distillate, crude oil, atmospheric pipestill bottoms, vacuum pipestill streams including bottoms, gas oil condensates, heavy non-virgin hydrocarbon streams from refineries, vacuum gas oils, heavy gas oil, naphtha contaminated with crude, atmospheric residue, heavy residue, (fi/residue admixture, naphtha/residue admixture, gas oil/residue admixture, crude oil, or any mixture thereof.
  • the first hydrocarbon feed in line 1001 can include one or more lighter hydrocarbons and the second hydrocarbon feed in line 1003 can include one or more heavy feedstocks.
  • the second hydrocarbon feed in line 1003 can have a nominal final boiling point > 315°C, > 399°C, > 454°C, or > 510°C. Nominal final boiling point means the temperature at which 99.5 wt% of a particular sample has reached its boiling point. Suitable hydrocarbon feeds can be or can include those described in U.S.
  • the system 100 can include one or more vapor/liquid separators (sometimes referred to as flash pot or flash drum) integrated therewith.
  • the vapor-liquid separator can be configured to upgrade the first hydrocarbon feed, e.g., by upgrading the hydrocarbon and steam mixture, upstream of the radiant section 1029.
  • the vapor-liquid separator with the furnace when the first hydrocarbon feed includes > 1 wt% of non-volatiles, e.g., > 5 wt%, such as about 5 wt% to about 50 wt% of non-volatiles having a nominal boiling point of > 760°C.
  • the non-volatiles include asphaltenes, such as > about 0.1 wt% asphaltenes based on the weight of the first hydrocarbon feed, e.g , > about 5 wt%.
  • Conventional vapor/liquid separation devices can be utilized to do this, though the process and systems disclosed herein are not limited thereto.
  • Examples of such conventional vapor/liquid separation devices can include those disclosed in U.S. Patent Nos. 7,138,047; 7,090,765; 7,097,758; 7,820,035; 7,311,746; 7,220,887; 7,244,871; 7,247,765; 7,351,872; 7,297,833; 7,488,459; 7,312,371 ; 6,632,351; 7,578,929; and 7,235,705.
  • a vapor phase can be separated from the first hydrocarbon feed in the vapor/liquid separation device.
  • the separated vapor phase can be conducted away from the vapor/liquid separator to the radiant coil(s) for steam cracking.
  • the liquid-phase separated from the first hydrocarbon feed can be conducted away from the vapor/liquid separation device, e.g., for storage and/or further processing.
  • Example 1 ethane was steam cracked at a conversion to other compounds of 75% to 80% and a steam-air decoking procedure was periodically used that ensured a mass flux at the quench exchanger inlet exceeding 39 kg m -2 - second -3 as the steam-air mixture entered into the inlet cones of a transfer line exchanger.
  • a steam cracking run length of 19 to 28 days between implementation of the steam-air decoking procedure was accomplished with the coke sufficiently removed during each steam-air decoking procedure such that coke build-up was avoided.
  • Example 2 ethane was steam cracked at a conversion to other compounds of 75% to 82% under steam cracking run lengths that were greater than 20 days between the periodic implementation of a steam-air decoking procedure. Radiant tubes composed of alumina were installed to enable the steam cracking run lengths and a sufficient amount of coke was removed during each steam-air decoking procedure such that coke build-up was avoided.
  • Example 3 ethane was steam cracked at a conversion to other compounds of 75% to 82% wider steam cracking run lengths that were greater than 20 days between the periodic implementation of a steam-air decoking procedure that used a coil-outlet-temperature of > 900°C.
  • the steam-air decoking procedure in this example was able to remove the coke and avoided accumulation of coke over multiple steam cracking run lengths.
  • Example 4 ethane was steam cracked within a plurality of radiant coils disposed in a steam cracker and a conversion of ethane to other compounds of 80% was obtained and sustained for mon ths.
  • an online decoking process that only implemented a steam-only decoking procedure on a portion of the radiant coils at a time while steam cracking continued in the remaining radiant coils was implemented.
  • less than all the radiant coils underwent decoking at any given time while the other radiant coils continued to receive the first hydrocarbon feed for steam cracking.
  • steam-air decoking in which the steam-air decoking effluent had a temperature of > 900°C was only used once during a nearly 7 month run length.

Abstract

L'invention concerne des procédés de vapocraquage d'hydrocarbures. Le procédé peut consister à introduire un hydrocarbure qui peut comprendre de l'éthane, du propane ou un mélange de ceux-ci dans des bobines rayonnantes dans des conditions de vapocraquage qui produisent un effluent de vapocraqueur et déposent le coke sur une surface interne de celles-ci. Une conversion d'éthane peut être ≥ 75 % ou une conversion de propane peut être ≥ 93 %. L'introduction des hydrocarbures dans au moins l'une des bobines rayonnantes peut être arrêtée périodiquement. Une charge de décokage peut être introduite dans la au moins une des bobines rayonnantes dans des conditions de procédé de décokage qui peuvent comprendre : (i) un effluent de décokage qui peut avoir une température de sortie de bobine > 900 °C, (ii) l'introduction de la charge de décokage à un débit massique au niveau de l'entrée d'échangeur de trempe > 39 kg m-2 seconde-1 et/ou (iii) l'introduction de la charge de décokage tout en maintenant l'introduction de la première charge d'hydrocarbures dans une ou plusieurs des bobines rayonnantes de la pluralité de bobines rayonnantes.
PCT/US2022/080171 2021-12-06 2022-11-18 Procédés et systèmes de vapocraquage de charges d'hydrocarbures WO2023107815A1 (fr)

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