WO2004005431A1 - Conversion de flux brouillard en flux annulaire pour application de craquage thermique - Google Patents

Conversion de flux brouillard en flux annulaire pour application de craquage thermique Download PDF

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Publication number
WO2004005431A1
WO2004005431A1 PCT/US2003/020375 US0320375W WO2004005431A1 WO 2004005431 A1 WO2004005431 A1 WO 2004005431A1 US 0320375 W US0320375 W US 0320375W WO 2004005431 A1 WO2004005431 A1 WO 2004005431A1
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WO
WIPO (PCT)
Prior art keywords
mist
flow
flash drum
stream
mist stream
Prior art date
Application number
PCT/US2003/020375
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English (en)
Inventor
Richard C. Stell
Arthur R. Dinicolantonio
Jennifer L. Bancroft
George Stephens
Original Assignee
Exxonmobil Chemical Patents Inc
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Priority claimed from US10/189,618 external-priority patent/US7097758B2/en
Priority claimed from US10/188,901 external-priority patent/US7090765B2/en
Priority claimed from US10/188,461 external-priority patent/US7138047B2/en
Application filed by Exxonmobil Chemical Patents Inc filed Critical Exxonmobil Chemical Patents Inc
Priority to AU2003281371A priority Critical patent/AU2003281371A1/en
Priority to DE60321239T priority patent/DE60321239D1/de
Priority to EP03742280A priority patent/EP1639060B1/fr
Priority to JP2004519667A priority patent/JP4403071B2/ja
Priority to AT03742280T priority patent/ATE396244T1/de
Priority to CA2489876A priority patent/CA2489876C/fr
Publication of WO2004005431A1 publication Critical patent/WO2004005431A1/fr

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Classifications

    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F28—HEAT EXCHANGE IN GENERAL
    • F28F—DETAILS OF HEAT-EXCHANGE AND HEAT-TRANSFER APPARATUS, OF GENERAL APPLICATION
    • F28F9/00—Casings; Header boxes; Auxiliary supports for elements; Auxiliary members within casings
    • F28F9/02—Header boxes; End plates
    • F28F9/026—Header boxes; End plates with static flow control means, e.g. with means for uniformly distributing heat exchange media into conduits
    • F28F9/0265—Header boxes; End plates with static flow control means, e.g. with means for uniformly distributing heat exchange media into conduits by using guiding means or impingement means inside the header box
    • 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
    • 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
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/10—Feedstock materials
    • C10G2300/1022—Fischer-Tropsch products
    • 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
    • C10G2300/1033—Oil well production fluids
    • 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
    • C10G2300/104—Light gasoline having a boiling range of about 20 - 100 °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
    • C10G2300/10—Feedstock materials
    • C10G2300/1037—Hydrocarbon fractions
    • C10G2300/1044—Heavy gasoline or naphtha having a boiling range of about 100 - 180 °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
    • C10G2300/10—Feedstock materials
    • C10G2300/1037—Hydrocarbon fractions
    • C10G2300/1048—Middle distillates
    • C10G2300/1051—Kerosene having a boiling range of about 180 - 230 °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
    • C10G2300/10—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
    • C10G2300/10—Feedstock materials
    • C10G2300/1037—Hydrocarbon fractions
    • C10G2300/1048—Middle distillates
    • C10G2300/1059—Gasoil having a boiling range of about 330 - 427 °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
    • C10G2300/10—Feedstock materials
    • C10G2300/107—Atmospheric residues having a boiling point of at least about 538 °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
    • C10G2300/10—Feedstock materials
    • C10G2300/1074—Vacuum distillates
    • 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
    • C10G2300/1077—Vacuum residues
    • 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
    • C10G2300/30—Physical properties of feedstocks or products
    • C10G2300/301—Boiling range
    • 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
    • C10G2300/80—Additives
    • C10G2300/805—Water
    • C10G2300/807—Steam
    • 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
    • C10G2400/20—C2-C4 olefins

Definitions

  • the present invention relates to converting mist flow to annular flow in a steam cracking application to enhance the flash drum removal efficiency of non- volatile hydrocarbons.
  • Steam cracking has long been used to crack various hydrocarbon feedstocks into olefins.
  • Conventional steam cracking utilizes a furnace which has two main sections: a convection section and a radiant section.
  • the hydrocarbon feedstock typically enters the convection section of the furnace as a liquid (except for light feedstocks which enter as a vapor) wherein it is typically heated and vaporized by indirect contact with hot flue gas from the radiant section and by direct contact with steam.
  • the vaporized feedstock is then introduced into the radiant section where the cracking takes place.
  • the resulting olefins leave the furnace for further downstream processing, such as quenching.
  • U.S. Patent 3,617,493 which is incorporated herein by reference, discloses the use of an external vaporization drum for the crude oil feed and discloses the use of a first flash to remove naphtha as vapor and a second flash to remove vapors with a boiling point between 450 and 1100°F (230 and 600°C).
  • the vapors are cracked in the pyrolysis furnace into olefins and the separated liquids from the two flash tanks are removed, stripped with steam, and used as fuel.
  • U.S. Patent 3,718,709 which is incorporated herein by reference, discloses a process to minimize coke deposition. It provides preheating of heavy feed inside or outside a pyrolysis furnace to vaporize about 50% of the heavy feed with superheated steam and the removal of the residual liquid. The vaporized hydrocarbons are subjected to cracking.
  • U.S. Patent 5,190,634 which is incorporated herein by reference, discloses a process for inhibiting coke formation in a furnace by preheating the feed in the presence of a small, critical amount of hydrogen in the convection section. The presence of hydrogen in the convection section inhibits the polymerization reaction of the hydrocarbons thereby inhibiting coke formation.
  • U.S. Patent 5,580,443 which is incorporated herein by reference, discloses a process wherein the feed is first preheated and then withdrawn from a preheater in the convection section of the pyrolysis furnace. This preheated feedstock is then mixed with a predetermined amount of steam (the dilution steam) and is then introduced into a gas-liquid separator to separate and remove a required proportion of the non-volatiles as liquid from the separator. The separated vapor from the gas-liquid separator is returned to the pyrolysis furnace for super-heating and cracking.
  • a predetermined amount of steam the dilution steam
  • the present inventors have recognized that in using a flash to separate heavy non-volatile hydrocarbons from the lighter volatile hydrocarbons which can be cracked in the pyrolysis furnace, it is important to maximize the non-volatile hydrocarbon removal efficiency. Otherwise, heavy, coke-forming non-volatile hydrocarbons could be entrained in the vapor phase and carried overhead into the furnace creating coking problems.
  • a minimum gas flow velocity of about 100 ft/sec (30 m/sec) has been found to be desirable.
  • the flash stream entering the flash drum usually comprises a vapor phase with liquid (the non- volatile hydrocarbon components) entrained as fine droplets.
  • the flash stream is two-phase flow.
  • this two-phase flow is in a "mist flow" regime.
  • fine droplets comprising non-volatile heavy hydrocarbons are entrained in the vapor phase, which is the volatile hydrocarbons and optionally steam.
  • the two-phase mist flow presents operational problems in the flash drum because at these high gas flow velocities the fine droplets comprising non- volatile hydrocarbons do not coalesce and, therefore, cannot be efficiently removed as liquid phase from the flash drum. It was found that, at a gas flow of 100 feet/second (30 m/s) velocity, the flash drum can only remove heavy non- volatile hydrocarbons at a low efficiency of about 73%.
  • the present invention provides a process for the effective removal of non-volatile hydrocarbon liquid from the volatile hydrocarbon vapor in the flash drum.
  • the present invention provides a process that converts a "mist flow” regime to an “annular flow” regime and hence significantly enhances the separation of non- volatile and volatile hydrocarbons in the flash drum.
  • the present invention provides a process for treating a heavy hydrocarbon feedstock which comprises preheating the heavy hydrocarbon feedstock, optionally comprising steam, in the convection section of a steam cracking furnace to vaporize a portion of the feedstock and form a mist stream comprising liquid droplets comprising non- volatile hydrocarbon in volatile hydrocarbon vapor, optionally with steam, the mist stream upon leaving the convection section having a first flow velocity and a first flow direction, treating the mist stream to coalesce the liquid droplets, the treating comprising first reducing the flow velocity followed by changing the flow direction, separating at least a portion of the liquid droplets from the vapor in a flash drum to form a vapor phase and a liquid phase, and feeding the vapor phase to the thermal cracking furnace.
  • the vapor phase is fed to a lower convection section and radiant section of the steam cracking furnace.
  • the treating of the mist flow comprises reducing the flow velocity of the mist stream.
  • the mist stream flow velocity can be reduced by at least 40%.
  • the mist stream velocity can be reduced to less than 60 feet/second (18 m/s).
  • the mist stream flow velocity is reduced and then is subjected to at least one centrifugal force, such that the liquid droplets coalesce.
  • the mist stream can be subjected to at least one change in its flow direction.
  • the mist stream droplets are coalesced in a distance of less than 25 pipe diameters, preferably in less than 8 inside pipe diameters, and most preferably in less than 4 inside pipe diameters.
  • the mist stream flows through a flow path that comprises at least one bend.
  • the flow path can further comprise at least one expander.
  • the flow path comprises multiple bends.
  • the bends can be at least 45 degrees, 90 degrees, 180 degrees, or combination thereof.
  • the mist stream is converted into an annular flow stream.
  • the flash efficiency can be increased to at least 85%, preferably at least 95%, more preferably at least 99%, and most preferably at least 99.8%.
  • the mist stream can be converted into an annular flow stream in less than 50 pipe diameters, preferably in less than 25 pipe diameters, more preferably in less than 8 pipe diameters, and most preferably in less than 4 pipe diameters.
  • a process for treating a hydrocarbon feedstock comprises: preheating a hydrocarbon feedstock, optionally including steam, in the convection section of a thermal cracking furnace to vaporize a portion of the feedstock and form a mist stream comprising liquid droplets comprising hydrocarbon in hydrocarbon vapor, optionally with steam, the mist stream upon leaving the convection section having a first flow velocity and a first flow direction, treating the mist stream to coalesce the liquid droplets, separating at least a portion of the liquid droplets from the vapor in a flash drum to form a vapor phase and a liquid phase, and feeding the vapor phase to the steam cracking furnace, wherein the flash comprises introducing the mist stream containing coalesced liquid droplets into a flash drum, removing the vapor phase from at least one upper flash drum outlet and removing the liquid phase from at least one lower flash drum outlet.
  • the present invention also discloses another embodiment in which the mist stream is tangentially introduced into the flash drum through at least one
  • Figure 1 illustrates a schematic flow diagram of a steam cracking process.
  • Figure 2 illustrates the design of expanders.
  • Figure 3 illustrates the design of a flash drum in accordance with the present invention.
  • a reference to a compound or component includes the compound or component by itself, as well as in combination with other compounds or components, such as mixtures of compounds.
  • Mist flow refers to a two-phase flow where tiny droplets of liquid are dispersed in the vapor phase flowing through a pipe. In clear pipe, mist flow looks like fast moving small rain droplets.
  • Annular flow refers to a two-phase flow where liquid flows as streams on the inside surface of a pipe and the vapor flows in the core of the pipe.
  • the vapor flow velocity of annular flow is about 20 feet/second (6 m/s).
  • a layer of fast moving liquid is observed. Few droplets of liquid are observed in the core of the vapor flow.
  • the change from mist to annular flow usually includes a transition period where mist and annular flow exist together.
  • the feedstock comprises at least two components: volatile hydrocarbons and non-volatile hydrocarbons.
  • the mist flow in accordance with the present invention, comprises fine droplets of non-volatile hydrocarbons entrained in volatile hydrocarbon vapor.
  • the non- volatile removal efficiency is calculated as follows:
  • Non-volatiles in the hydrocarbon entering the flash (mass/time)
  • Hydrocarbon is the sum of vapor (generally volatile) and liquid
  • Non-volatile hydrocarbon (generally non-volatile) hydrocarbon.
  • Non-volatiles are measured as follows: The boiling point distribution of the hydrocarbon feed is measured by Gas
  • Non-volatiles are the fraction of the hydrocarbon with a nominal boiling point above 1100°F (590°C) as measured by ASTM D-6352-98. This invention works very well with non- volatiles having a nominal boiling point above 1400°F (760°C).
  • a process for cracking a hydrocarbon feedstock 10 of the present invention as illustrated in Figure 1 comprises preheating a hydrocarbon feedstock by a bank of exchanger tubes 2, with or without the presence of water 11 and steam 12 in the upper convection section 1 of a steam cracking furnace 3 to vaporize a portion of the feedstock and to form a mist stream 13 comprising liquid droplets comprising non-volatile hydrocarbons in volatile hydrocarbon/steam vapor.
  • the further preheating of the feedstock/water/steam mixture can be carried out through a bank of heat exchange tubes 6.
  • the mist stream upon leaving the convection section 14 has a first flow velocity and a first flow direction.
  • the process also comprises treating the mist stream to coalesce the liquid droplets, separating at least a portion of the liquid droplets from the hydrocarbon vapor in a flash 5 to fonn a vapor phase 15 and a liquid phase 16, and feeding the vapor phase 8 to the lower convection section and the radiant section of the thermal cracking furnace.
  • the feedstock is a hydrocarbon. Any hydrocarbon feedstock having heavy non- volatile heavy ends can advantageously be utilized in the process.
  • feedstock could comprise, by way of non-limiting examples, one or more of steam cracked gas oil and residues, gas oils, heating oil, jet fuel, diesel, kerosene, gasoline, coker naphtha, steam cracked naphtha, catalytically cracked naphtha, hydrocrackate, reformate, raffinate reformate, Fischer-Tropsch liquids, Fischer-Tropsch gases, natural gasoline, distillate, virgin naphtha, crude oil, atmospheric pipestill bottoms, vacuum pipestill streams including bottoms, wide boiling range naphtha to gas oil condensates, heavy non-virgin hydrocarbon streams from refineries, vacuum gas oils, heavy gas oil, naphtha contaminated with crude, atmospheric resid, heavy residium, C4's/residue admixture, and naphtha residue admixture.
  • the heavy hydrocarbon feedstock has a nominal end boiling point of at least 600°F (310°C).
  • the preferred feedstocks are low sulfur waxy resids, atmospheric resids, and naphthas contaminated with crude. The most preferred is resid comprising 60-80% components having boiling points below 1100°F
  • the heavy hydrocarbon feedstock is preheated in the upper convection section of the furnace 1.
  • the feedstock may optionally be mixed with steam before preheating or after preheating (e.g., after preheating in preheater 2) in a sparger 4.
  • the preheating of the heavy hydrocarbon can take any form known by those of ordinary skill in the art.
  • the heating comprises indirect contact of the feedstock in the convection section of the furnace with hot flue gases from the radiant section of the furnace. This can be accomplished, by way of non-limiting example, by passing the feedstock through a bank of heat exchange tubes 2 located within the upper convection section 1 of the pyrolysis furnace 3.
  • the preheated feedstock 14 before the control system 6 has a temperature between 600 and 950°F (310 and 510°C).
  • the temperature of the heated feedstock is about 700 to 920°F (370 to 490°C), more preferably between 750 and 900°F (400 and 480°C) and most preferably between 810 and 890°F (430 and 475°C).
  • a portion of the feedstock is vaporized and a mist stream is formed comprising liquid droplets comprising non-volatile hydrocarbon in volatile hydrocarbon vapor, with or without steam.
  • the liquid is present as fine droplets comprising non-volatile hydrocarbons entrained in the vapor phase.
  • This two- phase mist flow is extremely difficult to separate into liquid and vapor. It is necessary to coalesce the fine mist into large droplets before entering the flash drum.
  • flow velocities of 100 ft/sec or greater are normally necessary to practically effect the transfer of heat from the hot flue gases and reduce coking in convection section.
  • the mist stream is treated to coalesce the liquid droplets.
  • the treating comprises reducing the velocity of the mist stream. It is found that reducing the velocity of the mist stream leaving convection section 14 before the flash 5 (location 9 in Figure 1) helps coalesce the mist stream. It is prefened to reduce the mist stream velocity by at least 40%, preferably at least 70%, more preferably at least 80%, and most preferably 85%.
  • Annular flow can be achieved by reducing flow velocity due to friction in large diameter pipes.
  • a substantial length of piping is necessary.
  • the reduction of velocity of the mist flow stream is accomplished by including in the piping outside the convection section one or more expanders.
  • at least one expander is believed necessary to achieve the prefened reduction of velocity.
  • the expander can be a simple cone shape 101 or manifolds 102 as illustrated in Figure 2. With the cross section area of the outlet end greater than the cross section area of the sum of all the inlets.
  • the mist flow is subject to at least one expander first and then to at least one bend, preferably multiple bends, with various degrees. When the mist flow stream flows through the expander(s), the velocity will decrease.
  • the number of expanders can vary according to the amount of velocity reduction required. As a general practice rule, more expanders can be used if high velocity reduction is required. Any expanders, for example, a manifold, can be used in the present invention.
  • the present invention enables the conversion of mist flow to annular flow in significantly less piping.
  • the mist stream droplets are coalesced in less than 25, more preferably less than 8, and most preferably less than 4 inside pipe diameters.
  • treating of the mist stream comprises subjecting the mist stream to at least one expander and one centrifugal force downstream of the expander such that the liquid droplets will coalesce. This can be accomplished by subjecting the mist stream to at least one change in its flow direction.
  • the piping outside the convection section is designed to include at least one bend in order to convert a mist flow stream into an annular flow stream. The bends can be located throughout the piping downstream of the expander between the control system 17 and just before the flash dram.
  • Different angle bends can be used. For example, 45 degree, 90 degree, and/or 180 degree bends can be used in the present invention. After an expander, the 180 degree bend provides the most vapor core velocity reduction.
  • the process includes at least one bend of at least 45 degrees.
  • the process includes at least one bend of 90 degrees.
  • the process includes at least one bend of 180 degrees. It is found that using the inventions disclosed herein, a flash drum removal efficiency of at least 85% can be accomplished. A prefened flash efficiency of at least 95%, a more prefened flash efficiency of at least 99%, and a most prefened flash efficiency of at least 99.8% can also be achieved using the present invention.
  • Flash is normally carried out in at least one flash drum.
  • the vapor phase stream is removed from at least one upper flash drum outlet and the liquid phase is removed from at least one lower flash drum outlet.
  • two or more lower flash drum outlets are present in the flash for liquid phase removal.
  • a process for treating a hydrocarbon feedstock comprises: heating a liquid hydrocarbon feedstock in the convection section of a thermal cracking furnace to vaporize a portion of the feedstock and form a mist stream comprising liquid droplets comprising hydrocarbon in hydrocarbon vapor, with or without steam, the mist stream upon leaving the convection section having a first flow velocity and a first flow direction, treating the mist stream to coalesce the liquid droplets, separating at least a portion of the liquid droplets from the hydrocarbon vapor in a flash drum to form a vapor phase and a liquid phase, and feeding the vapor phase to the radiant section of the steam cracking furnace, wherein the flash comprises introducing the stream containing coalesced liquid droplets into a flash drum, removing the vapor phase from at least one upper flash drum outlet and removing the liquid phase from at least one lower flash drum outlet.
  • a flash drum in accordance to the present invention is illustrated in
  • the flash stream 9 of Figure 1 enters the flash dram tangentially through at least one tangential flash drum inlet 201 of Figure 3.
  • the tangential inlets are level or slightly downward flow.
  • the non-volatile hydrocarbon liquid phase will form an outer annular flow along the inside flash drum wall and the volatile vapor phase will initially form an inner core and then flow upwardly in the flash dram.
  • the tangential entries should be the same direction as the Coriolis effect.
  • the liquid phase is removed from one bottom flash drum outlet.
  • a side flash drum outlet (203) or a vortex breaker can be added to prevent a vortex forming in the outlet.
  • the upward inner core flow of vapor phase is diverted around an annular baffle 202 inside the flash drum and removed from at least one upper flash drum outlet 204.
  • the baffle is installed inside the flash drum to further avoid and reduce any portion of the separated liquid phase, flowing downwards in the flash drum, from being entrained in the upflow vapor phase in the flash drum.
  • the vapor phase preferably, flows to the lower convection section 7 of Figure 1 and through crossover pipes 8 to the radiant section of the pyrolysis furnace.
  • Example 1 The invention is illustrated by the following Example, which is provided for the purpose of representation, and is not to be construed as limiting the scope of the invention. Unless stated otherwise, all percentages, parts, etc., are by weight.
  • Example 1 Example 1
  • Annular flow can be effected by reducing the bulk flow velocity and allowing sufficient time and friction for coalescing of droplets. After the bulk velocity is reduced, roughly 100 pipe flow diameters are required to coalesce drops. Air/water flow tests were conducted to determine how to produce annular flow in less than 100 pipe diameters.
  • Two 6 HP blowers produced a high velocity gas in 2" ID pipe. The air from the two blowers combine in a Y-fitting and flow into the 2" ID clear pipe. Just before the clear pipe is a T-fitting where water is added to produce the mist flow.
  • An anemometer at the end of the piping system measures the fluid velocity.
  • Test 2 showed that a bend alone at high velocity does not coalesce droplets and may even produce a finer mist.
  • Tests 3 and 4 showed that an expander alone did not coalesce droplets enough even after 75 pipe diameters of the larger diameter pipe.
  • Tests 5 and 6 showed that expanders followed by bends with short lengths of straight pipe did coalesce droplets. The larger the expanders followed by bends, the more complete the droplet coalescing into annular and even stratified flow.

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  • Chemical & Material Sciences (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Engineering & Computer Science (AREA)
  • Thermal Sciences (AREA)
  • Physics & Mathematics (AREA)
  • Organic Chemistry (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • General Chemical & Material Sciences (AREA)
  • General Engineering & Computer Science (AREA)
  • Mechanical Engineering (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
  • Separating Particles In Gases By Inertia (AREA)
  • Organic Low-Molecular-Weight Compounds And Preparation Thereof (AREA)
  • Lubricants (AREA)

Abstract

L'invention concerne un procédé visant à améliorer l'efficacité de séparation des produits non volatils dans un ballon de détente de système de craquage à la vapeur. Le flux de gaz de l'unité de convection est converti de flux brouillard en flux annulaire avant l'arrivée dans le ballon de détente, ce qui permet d'accroître l'efficacité de séparation. Pour cette conversion, on soumet d'abord le flux de gaz au moins à un dispositif d'expansion puis à des courbures selon des degrés différents, contraignant le flux à changer de direction au moins une fois. La conversion considérée contribue à la coalescence des fines gouttelettes de liquide et donc à leur séparation depuis la phase vapeur.
PCT/US2003/020375 2002-07-03 2003-06-27 Conversion de flux brouillard en flux annulaire pour application de craquage thermique WO2004005431A1 (fr)

Priority Applications (6)

Application Number Priority Date Filing Date Title
AU2003281371A AU2003281371A1 (en) 2002-07-03 2003-06-27 Converting mist flow to annular flow in thermal cracking application
DE60321239T DE60321239D1 (de) 2003-06-27 2003-06-27 Verfahren zur umwandlung von nebelführung zu annularen entweichungen in thermischen krackverfahren
EP03742280A EP1639060B1 (fr) 2002-07-03 2003-06-27 Conversion de flux brouillard en flux annulaire pour application de craquage thermique
JP2004519667A JP4403071B2 (ja) 2002-07-03 2003-06-27 熱分解法におけるミスト流の環状流への変換
AT03742280T ATE396244T1 (de) 2002-07-03 2003-06-27 Verfahren zur umwandlung von nebelführung zu annularen entweichungen in thermischen krackverfahren
CA2489876A CA2489876C (fr) 2002-07-03 2003-06-27 Conversion de flux brouillard en flux annulaire pour application de craquage thermique

Applications Claiming Priority (6)

Application Number Priority Date Filing Date Title
US10/188,901 2002-07-03
US10/188,461 2002-07-03
US10/189,618 US7097758B2 (en) 2002-07-03 2002-07-03 Converting mist flow to annular flow in thermal cracking application
US10/89,618 2002-07-03
US10/188,901 US7090765B2 (en) 2002-07-03 2002-07-03 Process for cracking hydrocarbon feed with water substitution
US10/188,461 US7138047B2 (en) 2002-07-03 2002-07-03 Process for steam cracking heavy hydrocarbon feedstocks

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PCT/US2003/020378 WO2004005433A1 (fr) 2002-07-03 2003-06-27 Procede de vapocraquage de charges d'hydrocarbures lourds
PCT/US2003/020377 WO2004005432A1 (fr) 2002-07-03 2003-06-27 Procede de craquage d'une charge d'hydrocarbure avec substitution d'eau

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PCT/US2003/020377 WO2004005432A1 (fr) 2002-07-03 2003-06-27 Procede de craquage d'une charge d'hydrocarbure avec substitution d'eau

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JP (3) JP4387301B2 (fr)
KR (2) KR100979027B1 (fr)
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US7097758B2 (en) 2002-07-03 2006-08-29 Exxonmobil Chemical Patents Inc. Converting mist flow to annular flow in thermal cracking application
US7138047B2 (en) 2002-07-03 2006-11-21 Exxonmobil Chemical Patents Inc. Process for steam cracking heavy hydrocarbon feedstocks
JP2008500444A (ja) * 2004-05-21 2008-01-10 エクソンモービル・ケミカル・パテンツ・インク 残留油を含む炭化水素原料の熱分解に用いられる蒸気／液体分離装置
US7776286B2 (en) * 2004-07-14 2010-08-17 Exxonmobil Chemical Patents Inc. Process for reducing fouling from flash/separation apparatus during cracking of hydrocarbon feedstocks
US7972498B2 (en) 2005-10-20 2011-07-05 Exxonmobil Chemical Patents Inc. Resid processing for steam cracker feed and catalytic cracking
US8115042B2 (en) 2006-12-21 2012-02-14 Exxonmobil Chemical Patents Inc. Oligomerisation of olefins

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US7247765B2 (en) 2004-05-21 2007-07-24 Exxonmobil Chemical Patents Inc. Cracking hydrocarbon feedstock containing resid utilizing partial condensation of vapor phase from vapor/liquid separation to mitigate fouling in a flash/separation vessel
US7297833B2 (en) 2004-05-21 2007-11-20 Exxonmobil Chemical Patents Inc. Steam cracking of light hydrocarbon feedstocks containing non-volatile components and/or coke precursors
US7358413B2 (en) 2004-07-14 2008-04-15 Exxonmobil Chemical Patents Inc. Process for reducing fouling from flash/separation apparatus during cracking of hydrocarbon feedstocks
US7312371B2 (en) 2004-05-21 2007-12-25 Exxonmobil Chemical Patents Inc. Steam cracking of hydrocarbon feedstocks containing non-volatile components and/or coke precursors
US7402237B2 (en) 2004-10-28 2008-07-22 Exxonmobil Chemical Patents Inc. Steam cracking of hydrocarbon feedstocks containing salt and/or particulate matter
US7311746B2 (en) 2004-05-21 2007-12-25 Exxonmobil Chemical Patents Inc. Vapor/liquid separation apparatus for use in cracking hydrocarbon feedstock containing resid
US7351872B2 (en) 2004-05-21 2008-04-01 Exxonmobil Chemical Patents Inc. Process and draft control system for use in cracking a heavy hydrocarbon feedstock in a pyrolysis furnace
US7481871B2 (en) 2004-12-10 2009-01-27 Exxonmobil Chemical Patents Inc. Vapor/liquid separation apparatus
US7488459B2 (en) 2004-05-21 2009-02-10 Exxonmobil Chemical Patents Inc. Apparatus and process for controlling temperature of heated feed directed to a flash drum whose overhead provides feed for cracking
CN101027378B (zh) * 2004-10-08 2011-01-19 国际壳牌研究有限公司 由费-托合成产物制备低级烯烃的方法
KR100931792B1 (ko) 2007-05-25 2009-12-11 주식회사 엘지화학 탄화수소 수증기 열분해용 촉매, 그의 제조방법 및 이를이용한 올레핀의 제조방법
ITMI20071209A1 (it) * 2007-06-15 2008-12-16 Eni Spa Processo per la purificazione di una corrente acquosa proveniente dalla reazione di fischer-tropsch
KR100999304B1 (ko) 2007-07-05 2010-12-08 주식회사 엘지화학 올레핀 제조용 탄화수소 열분해 방법
WO2009025640A1 (fr) * 2007-08-21 2009-02-26 Exxonmobil Chemical Patents Inc. Procédé et appareil de craquage à la vapeur de charges d'hydrocarbures
US8882991B2 (en) 2009-08-21 2014-11-11 Exxonmobil Chemical Patents Inc. Process and apparatus for cracking high boiling point hydrocarbon feedstock
US8940950B2 (en) 2010-12-10 2015-01-27 Exxonmobil Chemical Patents Inc. Method and apparatus for obtaining aromatics from diverse feedstock
US9181146B2 (en) 2010-12-10 2015-11-10 Exxonmobil Chemical Patents Inc. Process for the production of xylenes and light olefins
WO2013169774A2 (fr) 2012-05-07 2013-11-14 Phononic Devices, Inc. Composant d'échangeur de chaleur thermoélectrique comprenant un couvercle d'étalement de la chaleur protecteur et une résistance d'interface thermique optimale
US20130291555A1 (en) 2012-05-07 2013-11-07 Phononic Devices, Inc. Thermoelectric refrigeration system control scheme for high efficiency performance
US9181147B2 (en) 2012-05-07 2015-11-10 Exxonmobil Chemical Patents Inc. Process for the production of xylenes and light olefins
CN103215071A (zh) * 2013-04-12 2013-07-24 大连理工大学 一种费托油催化提质方法
US9593871B2 (en) 2014-07-21 2017-03-14 Phononic Devices, Inc. Systems and methods for operating a thermoelectric module to increase efficiency
US10458683B2 (en) 2014-07-21 2019-10-29 Phononic, Inc. Systems and methods for mitigating heat rejection limitations of a thermoelectric module
CN109694730B (zh) * 2017-10-24 2022-01-04 中国石油化工股份有限公司 一种原油裂解制备低碳烯烃的方法及装置
WO2020190786A1 (fr) * 2019-03-15 2020-09-24 Lummus Technology Llc Configuration pour la production d'oléfines
CN112694908B (zh) * 2020-12-15 2022-03-25 浙江大学 一种石油烃高效裂解方法
FI131014B1 (en) * 2022-06-16 2024-07-31 Coolbrook Oy Prevention of coke formation in hydrocarbon processing equipment

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Cited By (12)

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Publication number Priority date Publication date Assignee Title
US7097758B2 (en) 2002-07-03 2006-08-29 Exxonmobil Chemical Patents Inc. Converting mist flow to annular flow in thermal cracking application
US7138047B2 (en) 2002-07-03 2006-11-21 Exxonmobil Chemical Patents Inc. Process for steam cracking heavy hydrocarbon feedstocks
US7578929B2 (en) 2002-07-03 2009-08-25 Exxonmoil Chemical Patents Inc. Process for steam cracking heavy hydrocarbon feedstocks
WO2005095548A1 (fr) 2004-03-22 2005-10-13 Exxonmobil Chemical Patents Inc. Procede de craquage vapeur de brut lourd
US7820035B2 (en) 2004-03-22 2010-10-26 Exxonmobilchemical Patents Inc. Process for steam cracking heavy hydrocarbon feedstocks
JP2008500444A (ja) * 2004-05-21 2008-01-10 エクソンモービル・ケミカル・パテンツ・インク 残留油を含む炭化水素原料の熱分解に用いられる蒸気／液体分離装置
US7776286B2 (en) * 2004-07-14 2010-08-17 Exxonmobil Chemical Patents Inc. Process for reducing fouling from flash/separation apparatus during cracking of hydrocarbon feedstocks
US7972498B2 (en) 2005-10-20 2011-07-05 Exxonmobil Chemical Patents Inc. Resid processing for steam cracker feed and catalytic cracking
US8636895B2 (en) 2005-10-20 2014-01-28 Exxonmobil Chemical Patents Inc. Hydrocarbon resid processing and visbreaking steam cracker feed
US8696888B2 (en) 2005-10-20 2014-04-15 Exxonmobil Chemical Patents Inc. Hydrocarbon resid processing
US8784743B2 (en) 2005-10-20 2014-07-22 Exxonmobil Chemical Patents Inc. Hydrocarbon resid processing and visbreaking steam cracker feed
US8115042B2 (en) 2006-12-21 2012-02-14 Exxonmobil Chemical Patents Inc. Oligomerisation of olefins

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JP2005531684A (ja) 2005-10-20
CN1665910A (zh) 2005-09-07
CN1665909A (zh) 2005-09-07
EP1523534A1 (fr) 2005-04-20
EP1527151B1 (fr) 2018-07-18
JP5166674B2 (ja) 2013-03-21
ATE396244T1 (de) 2008-06-15
JP4403071B2 (ja) 2010-01-20
JP2005531683A (ja) 2005-10-20
JP2006508198A (ja) 2006-03-09
CA2489888A1 (fr) 2004-01-15
CN1665908A (zh) 2005-09-07
CA2489876C (fr) 2011-04-19
EP1639060A1 (fr) 2006-03-29
AU2003281371A1 (en) 2004-01-23
EP1523534B1 (fr) 2017-07-19
KR20050016708A (ko) 2005-02-21
WO2004005433A1 (fr) 2004-01-15
KR100979027B1 (ko) 2010-08-30
SG177003A1 (en) 2012-01-30
CN1281715C (zh) 2006-10-25
CA2490403A1 (fr) 2004-01-15
WO2004005432A1 (fr) 2004-01-15
CN100587030C (zh) 2010-02-03
KR20050016709A (ko) 2005-02-21
EP1639060B1 (fr) 2008-05-21
JP4387301B2 (ja) 2009-12-16
EP1527151A1 (fr) 2005-05-04
CA2490403C (fr) 2011-06-07
AU2003247756A1 (en) 2004-01-23
AU2003247755A1 (en) 2004-01-23
KR100945121B1 (ko) 2010-03-02
CA2489888C (fr) 2011-07-12
CA2489876A1 (fr) 2004-01-15
CN100494318C (zh) 2009-06-03

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