EP1523534B1 - Process for cracking hydrocarbon feed with water substitution - Google Patents

Process for cracking hydrocarbon feed with water substitution Download PDF

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Publication number
EP1523534B1
EP1523534B1 EP03763036.5A EP03763036A EP1523534B1 EP 1523534 B1 EP1523534 B1 EP 1523534B1 EP 03763036 A EP03763036 A EP 03763036A EP 1523534 B1 EP1523534 B1 EP 1523534B1
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EP
European Patent Office
Prior art keywords
water
feed
furnace
mixture
process according
Prior art date
Legal status (The legal status 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 status listed.)
Expired - Lifetime
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EP03763036.5A
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German (de)
English (en)
French (fr)
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EP1523534A1 (en
Inventor
David B. Spicer
Arthur R. Dinicolantonio
James Mitchell Frye
Richard C. Stell
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ExxonMobil Chemical Patents Inc
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ExxonMobil Chemical Patents Inc
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Priority claimed from US10/188,901 external-priority patent/US7090765B2/en
Priority claimed from US10/188,461 external-priority patent/US7138047B2/en
Priority claimed from US10/189,618 external-priority patent/US7097758B2/en
Application filed by ExxonMobil Chemical Patents Inc filed Critical ExxonMobil Chemical Patents Inc
Publication of EP1523534A1 publication Critical patent/EP1523534A1/en
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    • 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
    • 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
    • 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
    • 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 the cracking of hydrocarbon feed using water as a supplement to or substitute for dilution steam.
  • Steam cracking has long been used to crack various hydrocarbon feeds into olefins.
  • Conventional steam cracking utilizes a pyrolysis furnace, which has two main sections: a convection section and a radiant section reaction zone.
  • the hydrocarbon feed typically enters the convection section of the furnace as a liquid (except for light feeds 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 mixing with steam.
  • the vaporized feed and steam mixture is then introduced into the radiant section where the cracking takes place.
  • the resulting products including olefins leave the pyrolysis furnace for further downstream processing, such as quenching.
  • the hydrocarbon feed enters the convection section of the furnace where it is preheated in first heat exchange tubes by indirect contact with furnace flue gas from the radiant section.
  • a dilution steam stream can enter the convection section wherein it is superheated, also in heat exchange tubes by indirect contact with furnace flue gas from the radiant section.
  • the superheated dilution steam is then mixed with the hydrocarbon feed to reduce the hydrocarbon partial pressure in the radiant section reaction zone of the furnace.
  • hydrocarbon feed and dilution steam are heated in the convection section, typically by indirect contact with flue gas from the radiant section.
  • Other recovery services may also be included in the convection section such as a boiler feed water preheater and/or a steam superheater used to superheat high pressure steam which may be generated in the quench system of the furnace.
  • boiler feed water preheat and/or high pressure steam superheat services may not be available to absorb heat from the flue-gas stream flowing through the convection section.
  • the flue gas may exit the furnace at unacceptably high temperatures, for example, as high as 600 to 700°F (315 to 370°C).
  • GB998504 describes a steam cracker arranged to use water and steam for admixing with the feed to control the time temperature relationship in a radiant section increase the thermal efficiency.
  • the present invention provides an advantage of providing for additional dilution steam when it is otherwise unavailable at a reasonable cost.
  • the present invention also provides another advantage of improving furnace energy efficiency.
  • the present invention provides a process for treating hydrocarbon feed in a steam cracker furnace, the process comprising: (a) heating hydrocarbon feed, to provide a heated feed, (b) adding water in a sparger and dilution steam in another sparger to the heated feed to form a mixture, the water being added in an amount of from at least 1% based on water and dilution steam by weight, wherein both water and dilution steam are added and the water is added prior to the addition of the dilution steam (c) heating the mixture to provide a heated mixture and (d) feeding the heated mixture from (c) to the furnace, wherein the ratio of water to steam added to the heated feed is varied according to fluctuations in the temperature of flue gas exiting the furnace and/or the temperature in a convection section of the furnace.
  • the water may be added in an amount of at least 3% based on water and dilution steam by weight, at least 10% or at least 30% based on water and dilution steam by weight.
  • the ratio of water to steam added to the heated feed is varied according to fluctuations in the process temperature of the flue gas exiting the furnace or the temperature of process in the convection section of the furnace.
  • a first and a second sparger are part of a sparger assembly in which the first and second spargers are connected in fluid flow communication in series.
  • the present invention also provides a process for cracking hydrocarbon feed in a furnace, the furnace comprising a radiant section comprising burners that generate radiant heat and hot flue gas, and a convection section comprising heat exchange tubes, the process comprising:
  • the first sparger comprises an inner perforated conduit surrounded by an outer conduit so as to form an annular flow space between the inner and outer conduits.
  • the preheated hydrocarbon flows through the annular flow space and the water flows through the inner conduit and is injected into the preheated hydrocarbon feed through the openings (perforations) in the inner conduit.
  • the second sparger may comprise an inner perforated conduit surrounded by an outer conduit so as to form an annular flow space between the inner and outer conduits.
  • the feed from the first sparger flows through the annular flow space and the dilution steam flows through the inner conduit and is injected into the first feed mixture through the openings (perforations) in the inner conduit.
  • the first and second spargers may be part of a sparger assembly in which the first and second spargers are connected in fluid flow communication in series.
  • Fig.1 illustrates a schematic flow diagram of a process in accordance with the present invention employed with a pyrolysis furnace, with particular emphasis on the convection section of the furnace.
  • This figure also shows a control schematic for varying the ratio of water to dilution steam according to a process variable, namely, the temperature of process gas to the radiant section of the furnace.
  • Fig. 2 illustrates a schematic diagram of a control system for use in varying the ratio of water to dilution steam in connection with a process parameter, specifically, the temperature of the flue gas exiting the furnace.
  • Fig. 3 illustrates a schematic diagram of the same control system, but for varying the ratio of water to dilution steam in connection with the temperature of process gas in the convection section of the furnace.
  • the present invention relates to a process for treating hydrocarbon feed in a furnace.
  • the process comprises (a) heating hydrocarbon feed, (b) adding water and dilution steam to the heated feed to form a mixture, (c) heating the mixture, and (d) feeding the heated mixture to the furnace, wherein the water in (b) is added in an amount of from at least 1% based on water and dilution steam by weight.
  • Fig. 1, 1 generally refers to a pyrolysis furnace comprised of a lower radiant section 2, an intermediate convection section 3 and an upper flue gas exhaust section 4.
  • radiant burners provide radiant heat to hydrocarbon feed to produce the desired products by thermal cracking of the feed.
  • the burners generate hot gas that flows upwardly through convection section 3 and then out of the furnace through flue gas exhaust section 4.
  • hydrocarbon feed 33 enters an upper portion of the convection section 3 where it is preheated.
  • the preheating of the hydrocarbon feed can take any form known by those of ordinary skill in the art.
  • the heating comprises indirect contact of the feed in the upper convection section 3 of the furnace 1 with hot flue gases from the radiant section of the furnace. This can be accomplished, by way of non-limiting example, by passing the feed through heat exchange tubes 17 located within the convection section 3 of the furnace 1.
  • the preheated feed has a temperature between 200 and 600°F (95 and 315°C).
  • the temperature of the heated feed is 300 to 500°F (150 to 260°C) and more preferably between 350 and 500°F (175 and 260°C).
  • water 5 and dilution steam 6 are added thereto to form a mixture.
  • Water is added to the preheated feed in an amount of from at least 1% based on the total amount of water and dilution steam added by weight.
  • the water is added in an amount of at least 3% based on water and dilution steam by weight.
  • the water is added in an amount of at least 10%, most preferably at least 30%, based on water and dilution steam by weight.
  • the sum of the water flow and dilution steam flow provides the total desired reaction zone H 2 O required to achieve the desired hydrocarbon partial pressure.
  • first sparger 8 comprises an inner perforated conduit 9 surrounded by an outer conduit 10 so as to form an annular flow space 11 between the inner and outer conduits.
  • the preheated hydrocarbon feed 41 flows through the annular flow space 11.
  • water 5 flows through the inner perforated conduit 9 and is injected into the preheated hydrocarbon feed through the openings (perforations) shown in inner conduit 9.
  • Dilution steam 6 is added to the preheated hydrocarbon feed in a second sparger 12.
  • second sparger 12 comprises an inner perforated conduit 13 surrounded by an outer conduit 14 so as to form an annular flow space 15 between the inner and outer conduits.
  • the preheated hydrocarbon feed 41 to which the water has been added flows through the annular flow space 15.
  • dilution steam flows through the inner perforated conduit 13 and is injected into the preheated hydrocarbon feed through the openings (perforations) shown in inner conduit.
  • the first and second spargers are part of a sparger assembly as shown in which the spargers are connected in fluid flow communication in series.
  • the spargers 8 and 12 are interconnected in fluid flow communication in series by fluid flow interconnector 16.
  • the mixture (of hydrocarbon feed, water and dilution steam) flows back into furnace 1 wherein the mixture is further heated in a lower portion of convection section 3.
  • the further heating of the hydrocarbon feed can take any form known by those of ordinary skill in the art. However, it is preferred that the heating comprises indirect contact of the feed in the lower convection section 3 of the furnace 1 with hot flue gases from the radiant section of the furnace. This can be accomplished, by way of non-limiting example, by passing the feed through heat exchange tubes 18 located within the convection section 3 of the furnace 1. Following the additional heating of the mixture at 18, the resulting heated mixture exits the convection section at 19 and then flows to the radiant section of the furnace for thermal cracking of the hydrocarbon.
  • the heated feed to the radiant section preferably has a temperature between 800 and 1400°F (425 and 760°C). Preferably the temperature of the heated feed is 1050 to 1350°F (560 to 730°C).
  • Figure 1 further illustrates using the invention to control the process temperature to the radiant section 2.
  • the process temperature measured at 25 is an input to a controller 26 which controls the flow rate of water via a flow meter 28 and a control valve 29.
  • the water then enters the sparger 7.
  • controller 26 increases the flow of water.
  • Controller 26 also sends the flow rate signal to a computer control application schematically shown at 31, which determines the dilution steam flow rate as detailed below.
  • a pre-set flow rate of the hydrocarbon feed 33 is measured by flow meter 34, which is an input to controller 35, which in turn sends a signal to feed control valve 36.
  • Controller 35 also sends the feed rate signal to a computer control application 37, which determines the total H 2 O to the radiant section by multiplying the feed rate by a pre-set total H 2 O to feed rate ratio.
  • the total H 2 O rate signal is the second input to computer application 31.
  • Computer application 31 subtracts the water flow rate from the total H 2 O rate; the difference is the set point for the dilution steam controller 38.
  • Flow meter 39 measures the dilution steam rate, which is also an input to the controller 38.
  • Controller 38 instructs control valve 40 to reduce the dilution the steam rate 32 to the new set point.
  • the control scheme instructs control valve 29 to reduce water rate and instructs control valve 40 to increase the steam rate while maintaining constant total H 2 O rate.
  • this control scheme works the same way to control the discharge temperature of the flue gas 42 as illustrated in Figure 2 , and to control the process temperature in the convection section of the furnace, illustrated in Figure 3 .
  • flue gas exits at a temperature of less than 650°F (345°C), preferably less than 450°F (230°C), more preferably less than 350°F (175°C).
  • Processes in accordance with the present invention make it possible to maintain a desired hydrocarbon partial pressure in the radiant section reaction zone of a furnace, while increasing the convection section heat recovery requirement due to the heat of vaporization of the water stream. Such a system can result in a lower flue-gas discharge temperature and, thus, a more energy efficient furnace.
  • processes in accordance with the present invention enable the desired reaction zone hydrocarbon partial pressure to be maintained in a facility where the available supply of dilution steam is limited and/or is insufficient for the desired furnace operating conditions.

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  • Chemical & Material Sciences (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Engineering & Computer Science (AREA)
  • Physics & Mathematics (AREA)
  • Thermal Sciences (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • General Chemical & Material Sciences (AREA)
  • Organic Chemistry (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
  • Organic Low-Molecular-Weight Compounds And Preparation Thereof (AREA)
  • Lubricants (AREA)
  • Separating Particles In Gases By Inertia (AREA)
EP03763036.5A 2002-07-03 2003-06-27 Process for cracking hydrocarbon feed with water substitution Expired - Lifetime EP1523534B1 (en)

Applications Claiming Priority (7)

Application Number Priority Date Filing Date Title
US10/188,901 US7090765B2 (en) 2002-07-03 2002-07-03 Process for cracking hydrocarbon feed with water substitution
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US10/188,461 US7138047B2 (en) 2002-07-03 2002-07-03 Process for steam cracking heavy hydrocarbon feedstocks
US10/189,618 US7097758B2 (en) 2002-07-03 2002-07-03 Converting mist flow to annular flow in thermal cracking application
PCT/US2003/020377 WO2004005432A1 (en) 2002-07-03 2003-06-27 Process for cracking hydrocarbon feed with water substitution

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KR100945121B1 (ko) 2010-03-02
JP2005531684A (ja) 2005-10-20
CN1665909A (zh) 2005-09-07
WO2004005431A1 (en) 2004-01-15
EP1527151A1 (en) 2005-05-04
CA2489876C (en) 2011-04-19
AU2003281371A1 (en) 2004-01-23
CA2490403C (en) 2011-06-07
JP5166674B2 (ja) 2013-03-21
JP4387301B2 (ja) 2009-12-16
ATE396244T1 (de) 2008-06-15
JP2006508198A (ja) 2006-03-09
KR20050016709A (ko) 2005-02-21
EP1523534A1 (en) 2005-04-20
CN1281715C (zh) 2006-10-25
CN1665910A (zh) 2005-09-07
CA2489888A1 (en) 2004-01-15
AU2003247755A1 (en) 2004-01-23
EP1639060A1 (en) 2006-03-29
CN100587030C (zh) 2010-02-03
CN100494318C (zh) 2009-06-03
KR20050016708A (ko) 2005-02-21
CA2489876A1 (en) 2004-01-15
JP2005531683A (ja) 2005-10-20
WO2004005433A1 (en) 2004-01-15
AU2003247756A1 (en) 2004-01-23
CN1665908A (zh) 2005-09-07
JP4403071B2 (ja) 2010-01-20
EP1527151B1 (en) 2018-07-18
KR100979027B1 (ko) 2010-08-30
CA2489888C (en) 2011-07-12
SG177003A1 (en) 2012-01-30
CA2490403A1 (en) 2004-01-15
WO2004005432A1 (en) 2004-01-15
EP1639060B1 (en) 2008-05-21

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