EP4310160A1 - Procédé et installation de vapocraquage - Google Patents

Procédé et installation de vapocraquage Download PDF

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Publication number
EP4310160A1
EP4310160A1 EP22020353.3A EP22020353A EP4310160A1 EP 4310160 A1 EP4310160 A1 EP 4310160A1 EP 22020353 A EP22020353 A EP 22020353A EP 4310160 A1 EP4310160 A1 EP 4310160A1
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EP
European Patent Office
Prior art keywords
flue gas
gas
combustion process
cracking
heat
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.)
Pending
Application number
EP22020353.3A
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German (de)
English (en)
Inventor
Robert Stegemann
Tobias SINN
Torben HÖFEL
Sebastian Helfenbein
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Linde GmbH
Original Assignee
Linde GmbH
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
Application filed by Linde GmbH filed Critical Linde GmbH
Priority to EP22020353.3A priority Critical patent/EP4310160A1/fr
Publication of EP4310160A1 publication Critical patent/EP4310160A1/fr
Pending legal-status Critical Current

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    • 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
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23C—METHODS OR APPARATUS FOR COMBUSTION USING FLUID FUEL OR SOLID FUEL SUSPENDED IN  A CARRIER GAS OR AIR 
    • F23C9/00—Combustion apparatus characterised by arrangements for returning combustion products or flue gases to the combustion chamber
    • F23C9/06—Combustion apparatus characterised by arrangements for returning combustion products or flue gases to the combustion chamber for completing combustion
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23D—BURNERS
    • F23D14/00—Burners for combustion of a gas, e.g. of a gas stored under pressure as a liquid
    • F23D14/02—Premix gas burners, i.e. in which gaseous fuel is mixed with combustion air upstream of the combustion zone
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23D—BURNERS
    • F23D14/00—Burners for combustion of a gas, e.g. of a gas stored under pressure as a liquid
    • F23D14/32—Burners for combustion of a gas, e.g. of a gas stored under pressure as a liquid using a mixture of gaseous fuel and pure oxygen or oxygen-enriched air
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23D—BURNERS
    • F23D91/00—Burners specially adapted for specific applications, not otherwise provided for
    • F23D91/02—Burners specially adapted for specific applications, not otherwise provided for for use in particular heating operations
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23L—SUPPLYING AIR OR NON-COMBUSTIBLE LIQUIDS OR GASES TO COMBUSTION APPARATUS IN GENERAL ; VALVES OR DAMPERS SPECIALLY ADAPTED FOR CONTROLLING AIR SUPPLY OR DRAUGHT IN COMBUSTION APPARATUS; INDUCING DRAUGHT IN COMBUSTION APPARATUS; TOPS FOR CHIMNEYS OR VENTILATING SHAFTS; TERMINALS FOR FLUES
    • F23L7/00—Supplying non-combustible liquids or gases, other than air, to the fire, e.g. oxygen, steam
    • F23L7/007—Supplying oxygen or oxygen-enriched air
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23C—METHODS OR APPARATUS FOR COMBUSTION USING FLUID FUEL OR SOLID FUEL SUSPENDED IN  A CARRIER GAS OR AIR 
    • F23C2202/00—Fluegas recirculation
    • F23C2202/10—Premixing fluegas with fuel and combustion air
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F28—HEAT EXCHANGE IN GENERAL
    • F28D—HEAT-EXCHANGE APPARATUS, NOT PROVIDED FOR IN ANOTHER SUBCLASS, IN WHICH THE HEAT-EXCHANGE MEDIA DO NOT COME INTO DIRECT CONTACT
    • F28D21/00—Heat-exchange apparatus not covered by any of the groups F28D1/00 - F28D20/00
    • F28D21/0001—Recuperative heat exchangers
    • F28D21/0003—Recuperative heat exchangers the heat being recuperated from exhaust gases
    • F28D21/001—Recuperative heat exchangers the heat being recuperated from exhaust gases for thermal power plants or industrial processes

Definitions

  • the invention relates to a method and a system for steam splitting.
  • the conventional design of steam cracking systems is increasingly under pressure due to increasing demands to reduce greenhouse gas emissions.
  • Technical measures, both for existing and new systems, are necessary to meet more stringent efficiency and emissions requirements.
  • the present invention sets itself the task of creating improvements, particularly in this sense.
  • the present invention proposes a method of steam cracking using a cracking furnace having cracking tubes heated using a combustion process.
  • the combustion process is carried out using a fuel gas, an oxidizer gas and a recycle portion of a flue gas formed by the combustion process.
  • the term “Gas” should also explicitly include a mixture of several gases or gas components.
  • the fuel gas, the oxidizer gas and the return portion of the flue gas can be provided in any suitable manner and fed to the combustion process.
  • a mixture of two of these gases or all three gases can take place upstream, directly at, or downstream of suitable burners that are used in the combustion process.
  • the return portion of the flue gas can also be fed to the combustion process downstream of the burner by guiding it into a combustion chamber.
  • a corresponding use of parts of the gases mentioned in different ways (supply upstream of the burners, downstream of the burners or into the burners) or the operation of different burners in different ways is also possible.
  • the oxidizer gas has a superatmospheric oxygen content and a subatmospheric nitrogen content.
  • it can be (essentially) pure oxygen, but in other embodiments of the invention, as explained below, this is not the case.
  • the recirculation portion of the flue gas is at least partially provided at a temperature level of 160 to 800 ° C and / or with a temperature difference of 120 to 800 K above an ambient temperature of the cracking furnace for the combustion process, for example with the fuel gas or oxidizer gas (or parts thereof or mixtures of corresponding parts) are brought together or used in the manner just explained.
  • One aspect of the present invention is to use features of known so-called oxyfuel processes in steam cracking. This is achieved by using an appropriate oxygen-rich oxidizer gas.
  • Oxyfuel processes are combustion processes that can achieve very high flame temperatures. These can be used for gaseous, liquid and solid fuels. In contrast to conventional combustion with air, the fuel is typically burned with almost pure oxygen (i.e. with no or only a small proportion of nitrogen and argon). It is a technically very advantageous approach because it reduces both the production of carbon dioxide (by increasing the efficiency of the furnace) reduced, as well as subsequent carbon dioxide capture (due to the smaller amount of carbon dioxide and its higher concentration) can be made considerably easier. The two advantages reinforce each other. The more carbon dioxide production is reduced, the easier subsequent carbon dioxide capture becomes. An advantageous objective is to reduce carbon dioxide production in the course of an oxyfuel process to a minimum.
  • the thermal energy required to carry out the endothermic cracking reactions in steam cracking is provided by the combustion of heating gas in a process furnace.
  • the process gas (a mixture with a hydrocarbon component and a steam component) flows through so-called cracking tubes (or coils for short), which are located inside a combustion chamber of the process furnace, which is also called the radiation zone.
  • the process gas is continuously heated in these cans, allowing the desired fission reactions to take place in the cans.
  • Typical inlet temperatures for the process gas to be converted into the cans are between 550 and 750 °C, the outlet temperatures are typically in the range between 800 and 900 °C.
  • a cracking furnace therefore has, as is the case in the context of the present invention, cracking tubes that are heated using burners
  • the process ovens have a convection zone.
  • the convection zone is usually arranged offset above the radiation zone and includes several tube bundles that traverse the flue gas duct. Its function is to recover as much energy as possible from the hot flue gas that leaves the radiation zone. In fact, in the radiation zone only 35 to 50% of the total firing power is usually transferred to the process gas flowing through the cans.
  • the convection zone therefore plays a central role in energy management, as it is responsible for the use of approximately 40 to 60% of the heat input into a cracking furnace (ie the combustion output).
  • the flue gas heat recovered in the convection zone is typically used for several process tasks. These include, in particular, preheating of boiler feed water and/or a hydrocarbon feed, evaporation of a liquid hydrocarbon feed (with or without process steam injection) and superheating of process steam, a mixture of process steam and hydrocarbon feed, and of high-pressure steam.
  • part of the energy obtained from the flue gas in the convection zone can also be used to preheat the combustion air before it enters the combustion chamber.
  • This preheating typically takes place via heat exchange using a heat exchanger.
  • the increase in adiabatic flame temperature resulting from combustion air preheating improves the radiation zone efficiency and at the same time the sensible heat of the combustion air replaces part of the combustion heat.
  • the oxyfuel processes therefore pursue a functionally integrated approach that both reduces the production of carbon dioxide and significantly simplifies its subsequent capture.
  • Embodiments of the present invention are compared below with alternatives not according to the invention.
  • This is an alternative not according to the invention, referred to as the "first alternative", in the form of a conventional furnace design (without oxyfuel operation, without flue gas recirculation and without combustion air preheating), and an alternative not according to the invention referred to as the “second alternative” (without oxyfuel operation, without Flue gas recirculation, but with combustion air preheating), and an alternative not according to the invention known as the “third alternative” (with oxyfuel operation, with flue gas recirculation, and without combustion air or oxygen preheating).
  • flue gas recirculation takes place at a significantly lower temperature than is the case in the context of the present invention.
  • the heat required in the radiation zone is identical (for example approximately 41.7 MW).
  • identical or essentially identical or sufficiently similar "bridge wall” temperatures i.e. temperatures in the transition region from radiation to convection zone
  • 1100 to 1150 °C This is due in particular to the fact that the more “efficient” variants with a higher adiabatic combustion temperature also specifically release more heat in the radiation zone.
  • a total heat of 97 MW is required, for example. This total heat must be provided by underfired power. A relatively large amount of heat is lost to the atmosphere (for example 5 MW) in the form of hot flue gas (for example at 140 °C).
  • a significantly higher radiation zone efficiency can be achieved. Accordingly, less flue gas is produced or less heat has to be transferred in the convection zone and the total heat transferred is significantly lower (for example 78 MW).
  • the total heat does not have to be provided by underfired power, but is partially provided by sensitive heat using indirect air preheating.
  • the underfired power is significantly reduced (for example 66 MW). In this case, less heat is also lost to the atmosphere (for example 2 MW) in the form of hot flue gas (for example 90 °C). Comparatively low flue gas temperatures can be achieved, among other things, because a cold medium (the combustion air) is available for heat exchange.
  • An embodiment of the concept described here can, for example, be the external dilution of the oxidizing agent or oxidizer gases with the recycled portion of the flue gas (before this mixture then comes into contact with the fuel gas on the burner).
  • any other configurations are also possible, as mentioned, provided that corresponding advantages can be achieved.
  • the resulting oxygen concentration in the oxidizing agent diluted with flue gas recycle can be, for example, 31.5 mol% (required slightly over-stoichiometric oxygen content for combustion).
  • a total heat of, for example, 78 MW is also required.
  • the total heat must be provided primarily by underfired power (for example 76 MW), only reduced by the small effect of direct preheating using cold flue gas recycling (for example 2 MW).
  • the loss to the atmosphere is minimized (for example 1 MW) due to the very small amount of flue gas to the atmosphere, although in the example shown the flue gas temperature is even higher than in the second alternative not according to the invention (for example 140 ° C).
  • a similar radiation zone efficiency comparable to the second and third alternatives not according to the invention is also sought.
  • a lower oxygen concentration compared to scenario 3
  • the flue gas recycle takes place at a significantly higher temperature (for example 500 ° C), contrary to the intuitive strategy according to the state of the art, in which the flue gas recycle is as cold as possible.
  • the recycled flue gas has a temperature level which is not just slightly above atmospheric level (e.g. 80 to 200 ° C absolute, corresponding to e.g. 40 to 200 ° C above atmospheric temperature), but is significantly above atmospheric level, as mentioned above.
  • a total heat of, for example, 78 MW is also required.
  • a very high radiation zone efficiency can be achieved, in particular in combination with further embodiments such as the combination of the mentioned and other aspects explained below, such as the preheating of the oxidizer gas.
  • the aspect of hot flue gas recycling is deliberately used, although this appears counter-intuitive from the current state of the art.
  • the heat to be transferred in the convection zone is minimized compared to all other alternatives, as can be seen in Figure 2 .
  • This minimization occurs in particular at a low temperature level, which can further be exploited to maximize the thermodynamic efficiency of the entire system.
  • the small amount of heat of, for example, 5 MW in the temperature range below the temperature of the flue gas recirculation, i.e. below, for example, 500 ° C characterizes the amount of heat in the non-recycled exhaust gas stream.
  • the slight residual heat can be used, for example, to preheat the oxidizing agent by means of indirect heat exchange.
  • a remainder of the flue gas that is not used to form the recirculation portion is at least partially one Heat exchange is subjected to, as already mentioned before.
  • all media can be heated that are also heated in the convection zone of a conventional steam splitting process using the heat exchangers there.
  • the heat exchange comprises a heat exchange with at least part of the oxidizer gas in order to preheat it.
  • At least one heat exchange of the non-recycled flue gas takes place after the flue gas has been divided into recycled and non-recycled portions, with the aim of heat recovery, before the flue gas finally released into the atmosphere or to a carbon dioxide capture facility.
  • this heat exchange can include preheating the oxidizer gas (oxygen).
  • the heat exchange takes place in particular for heat recovery before the flue gas is released into the atmosphere or a carbon dioxide capture system.
  • the heat exchange of the non-recycled flue gas can either be integrated into the convection zone of the oven or carried out in separately installed heat exchangers. The latter can under certain circumstances represent a particularly advantageous solution, since the oxyfuel process may already have the aim of further treating the flue gas stream in a carbon dioxide capture system. For this reason, appropriate lines must be provided to guide the flue gas anyway.
  • embodiments of the invention may include carrying out the heat exchange mentioned using one or more heat exchangers arranged inside or outside a convection zone of the cracking furnace.
  • the non-recycled flue gas can be used, for example, to preheat the oxidizer gas.
  • the indirect heat exchange can also be carried out with one or more other media, for example for feed preheating or boiler feed water preheating. Due to the high partial pressure of the water in the carbon dioxide-rich and nitrogen-free or nitrogen-poor or low-nitrogen flue gas, a large part of the water can be condensed out at comparatively high condensation temperatures.
  • the heat exchange causes water to condense out of at least part of the flue gas, the water being separated at a separation temperature of 50 to 70 ° C. If the condensation heat is used at this temperature level (for example in heat pumps), almost the full calorific value of the heating gas can be used thermally ("condensing boiler") and thus the overall efficiency of the system can be further increased.
  • the heat exchange can also initially take place in a direct contact cooler against a water phase, i.e. the heat exchange can include direct contact cooling of at least part of the flue gas.
  • the water condensation described above can then also take place.
  • a direct contact cooler used can be pH-regulated, i.e. operated at a predetermined pH value or a predetermined pH value range and at the same time, for example, remove sulfur dioxide and possibly other impurities from the flue gas and condense the majority of the water from the flue gas.
  • the characteristic of "heat recovery" is also considered to be fulfilled here if the heat removed by means of direct contact cooling is then at least partially fed back into a process in a second step, for example by cooling the circulating water by means of heat exchange (i.e. not exclusively via, for example, cooling water cooling or air cooling is added to the atmosphere).
  • Heat recovery from the non-recycled flue gas can also only take place after hot flue gas from several sources, for example several oxyfuel process furnaces, has been combined.
  • the design of the heat recovery in the convection zone can be very flexibly adapted to the availability of the media to be heated by flexibly adjusting the approximate temperature of the flue gas recycle.
  • the adiabatic flame temperature of combustion can be adjusted by regulating the amount of flue gas recycle.
  • At least part of the flue gas can be subjected to carbon dioxide separation.
  • carbon dioxide separation minimizing the production of carbon dioxide in the course of an oxyfuel process is a further advantage in terms of simplifying the subsequent separation of carbon dioxide, so that such an embodiment of the invention is particularly advantageous.
  • a very high concentration of carbon dioxide in the flue gas - processes according to corresponding embodiments of the invention also lead to a particularly low total amount of carbon dioxide.
  • At least part of the flue gas is released into the atmosphere without first being passed through a denitrification device.
  • Embodiments according to the invention enable such an operation.
  • the radiation zone efficiency is improved and the emissions are reduced on the one hand by increasing the adiabatic flame temperature compared to the conventional reference according to the first alternative not according to the invention.
  • this is accompanied by a significant increase in the nitrogen oxide concentration in the flue gas, which requires additional measures such as the integration of a denitrification device, for example in the convection zone. Due to the absence or minimal residual concentration of the nitrogen component in the supplied oxidizing agent or in the recirculated flue gas, the formation of nitrogen oxides is eliminated during the combustion reaction or is reduced to small amounts. In conjunction with the oxyfuel process presented, operation without a denitrification device is possible while at the same time maintaining high furnace efficiency.
  • the oxidizer gas can have an oxygen content of more than 90 percent by volume, with no further gas components being supplied to the combustion process, in particular in addition to the fuel gas, the oxidizer gas and the recirculated portion of the flue gas.
  • the oxygen content of the oxidizer gas can in particular be more than 95 Percent by volume or 99 percent by volume, or it can be (substantially) pure oxygen or oxygen of a certain specification (such as "technical" oxygen).
  • the method according to the invention shows its full potential if only an oxidizer gas that is highly enriched in oxygen or highly depleted in nitrogen is supplied to the combustion process in the sense just stated, since under these circumstances the production can be minimized and the separation of carbon dioxide can be maximally simplified .
  • the method can also be used if the oxidizer gas is, for example, a mixture of combustion air and a gas that is highly enriched in oxygen or highly depleted in nitrogen.
  • the oxidizer gas can have an oxygen content of more than 30 and less than 90 percent by volume and can, for example, be a mixture of air and a corresponding other gas.
  • the oxidizer gas and the recirculated portion of the flue gas no further gas components are supplied to the combustion process.
  • a gas mixture can be taken from the cracking furnace, from which a fraction containing at least predominantly, i.e. in particular more than 50%, 60, 70, 80 or 90% on a mass, volume or molar basis, hydrogen and methane is formed is, wherein the fraction containing at least predominantly hydrogen and methane is used in a first proportion to form the fuel gas or as the fuel gas, and wherein a second part of the fraction comprising at least predominantly hydrogen and methane is discharged from the process.
  • the just mentioned fraction containing hydrogen and methane or a portion thereof can be further separated to obtain the first and second part as the first and second subsequent fraction in such a way that the first subsequent fraction has a higher proportion of methane than the second subsequent fraction and the second subsequent fraction has a higher hydrogen content than the first subsequent fraction.
  • methane can be burned preferably and hydrogen can preferably be made available for other purposes.
  • tail gas of the cracking furnace i.e. the mentioned fraction containing at least predominantly hydrogen and methane
  • methane-rich phase measures in the separating part that provide a separate hydrogen-rich phase and a methane-rich phase.
  • part of the hydrogen-rich phase can be viewed as an additional value-added product.
  • this modified separating part can be designed differently.
  • the design can include, for example, membrane processes, pressure swing absorption or cold separation processes.
  • the conventional or modified separating part can also benefit from a possibly changed pressure requirement on the combustion medium.
  • the pressures of the fuel gas in conventional furnace designs are, for example, 4 to 7 bar (abs.). Since the flow of the oxidizing agent in the oxyfuel process is not subject to a natural draft (see air and flue gas flow below), a significantly lower pressure of the fuel gas may be sufficient.
  • embodiments of the present invention can provide that the fuel gas is supplied to the combustion process at a pressure level of 1.02 to 3 bar absolute pressure. This potentially reduced pressure requirement can be utilized in the separator because it can operate at lower pressures.
  • the design of the air and flue gas routing using a fan or compressor can be designed in a variety of ways.
  • the oxidizer gas can be fed with a fan (before or after preheating, if available). However, the oxidizing agent can also be supplied at increased pressure (from an air separator).
  • a separate fan can be installed directly in the recycle. Additionally, a fan can be installed in the non-recycled flue gas, before and/or after cooling. Fans for recycled and non-recycled flue gas can be combined (in the flue gas stream before the recycle branch).
  • non-recycled flue gas can also Cooling via indirect and/or direct heat exchange involves compression, with the aim of compressing a carbon dioxide stream to a discharge pressure, liquefying a carbon dioxide stream and/or leading a carbon dioxide stream to a pressure swing absorption, in which, for example, inert gases such as oxygen and nitrogen can be removed.
  • FIG. 1 A steam cracking system designed according to an embodiment of the invention is schematically illustrated and designated overall by 100.
  • Illustrated steam cracking plant 100 includes one or more process furnaces or cracking furnaces 10, illustrated here with a reinforced line.
  • a cracking furnace is only mentioned for the sake of better understanding.
  • Typical steam cracking plants 100 include a number of corresponding cracking furnaces 10 which are operated under the same or different conditions can.
  • corresponding cracking furnaces 10 can have one or more of the components explained below.
  • the present invention is not limited to use in connection with a steam cracking system 100 as described in Figure 1 is illustrated, but can basically be used in all steam cracking systems in which burners are provided for heating.
  • the cracking furnace 10 includes a convection zone, indicated here as a total of 11, and a radiation zone, indicated here as a total of 12. In embodiments, it can also be provided, for example, to assign several radiation zones 12 to a convection zone 11.
  • heat exchangers 13 are arranged in the convection zone 11, each of which can also be provided in the convection zone 11 in a different arrangement or sequence.
  • These heat exchangers 13 are typically designed in the form of tube bundles guided through the convection stones 11 and flue gas from the radiation zone 12 flows around them.
  • the radiation zone 12 is heated by means of several burners 14, which are only partially designated separately here, and are arranged on the bottom and wall sides. Heating purely on the floor is also possible. Only using a burner 14 is it illustrated how a gas mixture is supplied to it, which is carried out from the cracking furnace 10 using a fuel gas 2 and an oxidizer gas 3 as well as using flue gas 4, which in the example shown is carried out after the third of the five heat exchangers 13 shown , is formed. Depending on the respective boundary conditions of a system, the number of heat exchangers 13 and the media that are heated in the heat exchangers can vary greatly. Accordingly, the exact location of the branch of the flue gas recycle 4 can vary.
  • This flue gas 5 can, for example, be passed through a heat exchanger 19, using which, for example, at least part of the oxidizer gas 3 can be heated.
  • oxidizer gas and flue gas recycling can be mixed beforehand and then brought into contact with the fuel gas before or on the burner 14.
  • oxidizer gas and flue gas recycling can be mixed beforehand and then brought into contact with the fuel gas before or on the burner 14.
  • the flue gas recycle 4 is guided directly into the combustion chamber after the burner 14, whereby only fuel gas 2 and oxidizer gas 3 are supplied directly to the burner 14 itself, which may require an adjustment of the burner due to the local high oxygen concentration .
  • gaseous or liquid feed stream 101 is supplied to the steam cracking system 100.
  • the use of several input streams 101 is also possible.
  • the feed stream 101 is first preheated in one of the heat exchangers 13.
  • a boiler feed water stream 102 is passed through the convection zone 11 or one of the heat exchangers 13 and preheated.
  • the boiler feed water stream 102 is then fed into a steam drum 15.
  • a process steam stream 103 is further heated and combined with the feed stream 101.
  • a collection stream 104 formed in this way from feed and steam is passed through another of the heat exchangers 13 in the convection zone 11 and then passed through the radiation zone 12 in typically several cans 16.
  • the representation in Figure 1 is greatly simplified.
  • a corresponding collection stream 104 is divided into a plurality of cracked tubes 16 and, after passing through the radiation zone 12, is again combined as a cracked gas stream in a common line (not illustrated).
  • a steam stream 105 can be taken from the steam drum 15 and heated in another heat exchanger 13 in the convection zone 11, whereby a high-pressure steam stream 106 can be generated. This can be used at a suitable location in the steam cracking system 100.
  • the quench heat exchanger 17 represents a primary quench heat exchanger in the example shown. In addition to a primary quench heat exchanger 17, secondary quench heat exchangers can also be present. Cooled cracked gas can be fed to further process units, which are indicated here in a highly schematic form at 18. These further process units 18 can in particular be process units for washing, compressing and fractionating the cracked gas, as are generally known in the field.
  • the quench heat exchanger 17 is fed with a water stream 106 from the steam drum 15. A steam stream 107 formed in this way in the quench heat exchanger 15 is returned to the steam drum 13.
  • FIGs 2 and 3 illustrate in the form of diagrams the first to third alternatives not according to the invention, which have already been explained in detail, compared to an embodiment of the invention, whereby in Figure 2 an amount of heat in MW is shown on the horizontal axis versus a temperature in °C on the vertical axis.
  • Figure 2 are the values of the first alternative not according to the invention with white circles and dashed lines, the values of the second alternative not according to the invention with black circles and solid lines, the values of the third alternative not according to the invention with white diamonds and again dashed lines and the values according to an embodiment of Invention illustrated with black diamonds and solid lines.
  • the values of the first to third alternatives not according to the invention are shown as 301 to 303 and the values according to an embodiment of the invention are shown as 304, each in the form of diagram bars.
  • Figure 2 shows a comparison of transferred heat for the alternatives not according to the invention and the design of the invention.
  • the heat transferred indirectly in the convection zone (via a heat exchanger) and the heat released into the atmosphere are illustrated.
  • the curves start at the "bridge wall" temperature at the entrance to the convection zone of approximately 1100 to 1150 °C and at a heat output that has already been transferred in the radiation zone (e.g. approximately 41.7 MW).
  • Figure 3 shows the total heat that was entered into the furnace section, divided into underfired heat (black), sensible heat through indirect air preheating (hatched) and direct preheating through hot flue gas recycling (white).
  • the heat of the sub-fired power plus indirect air preheating corresponds to the total heat transferred Figure 2 .
EP22020353.3A 2022-07-22 2022-07-22 Procédé et installation de vapocraquage Pending EP4310160A1 (fr)

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Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20040175663A1 (en) * 2003-03-06 2004-09-09 M. Shannon Melton Method for combusting fuel in a fired heater
WO2010115561A2 (fr) 2009-04-07 2010-10-14 Linde Aktiengesellschaft Procédé et dispositif de craquage de substances hydrocarbonées
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EP2682569A1 (fr) * 2012-07-05 2014-01-08 Linde Aktiengesellschaft Procédé et dispositif destinés à la transformation d'énergie
EP3415587A1 (fr) 2017-06-16 2018-12-19 Technip France Système et procédé de four de craquage pour le craquage d'une charge d'hydrocarbures en son sein
WO2021052642A1 (fr) * 2019-09-20 2021-03-25 Technip France Système de four de craquage et procédé de craquage d'une charge d'hydrocarbures à l'intérieur de celui-ci

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EP3415587A1 (fr) 2017-06-16 2018-12-19 Technip France Système et procédé de four de craquage pour le craquage d'une charge d'hydrocarbures en son sein
WO2021052642A1 (fr) * 2019-09-20 2021-03-25 Technip France Système de four de craquage et procédé de craquage d'une charge d'hydrocarbures à l'intérieur de celui-ci

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