WO2016077694A1 - Entrée de condenseur pour gaz de pyrolyse - Google Patents

Entrée de condenseur pour gaz de pyrolyse Download PDF

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Publication number
WO2016077694A1
WO2016077694A1 PCT/US2015/060577 US2015060577W WO2016077694A1 WO 2016077694 A1 WO2016077694 A1 WO 2016077694A1 US 2015060577 W US2015060577 W US 2015060577W WO 2016077694 A1 WO2016077694 A1 WO 2016077694A1
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Prior art keywords
pyrolysis
condensable gas
line
flow
pyrolysis vapor
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PCT/US2015/060577
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English (en)
Inventor
Zia Abdullah
Slawomir Winecki
Kevin YUGULIS
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Battelle Memorial Institute
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Publication of WO2016077694A1 publication Critical patent/WO2016077694A1/fr

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    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10B—DESTRUCTIVE DISTILLATION OF CARBONACEOUS MATERIALS FOR PRODUCTION OF GAS, COKE, TAR, OR SIMILAR MATERIALS
    • C10B53/00—Destructive distillation, specially adapted for particular solid raw materials or solid raw materials in special form
    • C10B53/02—Destructive distillation, specially adapted for particular solid raw materials or solid raw materials in special form of cellulose-containing material
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D5/00—Condensation of vapours; Recovering volatile solvents by condensation
    • B01D5/0078—Condensation of vapours; Recovering volatile solvents by condensation characterised by auxiliary systems or arrangements
    • B01D5/0081—Feeding the steam or the vapours
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D5/00—Condensation of vapours; Recovering volatile solvents by condensation
    • B01D5/0078—Condensation of vapours; Recovering volatile solvents by condensation characterised by auxiliary systems or arrangements
    • B01D5/0093—Removing and treatment of non condensable gases
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10K—PURIFYING OR MODIFYING THE CHEMICAL COMPOSITION OF COMBUSTIBLE GASES CONTAINING CARBON MONOXIDE
    • C10K1/00—Purifying combustible gases containing carbon monoxide
    • C10K1/04—Purifying combustible gases containing carbon monoxide by cooling to condense non-gaseous materials
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10K—PURIFYING OR MODIFYING THE CHEMICAL COMPOSITION OF COMBUSTIBLE GASES CONTAINING CARBON MONOXIDE
    • C10K1/00—Purifying combustible gases containing carbon monoxide
    • C10K1/08—Purifying combustible gases containing carbon monoxide by washing with liquids; Reviving the used wash liquors
    • C10K1/16—Purifying combustible gases containing carbon monoxide by washing with liquids; Reviving the used wash liquors with non-aqueous liquids
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F28—HEAT EXCHANGE IN GENERAL
    • F28B—STEAM OR VAPOUR CONDENSERS
    • F28B9/00—Auxiliary systems, arrangements, or devices
    • F28B9/02—Auxiliary systems, arrangements, or devices for feeding steam or vapour to condensers
    • 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
    • F28D2021/0019—Other heat exchangers for particular applications; Heat exchange systems not otherwise provided for
    • F28D2021/0022—Other heat exchangers for particular applications; Heat exchange systems not otherwise provided for for chemical reactors
    • 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
    • F28D2021/0019—Other heat exchangers for particular applications; Heat exchange systems not otherwise provided for
    • F28D2021/0061—Other heat exchangers for particular applications; Heat exchange systems not otherwise provided for for phase-change applications
    • F28D2021/0063—Condensers
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F28—HEAT EXCHANGE IN GENERAL
    • F28F—DETAILS OF HEAT-EXCHANGE AND HEAT-TRANSFER APPARATUS, OF GENERAL APPLICATION
    • F28F13/00—Arrangements for modifying heat-transfer, e.g. increasing, decreasing
    • F28F13/06—Arrangements for modifying heat-transfer, e.g. increasing, decreasing by affecting the pattern of flow of the heat-exchange media
    • F28F13/08—Arrangements for modifying heat-transfer, e.g. increasing, decreasing by affecting the pattern of flow of the heat-exchange media by varying the cross-section of the flow channels
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F28—HEAT EXCHANGE IN GENERAL
    • F28F—DETAILS OF HEAT-EXCHANGE AND HEAT-TRANSFER APPARATUS, OF GENERAL APPLICATION
    • F28F19/00—Preventing the formation of deposits or corrosion, e.g. by using filters or scrapers
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F28—HEAT EXCHANGE IN GENERAL
    • F28F—DETAILS OF HEAT-EXCHANGE AND HEAT-TRANSFER APPARATUS, OF GENERAL APPLICATION
    • F28F19/00—Preventing the formation of deposits or corrosion, e.g. by using filters or scrapers
    • F28F19/002—Preventing the formation of deposits or corrosion, e.g. by using filters or scrapers by using inserts or attachments
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E50/00—Technologies for the production of fuel of non-fossil origin
    • Y02E50/10—Biofuels, e.g. bio-diesel

Definitions

  • Biomass pyrolysis may be conducted, e.g., at about 450 °C to about 550 °C in various pyrolysis reactors. About 85% of the biomass may be converted to vapor, of which, e.g., about 75%) by mass may be condensed into liquid bio-oil and, e.g., about 25% by mass may be non- condensing gas.
  • Biomass pyrolysis vapor may include species that condense across a broad temperature range. For example, high molecular weight species may begin condensing just below the pyrolysis temperature. Thus, in a pyrolysis reactor operated at, e.g., 500 °C, species volatilized at a temperature of 500 °C may begin to condense at temperatures just below 500 °C. Species that condense at such high temperatures may condense into a viscous, tar-like fluid. Further, chemical condensation mechanisms may occur in the pyrolysis vapor to generate new vapor species having even higher condensation temperatures. These new species may condense rapidly upon contact with any surface having a temperature lower than the corresponding condensation temperature.
  • FIG. 1 depicts a conventional pyrolysis system including a pyrolysis reactor 102 connected by a line (108A and 108B) to a conventional condenser 106 through a char cyclone 104.
  • Pyrolysis reactor 102 and char cyclone 104 may be at the same temperature, e.g., 500 °C, while conventional condenser 106 may be at a temperature much less than 500 °C during operation.
  • char cyclone 104 may be physically coupled to conventional condenser 106 via a vapor line 108B, the temperature may drop below 500 °C between char cyclone 104 and conventional condenser 106, e.g., at a conventional interface 110 of vapor line 108B and conventional condenser 106. Heavy, viscous, tar-like condensation 112 may occur at conventional interface 110, which may plug vapor line 108B and may be very difficult to remove.
  • a non-condensing interface may be configured to direct a pyrolysis vapor flow into a condenser.
  • the non- condensing interface may include a non-condensable gas line.
  • the non-condensable gas line may be configured to be operatively coupled to direct a non-condensable gas flow to the condenser.
  • the non-condensing interface may include a pyrolysis vapor line.
  • the pyrolysis vapor line may be coupled or configured to enter the non-condensable gas line such that the non- condensable gas line at least partly surrounds at least a portion of the pyrolysis vapor line.
  • the pyrolysis vapor line may be configured to be physically uncoupled to the condenser.
  • the pyrolysis vapor line may be configured to direct a pyrolysis vapor flow into the non-condensable gas line and therefrom into the condenser such that the pyrolysis vapor flow is at least partly sheathed by the non-condensable gas flow.
  • a pyrolysis system may include a pyrolysis reactor.
  • the pyrolysis system may include a condenser.
  • the condenser may be configured to condense a pyrolysis vapor flow from the pyrolysis reactor.
  • the pyrolysis system may include a non-condensable gas line.
  • the non-condensable gas line may be operatively coupled to direct a non-condensable gas flow to the condenser.
  • the pyrolysis system may include a pyrolysis vapor line.
  • the pyrolysis vapor line may be operatively coupled to the pyrolysis reactor to accept the pyrolysis vapor flow.
  • the pyrolysis vapor line may be coupled to the non-condensable gas line such that non-condensable gas line at least partly surrounds a portion of the pyrolysis vapor line.
  • the pyrolysis vapor line may be configured to be physically uncoupled to the condenser.
  • the pyrolysis vapor line may be separated or physically isolated from the condenser.
  • the pyrolysis vapor line may be configured to direct the pyrolysis vapor flow into the non-condensable gas line and therefrom into the condenser.
  • the pyrolysis vapor flow may be at least partly sheathed by the non-condensable gas flow.
  • a method for mitigating premature condensation of pyrolysis products may include directing a pyrolysis vapor flow into a condenser.
  • the method may include directing the pyrolysis vapor flow away from a condensable surface prior to the condenser using a non-condensable gas flow.
  • the non-condensable gas flow may be effective to mitigate premature condensation of pyrolysis products from the pyrolysis vapor flow onto the condensable surface.
  • the method may include heating the non-condensable gas flow to heat a priorily condensable surface to a desired temperature, e.g., to provide a heated surface.
  • the desired temperature may be greater than a condensing temperature effective to mitigate condensation of pyrolysis products from the pyrolysis vapor flow onto the heated surface.
  • FIG. 1 depicts a generic pyrolysis system with condensate deposits at an entrance to a condenser.
  • FIG. 2 depicts an example non-condensing interface configured in an example pyrolysis system.
  • FIG. 3 shows a cross-sectional computational fluid dynamics (CFD) model of an example non-condensing interface.
  • FIG. 4 is a graph showing variation of flow in an example non-condensing interface.
  • FIG. 5 is a graph showing relationships between various geometry and flow factors of an example non-condensing interface.
  • FIG. 6 is a flow diagram outlining an example method for mitigating premature condensation of pyrolysis products.
  • FIG. 2 depicts an example pyrolysis system 200 including a pyrolysis reactor 202 connected by a line 208A,208B to a condenser 206 through an optional char particle separator 204.
  • Pyrolysis reactor 202 and optional particle separator 204 may be at the same temperature, e.g., 500 °C, while condenser 206 may be at a lower temperature during condensing operations, e.g., much less than 500°C.
  • Optional particle separator 204 may be physically coupled to condenser 206 via an example non-condensing interface 210.
  • Optional particle separator 204 may include, e.g., a particle separation cyclone, an aerosol separation electrostatic precipitator, or a particle separation cyclone and an aerosol separation electrostatic precipitator.
  • Pyrolysis vapor line 208B may not be directly physically coupled to condenser 206. Pyrolysis vapor line 208B may enter non-condensable gas line 216 at non-condensing interface 210. Non- condensable gas line 216 may at least partly surround a portion of pyrolysis vapor line 208B at non-condensing interface 210. Non-condensable gas line 216 may be physically coupled to condenser 206.
  • Non-condensable gas line 216 may be configured to direct a non-condensable gas flow 217 about at least a portion of pyrolysis vapor line 208B at non-condensing interface 210.
  • Non-condensable gas line 216 may be configured to direct non-condensable gas flow 217 in non-condensing interface 210 to condenser 206.
  • Non-condensable gas flow 217 in non- condensing interface 210 to condenser 206 may be in the same direction as a pyrolysis vapor flow 209 from pyrolysis vapor line 208B into condenser 206.
  • Non-condensable gas flow 217 provided by non-condensable gas line 216 at non-condensing interface 210 may direct pyrolysis vapor flow 209 exiting pyrolysis vapor line 208B to condenser 206 and away from the walls of non-condensable gas line 216.
  • Non-condensable gas line 216 may cause non-condensable gas flow 217 to mitigate or prevent pyrolysis vapor flow 209 from contacting an inner wall of the non-condensable gas line 216.
  • Non-condensable gas line 216 may cause non-condensable gas flow 217 to mitigate or prevent condensation of pyrolysis vapor flow 209 in one or more of pyrolysis vapor line 208B and non-condensing interface 210.
  • mitigate means to control, reduce, limit, or decrease the level or amount of the mentioned process or effect compared to the level or amount in the absence of the mentioned aspect of the apparatus, system, or method.
  • the use or presence of non- condensable gas line 216 may cause non-condensable gas flow 217 to control, reduce, limit, or decrease the amount or level of contact between pyrolysis vapor flow 209 and inner wall of non- condensable gas line 216 compared to the amount or level of contact in the absence of non- condensable gas line 216.
  • prevent means to substantially or completely control, reduce, limit, or decrease the level or amount of the mentioned process or effect compared to the level or amount in the absence of the mentioned aspect of the apparatus, system, or method.
  • mitigate or a corresponding grammatical derivative
  • an alternate embodiment is explicitly contemplated using the other of the two terms “mitigate” or “prevent.”
  • mitigate or a corresponding grammatical derivative
  • non-condensable gas flow 217 provided by non-condensable gas line 216 may be provided at a temperature effective to heat or maintain pyrolysis vapor line 208B at a desired temperature at non-condensing interface 210.
  • the desired temperature of pyrolysis vapor line 208B at non-condensing interface 210 may be a temperature selected to mitigate or prevent condensation of pyrolysis vapor species onto an inner surface of pyrolysis vapor line 208B from pyrolysis vapor flow 209.
  • the desired temperature of pyrolysis vapor line 208B at non-condensing interface 210 may be the temperature of one or more of pyrolysis reactor 202, line 208A, optional char particle separator 204, and the like.
  • the desired temperature of pyrolysis vapor line 208B at non-condensing interface 210 may be at least the pyrolysis temperature in pyrolysis reactor 202.
  • the desired temperature of pyrolysis vapor line 208B at non-condensing interface 210 may be greater than the pyrolysis temperature in pyrolysis reactor 202.
  • the desired temperature of pyrolysis vapor line 208B at non-condensing interface 210 may be at least the temperature of pyrolysis vapor flow 209 in pyrolysis vapor line 208B just prior to entering non-condensing interface 210.
  • the desired temperature of pyrolysis vapor line 208B at non-condensing interface 210 may be greater than the temperature of pyrolysis vapor flow 209 in pyrolysis vapor line 208B just prior to entering non-condensing interface 210.
  • the temperature of the pyrolysis system 200 may be the same from the pyrolysis temperature of pyrolysis reactor 202 to the desired temperature of pyrolysis vapor line 208B at non-condensing interface 210.
  • the temperature of the pyrolysis system 200 may be the same or may increase, e.g., monotonically, from the pyrolysis temperature of pyrolysis reactor 202 to the desired temperature of pyrolysis vapor line 208B at non-condensing interface 210.
  • the temperature of non-condensable gas flow 217 may be the same as the temperature of pyrolysis vapor flow 209, in some examples, e.g., 500 °C.
  • the desired temperature of pyrolysis vapor line 208B at non-condensing interface 210 may be a temperature in °C of about, or at least about 400, 410, 420, 430, 440, 450, 460, 470, 480, 490, 500, 510, 520, 530, 540, 550, 560, 570, 580, 590, 600, 610,620, 630, 640, 650, or a range between about any two of the preceding values, for example, between about 450 °C and about 650 °C.
  • the desired temperature of pyrolysis vapor line 208B at non-condensing interface 210 may be greater than another temperature in pyrolysis system 200 by a temperature differential, for example, greater than the pyrolysis temperature in pyrolysis reactor 202, the temperature of pyrolysis vapor flow 209 in pyrolysis vapor line 208B just prior to entering non-condensing interface 210, and the like.
  • the temperature differential of the desired temperature of pyrolysis vapor line 208B at non-condensing interface 210 over another temperature in pyrolysis system 200 may be a value in °C of about, or at least about, 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 15, 20, 25, 30, 35, 40, 50, 75, 100, 125,150, or 200.
  • the temperature differential may be about 5 °C, so that the temperature of pyrolysis vapor flow 209 in pyrolysis vapor line 208B is at about 505 °C when the pyrolysis temperature of pyrolysis reactor 202 is about 500°C.
  • non-condensable gas flow 217 provided by non-condensable gas line 216 at non-condensing interface 210 may include any gas that does not condense at the desired temperature of pyrolysis vapor line 208B at non-condensing interface 210.
  • Non- condensable gas flow 217 may include any gas that may not substantially react with desired pyrolysis vapor species in pyrolysis vapor flow 209 carried by pyrolysis vapor line 208B, or in bio-oil or other products condensed therefrom.
  • non-condensable gas flow 217 may include non-oxidizing gases such as: nitrogen; carbon dioxide; noble gases, e.g., helium, neon, argon, and the like; water vapor, vapors of saturated Ci-C 6 hydrocarbons, and the like.
  • non-condensable gas flow 217 may substantially exclude oxygen.
  • non-condensable gas flow 217 may include non-condensable gases exiting condenser 206, e.g., non-condensable gas products of biomass pyrolysis in pyrolysis reactor 202.
  • non-condensable gas flow 217 may be provided or supplemented by an external source (not shown) of non-condensable gas, such as nitrogen, C0 2 or natural gas.
  • non-condensable gas flow 217 may include natural gas, C0 2 , or non-condensable gas exiting condenser 208.
  • non-condensable gas flow 217 may be heated to heat or maintain pyrolysis vapor line 208B at non-condensing interface 210 to the desired temperature.
  • non-condensable gas flow 217 may be heated using a heat exchanger 214.
  • Heat exchanger 214 may be coupled to condenser 206 to at least partly cool condenser 206, and may direct heat extracted from condenser 206 to heat non-condensable gas flow 217 provided by non- condensable gas line 216.
  • non-condensable gas flow 217 may be heated by an external heater (not shown) in place of or in supplement to heat exchanger 214.
  • the external heater and/or heat exchanger 214 may be equipped with a suitable blower (not shown) configured to direct non-condensable gas flow 217.
  • the external heater may be, for example, an electrical resistance based heater, a combustion heater, and the like.
  • the combustion heater may be powered by combustion of one or more of a pyrolysis char, a pyrolysis vapor, biomass, natural gas, propane, coal, or bio-oil, and the like.
  • non-condensable gas line 216 and pyrolysis vapor line 208B may be configured in any geometry effective to provide non-condensable gas flow 217 about at least a portion of pyrolysis vapor line 208B at non-condensing interface 210.
  • non- condensable gas line 216 and pyrolysis vapor line 208B may be configured a core-shell geometry at non-condensing interface 210.
  • Non-condensable gas line 216 may be configured as a shell about pyrolysis vapor line 208B.
  • Pyrolysis vapor line 208B may be configured as a core within non-condensable gas line 216.
  • non-condensable gas line 216 and pyrolysis vapor line 208B may be configured as an annular core-shell geometry at non- condensing interface 210.
  • pyrolysis vapor line 208B may have an annular cross- section (not shown) when viewed perpendicular to pyrolysis vapor flow 209 along pyrolysis vapor line 208B at non-condensing interface 210.
  • Non-condensable gas line 216 may have an annular cross-section (not shown) when viewed perpendicular to non-condensable gas flow 217 along non-condensable gas line 216 at non-condensing interface 210.
  • Pyrolysis vapor flow 209 may travel through pyrolysis vapor line 208B, e.g., as a core gas flow, and non-condensable gas flow 217 may flow in a region 215 between pyrolysis vapor line 208B and non-condensable gas line 216, providing a flowing gas sheath around at least a portion of non-condensable gas line 216 upon exiting from pyrolysis vapor line 208B.
  • the flowing gas sheath provided by non-condensable gas flow 217 may direct pyrolysis vapor flow 209 away from inner walls of non-condensable gas line 216 in non-condensing interface 210.
  • the flowing gas sheath provided by non-condensable gas flow 217 may mitigate or prevent pyrolysis vapor flow 209 from coming into contact with the inner walls of non-condensable gas line 216 in non-condensing interface 210.
  • the flowing gas sheath provided by non-condensable gas flow 217 may mitigate or prevent condensation of deposits from pyrolysis vapor flow 209 onto an inside surface of non-condensable gas line 216.
  • Non-condensable gas flow 217 may mix with pyrolysis vapor flow 209 to be cooled together upon entering condenser 206.
  • cooling in the condenser 206 may also condense low molecular weight species from pyrolysis vapor flow 209.
  • at least some of the low molecular weight species, when condensed may act as solvents and may mitigate or prevent tar-like deposits from accumulating in condenser 206.
  • pyrolysis vapor line 208B may be terminated within non- condensable gas line 216 in non-condensing interface 210 before condenser 206 by a termination distance ⁇ 218 shown in FIG. 2. Termination distance ⁇ 218 may separate the thermal mass of condenser 206, condensate, and other liquids in condenser 206 from thermal contact with pyrolysis vapor line 208B. Such thermal contact with pyrolysis vapor line 208B may otherwise reduce the temperature of pyrolysis vapor line 208B.
  • FIG. 3 shows a cross-sectional computational fluid dynamics (CFD) model of an example embodiment of pyrolysis vapor flow 209 and non-condensable gas flow 217 flowing through non-condensing interface 210 to condenser 206.
  • CFD computational fluid dynamics
  • Such CFD models may be used, e.g., to design the geometry of non-condensing interface 210, and determine termination distance ⁇ 218 as a function of the geometry and flow conditions.
  • FIG. 3 shows that pyrolysis vapor flow 209 may exit pyrolysis vapor line 208B, and non-condensable gas flow 217 may exit region 215 between pyrolysis vapor line 208B and non-condensable gas line 216.
  • Pyrolysis vapor line 208B may be configured inside non-condensable gas line 216 such that region 215 may be configured as an annular region.
  • the CFD model shows that non-condensable gas flow 217 may provide at least a partial non-condensable flowing gas sheath around pyrolysis vapor flow 209 up to at least termination distance ⁇ 218. Termination distance ⁇ 218 may be determined based on a concentration of the pyrolysis vapor at the wall on the non-condensable line 216.
  • termination distance ⁇ 218 may be determined where the concentration of the pyrolysis vapor at the wall on the non-condensable line 216 is a value, in percent, of about 10, 9, 8, 7, 6, 5, 4, 3, 2, 1, 0,9, 0.8, 0.7, 0.6, 0.5, 0.4, 0.3, 0.2, 0.1, 0.05, 0.01, or less, e.g., about 1%.
  • the CFD model shows that non-condensable gas flow 217 and pyrolysis vapor flow 209 may begin to mix upon pyrolysis vapor flow 209 exiting pyrolysis vapor line 208B.
  • the non-condensable gas line 216 may be physically coupled to condenser 206 at termination distance ⁇ 218, or at some distance less than termination distance ⁇ 218.
  • the non-condensable gas line 216 may be physically coupled to condenser 206 at a distance less than termination distance ⁇ 218 such that the pyrolysis vapor flow 209 may not, or may not substantially come into contact with the condenser walls or the wall of non-condensable gas line 216.
  • the CFD model shows that while non-condensable gas flow 217 and pyrolysis vapor flow 209 may mix along the flow direction, pyrolysis vapor flow 209 at the inside surface of non-condensable gas line 216 may be less than a desired maximum concentration, e.g., less than about 1%, at termination distance ⁇ 218.
  • a desired maximum concentration e.g., less than about 1%
  • the inside surface of non-condensable gas line 216 may be protected from condensate or deposit formation because non-condensable gas flow 217 may direct pyrolysis vapor flow 209 away from the inside surface of non-condensable gas line 216.
  • non-condensable gas flow 217 may mitigate or prevent pyrolysis vapor flow 209 from contacting the inside surface of non-condensable gas line 216.
  • the desired maximum concentration of pyrolysis vapor flow 209 may be expressed as a percentage of the total combination of pyrolysis vapor flow 209 and non-condensable gas flow 217 the inside surface of non-condensable gas line 216.
  • the desired maximum concentration of pyrolysis vapor flow 209 at termination distance ⁇ 218 may be a percentage of about, or less than about, 10, 8, 9, 7, 6, 5, 4, 3, 2, 1, 0.9, 0.8, 0.7, 0.6, 0.5, 0.4, 0.3, 0.2, 0.1, 0.05, or 0.01, for example, less than about 5% or less than about 0.5%.
  • FIG. 3 also shows two parameters useful in computing flow characteristics in non- condensing interface 210, including outside diameter D 0 302 of region 215 between pyrolysis vapor line 208B and non-condensable gas line 216, and inside diameter D z 304 of region 215.
  • FIG. 4 is a graph 400 showing example variation of flow in non-condensing interface 210 in region 215 based on termination distance ⁇ 218, outside diameter D 0 302, and inside diameter D, 304, all computed together as 5/(D 0 -D z ) 404.
  • 5/(D 0 -D z ) 404 is plotted as a function of a Reynolds number, Re D 402 of the flow region 215, computed using an effective diameter, For Ren 402 less than approximately 6,000 with the flow region 215 in an annular configuration, the distance 6/(D 0 -D;) 404 may increase with increasing velocity, indicating contributions from convective effects.
  • 6/(D 0 -D;) 404 may be approximately constant with increasing Reo 402, indicating that mass transfer in the radial direction may be mainly affected by diffusion.
  • the distance 5/(D 0 -D z ) 404 may be greater than about 5.
  • FIG. 5 is a graph 500 showing example relationships between various geometry and flow factors of noncondensing interface 210.
  • Graph 500 plots 5/(D 0 -Dj) 404 as a function of a dimensionless flow rate calculated by dividing the Reynolds number of the annular flow Re ann uius 506 by the Reynolds number of the core flow Re cor e 504 for annulus gap width 502, (D 0 -D;)/D;.
  • Three annulus gap widths (D 0 -Dj)/D z are shown as Annulus A 502A, Annulus B 502B, and Annulus C 502C.
  • 5/(D 0 -Dj) may be greater than about 4 and (D 0 -D;)/D; may be greater than about 0.15; 5/(D 0 -Dj) may be greater than about 4 when (D 0 -D;)/D; may be greater than about 0.3; 5/(D 0 -Dj) may be greater than about 7 when (D 0 -D;)/D; may be greater than about 0.6; and the like.
  • Graph 500 shows that at low flow rates, the annulus gap width 502, (D 0 -Dj)/D z may not be a dominant factor determining termination distance ⁇ 218. Graph 500 shows that at low flow rates, the flow rate may be a significant factor determining termination distance ⁇ 218. Without wishing to be bound by theory, it is believed that at low flow rates, convective forces may be dominant and the non-condensable gas flow 217 may dilute pyrolysis vapor flow 209 and convect pyrolysis vapor flow 209 downstream. Graph 500 suggests that at high flow rates, convective forces may reach a maximum effect and radial diffusive fluxes may become dominant.
  • non- condensable gas flow 217 may mitigate or prevent pyrolysis vapor flow 209 from contacting the inside surface of non-condensable gas line 216 to mitigate or prevent condensate or deposit formation in non-condensing interface 210.
  • FIG. 6 is a flow diagram outlining an example method 600 effective for mitigating premature condensation of pyrolysis products.
  • Method 600 may include 602 directing a pyrolysis vapor flow into a condenser.
  • Method 600 may include 604 directing the pyrolysis vapor flow away from a condensable surface using a non-condensable gas flow.
  • directing the pyrolysis vapor flow away from the condensable surface using the non-condensable gas flow may include reducing, mitigating, or preventing the pyrolysis vapor flow from contacting the condensable surface.
  • the non-condensable gas flow may be effective to mitigate condensation of pyrolysis products from the pyrolysis vapor flow onto the condensable surface.
  • method 600 may include 606 heating the non-condensable gas flow to heat a priority condensable surface to a desired temperature, e.g., to provide a heated surface.
  • the desired temperature may be greater than a condensing temperature effective to mitigate condensation of pyrolysis products from the pyrolysis vapor flow onto the heated surface.
  • Non-condensing interface 210 may be configured to direct a pyrolysis vapor flow 209 into a condenser 206.
  • Non-condensing interface 210 may include a non-condensable gas line 216.
  • Non-condensable gas line 216 may be configured to be operatively coupled to direct a non- condensable gas flow 217 to condenser 206.
  • Non-condensing interface 210 may include a pyrolysis vapor line 208B.
  • Pyrolysis vapor line 208B may be coupled or configured to enter non-condensable gas line 216 such that non-condensable gas line 216 at least partly surrounds a portion of pyrolysis vapor line 208B.
  • Pyrolysis vapor line 208B may be configured to be physically uncoupled to condenser 206.
  • Pyrolysis vapor line 208B may be configured to direct pyrolysis vapor flow 209 into non-condensable gas line 216 and therefrom into condenser 206 such that pyrolysis vapor flow 209 is at least partly sheathed by non-condensable gas flow 217.
  • non-condensable gas line 216 may be configured to direct non-condensable gas flow 217 about at least a portion of pyrolysis vapor line 208B.
  • Non- condensable gas line 216 and pyrolysis vapor line 208B may be configured to respectively direct non-condensable gas flow 217 and pyrolysis vapor flow 209 in the same direction to condenser 206.
  • Non-condensable gas line 216 may cause non-condensable gas flow 217 to direct pyrolysis vapor flow 209 to condenser 206 and away from non-condensable gas line 216.
  • Non- condensable gas line 216 may cause non-condensable gas flow 217 to mitigate or prevent pyrolysis vapor flow 209 from contacting an inner wall of the non-condensable gas line 216.
  • non-condensing interface 210 may include condenser 206 operative ly coupled to non-condensable gas line 216.
  • a particle separator 204 may be operative ly coupled to convey pyrolysis vapor flow 209 to pyrolysis vapor line 208B.
  • a pyrolysis reactor 202 may be configured to produce pyrolysis vapor flow 209. Pyrolysis reactor 202 may be operatively coupled to convey pyrolysis vapor flow 209 to pyrolysis vapor line 208B, e.g., via another pyrolysis vapor line 208A and/or particle separator 204.
  • Non-condensing interface 210 may include pyrolysis reactor 202 together in a pyrolysis system 200.
  • Pyrolysis system 200 may be configured to maintain a constant or increasing temperature gradient from a pyrolysis temperature of pyrolysis reactor 202 to a desired temperature of pyrolysis vapor line 208B in non-condensing interface 210.
  • Pyrolysis system 200 may be configured to maintain a desired temperature of pyrolysis vapor line 208B in non-condensing interface 210 equal to or greater than another temperature in pyrolysis system 200.
  • Pyrolysis system 200 may be configured to maintain a desired temperature of pyrolysis vapor line 208B in non-condensing interface 210 greater than another temperature in pyrolysis system 200 by a temperature differential of at least about 5 °C.
  • Pyrolysis system 200 may include both pyrolysis reactor 202 and particle separator 204.
  • pyrolysis reactor 202 and particle separator 204 may be operatively coupled to convey pyrolysis vapor flow 209 through particle separator 204 and to pyrolysis vapor line 208B.
  • non-condensing interface 210 may include a heated source of non-condensable gas.
  • the heated source of non-condensable gas may be operatively coupled to provide non-condensable gas flow 217 heated effective to heat or maintain pyrolysis vapor line 208B in non-condensing interface 210 at a desired temperature.
  • the desired temperature of pyrolysis vapor line 208B in non-condensing interface 210 may be effective to mitigate or prevent formation of condensates or deposits from pyrolysis vapor flow 209.
  • the desired temperature of pyrolysis vapor line 208B may be equal or greater than a temperature of pyrolysis reactor 202.
  • the desired temperature of pyrolysis vapor line 208B may be equal or greater than a temperature of pyrolysis vapor flow 209 in non-condensing interface 210.
  • the heated source of non-condensable gas may provide non-condensable gas flow 217 to pyrolysis vapor line 208B in non-condensing interface 210 at a same or greater temperature compared to pyrolysis vapor flow 209 in pyrolysis vapor line 208B in non-condensing interface 210.
  • the heated source of non-condensable gas may provide non-condensable gas flow 217 at a temperature between about 450 °C and about 650 °C.
  • the heated source of non-condensable gas may provide non-condensable gas flow 217 substantially exclusive of a gas capable of reacting with a bio-oil in pyrolysis vapor flow 209.
  • the heated source of non-condensable gas may provide non-condensable gas flow 217 including one or more of: nitrogen; carbon dioxide; a noble gas; water vapor, a vapor of a saturated Ci-C 6 hydrocarbon; and a non-condensable gas exiting condenser 206.
  • the heated source of non-condensable gas may provide non-condensable gas flow 217 including one or more of: carbon dioxide; natural gas; and a non-condensable gas exiting condenser 206.
  • the heated source of non-condensable gas may include a heat exchanger 214, an electrical resistance heater, or a combustion heater.
  • the heated source of non- condensable gas may include a heat exchanger 214.
  • Heat exchanger 214 may be operatively coupled to condenser 206 to at least partly cool condenser 206 and direct heat extracted from condenser 206 to heat non-condensable gas flow 217.
  • the heated source of non-condensable gas may include a combustion heater (not shown).
  • the combustion heater may be configured to combust one or more of a pyrolysis char, a pyrolysis vapor, biomass, natural gas, propane, coal, or bio-oil.
  • non-condensable gas line 216 and pyrolysis vapor line 208B may be configured in a core-shell geometry.
  • Pyrolysis vapor line 208B may be configured as a core within a shell provided by non-condensable gas line 216 in non-condensing interface 210.
  • Non-condensable gas line 216 and pyrolysis vapor line 208B may be configured in an annular core-shell geometry in non-condensing interface 210.
  • Pyrolysis vapor line 208B may be terminated within non-condensable gas line 216 in non-condensing interface 210 before condenser 206 by a termination distance ⁇ 218.
  • pyrolysis vapor line 208B within non-condensable gas line 216 in non-condensing interface 210 may be physically separated or isolated from condenser 206 by termination distance 5 218.
  • Termination distance 5 218 may be effective to at least partly thermally isolate pyrolysis vapor line 208B from condenser 206 or one or more species within condenser 206.
  • non-condensable gas line 216 and pyrolysis vapor line 208B may be configured such that non-condensable gas flow 217 may provide at least a partial non- condensable flowing gas sheath around pyrolysis vapor flow 209 up to, e.g., through or across, at least termination distance 5 218.
  • Non-condensable gas line 216 and pyrolysis vapor line 208B may be configured to reduce a concentration of pyrolysis vapor flow 209 at an inside surface of non-condensable gas line 216, e.g., up to at least about termination distance ⁇ 218.
  • non-condensable gas line 216 and pyrolysis vapor line 208B may be configured to provide pyrolysis vapor flow 209 at an inside surface of non-condensable gas line 216 at a concentration of less than about 5% at termination distance ⁇ 218.
  • non-condensable gas line 216 and pyrolysis vapor line 208B together may define a region 215.
  • Region 215 may be characterized by an outside diameter D 0 302, an inside diameter D z 304, and a Reynolds number Reo 402.
  • Pyrolysis vapor line 208B may be terminated within non-condensable gas line 216 in non-condensing interface 210 before condenser 206 by a termination distance ⁇ 218. Further, 5/(D 0 -Dj) may be greater than about 5 when Reo 402 is greater than about 6,000.
  • 5/(D 0 -Dj) is may be greater than about 4 when (D 0 -D;)/D; is greater than about 0.15.
  • 5/(D 0 -Dj) may be greater than about 4 when (D 0 -D;)/D; is greater than about 0.3.
  • 5/(D 0 -Dj) may be greater than about 7 when (D 0 -D;)/D; is greater than about 0.6.
  • a pyrolysis system 200 may include a pyrolysis reactor 202.
  • Pyrolysis reactor 202 may be, for example, configured to pyrolyze biomass to provide a pyrolysis vapor flow 209.
  • Pyrolysis system 200 may include a condenser 206.
  • Condenser 206 may be configured to condense bio-oil from pyrolysis vapor flow 209.
  • Pyrolysis system 200 may include a non-condensable gas line 216.
  • Non-condensable gas line 216 may be operatively coupled to direct a non-condensable gas flow 217 to condenser 206.
  • Pyrolysis system 200 may include a pyrolysis vapor line 208B.
  • Pyrolysis vapor line 208B may be operatively coupled to pyrolysis reactor 202 to accept pyrolysis vapor flow 209.
  • Pyrolysis vapor line 208B may be coupled to non-condensable gas line 216 such that non-condensable gas line 216 at least partly surrounds a portion of pyrolysis vapor line 208B.
  • Pyrolysis vapor line 208B may be configured to be physically uncoupled to condenser 206.
  • pyrolysis vapor line 208B may be separated or physically isolated from condenser 206, e.g., by a termination distance ⁇ 218.
  • Pyrolysis vapor line 208B may be configured to direct pyrolysis vapor flow 209 into non-condensable gas line 216 and therefrom into condenser 206. Pyrolysis vapor flow 209 may be at least partly sheathed by non-condensable gas flow 217.
  • the portion of pyrolysis system 200 including pyrolysis vapor line 208B and non-condensable gas line 216, from where non-condensable gas line 216 at least partly surrounds a portion of pyrolysis vapor line 208B to where non-condensable gas line 216 may be coupled to the condenser 206, may be collectively termed a non-condensing interface 210.
  • non-condensable gas line 216 may be configured to direct non-condensable gas flow 217 about at least a portion of pyrolysis vapor line 208B.
  • Non- condensable gas line 216 and pyrolysis vapor line 208B may be configured to respectively direct non-condensable gas flow 217 and pyrolysis vapor flow 209 in the same direction to condenser 206.
  • Non-condensable gas line 216 may cause non-condensable gas flow 217 to direct pyrolysis vapor flow 209 to condenser 206 and away from non-condensable gas line 216.
  • Non- condensable gas line 216 may cause non-condensable gas flow 217 to mitigate or prevent pyrolysis vapor flow 209 from contacting an inner wall of the non-condensable gas line 216.
  • non-condensing interface 210 may include condenser 206 operative ly coupled to non-condensable gas line 216.
  • a particle separator 204 may be operative ly coupled to convey pyrolysis vapor flow 209 to pyrolysis vapor line 208B.
  • a pyrolysis reactor 202 may be configured to produce pyrolysis vapor flow 209. Pyrolysis reactor 202 may be operatively coupled to convey pyrolysis vapor flow 209 to pyrolysis vapor line 208B, e.g., via another pyrolysis vapor line 208A and/or particle separator 204.
  • non-condensing interface 210 may include a heated source of non-condensable gas.
  • the heated source of non-condensable gas may be operatively coupled to provide non-condensable gas flow 217 heated effective to heat or maintain pyrolysis vapor line 208B in non-condensing interface 210 at a desired temperature.
  • the desired temperature of pyrolysis vapor line 208B in non-condensing interface 210 may be effective to mitigate or prevent formation of condensates or deposits from pyrolysis vapor flow 209.
  • the desired temperature of pyrolysis vapor line 208B may be equal or greater than a temperature of pyrolysis reactor 202.
  • the desired temperature of pyrolysis vapor line 208B may be equal or greater than a temperature of pyrolysis vapor flow 209 in non-condensing interface 210.
  • the heated source of non-condensable gas may provide non-condensable gas flow 217 to pyrolysis vapor line 208B in non-condensing interface 210 at a same or greater temperature compared to pyrolysis vapor flow 209 in pyrolysis vapor line 208B in non-condensing interface 210.
  • the heated source of non-condensable gas may provide non-condensable gas flow 217 at a temperature between about 450 °C and about 650 °C.
  • the heated source of non-condensable gas may provide non-condensable gas flow 217 substantially exclusive of a gas capable of reacting with a bio-oil in pyrolysis vapor flow 209.
  • the heated source of non-condensable gas may provide non-condensable gas flow 217 including one or more of: nitrogen; carbon dioxide; a noble gas; water vapor, a vapor of a saturated Ci-C 6 hydrocarbon; or a non-condensable gas exiting condenser 206.
  • the heated source of non-condensable gas may provide non-condensable gas flow 217 including one or more of: carbon dioxide; natural gas; or a non-condensable gas exiting condenser 206.
  • the heated source of non-condensable gas may include a heat exchanger 214, an electrical resistance heater, or a combustion heater.
  • the heated source of non- condensable gas may include a heat exchanger 214.
  • Heat exchanger 214 may be operatively coupled to condenser 206 to at least partly cool condenser 206 and direct heat extracted from condenser 206 to heat non-condensable gas flow 217.
  • the heated source of non-condensable gas may include a combustion heater (not shown).
  • the combustion heater may be configured to combust one or more of a pyrolysis char, a pyrolysis vapor, biomass, natural gas, propane, coal, or bio-oil.
  • non-condensable gas line 216 and pyrolysis vapor line 208B may be configured in a core-shell geometry.
  • Pyrolysis vapor line 208B may be configured as a core within a shell provided by non-condensable gas line 216 in non-condensing interface 210.
  • Non-condensable gas line 216 and pyrolysis vapor line 208B may be configured in an annular core-shell geometry in non-condensing interface 210.
  • Pyrolysis vapor line 208B may be terminated within non-condensable gas line 216 in non-condensing interface 210 before condenser 206 by a termination distance ⁇ 218.
  • pyrolysis vapor line 208B within non-condensable gas line 216 in non-condensing interface 210 may be physically separated or isolated from condenser 206 by termination distance 5 218.
  • Termination distance 5 218 may be effective to at least partly thermally isolate pyrolysis vapor line 208B from condenser 206 or one or more species within condenser 206.
  • non-condensable gas line 216 and pyrolysis vapor line 208B may be configured such that non-condensable gas flow 217 may provide at least a partial non- condensable gas sheath around pyrolysis vapor flow 209 up to, e.g., through or across, at least termination distance 5 218.
  • Non-condensable gas line 216 and pyrolysis vapor line 208B may be configured to reduce a concentration of pyrolysis vapor flow 209 at an inside surface of non- condensable gas line 216, e.g., up to at least about termination distance 5 218.
  • non-condensable gas line 216 and pyrolysis vapor line 208B may be configured to reduce a concentration of pyrolysis vapor flow 209 at an inside surface of non-condensable gas line 216 to a concentration of less than about 5% at termination distance 5 218.
  • non-condensable gas line 216 and pyrolysis vapor line 208B together may define a region 215.
  • Region 215 may be characterized by an outside diameter D 0 302, an inside diameter D z 304, and a Reynolds number Reo 402.
  • Pyrolysis vapor line 208B may be terminated within non-condensable gas line 216 in non-condensing interface 210 before condenser 206 by a termination distance ⁇ 218. Further, 5/(D 0 -Dj) may be greater than about 5 when Reo 402 is greater than about 6,000.
  • 5/(D 0 -Dj) is may be greater than about 4 when (D 0 -D;)/D; is greater than about 0.15.
  • 5/(D 0 -Dj) may be greater than about 4 when (D o -D ⁇ /D, is greater than about 0.3.
  • 5/(D 0 -Dj) may be greater than about 7 when (D o -D ⁇ /D, is greater than about 0.6.
  • Method 600 may include 602 directing a pyrolysis vapor flow into a condenser.
  • Method 600 may include 604 directing the pyrolysis vapor flow away from a condensable surface using a non-condensable gas flow.
  • the non-condensable gas flow may be effective to mitigate condensation of pyrolysis products from the pyrolysis vapor flow onto the condensable surface.
  • method 600 may include 606 heating the non-condensable gas flow to heat a priority condensable surface to a desired temperature, e.g., to provide a heated surface.
  • the desired temperature may be greater than a condensing temperature effective to mitigate condensation of pyrolysis products from the pyrolysis vapor flow onto the heated surface.
  • method 600 may include 604 and 606.
  • method 600 may include pyrolyzing biomass to provide the pyrolysis vapor flow.
  • Method 600 may include removing char from the pyrolysis vapor flow.
  • the desired temperature may be equal to or greater than a pyrolysis temperature.
  • the desired temperature may be greater than a condensing temperature, for example, the temperature of a condensing step included in method 600.
  • the pyrolysis vapor flow may be directed to a condenser via a pyrolysis vapor line.
  • Method 600 may include at least partly thermally isolating the pyrolysis vapor line from the condenser.
  • Method 600 may include at least partly physically isolating the pyrolysis vapor line from the condenser.
  • Method 600 may include directing the pyrolysis vapor flow and the non-condensable gas flow in the same direction.
  • the desired temperature may be equal to or greater than the temperature of the pyrolysis vapor flow.
  • the pyrolysis vapor flow and the non-condensable gas flow may be at the same temperature.
  • the pyrolysis vapor flow and the non-condensable gas flow may be at the same temperature, e.g., about 500 °C.
  • the non-condensable gas flow may be at a greater temperature compared to the pyrolysis vapor flow by a temperature differential of at least about 5 °C.
  • the desired temperature may be equal to or greater than a temperature in a portion of a pyrolysis system or pyrolysis process.
  • the desired temperature may be equal to or greater than a temperature in a portion of a pyrolysis system or process by a temperature differential, e.g., a temperature differential of at least about 5 °C.
  • Method 600 may be conducted in a pyrolysis system and a temperature gradient of the pyrolysis system may be increased from a pyrolysis process or reactor to the desired temperature.
  • the temperature gradient of the pyrolysis system may increase monotonically from a pyrolysis process to the desired temperature.
  • the method 600 may include heating the non-condensable gas flow.
  • the non-condensable gas flow may be heated to a temperature between about 450 °C and about 650 °C.
  • the non-condensable gas flow may be provided substantially exclusive of an oxidizing gas.
  • the non-condensable gas flow may be provided substantially exclusive of a gas capable of reacting with a bio-oil in the pyrolysis vapor flow.
  • the non-condensable gas flow may be provided including one or more of: nitrogen; carbon dioxide; a noble gas; water vapor, a vapor of a saturated Ci-C 6 hydrocarbon; or a non-condensable gas exiting a condenser.
  • the non- condensable gas flow may be provided including one or more of: carbon dioxide; natural gas; or a non-condensable gas exiting a condenser.
  • method 600 may include heating the non-condensable gas flow using a heat exchanger, an electrical resistance heater, or a combustion heater.
  • Method 600 may include heating the non-condensable gas flow by exchanging heat from a condensing process to at least partly cool the condensing process.
  • Method 600 may include heating the non- condensable gas flow by exchanging heat to at least partly heat the non-condensable gas flow.
  • Method 600 may include heating the non-condensable gas flow by exchanging heat between a condensing process and the non-condensable gas flow to at least partly cool the condensing process and at least partly heat the non-condensable gas flow.
  • Method 600 may include heating the non-condensable gas flow by combusting one or more of a pyrolysis char, a pyrolysis vapor, biomass, natural gas, propane, coal, and bio-oil. Method 600 may include directing the pyrolysis vapor flow away from the condensable surface using the non-condensable gas flow including at least partly sheathing the pyrolysis vapor flow in the non-condensable gas flow.
  • method 600 may include directing the pyrolysis vapor flow away from the condensable surface using the non-condensable gas flow including sheathing the pyrolysis vapor flow 209 in the non-condensable gas flow 217 in a core-shell configuration.
  • Directing the pyrolysis vapor flow 209 away from the condensable surface using the non- condensable gas flow may include sheathing the pyrolysis vapor flow in the non-condensable gas flow in an annular core-shell configuration.
  • Directing the pyrolysis vapor including using a pyrolysis vapor line may include separating the pyrolysis vapor line from a condenser by a termination distance ⁇ .
  • the termination distance ⁇ may be effective to at least partly thermally isolate the pyrolysis vapor line from the condenser or one or more species within the condenser.
  • Directing the pyrolysis vapor flow away from the condensable surface using the non- condensable gas flow may include sheathing the pyrolysis vapor flow in the non-condensable gas flow.
  • the non-condensable gas flow may at least partly sheathe the pyrolysis vapor flow up to at least the termination distance ⁇ .
  • Directing the pyrolysis vapor flow away from the condensable surface using the non-condensable gas flow may include sheathing the pyrolysis vapor flow in the non-condensable gas flow.
  • the non-condensable gas flow may at least partly sheathe the pyrolysis vapor flow, e.g., up to at least about the termination distance ⁇ .
  • the non- condensable gas flow may at least partly sheathe the pyrolysis vapor flow up to at least the termination distance ⁇ such that the non-pyrolysis vapor flow may be at a concentration of less than about 5% at an inside surface of a non-condensable gas line at the termination distance ⁇ .
  • directing the pyrolysis vapor flow away from the condensable surface using the non-condensable gas flow may include sheathing the pyrolysis vapor flow in the non-condensable gas flow in a core-shell configuration.
  • the core-shell configuration may define a region between the core and the shell. The region may be characterized by an outside diameter D 0 302, an inside diameter D z 304, and a Reynolds number Reo 402 such that 5/(D 0 -Dj) may be greater than about 5 when Reo 402 is greater than about 6,000.
  • 5/(D 0 -D z ) may be greater than about 4 when (D 0 -Dj)/D z is greater than about 0.15. In some embodiments, 5/(D 0 -Dj) may be greater than about 4 when (D o -D ⁇ /D, is greater than about 0.3. In some embodiments, 5/(D 0 -Dj) may be greater than about 7 when (D 0 -Dj)/Dj is greater than about 0.6.

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  • Oil, Petroleum & Natural Gas (AREA)
  • Organic Chemistry (AREA)
  • General Chemical & Material Sciences (AREA)
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Abstract

L'invention concerne des procédés et des appareils servant à atténuer le dépôt prématuré de condensat en provenance du gaz de pyrolyse et l'obturation d'une entrée de condenseur. À titre d'exemple, un procédé servant à atténuer la condensation prématurée peut consister à introduire un écoulement de vapeur de pyrolyse dans un condenseur et à éloigner l'écoulement de vapeur de pyrolyse d'une surface condensable placée avant le condenseur à l'aide d'un écoulement de gaz non-condensable. L'écoulement de gaz non condensable peut être efficace pour atténuer la condensation prématurée des produits de pyrolyse en provenance de l'écoulement de vapeur de pyrolyse sur la surface condensable. En outre, ou selon une autre variante, le procédé peut consister à chauffer l'écoulement de gaz non condensable afin de chauffer une surface précédemment condensable jusqu'à une température souhaitée, pour produire par exemple une surface chauffée. La température souhaitée peut être supérieure à une température de condensation, efficace pour atténuer la condensation des produits de pyrolyse en provenance de l'écoulement de vapeur de pyrolyse sur la surface chauffée.
PCT/US2015/060577 2014-11-14 2015-11-13 Entrée de condenseur pour gaz de pyrolyse WO2016077694A1 (fr)

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Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US1230557A (en) * 1914-07-31 1917-06-19 John J Brown Condensing apparatus.
US4873829A (en) * 1988-08-29 1989-10-17 Williamson Anthony R Steam power plant
US20020035950A1 (en) * 1996-12-05 2002-03-28 Helmut Mangold Doped, pyrogenically prepared oxides
EP1619169A1 (fr) * 2004-07-20 2006-01-25 E. I. du Pont de Nemours and Company Procédé pour la fabrication de nanopoudre d'oxyde metallique
US8476480B1 (en) * 2008-08-29 2013-07-02 Iowa State University Research Foundation, Inc. Bio-oil fractionation and condensation
WO2015175610A1 (fr) * 2014-05-13 2015-11-19 Holtec International Système de conditionnement de vapeur

Patent Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US1230557A (en) * 1914-07-31 1917-06-19 John J Brown Condensing apparatus.
US4873829A (en) * 1988-08-29 1989-10-17 Williamson Anthony R Steam power plant
US20020035950A1 (en) * 1996-12-05 2002-03-28 Helmut Mangold Doped, pyrogenically prepared oxides
EP1619169A1 (fr) * 2004-07-20 2006-01-25 E. I. du Pont de Nemours and Company Procédé pour la fabrication de nanopoudre d'oxyde metallique
US8476480B1 (en) * 2008-08-29 2013-07-02 Iowa State University Research Foundation, Inc. Bio-oil fractionation and condensation
WO2015175610A1 (fr) * 2014-05-13 2015-11-19 Holtec International Système de conditionnement de vapeur

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