Classifications

• • C—CHEMISTRY; METALLURGY
  • C07—ORGANIC CHEMISTRY
  • C07C—ACYCLIC OR CARBOCYCLIC COMPOUNDS
  • C07C29/00—Preparation of compounds having hydroxy or O-metal groups bound to a carbon atom not belonging to a six-membered aromatic ring
  • C07C29/15—Preparation of compounds having hydroxy or O-metal groups bound to a carbon atom not belonging to a six-membered aromatic ring by reduction of oxides of carbon exclusively
  • C07C29/151—Preparation of compounds having hydroxy or O-metal groups bound to a carbon atom not belonging to a six-membered aromatic ring by reduction of oxides of carbon exclusively with hydrogen or hydrogen-containing gases
  • C07C29/1516—Multisteps
  • C07C29/1518—Multisteps one step being the formation of initial mixture of carbon oxides and hydrogen for synthesis
• • C—CHEMISTRY; METALLURGY
  • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
  • C10J—PRODUCTION OF PRODUCER GAS, WATER-GAS, SYNTHESIS GAS FROM SOLID CARBONACEOUS MATERIAL, OR MIXTURES CONTAINING THESE GASES; CARBURETTING AIR OR OTHER GASES
  • C10J3/00—Production of combustible gases containing carbon monoxide from solid carbonaceous fuels
  • C10J3/46—Gasification of granular or pulverulent flues in suspension
  • C10J3/48—Apparatus; Plants
  • C10J3/485—Entrained flow gasifiers
• • C—CHEMISTRY; METALLURGY
  • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
  • C10J—PRODUCTION OF PRODUCER GAS, WATER-GAS, SYNTHESIS GAS FROM SOLID CARBONACEOUS MATERIAL, OR MIXTURES CONTAINING THESE GASES; CARBURETTING AIR OR OTHER GASES
  • C10J3/00—Production of combustible gases containing carbon monoxide from solid carbonaceous fuels
  • C10J3/58—Production of combustible gases containing carbon monoxide from solid carbonaceous fuels combined with pre-distillation of the fuel
  • C10J3/60—Processes
  • C10J3/62—Processes with separate withdrawal of the distillation products
• • 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
  • C10K1/002—Removal of contaminants
  • C10K1/003—Removal of contaminants of acid contaminants, e.g. acid gas removal
  • C10K1/004—Sulfur containing contaminants, e.g. hydrogen sulfide
• • C—CHEMISTRY; METALLURGY
  • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
  • C10L—FUELS NOT OTHERWISE PROVIDED FOR; NATURAL GAS; SYNTHETIC NATURAL GAS OBTAINED BY PROCESSES NOT COVERED BY SUBCLASSES C10G, C10K; LIQUEFIED PETROLEUM GAS; ADDING MATERIALS TO FUELS OR FIRES TO REDUCE SMOKE OR UNDESIRABLE DEPOSITS OR TO FACILITATE SOOT REMOVAL; FIRELIGHTERS
  • C10L5/00—Solid fuels
  • C10L5/40—Solid fuels essentially based on materials of non-mineral origin
  • C10L5/44—Solid fuels essentially based on materials of non-mineral origin on vegetable substances
  • C10L5/442—Wood or forestry waste
• • C—CHEMISTRY; METALLURGY
  • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
  • C10L—FUELS NOT OTHERWISE PROVIDED FOR; NATURAL GAS; SYNTHETIC NATURAL GAS OBTAINED BY PROCESSES NOT COVERED BY SUBCLASSES C10G, C10K; LIQUEFIED PETROLEUM GAS; ADDING MATERIALS TO FUELS OR FIRES TO REDUCE SMOKE OR UNDESIRABLE DEPOSITS OR TO FACILITATE SOOT REMOVAL; FIRELIGHTERS
  • C10L9/00—Treating solid fuels to improve their combustion
  • C10L9/08—Treating solid fuels to improve their combustion by heat treatments, e.g. calcining
  • C10L9/083—Torrefaction
• • C—CHEMISTRY; METALLURGY
  • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
  • C10J—PRODUCTION OF PRODUCER GAS, WATER-GAS, SYNTHESIS GAS FROM SOLID CARBONACEOUS MATERIAL, OR MIXTURES CONTAINING THESE GASES; CARBURETTING AIR OR OTHER GASES
  • C10J2300/00—Details of gasification processes
  • C10J2300/09—Details of the feed, e.g. feeding of spent catalyst, inert gas or halogens
  • C10J2300/0903—Feed preparation
  • C10J2300/0906—Physical processes, e.g. shredding, comminuting, chopping, sorting
• • C—CHEMISTRY; METALLURGY
  • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
  • C10J—PRODUCTION OF PRODUCER GAS, WATER-GAS, SYNTHESIS GAS FROM SOLID CARBONACEOUS MATERIAL, OR MIXTURES CONTAINING THESE GASES; CARBURETTING AIR OR OTHER GASES
  • C10J2300/00—Details of gasification processes
  • C10J2300/09—Details of the feed, e.g. feeding of spent catalyst, inert gas or halogens
  • C10J2300/0903—Feed preparation
  • C10J2300/0909—Drying
• • C—CHEMISTRY; METALLURGY
  • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
  • C10J—PRODUCTION OF PRODUCER GAS, WATER-GAS, SYNTHESIS GAS FROM SOLID CARBONACEOUS MATERIAL, OR MIXTURES CONTAINING THESE GASES; CARBURETTING AIR OR OTHER GASES
  • C10J2300/00—Details of gasification processes
  • C10J2300/09—Details of the feed, e.g. feeding of spent catalyst, inert gas or halogens
  • C10J2300/0913—Carbonaceous raw material
  • C10J2300/0916—Biomass
• • C—CHEMISTRY; METALLURGY
  • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
  • C10J—PRODUCTION OF PRODUCER GAS, WATER-GAS, SYNTHESIS GAS FROM SOLID CARBONACEOUS MATERIAL, OR MIXTURES CONTAINING THESE GASES; CARBURETTING AIR OR OTHER GASES
  • C10J2300/00—Details of gasification processes
  • C10J2300/09—Details of the feed, e.g. feeding of spent catalyst, inert gas or halogens
  • C10J2300/0913—Carbonaceous raw material
  • C10J2300/0916—Biomass
  • C10J2300/092—Wood, cellulose
• • C—CHEMISTRY; METALLURGY
  • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
  • C10J—PRODUCTION OF PRODUCER GAS, WATER-GAS, SYNTHESIS GAS FROM SOLID CARBONACEOUS MATERIAL, OR MIXTURES CONTAINING THESE GASES; CARBURETTING AIR OR OTHER GASES
  • C10J2300/00—Details of gasification processes
  • C10J2300/09—Details of the feed, e.g. feeding of spent catalyst, inert gas or halogens
  • C10J2300/0953—Gasifying agents
  • C10J2300/0973—Water
  • C10J2300/0976—Water as steam
• • C—CHEMISTRY; METALLURGY
  • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
  • C10J—PRODUCTION OF PRODUCER GAS, WATER-GAS, SYNTHESIS GAS FROM SOLID CARBONACEOUS MATERIAL, OR MIXTURES CONTAINING THESE GASES; CARBURETTING AIR OR OTHER GASES
  • C10J2300/00—Details of gasification processes
  • C10J2300/12—Heating the gasifier
  • C10J2300/1246—Heating the gasifier by external or indirect heating
• • C—CHEMISTRY; METALLURGY
  • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
  • C10J—PRODUCTION OF PRODUCER GAS, WATER-GAS, SYNTHESIS GAS FROM SOLID CARBONACEOUS MATERIAL, OR MIXTURES CONTAINING THESE GASES; CARBURETTING AIR OR OTHER GASES
  • C10J2300/00—Details of gasification processes
  • C10J2300/12—Heating the gasifier
  • C10J2300/1269—Heating the gasifier by radiating device, e.g. radiant tubes
• • C—CHEMISTRY; METALLURGY
  • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
  • C10J—PRODUCTION OF PRODUCER GAS, WATER-GAS, SYNTHESIS GAS FROM SOLID CARBONACEOUS MATERIAL, OR MIXTURES CONTAINING THESE GASES; CARBURETTING AIR OR OTHER GASES
  • C10J2300/00—Details of gasification processes
  • C10J2300/16—Integration of gasification processes with another plant or parts within the plant
  • C10J2300/164—Integration of gasification processes with another plant or parts within the plant with conversion of synthesis gas
  • C10J2300/1656—Conversion of synthesis gas to chemicals
  • C10J2300/1665—Conversion of synthesis gas to chemicals to alcohols, e.g. methanol or ethanol
• • C—CHEMISTRY; METALLURGY
  • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
  • C10J—PRODUCTION OF PRODUCER GAS, WATER-GAS, SYNTHESIS GAS FROM SOLID CARBONACEOUS MATERIAL, OR MIXTURES CONTAINING THESE GASES; CARBURETTING AIR OR OTHER GASES
  • C10J2300/00—Details of gasification processes
  • C10J2300/18—Details of the gasification process, e.g. loops, autothermal operation
  • C10J2300/1853—Steam reforming, i.e. injection of steam only
• • C—CHEMISTRY; METALLURGY
  • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
  • C10J—PRODUCTION OF PRODUCER GAS, WATER-GAS, SYNTHESIS GAS FROM SOLID CARBONACEOUS MATERIAL, OR MIXTURES CONTAINING THESE GASES; CARBURETTING AIR OR OTHER GASES
  • C10J2300/00—Details of gasification processes
  • C10J2300/18—Details of the gasification process, e.g. loops, autothermal operation
  • C10J2300/1861—Heat exchange between at least two process streams
  • C10J2300/1884—Heat exchange between at least two process streams with one stream being synthesis gas
• • C—CHEMISTRY; METALLURGY
  • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
  • C10J—PRODUCTION OF PRODUCER GAS, WATER-GAS, SYNTHESIS GAS FROM SOLID CARBONACEOUS MATERIAL, OR MIXTURES CONTAINING THESE GASES; CARBURETTING AIR OR OTHER GASES
  • C10J2300/00—Details of gasification processes
  • C10J2300/18—Details of the gasification process, e.g. loops, autothermal operation
  • C10J2300/1861—Heat exchange between at least two process streams
  • C10J2300/1892—Heat exchange between at least two process streams with one stream being water/steam
• • C—CHEMISTRY; METALLURGY
  • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
  • C10L—FUELS NOT OTHERWISE PROVIDED FOR; NATURAL GAS; SYNTHETIC NATURAL GAS OBTAINED BY PROCESSES NOT COVERED BY SUBCLASSES C10G, C10K; LIQUEFIED PETROLEUM GAS; ADDING MATERIALS TO FUELS OR FIRES TO REDUCE SMOKE OR UNDESIRABLE DEPOSITS OR TO FACILITATE SOOT REMOVAL; FIRELIGHTERS
  • C10L2290/00—Fuel preparation or upgrading, processes or apparatus therefore, comprising specific process steps or apparatus units
  • C10L2290/02—Combustion or pyrolysis
• • C—CHEMISTRY; METALLURGY
  • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
  • C10L—FUELS NOT OTHERWISE PROVIDED FOR; NATURAL GAS; SYNTHETIC NATURAL GAS OBTAINED BY PROCESSES NOT COVERED BY SUBCLASSES C10G, C10K; LIQUEFIED PETROLEUM GAS; ADDING MATERIALS TO FUELS OR FIRES TO REDUCE SMOKE OR UNDESIRABLE DEPOSITS OR TO FACILITATE SOOT REMOVAL; FIRELIGHTERS
  • C10L2290/00—Fuel preparation or upgrading, processes or apparatus therefore, comprising specific process steps or apparatus units
  • C10L2290/04—Gasification
• • C—CHEMISTRY; METALLURGY
  • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
  • C10L—FUELS NOT OTHERWISE PROVIDED FOR; NATURAL GAS; SYNTHETIC NATURAL GAS OBTAINED BY PROCESSES NOT COVERED BY SUBCLASSES C10G, C10K; LIQUEFIED PETROLEUM GAS; ADDING MATERIALS TO FUELS OR FIRES TO REDUCE SMOKE OR UNDESIRABLE DEPOSITS OR TO FACILITATE SOOT REMOVAL; FIRELIGHTERS
  • C10L2290/00—Fuel preparation or upgrading, processes or apparatus therefore, comprising specific process steps or apparatus units
  • C10L2290/06—Heat exchange, direct or indirect
• • C—CHEMISTRY; METALLURGY
  • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
  • C10L—FUELS NOT OTHERWISE PROVIDED FOR; NATURAL GAS; SYNTHETIC NATURAL GAS OBTAINED BY PROCESSES NOT COVERED BY SUBCLASSES C10G, C10K; LIQUEFIED PETROLEUM GAS; ADDING MATERIALS TO FUELS OR FIRES TO REDUCE SMOKE OR UNDESIRABLE DEPOSITS OR TO FACILITATE SOOT REMOVAL; FIRELIGHTERS
  • C10L2290/00—Fuel preparation or upgrading, processes or apparatus therefore, comprising specific process steps or apparatus units
  • C10L2290/08—Drying or removing water
• • C—CHEMISTRY; METALLURGY
  • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
  • C10L—FUELS NOT OTHERWISE PROVIDED FOR; NATURAL GAS; SYNTHETIC NATURAL GAS OBTAINED BY PROCESSES NOT COVERED BY SUBCLASSES C10G, C10K; LIQUEFIED PETROLEUM GAS; ADDING MATERIALS TO FUELS OR FIRES TO REDUCE SMOKE OR UNDESIRABLE DEPOSITS OR TO FACILITATE SOOT REMOVAL; FIRELIGHTERS
  • C10L2290/00—Fuel preparation or upgrading, processes or apparatus therefore, comprising specific process steps or apparatus units
  • C10L2290/28—Cutting, disintegrating, shredding or grinding
• • C—CHEMISTRY; METALLURGY
  • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
  • C10L—FUELS NOT OTHERWISE PROVIDED FOR; NATURAL GAS; SYNTHETIC NATURAL GAS OBTAINED BY PROCESSES NOT COVERED BY SUBCLASSES C10G, C10K; LIQUEFIED PETROLEUM GAS; ADDING MATERIALS TO FUELS OR FIRES TO REDUCE SMOKE OR UNDESIRABLE DEPOSITS OR TO FACILITATE SOOT REMOVAL; FIRELIGHTERS
  • C10L2290/00—Fuel preparation or upgrading, processes or apparatus therefore, comprising specific process steps or apparatus units
  • C10L2290/56—Specific details of the apparatus for preparation or upgrading of a fuel
  • C10L2290/562—Modular or modular elements containing apparatus
• • D—TEXTILES; PAPER
  • D21—PAPER-MAKING; PRODUCTION OF CELLULOSE
  • D21B—FIBROUS RAW MATERIALS OR THEIR MECHANICAL TREATMENT
  • D21B1/00—Fibrous raw materials or their mechanical treatment
  • D21B1/04—Fibrous raw materials or their mechanical treatment by dividing raw materials into small particles, e.g. fibres
  • D21B1/12—Fibrous raw materials or their mechanical treatment by dividing raw materials into small particles, e.g. fibres by wet methods, by the use of steam
  • D21B1/30—Defibrating by other means
  • D21B1/36—Explosive disintegration by sudden pressure reduction
• • 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
• • 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
  • Y02E50/30—Fuel from waste, e.g. synthetic alcohol or diesel
• • 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
  • Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
  • Y02P20/00—Technologies relating to chemical industry
  • Y02P20/141—Feedstock
  • Y02P20/145—Feedstock the feedstock being materials of biological origin

Definitions

• the design generally relates to treatment of biomass using steam explosion methods as a pre-process before gasification or combustion.
• the design specifically relates to an integrated plant that uses this biomass to produce a liquid fuel from the biomass or to convert the biomass into a densified form to facilitate economic transport to facilities for further processing to liquid fuel, heat/power, animal feed, bedding, or chemicals.
• An integrated plant that includes a steam explosion unit and biomass gasifier to generate syngas from biomass.
• a steam explosion unit applies a combination of heat, pressure, and moisture to the biomass to make the biomass into a moist, fine particle form.
• the steam explosion unit applies steam with a high pressure to heat and pressurize any gases and fluids present inside the biomass to internally blow apart the bulk structure of the biomass via a rapid depressurization of the biomass with the increased moisture content.
• Those produced moist, fine particles of biomass are subsequently fed to a feed section of the biomass gasifier, which reacts with the biomass particles in a rapid biomass gasification reaction to produce syngas components.
• the moist, fine particles may be processed into densified forms (such as pellets) to facilitate economic transport to facilities for further processing to liquid fuel, heat/power, animal feed, litter, or chemicals.
• Figures 1 A and 1 B illustrate flow schematics of embodiments of a steam explosion unit having an input cavity to receive biomass as a feedstock, two or more steam supply inputs, and two or more stages to pre-treat the biomass for subsequent supply to a biomass gasifier.
• Figure 2 illustrates a flow schematic of an embodiment of a steam explosion unit having a steam explosion stage that supplies particles of biomass to either a dryer, the torrefaction unit, a densification unit, the biomass gasifier, or to a catalytic converter.
• Figures 3-1 to 3-5 illustrates alternative configurations for exemplary biomass gasifiers.
• Figures 3A and 3B illustrate embodiments of flow diagrams of an integrated plant to generate syngas from biomass and generate a liquid fuel product from the syngas, or biomass in a densified form.
• Figures 4A-C illustrate different levels of magnification of an example chip of biomass having a fiber bundle of cellulose fibers surrounded and bonded together by lignin.
• Figure 4D illustrates example chips of biomass exploded into fine particles of biomass.
• Figure 4E illustrates a chip of biomass having a bundle of fibers that are frayed or partially separated into individual fibers.
• Figure 5 illustrates a flow schematic of an embodiment for the radiant heat chemical reactor configured to generate chemical products including synthesis gas products.
• the integrated plant contains at least a steam explosion unit and a biomass gasifier to generate syngas from biomass.
• the steam explosion unit may have an input cavity to receive biomass as a feedstock, one or more steam supply inputs, and two or more stages to pre-treat the biomass for subsequent supply to the biomass gasifier. The stages use a
• the steam explosion process breaks down a bulk structure of the received biomass, at least in part, by applying steam from a first steam supply input to begin degrading bonds between lignin and hemi- cellulose from cellulose fibers of the biomass and increase a moisture content of the received biomass.
• steam at at least ten times atmospheric pressure from a second steam supply input is applied to heat and pressurize any gases and fluids present inside the biomass to internally blow apart the bulk structure of the received biomass via a rapid depressurization of the biomass with the increased moisture content and degraded bonds.
• the biomass produced into the moist fine particle form from the stages has average dimensions of less than 70 microns thick and less than 500 microns in length. Those produced moist fine particles of biomass are subsequently fed to a feed section of the biomass gasifier.
• the biomass gasifier has a reactor vessel configured to react the biomass in moist fine particle form with an increased surface area and decreased particle size due to being blown apart by the steam explosion unit.
• the biomass gasifier has a third steam supply input and one or more heaters, and in the presence of the steam the biomass in fine particle form are reacted in the reactor vessel in a rapid biomass gasification reaction in greater than 0.1 second resident time to produce at least syngas components, including hydrogen (H2) and carbon monoxide (CO).
• a possible biomass gasifier implementation has a high temperature steam supply input and one or more heaters, such as, for example, gas fire burners or regenerative heaters.
• the particles of the biomass broken down by the steam explosion unit are reacted in the reactor vessel in a rapid biomass gasification reaction at a temperature of greater than 700 degrees C in less than a one second residence time in the biomass gasifier to create syngas components, including hydrogen (H2) and carbon monoxide (CO), which are fed to a methanol (CH30H) synthesis reactor.
• H2 hydrogen
• CO carbon monoxide
• the one or more steam supply inputs may include a low pressure steam produced from recycled dirty water recovered from the one or more cyclone units.
• embodiments as described herein include tapping off-gases from the cyclone unit and feeding the off-gases to the biomass gasifier.
• the design also may include a few ways to decrease the overall steam to biomass ratios used in the SEP process in order to decrease the amount of dirty water being produced from the plant and therefore may make drying the resultant particles of biomass easier.
• Turpentine and other volatiles may be delivered to the biomass gasifier via steam atomization of the dirty condensate water recovered from the one or more cyclone units.
• a feeding steam containing volatiles/turpentine may include off gases from the one or more cyclones and fed into the gasifier.
• a turpentine recovery unit may be included, with product to sales, the gasifier, or the burner system for the gasifier or reformer.
• no additional air is introduced between the SEP pretreatment step of the biomass particles and the entrained gas feeding of the biomass particles into the biomass gasifier, which reduces emissions and purge gases.
• Options may be included for using the motive gas out of the steam explosion unit for entrainment in the biomass gasifier.
• Methods may also be incorporated to reduce pressure in the exit of the steam explosion unit to reduce motive gas. Accordingly, one or more pressure reduction areas may be included to reduce the high pressure from the SEP vessel to a lower discharge pressure. Therefore, the design may include locating pressure drop points out of the steam explosion unit to reduce the pressure from the high pressure in the steam explosion unit to a reduced pressure such a s 4-10 bar. The pressure drop may occur earlier in the pipe leading to the cyclone.
• FIG. 1 A and 1 B illustrate flow schematics of embodiments of a steam explosion unit having an input cavity to receive biomass as a feedstock, two or more steam supply inputs, and two or more stages to pre-treat the biomass for subsequent supply to a biomass gasifier.
• Moisture values in the incoming biomass in chip form can vary from about 15% to 60% for biomass left outside without extra drying. Chips of biomass may be generated by a chipper unit 104 cooperating with some filters with dimensions to create chips of less than about one inch and on average about 0.5 inches in average length and a 1 ⁇ 4 inch in thickness on average.
• the biomass chipper unit 104 may contain four or more blades used to chop and chip the biomass.
• the feed speed of the logs of biomass, the speed of the knife blades, the protrusion distance of the knives and the angle of the knives, can all act to control the chip size.
• the chips are then screened and those that are oversized may be rechipped. There may be a blending of chips from different sources or timber species to enhance certain properties.
• a magnet or other scanner may be passed over to detect and remove impurities.
• Chips of biomass are fed on a conveyor or potentially placed in a pressure vessel in the thermally decomposing stage in the steam explosion unit 108 that starts a decomposition, hydrating/moistening, and softening of the chips of biomass using initially low-pressure saturated steam.
• the low-pressure saturated steam may be at 100 degrees C.
• the system may also inject some flow aids at this point, such as recycled ash from the biomass gasifier 1 14, to prevent clogs and plugging by the biomass chips.
• the chipper unit 104 may feed to and the steam explosion unit 108 is configured to receive two or more types of biomass feed stocks, where the different types of biomass include 1 ) soft woods, 2) hard woods, 3) grasses, 4) plant hulls, and 5) any combination that are blended and steam explosion processed into a homogenized torrefied feedstock within the steam explosion unit 108 that is subsequently collected and then fed into the biomass gasifier 1 14.
• the steam explosion unit 108, torrefaction unit 1 12, and biomass gasifier 1 14 are designed to be feedstock flexible without changing out the physical design of the feed supply equipment or the physical design of the biomass gasifier 1 14 via at least particle size control of the biomass particles produced from steam explosion stage and torrefaction unit 1 12.
• the steam explosion unit 108 has an input cavity to receive biomass as a feedstock, one or more steam supply inputs, and two or more stages to pre-treat the biomass for subsequent supply to a biomass gasifier 1 14.
• the stages use a combination of heat, pressure, and moisture that are applied to the biomass to make the biomass into a moist fine particle form.
• the steam explosion process breaks down a bulk structure of the received biomass, at least in part, by applying steam from a low pressure steam supply input to begin degrading bonds between lignin and hemi-cellulose from cellulose fibers of the biomass and increase a moisture content of the received biomass.
• the two or more stages of the steam explosion unit 108 include at least a thermally hydrating stage and a steam explosion stage.
• the thermally hydrating stage has the input cavity to receive chips of the biomass and the low pressure steam supply input to apply low-pressure saturated steam into a vessel containing the chips of biomass.
• the thermally hydrating stage is configured to receive the biomass in chip form including leaves, needles, bark, and wood.
• the thermally hydrating stage applies the low-pressure steam to the biomass at a temperature above a glass transition point of the lignin in order to soften and elevate the moisture content the biomass so the cellulose fibers of the biomass in the steam explosion stage can easily be internally blown apart from the biomass in chip form.
• the chips of biomass are heated to greater than 60 Q C using the steam.
• the low pressure steam supply input applies low-pressure saturated steam into a vessel containing the chips of biomass at an elevated temperature of above 60 degrees C but less than 145 degrees C at a pressure around atmospheric PSI, to start a decomposition, hydrating, and softening of the received biomass in chip form.
• the low pressure supply input may consist of several nozzles strategically placed around the vessel. The chips stay in the thermally hydrating stage long enough to saturate with moisture.
• the thermally hydrating stage feeds chips of biomass that have been softened and increased in moisture content to the steam explosion stage, which is at a pressure 10 to 40 times the pressure as is present in the thermally hydrating stage and an elevated temperature, such as a temperature of 160-270 Q C, 204 Q C preferably.
• the pressure may be at 180 - 850 Pound per Square Inch (PSI) (256 PSI preferably).
• PSI Pound per Square Inch
• the steam explosion stage further raises the moisture content of the biomass to at least 40% by weight and preferably 50 to 60% moisture content by weight.
• the % moisture by weight may be the weight of water divided by a total weight consisting of the chips of biomass plus a water weight.
• the softened and hydrated chips of biomass are exposed to high temperature and high-pressure steam for a sufficient time period, such as 3 minutes to 15 minutes, to create high pressure steam inside the partially hollow cellulose fibers and other porous areas in the bulk structure of the biomass material.
• a sufficient time period such as 3 minutes to 15 minutes.
• SEP Steam Explosion Process
• the softened biomass in chip form are any combination of 1 ) crushed and 2) compressed into a plug form, which is then fed into a continuous screw conveyor system.
• the continuous screw conveyor system moves the biomass in plug form into the steam explosion stage.
• the continuous screw conveyor system uses the biomass in plug form to prevent blow back backpressure from the high-pressure steam present in the steam explosion stage from affecting the thermally hydrating stage.
• Other methods could be used such as 1 ) check valves and 2) moving biomass in stages where each stage is isolatable by an opening and closing mechanism.
• the steam explosion stage can operate at pressures up to 850 psi.
• the plug screw feeder conveys the chips along the steam explosion stage.
• High- pressure steam is introduced into the plug screw feeder in a section called the steam mixing conveyor.
• the high pressure supply input may consist of several nozzles strategically placed around the steam mixing conveyor. Retention time of the biomass chip material through the steam explosion stage is accurately controlled via the plug screw feeder.
• the biomass in plug form is exposed to high temperature and high pressure steam at at least 160 degree C and 160 PSI from the high pressure steam input for at least 5 minutes and preferably around 10 minutes until moisture penetrates porous portions of the bulk structure of the biomass and all of the liquids and gases in the biomass are raised to the high pressure.
• the system needs a certain level of humidity/moisture in the biomass chips to provide the source of explosion. So usually, the chip's moisture is generally at least 50 to 55% by weight while in the steam explosion reactor.
• the pressure and temperature are raised in a chamber containing the chips of biomass with softened lignin to an increased temperature of at least twenty degrees greater than an operating environment of the vessel with chips of biomass in the thermally hydrating stage and to an increased pressure greater than ten times atmospheric in the chamber but for a shorter duration than the set period of time in the thermally hydrating stage.
• the continuous screw conveyor system feeds the biomass in plug form through the steam explosion stage to an exit.
• a small opening forms the exit and goes into a tube or other container area that is maintained at around 4-10 bar of pressure and any internal fluids or gases at the high pressure expand to internally blow apart the biomass.
• the pressure drop is from the high pressure in the Steam Explosion reactor all the way down to atmospheric pressure. In either case, the large pressure drop occurring in the tube or other container between the exit in the steam explosion stage and a cyclone water removal stage is dropped rapidly.
• the pressure drop occurs rapidly by extruding the bulk structure of the biomass at between 160 to 850 PSI into a tube at the dramatically reduced pressure, such as 4-10 bar, to cause an internal "explosion” rapid expansion of steam upon the drop in pressure or due to the "flashing" of liquid water to vapor upon the drop in pressure below its vapor pressure, which internally blows apart the biomass in chip form into minute fine particles of biomass.
• the steam explosion reactor portion of the steam explosion stage contains a specialized discharge mechanism configured to "explode” the biomass chip material to a next stage at atmospheric pressure. The discharge mechanism opens to push the biomass from the high-pressure steam explosion reactor out this reactor discharge outlet valve or door into the feed line of the blow tank.
• the moisture and biomass chips get extruded out the reactor discharge to a container, such as the blow line, at approximately atmospheric pressure.
• the high-pressure steam or water conversion to vapor inside the partially hollow fibers and other porous areas of the biomass material causes the biomass cell to explode into fine particles of moist powder.
• the bulk structure of the biomass includes organic polymers of lignin and hemi-cellulose that surrounds a plurality of cellulose fibers.
• the bulk structure of the biomass is internally blown apart in this SEP step that uses at least moisture, pressure, and heat to liberate and expose the cellulose fibers to be able, as an example, to directly react during the biomass gasification reaction rather than react only after the layers of lignin and hemi-cellulose have first reacted to then expose the cellulose fibers.
• the high temperatures also lowers the energy/force required to breakdown the biomass' structure as there is a softening of lignin that facilitates fiber separation along the middle lamella.
• a mechanical mechanism opens, such as a valve or door, or merely a small hole exists in the steam explosion reactor.
• the reactor is filled with softened biomass chips potentially in plug form at high pressure and after a period of time exposes those softened biomass chips to a low pressure that physically blows apart the bulk structure of fiber bundle of the biomass containing the lignin, cellulose fibers, and hemi-cellulose into fragments and separates one from another.
• severities e.g. 175-185 degrees C and 160 PSI
• particles in the size of fragments of small fibers come out of the discharge and at higher severities (e.g. 300 PSI) very, very, fine grains of particles are produced.
• the biomass produced into the moist fine particle form from the stages has average dimensions of less than 50 microns thick and less than 500 microns in length.
• the produced fine particles of biomass with reduced moisture content includes cellulose fibers that are fragmented, torn, shredded and any combination of these and may generally have an average dimension of less than 30 microns thick and less than 250 microns in length.
• Those produced moist fine particles of biomass are subsequently fed to a feed section of the biomass gasifier 1 14.
• lignin and hemi-cellulose results in all three 1 ) an increase of a surface area of the biomass in fine particle form compared to the received biomass in chip form, 2) an elimination of a need to react outer layers of lignin and hemi-cellulose prior to starting a reaction of the cellulose fibers, and 3) a change in viscosity of the biomass in fine particle form to flow like grains of sand rather than like fibers.
• the morphological changes to the biomass coming out of SEP reactor can include: a. No intact fiber structure exists rather all parts are exploded causing more surface area, which leads to higher reaction rates in the biomass gasifier; b. Fibers appear to buckle, they delaminate, and cell wall is exposed and cracked; c. Some lignin remains clinging to the cell wall of the cellulose fibers; d. Hemi-cellulose is partially hydrolyzed and along with lignin are partially solubilized; e. The bond between lignin and carbohydrates/polysaccharides (i. e. hemi- cellulose and cellulose) is mostly cleaved; and f. many other changes discussed herein.
• the biomass comes from the chipper unit 104 as chips up to 1 inch in length and 0.25 inches in thickness on average and go out as moist fine particles of 20-50 microns thick in diameter and less than 100 microns in length on average, which is a reduction of over 2000 times in size.
• the produced fine particles of biomass are fed downstream to the biomass gasifier 1 14 for the rapid biomass gasification reaction in a reactor of the biomass gasifier 1 14 because they create a higher surface to volume ratio for the same amount of biomass compared to the received biomass in chip form, which allows a higher heat transfer to the biomass material and a more rapid thermal decomposition and gasification of all the molecules in the biomass.
• one or more steam supply inputs may include a low pressure steam produced from recycled dirty water recovered from the one or more cyclone units.
• embodiments as described herein include tapping off-gases from the cyclone unit and feeding the off- gases to the biomass gasifier. Also, those gases and any additional condensate may be fed to a turpentine recovery unit.
• cyclic operations are possible rather than a continuous conveyor system.
• the cyclic operation allows soft moist chips to be loaded into the SEP reactor and then the steam input introduces high temperature and high- pressure steam for 10 minutes to raise the pressure of the gases and liquids in the biomass. After that period, the valve or door opens to extrude biomass particles into feed line into blow tank.
• a collection chamber at an outlet stage of the steam explosion stage is used to collect the biomass reduced into smaller particle sizes and in pulp form.
• One or more cyclone filters can be in line with the feed line to separate water vapor from biomass particles, where biomass particles are then fed into a blow tank.
• the steam explosion stage filled with high-pressure steam and/or superheated water contains a discharge outlet configured to "explode” the biomass material to a next stage at atmospheric pressure to produce biomass in fine particle form.
• the biomass in fine particle form flows through a feed line of a blow tank at high velocity.
• the biomass in moist fine particles form enters the feed line of the blow tank.
• the feed line is initially small, such as only 1 .5 in. in diameter, with the particles of the biomass passing through at high velocity.
• Flow enhancements such as wax, may be added in initial portion of the blow line while the fibers are still wet to improve material consistency and avoid hydro bonding.
• the feed line now expands to 60 in. in diameter and the biomass in moist fine particles form has its heat maintained by heating coils traced around and warming the blow line. Maintaining the temperature of the biomass tends to help crystallize the rosins and resin acids of the biomass preventing the fiber particles from conglomerating back together. Thus, the temperature helps to prevent the lignin from clumping and rosins from hardening.
• the flow aids including any of 1 ) ash recycled from the biomass gasifier 1 14 and 2) olephins, such as wax, are injected at any of 1 ) the discharge outlet of the steam explosion stage and 2) in the feed line to prevent clogs by the biomass.
• the feed line may have heating coils traced around the feed line to maintain an elevated temperature of the biomass in fine particle form to help prevent crystallization of rosins and resin acids in the biomass in fine particle form.
• the produced particles of biomass loses a large percentage of the moisture content due to steam flashing in the blow line and being vented off as a water vapor.
• the produced particles of biomass and moisture are then separated by a cyclone filter and then fed into a blow tank.
• a water separation unit is inline with the blow line.
• a collection chamber at an outlet stage of the steam explosion stage is used to collect the biomass reduced into smaller particle sizes and in pulp form and is fed to the water separation unit. Water is removed from the biomass in fine particle form in a cyclone unit and/or a dryer unit.
• a moisture content of the fine particles of biomass is further dried out at an exit of the blow tank by a dryer unit such as a flash dryer or low temperature torrefaction unit that reduces the moisture content of fine particles of biomass to 5- 20% by weight preferably and up to 35% in general.
• a goal of the fiber preparation is to create particles of biomass with maximum surface area and as dry as feasible to 5-20% moisture by weight of the outputted biomass fine particle.
• the flash dryer merely blows hot air to dry the biomass particles coming out from the blow tank.
• the flash dryer can be generally located at the outlet of the blow tank or replace the cyclone at its entrance to make the outputted biomass particles contain a greater than 5% but less than 35% moisture content by weight.
• the resulting particles of biomass differs from Thermal Mechanical Pulping (TMP) in that particles act more like crystal structures and flows easier than fibers which tend to entangle and clump.
• TMP Thermal Mechanical Pulping
• the reduced moisture content of 5% to about 35% by weight of the biomass in fine particle form is fed by a conveying system, as an example, to a torrefaction unit 1 12 to undergo torrefaction or pyrolysis at a temperature from 100 to 700 degrees C for a preset amount of time.
• a conveyor system supplies the biomass in particle form to a torrefaction unit 1 12 to process the biomass at a temperature of less than 700 degrees C for a preset amount of time to create off gases to be used in a creation of a portion of the syngas components that are collected by a tank and may be eventually fed to an organic liquid product synthesis reactor such as the methanol synthesis reactor.
• the fine particles of biomass out of the blow tank and flash dryer has a low moisture content already due to the steam flashing, further air drying, and are a composite of fragments of cellulose fibers with a lignin coating, pieces of lignin, cellulose, and hemi-cellulose, etc.
• the biomass gasifier 1 14 has a reactor vessel configured to react the biomass in moist fine particle form with an increased surface area due to being blown apart by the steam explosion unit 108.
• the biomass gasifier 1 14 has a high pressure steam supply input and one or more heaters, and in the presence of the steam the biomass in fine particle form are reacted in the reactor vessel in a rapid biomass gasification reaction between 0.1 and 5.0 second resident time to produce at least syngas components, including hydrogen (H2) and carbon monoxide (CO).
• syngas components including hydrogen (H2) and carbon monoxide (CO).
• H2 hydrogen
• CO carbon monoxide
• the torrefaction unit and biomass gasifier 1 14 may be combined as an integral unit.
• the moist blown apart particles of biomass may be fed in slurry form from the output of the steam explosion reactor directly, or after drying, to a pelletizer.
• the pelletizer may density the biomass from form into pellets of biomass, which those pellets are then fed into the biomass gasifier. This direct feed and conversion of biomass from form to pellet form saves multiple steps and lots of energy consumption involved in those eliminated steps.
• the pellets may be transported to facilities for further processing to liquid fuel, heat/power, animal feed, litter, or chemicals.
• the biomass gasifier 1 14 is designed to radiantly transfer heat to particles of biomass flowing through the reactor design with a rapid gasification residence time, of the biomass particles of 0.1 to 10 seconds and preferably less one second.
• the biomass particles and reactant gas flowing through the radiant heat reactor primarily are driven from radiant heat from the surfaces of the radiant heat reactor and potentially heat transfer aid particles entrained in the flow.
• the reactor may heat the particles in a temperature in excess of generally 900 degrees C and preferably at least 1200°C to produce the syngas components including carbon monoxide and hydrogen, as well as keep produced methane at a level of ⁇ 1 % of the compositional makeup of exit products, minimal tars remaining in the exit products, and resulting ash.
• Figures 3-1 to 3-5 illustrate exemplary embodiments of the biomass gasifier 1 14.
• Figure 3-1 illustrates a fountain reactor using radiant heat in which entrainment gases carrying biomass enter at the bottom of the gasifier and are projected through a center tube and fountain over a separation wall created by the center tube and fall in a section created between an outer tube and the center tube.
• Figures 3-2 and 3-3 illustrate an exemplary bayonet reactor radiant heat design where a series of radiant heat tubes are used to heat injected biomass. Gas fired burners can provide heat directly to the tubes or to an intermediate source, such as a heating gas, supplied to the tubes.
• the biomass may be external to the tubes, while heat is supplied internal to the tubes. Alternatively, the biomass may be in between the tube sheet and the refractory lining.
• Figure 3-4 illustrates an exemplary downdraft radiant heat reactor in which multiple tubes are used to provide radiant heat to the reactor. The biomass may either be external to the tubes, while heat is supplied internal to the tubes, or visa-versa.
• Figure 3-5 illustrates a cut away view of an embodiment for biomass gasifier including a receiver cavity enclosing offset and staggered reactor tubes.
• the thermal receiver 306 has a cavity with an inner wall.
• the radiation driven geometry of the cavity wall of the thermal receiver 306 relative to the reactor tubes 302 locates the multiple tubes 302 of the chemical reactor as offset and in a staggered
• a surface area of the cavity walls is greater than an area occupied by the reactor tubes 302 to allow radiation to reach areas on the tubes 302 from multiple angles.
• the inner wall of the receiver 306 cavity and the reactor tubes 302 exchange energy primarily by radiation, with the walls and tubes 302 acting as re-emitters of radiation to achieve a high radiative heat flux reaching all of the tubes 302, and thus, avoid shielding and blocking the radiation from reaching the tubes 302, allowing for the reactor tubes 302 to achieve a fairly uniform
• the geometry of the reactor tubes 302 and cavity wall shapes a distribution of incident radiation with these 1 ) staggered and offset tubes 302 that are combined with 2) a large diameter cavity wall compared to an area occupied by the enclosed tubes 302, and additionally 3) combined with an inter-tube radiation exchange between the multiple reactor tube geometric arrangement relative to each other where the geometry.
• the wall is made of material that highly reflects radiation or absorbs and re-emits the radiation.
• the shaping of the distribution of the incident radiation uses both reflection and absorption of radiation within the cavity of the receiver 306.
• the inner wall of the thermal receiver 306 is aligned to and acts as a radiation distributor by either 1 ) absorbing and re-emitting radiant energy, 2) highly reflecting the incident radiation to the tubes 302, or 3) any combination of these, to maintain an operational temperature of the enclosed ultrahigh heat flux chemical reactor.
• the radiation from the 1 ) cavity walls, 2) directly from the regenerative burners, and 3) from an outside wall of other tubes acting as re-emitters of radiation is absorbed by the reactor tubes 302, and then the heat is transferred by conduction to the inner wall of the reactor tubes 302 where the heat radiates to the reacting particles and gases at temperatures between 900 degrees C and 1600 degrees C, and preferably above 1 100 degrees C.
• the inner wall of the cavity of the receiver 306 and the reactor tubes 302 exchange energy between each other primarily by radiation, not by convection or conduction, allowing for the reactor tubes 302 to achieve a fairly uniform temperature profile even though generally lower temperature biomass particles and entrainment gas enter the reactor tubes 302 in the reaction zone from a first entrance point and traverse through the heated cavity to exit the reaction zone at a second exit point.
• This radiation heat transfer from the inner wall and the reactor tubes 302 drives the chemical reaction and causes the temperature of the chemical reactants to rapidly rise to close to the temperature of the products and other effluent materials departing from the exit of the reactor.
• a length and diameter dimensions of a gasification reaction zone of each of the reactor tubes 302 is sized to give the very short residence time of greater than 0.01 second at the gasification temperatures of at least 900 degrees C, and an exit of the gasification zone in the multiple reactor tubes 302.
• the reaction products have a temperature from the exit of the gasification zone that equals or exceeds 900 degrees C, and the multiple reactor tubes 302 in this chemical reactor design increase available reactor surface area for radiative exchange to the biomass particles, as well as inter-tube radiation exchange.
• a rapid gasification of dispersed falling biomass particulates with a resultant stable ash formation occurs within a residence time within the reaction zone in the reactor tubes 302, resulting in a complete amelioration of tar to less than 500 milligrams per normal cubic meter, and at least a 90 % conversion of the biomass into the production of the hydrogen and carbon monoxide products.
• the design reduces the required surface area of the reactor tubes 302 and furnace interior, thus reducing the size, weight, and cost of the furnace chamber (size & weight are important for tower-mounted solar applications as well as other applications).
• biomass gasification requires temperatures in excess of 1000 °C. These are difficult to achieve in standard fluidized bed gasifiers, because higher temperatures requires combustion of an ever larger portion of the biomass itself. As a result, indirect and fluidized bed gasification is typically limited to temperatures of 800 °C. At these temperatures, production of unwanted higher hydrocarbons (tars) is significant. These tars clog up downstream equipment and foul/deactivate catalyst surfaces, requiring significant capital investment (10-30% of total plant cost) in tar removal equipment. High heat flux thermal systems are able to achieve high temperatures very efficiently. More importantly, the efficiency of the process can be controlled as a function of concentration and desired temperature, and is no longer linked to the fraction of biomass lost to achieving high temperature. As a result, temperatures in the tar cracking regime (1000-1300 °C) can be achieved without any loss of fuel yield from the biomass or overall process efficiency. This removes the complex train of tar cracking equipment typically associated with a biomass gasification system.
• a material making up the inner wall of the receiver 306 cavity may have mechanical and chemical properties to retain its structural strength at high
• temperatures between 1 100-1600 °C have very high emissivity of ⁇ >0.8 or high reflectivity of ⁇ 0.2, as well as high heat capacity (>200 J/kg-K), and low thermal conductivity ( ⁇ 1 W/m-K) for the receiver 306 cavity.
• a material making up the reactor tubes 302 possesses high emissivity ( ⁇ >0.8), high thermal conductivity (>1 W/m-K), moderate to high heat capacity (>150 J/kg-K).
• An example Particle Size Analysis to determine the particle size can be a Digital Image Processing Particle Size and Shape Analysis System such as a
• Camsizer XT particle size analyzer Such a system uses one or more cameras to provide rapid and precise particle size and particle shape distributions for dry powders and bulk material in the size range, for example, from 30 ⁇ to 30mm. The measurements from the digital image processing system allows a correlation to existing data from techniques as diverse as sieving and sedimentation, which in some instances may also be used to measure particle size. In an embodiment, the particle size of the steam exploded wood chips are measured using a Horiba, Ltd. Camsizer XT particle size analyzer. The sample to be measured is mixed in a resealable bag by kneading and agitating the material in the bag by external manipulation.
• a sample amount such as approximately 3 cm A 3 is loaded into the sample hopper of the instrument.
• the target is to run and analyze enough sample size, such as at least 2 million particles from each sample, so the sample volume is only important insofar as it corresponds to an adequate number of particles.
• the camera imaging rate is fixed, and both "basic" and zoom images are obtained for every run.
• a single value for average particle size such as the diameter is less than 50 microns, may be the objective measurement standard.
• a three point value for both Fe-max and xc-min is more complete. So that's like a 6 point value.
• the particle size distribution (PSD) may be defined as Fe-Max D10, D50, D90 and Xc-min D10, D50, D90.
• the measurement then can use multiple values such as input 6 values to determine the measurement. Other similar mechanisms may be used.
• Calculations can be made using Fe max and xc min on a volume basis. Two models can be used to analyze the particle images: xc-min, which yields results comparable to those obtained by physically screening/sieving samples, and Fe-max, which is similar to measuring the longest dimension of a given particle with a caliper. Raw data, frequency plots, binned results, and particle images are obtained for all samples. D10, D50, and D90 may be calculated on a volume basis, as is the average aspect ratio. D90 describes the diameter where ninety percent of the distribution has a smaller particle size and ten percent has a larger particle size. The D10 diameter has ten percent smaller and ninety percent larger. A three point specification featuring the D10, D50, and D90 is considered complete and
• the particle size distribution PSD may be defined as D50 ( ⁇ ) Model Fe-max.
• Figure 2 illustrates a flow schematic of an embodiment of a steam explosion unit 108 having a steam explosion stage and thermally hydrating stage that supplies particles of biomass to either a torrefaction unit, or to the biomass gasifier 1 14, or to a catalytic converter.
• a conveying system coupled to a collection chamber at the outlet stage of the steam explosion unit 208 supplies particles of biomass in particle form to either a torrefaction unit 212, or to the biomass gasifier 214, or to a catalytic converter 215.
• a majority of the initial lignin and cellulose making up the biomass in the receiver section of the steam tube stage in the steam explosion unit 208 remains in the produced particles of biomass but now substantially separated from the cellulose fibers in the collection chamber at the outlet stage of the steam explosion stage 208.
• the collection chamber in the steam explosion unit 208 is configured to collect non-condensable hydrocarbons from any off gases produced from the biomass during the steam explosion process.
• water is removed from the biomass in a water separation unit 21 1 , for example a cyclone unit, and the reduced moisture content biomass made of loose fibers and separated lignin and cellulose may be fed to a torrefaction unit 212 to under go multiple stages of torrefaction.
• Condensable hydrocarbons including alcohols, ethers, and other C5 hydrocarbons may be separated by a filter unit 213 from the water removed from the biomass and then the condensable hydrocarbons are sent to a gasoline blending unit
• Figure 3A illustrates an embodiment of a flow diagram of an integrated plant to generate syngas from biomass and generate a liquid fuel product from the syngas.
• one or more gas collection tanks in the steam explosion unit 308 may collect non-condensable hydrocarbons from any off gases produced from the biomass during the SEP process and send those non- condensable hydrocarbons with any collected in the torrefaction unit 312 to a catalytic converter 316.
• the reduced moisture content pulp may go directly from the steam explosion unit 308 to the biomass gasifier 314, a torrefaction unit 312, or to a catalytic converter 316.
• the particles of biomass go to the torrefaction unit 312 and then onto the biomass gasifier 314.
• the torrefaction unit 312 and biomass gasifier may be combined into a single unit.
• compositions of biomass types that can be blended include:
• the biomass gasifier 314 has a reactor configured to react particles of the biomass broken down by the two or more stages of the steam explosion unit 308 and those biomass particles are subsequently fed to a feed section of the biomass gasifier 314.
• the biomass gasifier 314 has a high temperature steam supply input and one or more heaters and in the presence of the steam the particles of the biomass broken down by the steam explosion unit 308 are reacted in the reactor vessel in a rapid biomass gasification reaction at a temperature of greater than 700 degrees C in less than a five second residence time in the biomass gasifier 314 to create syngas components, including hydrogen (H2) and carbon monoxide (CO), which are fed to a methanol (CH3OH) synthesis reactor 310.
• H2 hydrogen
• CO carbon monoxide
• the heat transferred to the biomass particles made up of loose or fragments of cellulose fibers, lignin, and hemicellulose no longer needs to penetrate the layers of lignin and hemicellulose to reach the fibers.
• the rapid biomass gasification reaction occurs at a temperature of greater than 700 degrees C to ensure the removal tars from forming during the gasification reaction.
• a starting temperature of 700 degrees but less than 950 degrees is potentially a significant range of operation for the biomass gasifier. All of the biomass gasifies more thoroughly and readily.
• the biomass gasifier 314 may have a radiant heat transfer to particles flowing through the reactor design with a rapid gasification residence time, of the biomass particles of 0.1 to 10 seconds and preferably less one second, of biomass particles and reactant gas flowing through the radiant heat reactor, and primarily radiant heat from the surfaces of the radiant heat reactor and particles entrained in the flow heat the particles and resulting gases to a temperature in excess of generally 700 degrees C and preferably at least 1200°C to produce the syngas components including carbon monoxide and hydrogen, as well as keep produced methane at a level of ⁇ 1 % of the compositional makeup of exit products, minimal tars remaining in the exit products, and resulting ash.
• the temperature range for biomass gasification is greater than 800 degrees C to 1400 degrees C.
• Syngas may be a mixture of carbon monoxide and hydrogen that can be converted into a large number of organic compounds that are useful as chemical feed stocks, fuels and solvents.
• the steam explosion unit 208 and/or torrefaction of biomass causes off gases to be fed to a catalytic converter 216 that can generate hydrogen and carbon monoxide for methanol production.
• the biomass gasifier 214 gasifies biomass at high enough temperatures to eliminate a need for a catalyst to generate hydrogen and carbon monoxide for methanol production.
• a lower temperature catalytic conversion of particles of biomass may be used to generate hydrogen and carbon monoxide for methanol production.
• the steam explosion process and torrefaction process may be used to generate condensable hydrocarbons for use in gasoline blending to increase the octane of the final gasoline product.
• olefins may be any unsaturated hydrocarbon, such as ethylene, propylene, and butylenes, containing one or more pairs of carbon atoms linked by a double bond.
• Olefins may have the general formula CnH2n, C being a carbon atom, H a hydrogen atom, and n an integer.
• the torrefaction unit 212 has two or more areas to segregate out and then route the non-condensable gases including the C1 to C4 olefins, as well as other gases including CO, CH4, CO2 and H2, through a supply line to the catalytic converter 216 that catalytically transform portions of the non-condensable gases to the syngas components of CO, H2, CO2 in small amounts, and potentially CH4 that are sent in parallel with the portion of syngas components from the biomass gasifier 214 to a combined input to the methanol synthesis reactor.
• the catalytic converter 216 has a control system to regulate a supply of an oxygenated gas and steam along with the non-condensable gases to the catalytic converter 216, which produces at least H2, and CO as exit gases.
• the catalytic converter 216 uses the control system and the composition of a catalyst material inside the catalytic converter 216 to, rather than convert the supplied non-condensable gases completely into CO2 and H2O in the exit gas, the non-condensable gases, steam, and oxygenated gas are passed through the catalytic converter 216 in a proper ratio to achieve an equilibrium reaction that favors a production of carbon monoxide (CO) and hydrogen (H2) in the exit gas; and thus, reclaim the valuable Renewable Identification Number (RIN) credits associated with the non-condensable gases.
• CO carbon monoxide
• H2 hydrogen
• RIN credits are a numeric code that is generated by the producer or importer of renewable fuel representing gallons of renewable fuel produced using a renewable energy crop, such as biomass.
• the primary negative of torrefaction in prior suggestions is the loss of carbon and the associated RIN credits in the volatile materials removed by torrefaction.
• Biomass gasification is used to decompose the complex hydrocarbons of biomass into simpler gaseous molecules, primarily hydrogen, carbon monoxide, and carbon dioxide. Some char, mineral ash, and tars are also formed, along with methane, ethane, water, and other constituents.
• the mixture of raw product gases vary according to the types of biomass feedstock used and gasification processes used. The product gas must be cleaned of solids, tars, and other contaminants sufficient for the intended use.
• the biomass gasifier has a gas clean up section to clean ash, sulfur, water, and other contaminants from the syngas gas stream exiting the biomass gasifier 314.
• the syngas is then compressed to the proper pressure needed for methanol synthesis.
• the syngas from the catalytic converter 316 may connect upstream or downstream of the compression stage.
• the synthesis gas of H2 and CO from the gasifier and the catalytic converter 316 exit gases are sent to the common input to the one or more methanol synthesis reactors.
• the exact ratio of Hydrogen to Carbon monoxide can be optimized by a control system receiving analysis from monitoring equipment on the compositions of syngas exiting the biomass gasifier 314 and catalytic converters 316 and causing the optimize the ratio for methanol synthesis.
• the methanol produced by the one or more methanol synthesis reactors is then processed in a methanol to gasoline process.
• the liquid fuel produced in the integrated plant may be gasoline or another such as diesel, jet fuel, or some alcohols.
• the torrefaction unit 312 may have its own several discrete heating stages. Each heating stage is set at a different operating temperature, rate of heat transfer, and heating duration, within the unit in order to be matched to optimize a composition of the non-condensable gases and condensable volatile material produced from the biomass in that stage of the torrefaction unit 312. Each stage has one or more temperature sensors to supply feedback to a control system for the torrefaction unit 312 to regulate the different operating temperatures and rates of heat transfer within the unit.
• Pellets of biomass may be taken directly out of the densification unit and used for many purposes.
• FIG. 3B illustrates an embodiment of a flow diagram of an integrated plant to generate syngas from biomass, and/or to generate biomass in densified form.
• the integrated plant may have a steam methane reformation unit 327 in parallel with the biomass gasifier.
• the SEP unit may supply biomass in fine particle form to a densification unit.
• the densification unit creates biomass in densified form including but not limited to biomass in pellets.
• Both the biomass gasifier 314 and the SMR 327 can supply syngas components to the downstream organic liquid product synthesis reactor, such as methanol synthesis reactor 310.
• the methanol is then supplied to a methanol to gasoline process to create a high quality and high octane gasoline.
• the methanol may also be supplied to other liquefied fuel processes including jet fuel, DME, gasoline, diesel, and mixed alcohol.
• a feed system may feed the moist fine particles of biomass in slurry form from an output of the steam explosion unit directly to a densification unit.
• the densification unit is configured to density the moist biomass in fine particle form into denser forms, including but not limited to pellets of biomass.
• an optional dryer unit may be between the SEP unit and the densification unit or located after the densification unit.
• the biomass in densified pellet form is then fed into one or more of 1 ) a biomass gasifier, 2) a combustion unit for process heat, 3) a combustion unit to generate electric power, 4) a process unit to produce chemicals, 5) a packaging unit to box and sell as animal feed, litter, or fuel.
• the integrated plant may have a SEP unit feeding an optional densification Unit, then to an optional Torrefaction unit, and then to the rest of the plant.
• the integrated plant may have a SEP unit feeding a dryer unit followed by a densification unit that feeds one or more of 1 ) a biomass gasifier, 2) a combustion unit for process heat, 3) a combustion unit to generate electric power, 4) a process unit to produce chemicals, 5) a packaging unit to box and sell as animal feed, litter or fuel.
• the SEP unit feeds a dryer unit followed by a torrefaction unit, followed by a densification unit that feeds the rest of the plant.
• Figures 4A-C illustrates different levels of magnification of an example chip of biomass 451 having a fiber bundle of cellulose fibers surrounded and bonded together by lignin.
• Figure 4D illustrates example chips of biomass, including a first chip of biomass 451 , exploded into fine particles of biomass 453.
• Figure 4E illustrates a chip of biomass 451 having a bundle of fibers that are frayed or partially separated into individual fibers.
• FIG. 5 illustrates a flow schematic of an embodiment for the radiant heat chemical reactor configured to generate chemical products including synthesis gas products.
• the multiple shell radiant heat chemical reactor 514 includes a refractory vessel 534 having an annulus shaped cavity with an inner wall.
• the radiant heat chemical reactor 514 has two or more radiant tubes 536 made out of a solid material.
• the one or more radiant tubes 536 are located inside the cavity of the refractory lined vessel 534.
• the exothermic heat source 538 heats a space inside the tubes 536.
• each radiant tube 536 is heated from the inside with an exothermic heat source 538, such as regenerative burners or gas fired burners, at each end of the tube 536.
• an exothermic heat source 538 such as regenerative burners or gas fired burners
• Each radiant tube 536 is heated from the inside with fire and gases from the burners through heat insertion inlets at each end of the tube 536 and potentially by one or more heat insertion ports located in between the two ends. Flames and heated gas of one or more natural gas fired burners 538 act as the exothermic heat source supplied to the multiple radiant tubes at temperatures between 900° C and 1800° C and connect to both ends of the radiant tubes 536.
• Each tube 536 may be made of SiC or other similar material.
• One or more feed lines 542 supply biomass and reactant gas into the top or upper portion of the chemical reactor 514.
• the feed lines 542 for the biomass particles and steam enter below the entry points in the refractory lined vessel 534 for the radiant tubes 536 that are internally heated.
• the feed lines 1 12 are configured to supply chemical reactants including 1 ) biomass particles, 2) reactant gas, 3) steam, 4) heat transfer aid particles, or 5) any of the four into the radiant heat chemical reactor.
• a chemical reaction driven by radiant heat occurs outside the multiple radiant tubes 536 with internal fires.
• the chemical reaction driven by radiant heat occurs within an inner wall of a cavity of the refractory lined vessel 534 and an outer wall of each of the one or more radiant tubes 536.
• the chemical reaction may be an endothermic reaction including one or more of 1 ) biomass gasification (CnHm + H20 ⁇ CO + H2 + H20 + X), 2) and other similar hydrocarbon decomposition reactions, which are conducted in the radiant heat chemical reactor 514 using the radiant heat.
• a steam (H2O) to carbon molar ratio is in the range of 1 :1 to 1 :4, and the temperature is high enough that the chemical reaction occurs without the presence of a catalyst.
• the torrefied biomass particles used as a feed stock into the radiant heat reactor design conveys the beneficial effects of increasing and being able to sustain process gas temperatures of excess of 1200 degrees C through more effective heat transfer of radiation to the particles entrained with the gas, increased gasifier yield of generation of syngas components of carbon monoxide and hydrogen for a given amount of biomass fed in, and improved process hygiene via decreased production of tars and C2+ olefins.
• the control system for the radiant heat reactor matches the radiant heat transferred from the surfaces of the reactor to a flow rate of the biomass particles to produce the above benefits.
• the control system controls the gas-fired burners 538 to supply heat energy to the chemical reactor 514 to aid in causing the radiant heat driven chemical reactor to have a high heat flux.
• the inside surfaces of the chemical reactor 514 are aligned to 1 ) absorb and re-emit radiant energy, 2) highly reflect radiant energy, and 3) any combination of these, to maintain an operational temperature of the enclosed ultra-high heat flux chemical reactor 514.
• the inner wall of the cavity of the refractory vessel and the outer wall of each of the one or more tubes 536 emits radiant heat energy to, for example, the biomass particles and any other heat- transfer-aid particles present falling between an outside wall of a given tube 536 and an inner wall of the refractory vessel.
• the refractory vessel thus absorbs or reflects, via the tubes 536, the concentrated energy from the burners 538 positioned along on the top and bottom of the refractory vessel to cause energy transport by thermal radiation and reflection to generally convey that heat flux to the biomass particles, heat transfer aid particles and reactant gas inside the chemical reactor.
• the inner wall of the cavity of the thermal refractory vessel and the multiple tubes 536 act as radiation distributors by either absorbing radiation and re-radiating it to the heat- transfer-aid particles or reflecting the incident radiation to the heat-transfer-aid particles.
• the radiant heat chemical reactor 514 uses an ultra-high heat flux and high temperature that is driven primarily by radiative heat transfer, and not convection or conduction.
• Convection biomass gasifiers used generally on coal particles typically at most reach heat fluxes of 5-10 kW/m A 2.
• the high radiant heat flux biomass gasifier will use heat fluxes significantly greater, at least three times the amount, than those found in convection driven biomass gasifiers (i.e. greater than 25 kW/m A 2).
• the program modules may be implemented as software instructions, Logic blocks of electronic hardware, and a combination of both.
• the software portion may be stored on a machine-readable medium and written in any number of programming languages such as Java, C++, C, etc.
• the machine- readable medium may be a hard drive, external drive, DRAM, Tape Drives, memory sticks, etc. Therefore, the algorithms and controls systems may be fabricated exclusively of hardware logic, hardware logic interacting with software, or solely software.
• recuperated waste heat from various plant processes can be used to pre-heat combustion air, or can be used for other similar heating means.
• Regenerative gas burners or conventional burners can be used as a heat source for the furnace.
• Alcohols C1 , C2 and higher as well as ethers that are formed in the torrefaction process may be used as a high value in boosting the octane rating of the generated liquid fuel, such as gasoline.
• Biomass gasifier reactors other than a radiant heat chemical reactor may be used.
• the Steam Methane Reforming may be/ include a SHR (steam
• hydrocarbon reformer that cracks short-chained hydrocarbons ( ⁇ C20) including hydrocarbons (alkanes, alkenes, alkynes, aromatics, furans, phenols, carboxylic acids, ketones, aldehydes, ethers, etc., as well as oxygenates into syngas

Landscapes

• Chemical & Material Sciences (AREA)
• Organic Chemistry (AREA)
• Engineering & Computer Science (AREA)
• Combustion & Propulsion (AREA)
• Oil, Petroleum & Natural Gas (AREA)
• Biodiversity & Conservation Biology (AREA)
• Thermal Sciences (AREA)
• Life Sciences & Earth Sciences (AREA)
• Physics & Mathematics (AREA)
• Ecology (AREA)
• Forests & Forestry (AREA)
• Wood Science & Technology (AREA)
• Chemical Kinetics & Catalysis (AREA)
• General Chemical & Material Sciences (AREA)
• Processing Of Solid Wastes (AREA)
• Solid Fuels And Fuel-Associated Substances (AREA)

Priority Applications (9)

Applications Claiming Priority (4)

Related Parent Applications (1)

Related Child Applications (1)

Publications (2)

Family

ID=49769210

Family Applications (1)

Country Status (6)

Cited By (12)

Families Citing this family (7)

Citations (6)

Family Cites Families (6)

• 2013
  • 2013-06-04 WO PCT/US2013/044143 patent/WO2013191897A1/en active Application Filing
  • 2013-06-04 JP JP2015518422A patent/JP2015527425A/ja active Pending
  • 2013-06-04 AU AU2013277608A patent/AU2013277608B2/en not_active Ceased
  • 2013-06-04 CA CA2873484A patent/CA2873484A1/en not_active Abandoned
  • 2013-06-04 CN CN201380040145.8A patent/CN104519991A/zh active Pending
  • 2013-06-04 EP EP13806846.5A patent/EP2864037A4/en not_active Withdrawn

Patent Citations (6)

Non-Patent Citations (2)

Also Published As

Similar Documents

Legal Events