EP3583356B1 - Method for firing a biofuel - Google Patents
Method for firing a biofuel Download PDFInfo
- Publication number
- EP3583356B1 EP3583356B1 EP18707851.4A EP18707851A EP3583356B1 EP 3583356 B1 EP3583356 B1 EP 3583356B1 EP 18707851 A EP18707851 A EP 18707851A EP 3583356 B1 EP3583356 B1 EP 3583356B1
- Authority
- EP
- European Patent Office
- Prior art keywords
- biofuel
- stage
- combustion
- air stream
- air
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Active
Links
- 239000002551 biofuel Substances 0.000 title claims description 104
- 238000010304 firing Methods 0.000 title claims description 37
- 238000000034 method Methods 0.000 title claims description 24
- 238000002485 combustion reaction Methods 0.000 claims description 97
- 239000002245 particle Substances 0.000 claims description 14
- 241000609240 Ambelania acida Species 0.000 claims description 4
- 239000010905 bagasse Substances 0.000 claims description 4
- 239000003415 peat Substances 0.000 claims description 4
- 239000010902 straw Substances 0.000 claims description 4
- 239000002023 wood Substances 0.000 claims description 4
- 244000025254 Cannabis sativa Species 0.000 claims description 3
- UGFAIRIUMAVXCW-UHFFFAOYSA-N Carbon monoxide Chemical compound [O+]#[C-] UGFAIRIUMAVXCW-UHFFFAOYSA-N 0.000 description 10
- 239000003546 flue gas Substances 0.000 description 10
- QGZKDVFQNNGYKY-UHFFFAOYSA-N Ammonia Chemical compound N QGZKDVFQNNGYKY-UHFFFAOYSA-N 0.000 description 8
- 235000017899 Spathodea campanulata Nutrition 0.000 description 7
- 230000008569 process Effects 0.000 description 7
- MWUXSHHQAYIFBG-UHFFFAOYSA-N Nitric oxide Chemical class O=[N] MWUXSHHQAYIFBG-UHFFFAOYSA-N 0.000 description 4
- 239000007789 gas Substances 0.000 description 4
- 230000003287 optical effect Effects 0.000 description 4
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 3
- 230000003197 catalytic effect Effects 0.000 description 3
- 239000003638 chemical reducing agent Substances 0.000 description 3
- 239000000567 combustion gas Substances 0.000 description 3
- 238000004891 communication Methods 0.000 description 3
- 239000000446 fuel Substances 0.000 description 3
- 238000004519 manufacturing process Methods 0.000 description 3
- 238000002156 mixing Methods 0.000 description 3
- 229910000069 nitrogen hydride Inorganic materials 0.000 description 3
- 230000015572 biosynthetic process Effects 0.000 description 2
- 238000013500 data storage Methods 0.000 description 2
- 238000010586 diagram Methods 0.000 description 2
- 238000010790 dilution Methods 0.000 description 2
- 239000012895 dilution Substances 0.000 description 2
- 238000001035 drying Methods 0.000 description 2
- 239000012530 fluid Substances 0.000 description 2
- 230000006870 function Effects 0.000 description 2
- 238000010438 heat treatment Methods 0.000 description 2
- 230000001939 inductive effect Effects 0.000 description 2
- 238000002347 injection Methods 0.000 description 2
- 239000007924 injection Substances 0.000 description 2
- 239000000463 material Substances 0.000 description 2
- 239000002028 Biomass Substances 0.000 description 1
- 239000004215 Carbon black (E152) Substances 0.000 description 1
- 241000209504 Poaceae Species 0.000 description 1
- 238000003916 acid precipitation Methods 0.000 description 1
- 229910021529 ammonia Inorganic materials 0.000 description 1
- QVGXLLKOCUKJST-UHFFFAOYSA-N atomic oxygen Chemical compound [O] QVGXLLKOCUKJST-UHFFFAOYSA-N 0.000 description 1
- 238000007599 discharging Methods 0.000 description 1
- 239000000428 dust Substances 0.000 description 1
- 230000005611 electricity Effects 0.000 description 1
- 230000007717 exclusion Effects 0.000 description 1
- 229930195733 hydrocarbon Natural products 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 239000000543 intermediate Substances 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 229910052757 nitrogen Inorganic materials 0.000 description 1
- QJGQUHMNIGDVPM-UHFFFAOYSA-N nitrogen group Chemical group [N] QJGQUHMNIGDVPM-UHFFFAOYSA-N 0.000 description 1
- 239000001301 oxygen Substances 0.000 description 1
- 229910052760 oxygen Inorganic materials 0.000 description 1
- 238000012545 processing Methods 0.000 description 1
- 230000009467 reduction Effects 0.000 description 1
- 230000001105 regulatory effect Effects 0.000 description 1
- 230000004043 responsiveness Effects 0.000 description 1
- 230000000979 retarding effect Effects 0.000 description 1
- 239000004065 semiconductor Substances 0.000 description 1
- 241000894007 species Species 0.000 description 1
- 238000012546 transfer Methods 0.000 description 1
- 230000007704 transition Effects 0.000 description 1
- 238000011144 upstream manufacturing Methods 0.000 description 1
- 230000000007 visual effect Effects 0.000 description 1
- 239000011800 void material Substances 0.000 description 1
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 1
Images
Classifications
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
- F23G—CREMATION FURNACES; CONSUMING WASTE PRODUCTS BY COMBUSTION
- F23G5/00—Incineration of waste; Incinerator constructions; Details, accessories or control therefor
- F23G5/02—Incineration of waste; Incinerator constructions; Details, accessories or control therefor with pretreatment
- F23G5/033—Incineration of waste; Incinerator constructions; Details, accessories or control therefor with pretreatment comminuting or crushing
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
- F23G—CREMATION FURNACES; CONSUMING WASTE PRODUCTS BY COMBUSTION
- F23G5/00—Incineration of waste; Incinerator constructions; Details, accessories or control therefor
- F23G5/32—Incineration of waste; Incinerator constructions; Details, accessories or control therefor the waste being subjected to a whirling movement, e.g. cyclonic incinerators
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
- F23C—METHODS OR APPARATUS FOR COMBUSTION USING FLUID FUEL OR SOLID FUEL SUSPENDED IN A CARRIER GAS OR AIR
- F23C6/00—Combustion apparatus characterised by the combination of two or more combustion chambers or combustion zones, e.g. for staged combustion
- F23C6/04—Combustion apparatus characterised by the combination of two or more combustion chambers or combustion zones, e.g. for staged combustion in series connection
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
- F23D—BURNERS
- F23D1/00—Burners for combustion of pulverulent fuel
- F23D1/02—Vortex burners, e.g. for cyclone-type combustion apparatus
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
- F23G—CREMATION FURNACES; CONSUMING WASTE PRODUCTS BY COMBUSTION
- F23G5/00—Incineration of waste; Incinerator constructions; Details, accessories or control therefor
- F23G5/38—Multi-hearth arrangements
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
- F23G—CREMATION FURNACES; CONSUMING WASTE PRODUCTS BY COMBUSTION
- F23G7/00—Incinerators or other apparatus for consuming industrial waste, e.g. chemicals
- F23G7/10—Incinerators or other apparatus for consuming industrial waste, e.g. chemicals of field or garden waste or biomasses
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
- F23L—SUPPLYING AIR OR NON-COMBUSTIBLE LIQUIDS OR GASES TO COMBUSTION APPARATUS IN GENERAL ; VALVES OR DAMPERS SPECIALLY ADAPTED FOR CONTROLLING AIR SUPPLY OR DRAUGHT IN COMBUSTION APPARATUS; INDUCING DRAUGHT IN COMBUSTION APPARATUS; TOPS FOR CHIMNEYS OR VENTILATING SHAFTS; TERMINALS FOR FLUES
- F23L9/00—Passages or apertures for delivering secondary air for completing combustion of fuel
- F23L9/02—Passages or apertures for delivering secondary air for completing combustion of fuel by discharging the air above the fire
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
- F23G—CREMATION FURNACES; CONSUMING WASTE PRODUCTS BY COMBUSTION
- F23G2202/00—Combustion
- F23G2202/10—Combustion in two or more stages
- F23G2202/101—Combustion in two or more stages with controlled oxidant supply
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
- F23G—CREMATION FURNACES; CONSUMING WASTE PRODUCTS BY COMBUSTION
- F23G2203/00—Furnace arrangements
- F23G2203/30—Cyclonic combustion furnace
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
- F23G—CREMATION FURNACES; CONSUMING WASTE PRODUCTS BY COMBUSTION
- F23G2209/00—Specific waste
- F23G2209/26—Biowaste
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
- F23J—REMOVAL OR TREATMENT OF COMBUSTION PRODUCTS OR COMBUSTION RESIDUES; FLUES
- F23J2219/00—Treatment devices
- F23J2219/10—Catalytic reduction devices
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
- F23K—FEEDING FUEL TO COMBUSTION APPARATUS
- F23K2201/00—Pretreatment of solid fuel
- F23K2201/10—Pulverizing
- F23K2201/1006—Mills adapted for use with furnaces
Definitions
- Embodiments of the invention relate generally to energy production, and more specifically, to a method for firing a biofuel.
- biofuels are increasingly used in the production of energy.
- many electrical power plants also referred to hereinafter simply as "power plants”
- burn biofuels to produce steam which in turn powers a steam turbine generator.
- the biofuel is burned on a stoker grate within a combustion chamber. Burning biofuel on a stoker grate, however, can potentially create a relatively unpredictable and/or uncontrolled combustion reaction for a given amount of biofuel.
- predictable and “unpredictable”, as used herein with respect to a combustion reaction refer to the likelihood that the combustion reaction will follow a predicted/calculated rate and/or stoichiometry.
- SNCRs selective non-catalytic reducers
- SCRs selective catalytic reducers
- SNCRs and SCRs are resource intensive and expensive to operate.
- NH3 ammonia
- Document US 6 269 755 B1 discloses an industrial burner for combustion of biomass. Said industrial burner is designed to achieve high turndown ratios and high heat release ratios.
- a combustion chamber disclosed in this document comprises three stages with the same amount of air provided to each of them.
- Document US 4 398 477 A discloses a combustion furnace that avoids discharging large amount of dust into the environment and uses combustion gases as a direct heat source, i.e., not requiring a heat exchanger. This combustion furnace comprises two chambers wherein the second chamber receives more air than the first one.
- Document US 3 831 535 A discloses a system with a combustion chamber and a blending chamber. The combustion chamber burns a biofuel and the blending chamber burns gases produced from drying veneer.
- Document US 2006/225424 A1 discloses a cyclonic combustor for a biofuel.
- the cyclonic combustor includes an ignition zone, a combustion zone and a dilution zone. Air is provided in the ignition zone and in the combustion zone in stoichiometric amounts to lower emission of nitrogen oxides.
- the dilution zone is provided with air to dilute and cool down combustion gases so that said combustion gases can be used in a gas turbine.
- a method of firing a biofuel is provided as claimed in claim 1.
- a system for firing a biofuel includes a combustion chamber having a first stage and a second stage.
- the combustion chamber is operative to provide for combustion of the biofuel in a suspended state while flowing from the first stage to the second stage.
- the combustion chamber further has a first injector and a second injector operative to introduce a first air stream and a second air stream into the combustion chamber at the first stage and at the second stage, respectively, to facilitate combustion of the biofuel.
- a non-transitory computer readable medium storing instructions is provided as claimed in claim 5.
- the terms “substantially”, “generally” and “about” indicate conditions within reasonably achievable manufacturing and assembly tolerances, relative to ideal desired conditions suitable for achieving the functional purpose of a component or assembly.
- the term “real-time”, as used herein, means a level of processing responsiveness that a user senses as sufficiently immediate or that enables the processor to keep up with an external process.
- “electrically coupled”, “electrically connected”, and “electrical communication” mean that the referenced elements are directly or indirectly connected such that an electrical current, or other communication medium, may flow from one to the other.
- connection may include a direct conductive connection, i.e., without an intervening capacitive, inductive or active element, an inductive connection, a capacitive connection, and/or any other suitable electrical connection. Intervening components may be present.
- fluidly connected means that the referenced elements are connected such that a fluid (to include a liquid, gas and/or plasma) may flow from one to the other.
- upstream and downstream describe the position of the referenced elements with respect to a flow path of a fluid and/or gas flowing between and/or near the referenced elements.
- stream as used herein with respect to particles, means a continuous or near continuous flow of particles.
- heating contact means that the referenced objects are in proximity of one another such that heat/thermal energy can transfer between them.
- suspended state combustion refers to the process of combusting a fuel suspended in air.
- embodiments disclosed herein are primarily described with respect to power plants, it is to be understood that embodiments of the invention may be applicable to any apparatus and/or method that needs to limit and/or eliminate NOx emissions resulting from the combustion of a biofuel, e.g., an incinerator.
- a system 10 for firing a biofuel (12, FIG. 2 ), e.g., bagasse, switchblade and/or other grasses, wood, peat, straw, and/or other suitable biofuels, in accordance with embodiments of the invention is shown.
- the system 10 includes a combustion chamber 14, and may further include a controller 16 having at least one processor 18 and a memory device 20, a mill 22, an SCR 24, and/or an exhaust stack 26.
- the system 10 may form part of a power plant 28 where the combustion chamber 14 is incorporated into a boiler 30 which produces steam for the generation of electricity via a steam turbine generator 32.
- the mill 22 is operative to receive and process the biofuel 12 for combustion within the combustion chamber 14, i.e., the mill 22 shreds, pulverizes, and/or otherwise conditions the biofuel 12 for firing within the combustion chamber 14.
- the mill 22 may process the biofuel 12 to particles sizes less than or equal to about 2 mm.
- the mill 22 may process the biofuel 12 to particles sizes less than or equal to about 1 mm.
- the mill 22 may be a non-screened styled hammer mill integrated with a flash drying column disposed at the inlet of a beater wheel exhaust fan. The processed biofuel 12 is then transported/fed from the mill 22 to the combustion chamber 14 via conduit 34.
- the combustion chamber 14 is operative to receive and to facilitate combustion of the biofuel 12, which results in the generation of heat and a flue gas.
- the flue gas may be sent from the combustion chamber 14 to the SCR 24 via conduit 36.
- the heat from combusting the biofuel 12 may be captured and used to generate steam, e.g., via water walls in heating contact with the flue gas, which is then sent to the steam turbine generator 32 via conduit 38.
- the SCR 24 is operative to reduce NOx within the flue gas prior to emission of the flue gas into the atmosphere via conduit 40 and exhaust stack 26.
- the combustion chamber 14 has two or more stages 42 and 44, and one or more wind boxes 46 and 48 each having a plurality of nozzles/injectors 50, 52, and 54. While FIG. 2 depicts the stages 42 and 44 as discrete and spaced apart, it will be understood that, in embodiments, the stages 42 and 44 may be continuous and flush with one another, i.e., the stages 42 and 44 may smoothly transition from one 42 to the next 44. As shown in FIG. 2 , a first set of wind boxes 46 have nozzles 50 and 52 that are operative to introduce the biofuel 12 and a first air stream 56 into the first stage 42. As will be appreciated, the first air steam 56 may be generated from both primary and secondary air supplies.
- nozzles 50 may introduce the biofuel 12 into the first stage 42 via primary air, while secondary air is introduced into the first stage 42 via nozzles 52.
- Particles of the biofuel 12 may be introduced into the combustion chamber 14 via nozzles 50 at a slip speed, with respect to primary air, of between about 0-30,48 meters/second (0-100 feet/second).
- slip speed refers to the difference in the velocity of the particles of the biofuel 12 and the velocity of the primary air transporting the biofuel 12 via nozzles 50.
- 100% of the biofuel may be injected by the nozzles 50 within the first stage 42.
- the nozzles 50 and 52 may be arranged into one or more firing layers 60, 62 and 64, i.e., groups of nozzles 50 and 52 disposed at and/or near the same position along a vertical/longitudinal axis 58 of the combustion chamber 14.
- a first firing layer 60 may include nozzles 50 that introduce the biofuel 12 and primary air
- a second firing layer 62 may include nozzles 52 that introduce secondary air
- a third firing layer 64 may include nozzles 50 that introduce the biofuel 12 and primary air.
- each firing layer 60, 62, and 64 includes either nozzles 50, that introduce only primary air and the biofuel, or nozzles 52, that introduce only secondary air
- an individual firing layer 60, 62, and 64 may include both nozzles 50 and nozzles 52.
- FIG. 2 shows three firing layers 60, 62, and 64 in the first stage 42, it will be understood that embodiments of the invention may include any number of firing layers in the first stage 42.
- the biofuel 12 and first air stream 56 are ignited such that the biofuel 12 combusts while in a suspended state.
- the second stage 44 is downstream of the first stage 42 with respect to the combusting biofuel 12.
- the combusting biofuel 12 forms a fireball 66 that spans the vertical axis 58 from the first 42 to the second 44 stage.
- a second set of wind boxes 48 have nozzles 54 that are operative to introduce a second air stream 68, e.g., closed coupled over-fired air and/or separated over-fired air, into the second stage 44.
- a second air stream 68 e.g., closed coupled over-fired air and/or separated over-fired air
- staged air air staging
- staged combustion and “staging the combustion” refer to above described splitting of the air consumed by the combustion of the biofuel 12 between the first 42 and second 44 stages via the first 56 and the second 68 air streams.
- nozzles 54 may be arranged into one or more firing layers 70 and 72 similar to nozzles 50 and 52 and firing layers 60, 62, and 64.
- the biofuel 12 may be tangentially fired, i.e., the biofuel 12 is introduced into the first stage (42 in FIG. 2 ) via nozzles 50 at an angle ⁇ formed between the trajectory of the primary air component of the first air stream 56, and a radial line 74 extending from the vertical axis 58 to the nozzles 50.
- the nozzles 50 inject the biofuel 12 via the primary air component of the first air steam 56 tangentially to an imaginary circle 66, representative of the fireball, that is centered on the vertical axis 58.
- the angle ⁇ may range from 2-10 degrees. While FIG.
- the nozzles 50 may be disposed at any point within the firing layer 60 outside of the fireball 66.
- the nozzles (50, 52 and 54 in FIG. 2 ) of the other firing layers (62, 64, 70, and 72 in FIG. 2 ) may be oriented in the same manner as the nozzles 50 of first firing layer 60 shown in FIG. 3 . Accordingly, upon leaving the nozzles 50, the particles of the biofuel 12 follow a helix shaped flight path 76, e.g., a corkscrew, within the fireball 66 as they flow from the first stage 42 to the second stage 44. In other words, tangentially firing the biofuel 12 causes the fireball 66 to rotate about the vertical axis 58.
- the helix shaped flight path 76 provides for a more controlled combustion reaction for particles of the biofuel 12 over traditional stoker grate firing methods.
- the helix shaped flight path 76 causes the flue gas to circulate about the "eye"/center of the fireball 66, i.e., the vertical axis 58, which dilutes the oxygen concentration within the fireball 66, thereby retarding the combustion reaction and/or temperature.
- staging of the combustion reaction additionally retards the combustion reaction and/or combustion temperature, which also increases the de-NOx performance of the combustion reaction.
- the aforementioned provides for better control over the stoichiometry of the combustion reaction.
- the first 56 and the second 68 airstreams can be adjusted to regulate the stoichiometry of the combustion reaction in a predictable manner so as to limit the generation of NOx.
- the first air stream 56 provides a greater than or equal amount of air consumed by the combustion reaction than does the second air stream 68.
- the first air stream 56 provides about 50-70% of the air consumed by the combustion of the biofuel 12, which in turn regulates the stoichiometry of the combustion reaction of the biofuel 12 in the first stage 42 to between about 0.6-0.8.
- the second air stream 68 provides the remaining air consumed by combustion reaction, which in turn regulates the stoichiometry of the combustion reaction in the second stage 44 to less than or equal to about 1.2.
- regulating the stoichiometry of the first 42 and the second 44 stages via staging of the combustion reaction i.e., staging of the introduction of the first 56 and second 68 air streams, drives nitrogen ("N") out of the biofuel 12 to become molecular nitrogen (“N2") within the first stage 42, as opposed to forming NOx as typically occurs in the unpredictable stoichiometric conditions associated with traditional stoker grate methods.
- N2 molecular nitrogen
- the nitrogenous species are released from the volatile matter of the biofuel 12 and subsequently reduced to N2 by hydrocarbon intermediates within the first stage 42.
- combusting the biofuel 12 may result in about 12381, 88Kg/Kwh (0.08 lb/MBtu) of NOx prior to treatment of the flue gas by the SCR (24 in FIG. 1 ) and/or without the use of support fuel.
- the SCR 24 may further reduce the NOx within the emitted flue gas to less than or equal to about 1547, 72 Kg/Kwh (0.01 lb/ MBtu) without the use of an SNCR.
- system 10 may include the necessary electronics, software, memory, storage, databases, firmware, logic/state machines, microprocessors, communication links, displays or other visual or audio user interfaces, printing devices, and any other input/output interfaces to perform the functions described herein and/or to achieve the results described herein, which may be executed in real-time.
- the system 10 may include at least one processor 18 and system memory / data storage structures 20 in the form of a controller 16 that electrically communicates with one or more of the components of the system 10.
- the memory may include random access memory (“RAM”) and read-only memory (“ROM").
- the at least one processor may include one or more conventional microprocessors and one or more supplementary co-processors such as math co-processors or the like.
- the data storage structures discussed herein may include an appropriate combination of magnetic, optical and/or semiconductor memory, and may include, for example, RAM, ROM, flash drive, an optical disc such as a compact disc and/or a hard disk or drive.
- a software application that provides for control over one or more of the various components of the system 10 may be read into a main memory of the at least one processor from a computer-readable medium.
- computer-readable medium refers to any medium that provides or participates in providing instructions to the at least one processor 18 (or any other processor of a device described herein) for execution.
- Such a medium may take many forms, including but not limited to, non-volatile media and volatile media.
- Non-volatile media include, for example, optical, magnetic, or opto-magnetic disks, such as memory.
- Volatile media include dynamic random access memory (“DRAM”), which typically constitutes the main memory.
- DRAM dynamic random access memory
- Computer-readable media include, for example, a floppy disk, a flexible disk, hard disk, magnetic tape, any other magnetic medium, a CD-ROM, DVD, any other optical medium, a RAM, a PROM, an EPROM or EEPROM (electronically erasable programmable read-only memory), a FLASH-EEPROM, any other memory chip or cartridge, or any other medium from which a computer can read.
- a method of firing a biofuel includes: introducing the biofuel into a combustion chamber having a first stage and a second stage; combusting the biofuel in a suspended state while flowing from the first stage to the second stage; and introducing a first air stream and a second air stream into the combustion chamber at the first stage and at the second stage, respectively, to facilitate combustion of the biofuel.
- introducing the biofuel into a combustion chamber further includes tangentially firing at least some of the biofuel at the first stage.
- the biofuel has a maximum particle size less than or equal to about 2 mm.
- the first air stream provides a greater than or equal amount of the air consumed by combustion of the biofuel than the second air stream and the first air stream provides about 50-70% of the air consumed by combustion of the biofuel.
- combusting the biofuel produces less than or equal to about 12381, 77 Kg/Kwh (0.08 lb/MBtu) of NOx.
- the biofuel is at least one of bagasse, wood, peat, straw, and grass.
- the system includes a combustion chamber having a first stage and a second stage.
- the combustion chamber is operative to provide for combustion of the biofuel in a suspended state while flowing from the first stage to the second stage.
- the combustion chamber further has a first injector and a second injector operative to introduce a first air stream and a second air stream into the combustion chamber at the first stage and at the second stage, respectively, to facilitate combustion of the biofuel.
- first injector is operative to introduce at least some of the biofuel into the combustion chamber at the first stage via tangential firing.
- the system further includes a mill operative to provide the biofuel to the combustion chamber at a maximum particle size less than or equal to about 2 mm.
- the first air stream provides a greater than or equal amount of the air consumed by combustion of the biofuel than the second air stream.
- the first air stream provides about 50-70% of the air consumed by combustion of the biofuel.
- the system further includes a selective catalytic reducer that is operative to limit NOx emissions resulting from combustion of the biofuel to less than or equal to about 1547, 72 Kg/Kwh (0.01 lb/MBtu) .
- the biofuel is at least one of bagasse, wood, peat, straw, and grass.
- the invention also provides for a non-transitory computer readable medium storing instructions.
- the stored instructions are configured to adapt a controller to: introduce a biofuel into a combustion chamber having a first stage and a second stage; combust the biofuel in a suspended state while flowing from the first stage to the second stage; and introduce a first air stream and a second air stream into the combustion chamber at the first stage and at the second stage, respectively, to facilitate combustion of the biofuel.
- at least some of the biofuel is introduced into the combustion chamber at the first stage via tangential firing.
- the biofuel has a maximum particle size less than or equal to about 2 mm.
- the first air stream provides a greater than or equal amount of the air consumed by combustion of the biofuel than the second air stream and the first air stream provides about 50-70% of the air consumed by combustion of the biofuel.
- combustion of the biofuel produces less than or equal to about 12381, 77 Kg/Kwh (0.08 lb/MBtu) of NOx.
- some embodiments of the invention generate significantly lower amounts of NOx than traditional methods of firing biofuels, e.g., stoker grates.
- some embodiments of the invention are able to achieve NOx emissions as low as about 0.08 lb/MBtu without the use of an SCR, and as low as about 1547, 72 Kg/Kwh (0.01 lb/MBtu) with an SCR unaccompanied by an SCNR.
- some embodiments of the invention greatly reduce the operational costs of an encompassing power plant. Additionally, by achieving NOx emissions as low as 12381, 77 Kg/Kwh (0.08 lb/MBtu), the SCR of some embodiments of the invention may be smaller than those typically used in traditional biofuel power plants.
- the tangential firing of the biofuel 12 in some embodiments causes the combustion reaction to occur "globally", i.e., uniformly, within the first stage 42.
- some embodiments provide for the ignition and/or mixing of the biofuel 12 and first air stream 56, as well as improved flame stability, without the need for localized, high turbulence injections of fuel and air.
Description
- Embodiments of the invention relate generally to energy production, and more specifically, to a method for firing a biofuel.
- As demand for renewable energy sources continues to grow, biofuels are increasingly used in the production of energy. In particular, many electrical power plants, also referred to hereinafter simply as "power plants", burn biofuels to produce steam, which in turn powers a steam turbine generator. In many such power plants, the biofuel is burned on a stoker grate within a combustion chamber. Burning biofuel on a stoker grate, however, can potentially create a relatively unpredictable and/or uncontrolled combustion reaction for a given amount of biofuel. The terms "predictable" and "unpredictable", as used herein with respect to a combustion reaction, refer to the likelihood that the combustion reaction will follow a predicted/calculated rate and/or stoichiometry. Typically, the more unpredictable/predictable a combustion reaction, the harder/easier it is to control the stoichiometry of the combustion reaction, and the greater/lesser the amount of mono-nitrogen oxides ("NOx") produced from the combustion reaction. Accordingly, stoker grate-based power plants, which as stated above tend to create unpredictable combustion reactions, generally create high amounts of NOx.
- As NOx has been determined to contribute to the formation of acid rain, many governments have defined NOx emission limits for biofuel burning power plants. In order to meet such NOx emission limits, many biofuel burning power plants employ both selective non-catalytic reducers ("SNCRs") and selective catalytic reducers ("SCRs"). SNCRs and SCRs, however, are resource intensive and expensive to operate. Moreover, many SNCRs rely on ammonia ("NH3") injection into an emitted flue gas for NOx reduction. Using NH3 to reduce NOx under the wrong temperature conditions, however, risks NOx formation and/or NH3 slip in the emitted flue gas.
- Document
US 6 269 755 B1 discloses an industrial burner for combustion of biomass. Said industrial burner is designed to achieve high turndown ratios and high heat release ratios. A combustion chamber disclosed in this document comprises three stages with the same amount of air provided to each of them. DocumentUS 4 398 477 A discloses a combustion furnace that avoids discharging large amount of dust into the environment and uses combustion gases as a direct heat source, i.e., not requiring a heat exchanger. This combustion furnace comprises two chambers wherein the second chamber receives more air than the first one. DocumentUS 3 831 535 A discloses a system with a combustion chamber and a blending chamber. The combustion chamber burns a biofuel and the blending chamber burns gases produced from drying veneer. DocumentUS 2006/225424 A1 discloses a cyclonic combustor for a biofuel. The cyclonic combustor includes an ignition zone, a combustion zone and a dilution zone. Air is provided in the ignition zone and in the combustion zone in stoichiometric amounts to lower emission of nitrogen oxides. The dilution zone is provided with air to dilute and cool down combustion gases so that said combustion gases can be used in a gas turbine. - What is needed, therefore, is an improved system and method for firing a biofuel.
- According to the invention, a method of firing a biofuel is provided as claimed in
claim 1. - Within the scope of this disclosure, a system for firing a biofuel is provided. The system includes a combustion chamber having a first stage and a second stage. The combustion chamber is operative to provide for combustion of the biofuel in a suspended state while flowing from the first stage to the second stage. The combustion chamber further has a first injector and a second injector operative to introduce a first air stream and a second air stream into the combustion chamber at the first stage and at the second stage, respectively, to facilitate combustion of the biofuel.
- According to the invention, a non-transitory computer readable medium storing instructions is provided as claimed in claim 5.
- The present invention will be better understood from reading the following description of non-limiting embodiments, with reference to the attached drawings, wherein below:
-
FIG. 1 is a block diagram of a system for firing a biofuel, in accordance with an embodiment of the invention; -
FIG. 2 is a diagram of a combustion chamber of the system ofFIG. 1 , in accordance with an embodiment of the invention; and -
FIG. 3 is a cross-sectional view of a firing layer of the combustion chamber ofFIG. 2 , in accordance with an embodiment of the invention. - Reference will be made below in detail to exemplary embodiments of the invention, examples of which are illustrated in the accompanying drawings. Wherever possible, the same reference characters used throughout the drawings refer to the same or like parts, without duplicative description.
- As used herein, the terms "substantially", "generally" and "about" indicate conditions within reasonably achievable manufacturing and assembly tolerances, relative to ideal desired conditions suitable for achieving the functional purpose of a component or assembly. The term "real-time", as used herein, means a level of processing responsiveness that a user senses as sufficiently immediate or that enables the processor to keep up with an external process. As used herein, "electrically coupled", "electrically connected", and "electrical communication" mean that the referenced elements are directly or indirectly connected such that an electrical current, or other communication medium, may flow from one to the other. The connection may include a direct conductive connection, i.e., without an intervening capacitive, inductive or active element, an inductive connection, a capacitive connection, and/or any other suitable electrical connection. Intervening components may be present. As also used herein, the term "fluidly connected" means that the referenced elements are connected such that a fluid (to include a liquid, gas and/or plasma) may flow from one to the other. Accordingly, the terms "upstream" and "downstream", as used herein, describe the position of the referenced elements with respect to a flow path of a fluid and/or gas flowing between and/or near the referenced elements. Further, the term "stream", as used herein with respect to particles, means a continuous or near continuous flow of particles. As also used herein, the term "heating contact" means that the referenced objects are in proximity of one another such that heat/thermal energy can transfer between them. As further used herein, the terms "suspended state combustion" refers to the process of combusting a fuel suspended in air.
- Additionally, while the embodiments disclosed herein are primarily described with respect to power plants, it is to be understood that embodiments of the invention may be applicable to any apparatus and/or method that needs to limit and/or eliminate NOx emissions resulting from the combustion of a biofuel, e.g., an incinerator.
- Referring now to
FIG. 1 , asystem 10 for firing a biofuel (12,FIG. 2 ), e.g., bagasse, switchblade and/or other grasses, wood, peat, straw, and/or other suitable biofuels, in accordance with embodiments of the invention is shown. Thesystem 10 includes acombustion chamber 14, and may further include acontroller 16 having at least oneprocessor 18 and amemory device 20, amill 22, anSCR 24, and/or anexhaust stack 26. As will be appreciated, thesystem 10 may form part of apower plant 28 where thecombustion chamber 14 is incorporated into aboiler 30 which produces steam for the generation of electricity via asteam turbine generator 32. - As will be understood, the
mill 22 is operative to receive and process thebiofuel 12 for combustion within thecombustion chamber 14, i.e., themill 22 shreds, pulverizes, and/or otherwise conditions thebiofuel 12 for firing within thecombustion chamber 14. For example, in embodiments, themill 22 may process thebiofuel 12 to particles sizes less than or equal to about 2 mm. In other embodiments, themill 22 may process thebiofuel 12 to particles sizes less than or equal to about 1 mm. Themill 22 may be a non-screened styled hammer mill integrated with a flash drying column disposed at the inlet of a beater wheel exhaust fan. The processedbiofuel 12 is then transported/fed from themill 22 to thecombustion chamber 14 viaconduit 34. - The
combustion chamber 14 is operative to receive and to facilitate combustion of thebiofuel 12, which results in the generation of heat and a flue gas. The flue gas may be sent from thecombustion chamber 14 to the SCR 24 viaconduit 36. In embodiments where thecombustion chamber 14 is integrated into theboiler 30, the heat from combusting thebiofuel 12 may be captured and used to generate steam, e.g., via water walls in heating contact with the flue gas, which is then sent to thesteam turbine generator 32 viaconduit 38. - The SCR 24 is operative to reduce NOx within the flue gas prior to emission of the flue gas into the atmosphere via
conduit 40 andexhaust stack 26. - Turning now to
FIG. 2 , thecombustion chamber 14 has two ormore stages more wind boxes injectors FIG. 2 depicts thestages stages stages FIG. 2 , a first set ofwind boxes 46 havenozzles biofuel 12 and afirst air stream 56 into thefirst stage 42. As will be appreciated, thefirst air steam 56 may be generated from both primary and secondary air supplies. For example, in embodiments,nozzles 50 may introduce thebiofuel 12 into thefirst stage 42 via primary air, while secondary air is introduced into thefirst stage 42 vianozzles 52. Particles of thebiofuel 12 may be introduced into thecombustion chamber 14 vianozzles 50 at a slip speed, with respect to primary air, of between about 0-30,48 meters/second (0-100 feet/second). As used herein, the term slip speed refers to the difference in the velocity of the particles of thebiofuel 12 and the velocity of the primary air transporting thebiofuel 12 vianozzles 50. In embodiments, 100% of the biofuel may be injected by thenozzles 50 within thefirst stage 42. - As also shown in
FIG. 2 , thenozzles nozzles longitudinal axis 58 of thecombustion chamber 14. For example, afirst firing layer 60 may includenozzles 50 that introduce thebiofuel 12 and primary air, asecond firing layer 62 may includenozzles 52 that introduce secondary air, and athird firing layer 64 may includenozzles 50 that introduce thebiofuel 12 and primary air. While the firing layers 60, 62, and 64 are depicted herein as being uniform, i.e., eachfiring layer nozzles 50, that introduce only primary air and the biofuel, ornozzles 52, that introduce only secondary air, it will be understood that, in embodiments, anindividual firing layer nozzles 50 andnozzles 52. Further, whileFIG. 2 shows three firinglayers first stage 42, it will be understood that embodiments of the invention may include any number of firing layers in thefirst stage 42. - Upon introduction into the
first stage 42, thebiofuel 12 andfirst air stream 56 are ignited such that thebiofuel 12 combusts while in a suspended state. As further shown inFIG. 2 , thesecond stage 44 is downstream of thefirst stage 42 with respect to the combustingbiofuel 12. Thus, due to convective forces generated by combusting thebiofuel 12, particles of thebiofuel 12 rise, or otherwise move, within thecombustion chamber 14 as they undergo combustion such that they flow from thefirst stage 42 to thesecond stage 44. In other words, the combustingbiofuel 12 forms afireball 66 that spans thevertical axis 58 from the first 42 to the second 44 stage. - As further shown in
FIG. 2 , a second set ofwind boxes 48 havenozzles 54 that are operative to introduce asecond air stream 68, e.g., closed coupled over-fired air and/or separated over-fired air, into thesecond stage 44. Accordingly, as used herein, the terms "staged air", "air staging", "staged combustion", and "staging the combustion" refer to above described splitting of the air consumed by the combustion of thebiofuel 12 between the first 42 and second 44 stages via the first 56 and the second 68 air streams. As will also be appreciated,nozzles 54 may be arranged into one or more firing layers 70 and 72 similar tonozzles - Moving now to
FIG. 3 , a cross-sectional view offiring layer 60 is shown. As will be appreciated, in embodiments, thebiofuel 12 may be tangentially fired, i.e., thebiofuel 12 is introduced into the first stage (42 inFIG. 2 ) vianozzles 50 at an angle Ø formed between the trajectory of the primary air component of thefirst air stream 56, and aradial line 74 extending from thevertical axis 58 to thenozzles 50. In other words, thenozzles 50 inject thebiofuel 12 via the primary air component of thefirst air steam 56 tangentially to animaginary circle 66, representative of the fireball, that is centered on thevertical axis 58. In certain aspects, the angle Ø may range from 2-10 degrees. WhileFIG. 3 depicts thenozzles 50 within thefirst firing layer 60 as disposed within the corners of thecombustion chamber 14, in other embodiments, thenozzles 50 may be disposed at any point within thefiring layer 60 outside of thefireball 66. As will be understood, the nozzles (50, 52 and 54 inFIG. 2 ) of the other firing layers (62, 64, 70, and 72 inFIG. 2 ) may be oriented in the same manner as thenozzles 50 offirst firing layer 60 shown inFIG. 3 . Accordingly, upon leaving thenozzles 50, the particles of thebiofuel 12 follow a helix shapedflight path 76, e.g., a corkscrew, within thefireball 66 as they flow from thefirst stage 42 to thesecond stage 44. In other words, tangentially firing thebiofuel 12 causes thefireball 66 to rotate about thevertical axis 58. - Returning back to
FIG. 2 , as will be appreciated, the helix shapedflight path 76 provides for a more controlled combustion reaction for particles of thebiofuel 12 over traditional stoker grate firing methods. In particular, the helix shapedflight path 76 causes the flue gas to circulate about the "eye"/center of thefireball 66, i.e., thevertical axis 58, which dilutes the oxygen concentration within thefireball 66, thereby retarding the combustion reaction and/or temperature. Further, staging of the combustion reaction additionally retards the combustion reaction and/or combustion temperature, which also increases the de-NOx performance of the combustion reaction. As will be appreciated, the aforementioned provides for better control over the stoichiometry of the combustion reaction. In particular, the first 56 and the second 68 airstreams can be adjusted to regulate the stoichiometry of the combustion reaction in a predictable manner so as to limit the generation of NOx. - Accordingly, the
first air stream 56 provides a greater than or equal amount of air consumed by the combustion reaction than does thesecond air stream 68. For example, in embodiments, thefirst air stream 56 provides about 50-70% of the air consumed by the combustion of thebiofuel 12, which in turn regulates the stoichiometry of the combustion reaction of thebiofuel 12 in thefirst stage 42 to between about 0.6-0.8. As will be understood, thesecond air stream 68 provides the remaining air consumed by combustion reaction, which in turn regulates the stoichiometry of the combustion reaction in thesecond stage 44 to less than or equal to about 1.2. As will be understood, regulating the stoichiometry of the first 42 and the second 44 stages via staging of the combustion reaction, i.e., staging of the introduction of the first 56 and second 68 air streams, drives nitrogen ("N") out of thebiofuel 12 to become molecular nitrogen ("N2") within thefirst stage 42, as opposed to forming NOx as typically occurs in the unpredictable stoichiometric conditions associated with traditional stoker grate methods. In other words, in embodiments, the nitrogenous species are released from the volatile matter of thebiofuel 12 and subsequently reduced to N2 by hydrocarbon intermediates within thefirst stage 42. - Thus, in certain aspects of the invention, combusting the
biofuel 12 may result in about 12381, 88Kg/Kwh (0.08 lb/MBtu) of NOx prior to treatment of the flue gas by the SCR (24 inFIG. 1 ) and/or without the use of support fuel. As such, theSCR 24 may further reduce the NOx within the emitted flue gas to less than or equal to about 1547, 72 Kg/Kwh (0.01 lb/ MBtu) without the use of an SNCR. - Finally, it is also to be understood that the
system 10 may include the necessary electronics, software, memory, storage, databases, firmware, logic/state machines, microprocessors, communication links, displays or other visual or audio user interfaces, printing devices, and any other input/output interfaces to perform the functions described herein and/or to achieve the results described herein, which may be executed in real-time. For example, as stated above, thesystem 10 may include at least oneprocessor 18 and system memory /data storage structures 20 in the form of acontroller 16 that electrically communicates with one or more of the components of thesystem 10. The memory may include random access memory ("RAM") and read-only memory ("ROM"). The at least one processor may include one or more conventional microprocessors and one or more supplementary co-processors such as math co-processors or the like. The data storage structures discussed herein may include an appropriate combination of magnetic, optical and/or semiconductor memory, and may include, for example, RAM, ROM, flash drive, an optical disc such as a compact disc and/or a hard disk or drive. - Additionally, a software application that provides for control over one or more of the various components of the
system 10 may be read into a main memory of the at least one processor from a computer-readable medium. The term "computer-readable medium", as used herein, refers to any medium that provides or participates in providing instructions to the at least one processor 18 (or any other processor of a device described herein) for execution. Such a medium may take many forms, including but not limited to, non-volatile media and volatile media. Non-volatile media include, for example, optical, magnetic, or opto-magnetic disks, such as memory. Volatile media include dynamic random access memory ("DRAM"), which typically constitutes the main memory. Common forms of computer-readable media include, for example, a floppy disk, a flexible disk, hard disk, magnetic tape, any other magnetic medium, a CD-ROM, DVD, any other optical medium, a RAM, a PROM, an EPROM or EEPROM (electronically erasable programmable read-only memory), a FLASH-EEPROM, any other memory chip or cartridge, or any other medium from which a computer can read. - While in embodiments, the execution of sequences of instructions in the software application causes the at least one processor to perform the methods/processes described herein, hard-wired circuitry may be used in place of, or in combination with, software instructions for implementation of the methods/processes of the present invention. Therefore, embodiments of the present invention are not limited to any specific combination of hardware and/or software.
- It is further to be understood that the above description is intended to be illustrative, and not restrictive. For example, the above-described embodiments (and/or aspects thereof) may be used in combination with each other. Additionally, many modifications may be made to adapt a particular situation or material to the teachings of the invention without departing from its scope.
- According to the invention, a method of firing a biofuel is provided. The method includes: introducing the biofuel into a combustion chamber having a first stage and a second stage; combusting the biofuel in a suspended state while flowing from the first stage to the second stage; and introducing a first air stream and a second air stream into the combustion chamber at the first stage and at the second stage, respectively, to facilitate combustion of the biofuel. In certain embodiments, introducing the biofuel into a combustion chamber further includes tangentially firing at least some of the biofuel at the first stage. In certain embodiments, the biofuel has a maximum particle size less than or equal to about 2 mm. The first air stream provides a greater than or equal amount of the air consumed by combustion of the biofuel than the second air stream and the first air stream provides about 50-70% of the air consumed by combustion of the biofuel. In certain embodiments, combusting the biofuel produces less than or equal to about 12381, 77 Kg/Kwh (0.08 lb/MBtu) of NOx. In certain embodiments, the biofuel is at least one of bagasse, wood, peat, straw, and grass.
- Other embodiments not covered by the present invention provide for a system for firing a biofuel. The system includes a combustion chamber having a first stage and a second stage. The combustion chamber is operative to provide for combustion of the biofuel in a suspended state while flowing from the first stage to the second stage. The combustion chamber further has a first injector and a second injector operative to introduce a first air stream and a second air stream into the combustion chamber at the first stage and at the second stage, respectively, to facilitate combustion of the biofuel. In certain embodiments, first injector is operative to introduce at least some of the biofuel into the combustion chamber at the first stage via tangential firing. In certain embodiments, the system further includes a mill operative to provide the biofuel to the combustion chamber at a maximum particle size less than or equal to about 2 mm. In certain embodiments, the first air stream provides a greater than or equal amount of the air consumed by combustion of the biofuel than the second air stream. In certain embodiments, the first air stream provides about 50-70% of the air consumed by combustion of the biofuel. In certain embodiments, the system further includes a selective catalytic reducer that is operative to limit NOx emissions resulting from combustion of the biofuel to less than or equal to about 1547, 72 Kg/Kwh (0.01 lb/MBtu) . In certain embodiments, the biofuel is at least one of bagasse, wood, peat, straw, and grass.
- The invention also provides for a non-transitory computer readable medium storing instructions. The stored instructions are configured to adapt a controller to: introduce a biofuel into a combustion chamber having a first stage and a second stage; combust the biofuel in a suspended state while flowing from the first stage to the second stage; and introduce a first air stream and a second air stream into the combustion chamber at the first stage and at the second stage, respectively, to facilitate combustion of the biofuel. In certain embodiments, at least some of the biofuel is introduced into the combustion chamber at the first stage via tangential firing. In certain embodiments, the biofuel has a maximum particle size less than or equal to about 2 mm. The first air stream provides a greater than or equal amount of the air consumed by combustion of the biofuel than the second air stream and the first air stream provides about 50-70% of the air consumed by combustion of the biofuel. In certain embodiments, combustion of the biofuel produces less than or equal to about 12381, 77 Kg/Kwh (0.08 lb/MBtu) of NOx.
- Accordingly, by combusting the biofuel in a suspended state and staging the introduction of air consumed by the combustion reaction, some embodiments of the invention generate significantly lower amounts of NOx than traditional methods of firing biofuels, e.g., stoker grates. In particular, some embodiments of the invention are able to achieve NOx emissions as low as about 0.08 lb/MBtu without the use of an SCR, and as low as about 1547, 72 Kg/Kwh (0.01 lb/MBtu) with an SCR unaccompanied by an SCNR. By eliminating the need for an SCNR to reach about 1547, 72 Kg/Kwh (0.01 lb/MBtu) emitted NOx, some embodiments of the invention greatly reduce the operational costs of an encompassing power plant. Additionally, by achieving NOx emissions as low as 12381, 77 Kg/Kwh (0.08 lb/MBtu), the SCR of some embodiments of the invention may be smaller than those typically used in traditional biofuel power plants.
- Further, the tangential firing of the
biofuel 12 in some embodiments causes the combustion reaction to occur "globally", i.e., uniformly, within thefirst stage 42. Thus, some embodiments provide for the ignition and/or mixing of thebiofuel 12 andfirst air stream 56, as well as improved flame stability, without the need for localized, high turbulence injections of fuel and air. - While the dimensions and types of materials described herein are intended to define the parameters of the invention, they are by no means limiting and are exemplary embodiments. Many other embodiments will be apparent to those of skill in the art upon reviewing the above description. The scope of the invention should, therefore, be determined with reference to the appended claims, along with the full scope of equivalents to which such claims are entitled. In the appended claims, the terms "including" and "in which" are used as the plain-English equivalents of the respective terms "comprising" and "wherein." Moreover, in the following claims, terms such as "first", "second", "third", "upper", "lower", "bottom", "top", etc. are used merely as labels, and are not intended to impose numerical or positional requirements on their objects. Further, the limitations of the following claims are not written in means-plus-function format and are not intended to be interpreted as such, unless and until such claim limitations expressly use the phrase "means for" followed by a statement of function void of further structure.
- This written description uses examples to disclose several embodiments of the invention, including the best mode, and also to enable one of ordinary skill in the art to practice the embodiments of invention, including making and using any devices or systems and performing any incorporated methods. The patentable scope of the invention is defined by the claims, and may include other examples that occur to one of ordinary skill in the art. Such other examples are intended to be within the scope of the claims if they have structural elements that do not differ from the literal language of the claims.
- As used herein, an element or step recited in the singular and proceeded with the word "a" or "an" should be understood as not excluding plural of said elements or steps, unless such exclusion is explicitly stated. Furthermore, references to "one embodiment" of the present invention are not intended to be interpreted as excluding the existence of additional embodiments that also incorporate the recited features. Moreover, unless explicitly stated to the contrary, embodiments "comprising", "including", or "having" an element or a plurality of elements having a particular property may include additional such elements not having that property.
- Since certain changes may be made in the above-described invention, without departing from the scope of the invention herein involved, it is intended that all of the subject matter of the above description shown in the accompanying drawings shall be interpreted merely as examples illustrating the inventive concept herein and shall not be construed as limiting the invention.
Claims (7)
- A method of firing a biofuel (12) comprising:• introducing the biofuel (12) into a combustion chamber (14) having a first stage (42) and a second stage (44),• combusting the biofuel (12) in a suspended state while flowing from the first stage (42) to the second stage (44), and• introducing a first air stream (56) and a second air stream (68) into the combustion chamber (14) at the first stage (42) and at the second stage (44), respectively, to facilitate combustion of the biofuel (12), andcharacterized in thatthe first air stream (56) provides a greater than or equal amount of the air consumed by combustion of the biofuel (12) than the second air stream (68), andwherein the first air stream (56) provides 50-70% of the air consumed by combustion of the biofuel (12).
- The method according to claim 1, characterized in that introducing the biofuel (12) into a combustion chamber (14) further comprises tangentially firing at least some of the biofuel (12) at the first stage (42).
- The method according to claim 1 or 2, characterized in that the biofuel (12) has a maximum particle size less than or equal to 2 mm.
- The method according to any of claims 1 to 3, characterized in that the biofuel (12) is at least one of bagasse, wood, peat, straw, and grass.
- A non-transitoiy computer readable medium storing instructions configured to adapt a controller (16) to:• introduce a biofuel (12) into a combustion chamber (14) having a first stage (42) and a second stage (44),• combust the biofuel (12) in a suspended state while flowing from the first stage (42) to the second stage (44), and• introduce a first air stream (56) and a second air stream (68) into the combustion chamber (14) at the first stage (42) and at the second stage (44), respectively, to facilitate combustion of the biofuel (12), andcharacterized in that the first air stream (56) provides a greater than or equal amount of the air consumed by combustion of the biofuel (12) than the second air stream (68), wherein the first air stream (56) provides 50-70% of the air consumed by combustion of the biofuel (12).
- The non-transitoiy computer readable medium according to claim 5, characterized in that at least some of the biofuel (12) is introduced into the combustion chamber (14) at the first stage (42) via tangential firing.
- The non-transitory computer readable medium according to claim 5 or 6, characterized in that the biofuel (12) has a maximum particle size less than or equal to 2 mm.
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US15/435,740 US20180238541A1 (en) | 2017-02-17 | 2017-02-17 | System and method for firing a biofuel |
PCT/EP2018/052467 WO2018149651A1 (en) | 2017-02-17 | 2018-02-01 | System and method for firing a biofuel |
Publications (2)
Publication Number | Publication Date |
---|---|
EP3583356A1 EP3583356A1 (en) | 2019-12-25 |
EP3583356B1 true EP3583356B1 (en) | 2023-01-11 |
Family
ID=61521467
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
EP18707851.4A Active EP3583356B1 (en) | 2017-02-17 | 2018-02-01 | Method for firing a biofuel |
Country Status (6)
Country | Link |
---|---|
US (1) | US20180238541A1 (en) |
EP (1) | EP3583356B1 (en) |
JP (1) | JP7027435B2 (en) |
CN (1) | CN110476015A (en) |
PL (1) | PL3583356T3 (en) |
WO (1) | WO2018149651A1 (en) |
Family Cites Families (20)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3658017A (en) * | 1971-01-04 | 1972-04-25 | Gen Electric | Incinerator |
US3727563A (en) * | 1971-07-02 | 1973-04-17 | Gen Electric | Incinerator |
US3831535A (en) * | 1973-11-02 | 1974-08-27 | Mill Conversion Contractor Inc | Wood waste burner system |
JPS56916A (en) * | 1979-06-15 | 1981-01-08 | Hokkaido Togyo Kk | Method and apparatus for generating hot blast for incineration of chaff |
US4582045A (en) * | 1981-12-17 | 1986-04-15 | Dorau Warren G | Heating apparatus |
US4565137A (en) * | 1983-08-08 | 1986-01-21 | Aqua-Chem, Inc. | Bio-mass suspension burner |
US4793322A (en) * | 1986-11-06 | 1988-12-27 | Shimek Ronald J | Direct-vented gas fireplace |
US6269755B1 (en) * | 1998-08-03 | 2001-08-07 | Independent Stave Company, Inc. | Burners with high turndown ratio |
JP2002195532A (en) * | 2000-12-20 | 2002-07-10 | Mitsubishi Heavy Ind Ltd | Method and system for evaluating environmental load in refuse incineration power plant and computer readable medium recording program of environmental load evaluation program |
SE519605C2 (en) * | 2001-04-26 | 2003-03-18 | Swedish Bioburner System Ab | Solid fuel device and method |
ATE478305T1 (en) | 2005-04-12 | 2010-09-15 | Zilkha Biomass Energy Llc | INTEGRATED BIOMASS ENERGY SYSTEM |
JP4919844B2 (en) | 2007-03-16 | 2012-04-18 | バブコック日立株式会社 | Fuel adjustment device and fuel adjustment method |
WO2009020739A2 (en) * | 2007-08-03 | 2009-02-12 | The Mcburney Corporation | Biomass energy recovery apparatus |
US20110100272A1 (en) * | 2009-08-20 | 2011-05-05 | Robert Joel Hasselbring | Vortex incinerator |
JP2011127836A (en) * | 2009-12-17 | 2011-06-30 | Mitsubishi Heavy Ind Ltd | Solid fuel burning burner and solid fuel burning boiler |
JP5897364B2 (en) | 2012-03-21 | 2016-03-30 | 川崎重工業株式会社 | Pulverized coal biomass mixed burner |
JP6289343B2 (en) | 2014-11-05 | 2018-03-07 | 三菱日立パワーシステムズ株式会社 | boiler |
EP3037724B1 (en) * | 2014-12-22 | 2019-07-31 | Improbed AB | A method for operating a fluidized bed boiler |
US20170248307A1 (en) * | 2016-02-26 | 2017-08-31 | We2E | Vortex combustion boiler |
CN105910097A (en) * | 2016-06-06 | 2016-08-31 | 西安交通大学 | System and method for achieving fuel reburning denitration through whirlwind cylinder grading of power station boiler |
-
2017
- 2017-02-17 US US15/435,740 patent/US20180238541A1/en not_active Abandoned
-
2018
- 2018-02-01 EP EP18707851.4A patent/EP3583356B1/en active Active
- 2018-02-01 JP JP2019542143A patent/JP7027435B2/en not_active Ceased
- 2018-02-01 CN CN201880011851.2A patent/CN110476015A/en active Pending
- 2018-02-01 WO PCT/EP2018/052467 patent/WO2018149651A1/en unknown
- 2018-02-01 PL PL18707851.4T patent/PL3583356T3/en unknown
Also Published As
Publication number | Publication date |
---|---|
JP2020510803A (en) | 2020-04-09 |
EP3583356A1 (en) | 2019-12-25 |
WO2018149651A1 (en) | 2018-08-23 |
JP7027435B2 (en) | 2022-03-01 |
PL3583356T3 (en) | 2023-03-06 |
CN110476015A (en) | 2019-11-19 |
US20180238541A1 (en) | 2018-08-23 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
US7775791B2 (en) | Method and apparatus for staged combustion of air and fuel | |
JP5068183B2 (en) | Combustion method and system | |
US9752773B2 (en) | Apparatus and method of controlling the thermal performance of an oxygen-fired boiler | |
EP2249081B1 (en) | Biomass center air jet burner | |
US10760789B2 (en) | Boiler and a method for NOx emission control from a boiler | |
JP7039782B2 (en) | Thermal power plant, co-firing boiler and boiler modification method | |
US8302545B2 (en) | Systems for staged combustion of air and fuel | |
EP3583356B1 (en) | Method for firing a biofuel | |
EP2751484A2 (en) | Combustion apparatus with indirect firing system | |
Xu et al. | Lower-cost alternative De-NOx solutions for coal-fired power plants | |
JP6246709B2 (en) | Combustion burner and boiler | |
JP2007292335A (en) | Thermal power generation plant and pulverized coal supply controlling method | |
EP2863123B1 (en) | Method of low-emission incineration of low and mean calorific value gases containing NH3, HCN, C5H5N, and other nitrogen-containing compounds in combustion chambers of industrial power equipment, and the system for practicing the method | |
CN103672940A (en) | Method for reducing nitrogen oxide generated by combustion of boiler | |
JP2012021652A (en) | Combustion furnace for coal firing boiler and method of operating the same | |
EP3504479B1 (en) | Overfire air system for low nitrogen oxide tangentially fired boiler | |
KR101995156B1 (en) | Combustion apparatus and generation system including the same | |
Shan et al. | Oxy-coal burner design for utility boilers | |
RU169645U1 (en) | VERTICAL PRISMATIC LOW EMISSION HEATER | |
US20210356118A1 (en) | Pure oxygen combustion method with low nitrogen source | |
US20050279263A1 (en) | Fuel staging methods for low NOx tangential fired boiler operation | |
AU2010201710B8 (en) | Biomass center air jet burner |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
STAA | Information on the status of an ep patent application or granted ep patent |
Free format text: STATUS: UNKNOWN |
|
STAA | Information on the status of an ep patent application or granted ep patent |
Free format text: STATUS: THE INTERNATIONAL PUBLICATION HAS BEEN MADE |
|
PUAI | Public reference made under article 153(3) epc to a published international application that has entered the european phase |
Free format text: ORIGINAL CODE: 0009012 |
|
STAA | Information on the status of an ep patent application or granted ep patent |
Free format text: STATUS: REQUEST FOR EXAMINATION WAS MADE |
|
17P | Request for examination filed |
Effective date: 20190916 |
|
AK | Designated contracting states |
Kind code of ref document: A1 Designated state(s): AL AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HR HU IE IS IT LI LT LU LV MC MK MT NL NO PL PT RO RS SE SI SK SM TR |
|
AX | Request for extension of the european patent |
Extension state: BA ME |
|
DAV | Request for validation of the european patent (deleted) | ||
DAX | Request for extension of the european patent (deleted) | ||
RAP3 | Party data changed (applicant data changed or rights of an application transferred) |
Owner name: GENERAL ELECTRIC TECHNOLOGY GMBH |
|
STAA | Information on the status of an ep patent application or granted ep patent |
Free format text: STATUS: EXAMINATION IS IN PROGRESS |
|
STAA | Information on the status of an ep patent application or granted ep patent |
Free format text: STATUS: EXAMINATION IS IN PROGRESS |
|
17Q | First examination report despatched |
Effective date: 20210907 |
|
GRAP | Despatch of communication of intention to grant a patent |
Free format text: ORIGINAL CODE: EPIDOSNIGR1 |
|
STAA | Information on the status of an ep patent application or granted ep patent |
Free format text: STATUS: GRANT OF PATENT IS INTENDED |
|
INTG | Intention to grant announced |
Effective date: 20220923 |
|
GRAS | Grant fee paid |
Free format text: ORIGINAL CODE: EPIDOSNIGR3 |
|
GRAA | (expected) grant |
Free format text: ORIGINAL CODE: 0009210 |
|
STAA | Information on the status of an ep patent application or granted ep patent |
Free format text: STATUS: THE PATENT HAS BEEN GRANTED |
|
AK | Designated contracting states |
Kind code of ref document: B1 Designated state(s): AL AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HR HU IE IS IT LI LT LU LV MC MK MT NL NO PL PT RO RS SE SI SK SM TR |
|
REG | Reference to a national code |
Ref country code: GB Ref legal event code: FG4D |
|
REG | Reference to a national code |
Ref country code: CH Ref legal event code: EP |
|
REG | Reference to a national code |
Ref country code: DE Ref legal event code: R096 Ref document number: 602018045267 Country of ref document: DE |
|
REG | Reference to a national code |
Ref country code: IE Ref legal event code: FG4D |
|
REG | Reference to a national code |
Ref country code: AT Ref legal event code: REF Ref document number: 1543652 Country of ref document: AT Kind code of ref document: T Effective date: 20230215 |
|
REG | Reference to a national code |
Ref country code: LT Ref legal event code: MG9D |
|
REG | Reference to a national code |
Ref country code: NL Ref legal event code: MP Effective date: 20230111 |
|
PGFP | Annual fee paid to national office [announced via postgrant information from national office to epo] |
Ref country code: TR Payment date: 20230307 Year of fee payment: 6 Ref country code: PL Payment date: 20230216 Year of fee payment: 6 Ref country code: DE Payment date: 20230119 Year of fee payment: 6 |
|
REG | Reference to a national code |
Ref country code: AT Ref legal event code: MK05 Ref document number: 1543652 Country of ref document: AT Kind code of ref document: T Effective date: 20230111 |
|
P01 | Opt-out of the competence of the unified patent court (upc) registered |
Effective date: 20230523 |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
Ref country code: NL Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20230111 |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
Ref country code: RS Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20230111 Ref country code: PT Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20230511 Ref country code: NO Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20230411 Ref country code: LV Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20230111 Ref country code: LT Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20230111 Ref country code: HR Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20230111 Ref country code: ES Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20230111 Ref country code: AT Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20230111 |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
Ref country code: SE Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20230111 Ref country code: IS Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20230511 Ref country code: GR Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20230412 Ref country code: FI Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20230111 |
|
REG | Reference to a national code |
Ref country code: CH Ref legal event code: PL |
|
REG | Reference to a national code |
Ref country code: DE Ref legal event code: R097 Ref document number: 602018045267 Country of ref document: DE |
|
REG | Reference to a national code |
Ref country code: BE Ref legal event code: MM Effective date: 20230228 |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
Ref country code: SM Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20230111 Ref country code: RO Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20230111 Ref country code: MC Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20230111 Ref country code: LU Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES Effective date: 20230201 Ref country code: LI Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES Effective date: 20230228 Ref country code: EE Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20230111 Ref country code: DK Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20230111 Ref country code: CZ Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20230111 Ref country code: CH Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES Effective date: 20230228 |
|
PLBE | No opposition filed within time limit |
Free format text: ORIGINAL CODE: 0009261 |
|
STAA | Information on the status of an ep patent application or granted ep patent |
Free format text: STATUS: NO OPPOSITION FILED WITHIN TIME LIMIT |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
Ref country code: SK Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20230111 |
|
26N | No opposition filed |
Effective date: 20231012 |
|
REG | Reference to a national code |
Ref country code: IE Ref legal event code: MM4A |
|
GBPC | Gb: european patent ceased through non-payment of renewal fee |
Effective date: 20230411 |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
Ref country code: GB Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES Effective date: 20230411 |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
Ref country code: SI Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20230111 Ref country code: IE Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES Effective date: 20230201 Ref country code: GB Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES Effective date: 20230411 Ref country code: FR Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES Effective date: 20230311 |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
Ref country code: BE Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES Effective date: 20230228 |