Patent Grant
11369921
The disclosure relates generally to treatment of waste gas and particularly to applying additives to waste gas to remove target contaminants.
Increasingly stringent pollution control standards for acid gases and trace air toxics, including hydrochloric acid (HCl), sulfur trioxide (SO3), and mercury (Hg), pose greater challenges for industries. Current best control practices for sorbent pollution control processes, such as activated carbon injection (ACI) and dry sorbent injection (DSI), must be improved. In many cases, a further increase in sorbent injection rate is uneconomical, ineffective, and/or otherwise adversely impacts the waste gas treatment process.
External constraints can also hamper additive or sorbent performance. The effectiveness of in-duct sorbent injection can often be limited due to constraints of duct layout, non-ideal injection locations, sorbent in-flight residence time, temperature, adverse flue gas chemistry, and close proximity to particulate control device.
Devices placed in the duct to improve additive or sorbent performance, such as in-line gas mixing devices, can cause operational issues. At periods of high load, for example when a power plant is running at or near full capacity during summer extremes, the pressure drop caused by can cause a measurable impact on plant performance and efficiency.
There is therefore a need for improved methods of sorbent/gas mixing that can be implemented in limited duct space while maintaining plant operational parameters within acceptable levels.
There is a further need for methods and systems that can achieve desired sorbent/gas mixing with lower pressure drop at high or peak load conditions.
These and other needs are addressed by the various aspects, embodiments, and configurations of the present disclosure. The disclosure is directed to a method and system for enhanced removal of contaminants from coal combustion and other thermal processes, particularly the use of various mixing device configurations that can provide improved additive distribution in a contaminated gas stream and/or can reduce the pressure drop across a mixing device.
The method and system can include:
The additive-containing gas stream can include a substantially homogeneous distribution of the additive in the additive-containing gas stream.
The energy for mixing by the mixing device can be primarily from a loss in pressure as the contaminated gas stream flows through the mixing device.
The contaminant can include mercury, and the additive can be one or more of a halogen, halide, and powdered activated carbon.
The contaminant can include one or more of nitrogen oxides (NOX), sulfur oxides (SOX), hydrochloric acid (HCl), hydrogen sulfide, and hydrofluoric acid (HF), and the additive one or more of lime, an alkaline earth metal sesquicarbonate, an alkali metal sesquicarbonate, a metal oxide, an alkaline earth metal carbonate, an alkali earth metal carbonate, an alkaline earth metal bicarbonate, and an alkali earth metal bicarbonate.
In the additive-containing gas stream, the distance from an output of the mixing device to an input of a downstream particulate control device can be at least about one times the hydraulic diameter of the pipe or duct, but is commonly no more than about ten times the hydraulic diameter.
The distance from a point of introduction of the additive into the contaminated gas stream to an input to the mixing device can be at least about one times the hydraulic diameter but is commonly no more than about ten times the hydraulic diameter.
A distance from an output of the static mixing device to a location of introduction of the additive (or in some applications from a point of introduction of the additive into the contaminated gas stream to an input to the mixing device) can be no more than about one times the hydraulic diameter of a conduit positioned between the mixing device and introduction location.
The mixing device can be a static mixing device having an arrangement of mixing elements in one or more mixing sections. The mixing elements, for instance, can be one or more of static fan-type blades, baffles, and/or plates. The mixing elements can be curved and/or helically shaped. The arrangement of mixing elements commonly includes from about 1 to about 5 static, or substantially stationary and/or fixed, mixing elements but can include from about 2 to about 25 mixing elements.
The flue gas velocity of the contaminated gas stream commonly ranges from about 5 to about 50 m/s.
The additive-containing gas stream can have substantially turbulent flow, and the mixing device can simultaneously cause flow division and radial mixing in the additive-containing gas stream.
A number of differing process configurations are possible.
The additive, whether an acid gas controlling, mercury capture additive, flue gas conditioning agent, or other additive, may be added downstream of the mixing device or mixing system.
The additive, whether an acid gas controlling or mercury capture additive, can be introduced into the contaminated gas stream downstream of an air heater, and the mixing device can be positioned downstream of both the air heater and the point of introduction of the additive.
The acid gas controlling additive can be an alkaline sorbent, and the alkaline sorbent and/or a mercury capture sorbent can be introduced into the contaminated gas stream downstream of the mixing device.
The alkaline sorbent can be introduced into the contaminated gas stream downstream of a first particulate control device and upstream of a second particulate control device.
The additive can be introduced into the contaminated gas stream upstream of an air heater.
The static mixing device can be positioned upstream of the air heater.
The additive can be an alkaline sorbent, and the alkaline sorbent and/or a mercury capture sorbent can be introduced into the contaminated gas stream downstream of the mixing device and air heater.
The mixing device can be positioned downstream of the air heater.
The additive can be an alkaline sorbent, and the alkaline sorbent and/or a mercury capture sorbent can be introduced into the contaminated gas stream downstream of the mixing device and air heater.
The additive can include both an alkaline sorbent and a mercury capture sorbent, and both the alkaline and mercury capture sorbents can be introduced into the contaminated gas stream upstream of the mixing device.
A mixing system can comprise a plurality of mixing devices. The plurality of mixing devices may be organized in an array. Typically, the array contains rows and columns. Rows or columns of mixing devices in an array may be rotated about an axis. Such rotation may reduce the operational cross sectional area (or cross-sectional area of the mixing device normal to the direction of gas flow) of the mixing devices relative to the cross sectional area of the pipe or duct (normal to the direction of gas flow).
An array of mixing devices can comprise rotatable mixing elements. The mixing elements may be adjusted individually, or they may be part of a rotating axis that runs through a row or column of mixing devices.
A method and system can include:
The in-line mixing device can be a static or dynamic mixing device and can cover only part of the cross section of a duct or pipe. For example, the mixing device can cover less than 50%, or less than 25%, of the cross section of the duct.
When the additive is injected downstream of the mixing device, the mixing device can create a turbulent zone that induces mixing of the additive in the gas stream even though the mixing device covers only part of the duct.
A gas treatment system and method can include:
One or more of the following can be true:
A computer-controlled feedback system can be utilized to determine when the mixing devices, or the mixing elements, should be moved from the first to the second orientations and vice versa.
The control system can include:
The microprocessor, in response to receiving a sensed stimulus indicating an occurrence of a selected event (e.g., a selected, determined, or predetermined current power load, pressure drop, sorbent consumption, and/or sensed contaminant concentration), can change a position and/or orientation of the mixing device and/or a member thereof relative to a direction of flow of the contaminated gas stream from a first position and/or orientation to a second position and/or orientation to change one or more of the above parameters (a)-(d) of the contaminated gas stream passing the mixing device.
The computer-controlled feedback system may be connected to a mechanical actuating system that rotates the static mixing devices or mixing elements.
The present disclosure can provide a number of advantages depending on the particular configuration. The disclosed process and system can couple a primary sorbent injection process with an upstream or downstream stationary static gas mixing device having a high degree of mixing effectiveness to achieve a more uniform particle distribution, to eliminate substantially stratification, such as from a vertical temperature gradient, or cause destratification in the gas stream, and to improve contact between gas and sorbent. Typical applications are gas/gas mixing such as ammonia distribution in a Selective Catalytic Reduction or SCR unit. However, in the method and system, the same or similar mixing device geometry can achieve substantially uniform particle mixing with gas over a shorter, and often the shortest possible, path. The substantially uniform particle mixing can enhance mass transfer of trace pollutants to the sorbent with a minimal impact on system pressure drop. The disclosed process and system can provide reduced sized mixing devices to reduce pressure drop in the gas stream. The disclosed process and system can, for example, provide reduced pressure drop by alternating a position and/or orientation of the mixing device(s) relative to a direction of gas stream flow. The disclosed process and system can provide a control-feedback computational system that varies the pressure drop in response to one or more sensed stimuli.
These and other advantages will be apparent from the disclosure of the aspects, embodiments, and configurations contained herein.
“A” or “an” entity refers to one or more of that entity. As such, the terms “a” (or “an”), “one or more” and “at least one” can be used interchangeably herein. It is also to be noted that the terms “comprising”, “including”, and “having” can be used interchangeably.
“Absorption” is the incorporation of a substance in one state into another of a different state (e.g. liquids being absorbed by a solid or gases being absorbed by a liquid). Absorption is a physical or chemical phenomenon or a process in which atoms, molecules, or ions enter some bulk phase—gas, liquid or solid material. This is a different process from adsorption, since molecules undergoing absorption are taken up by the volume, not by the surface (as in the case for adsorption).
“Adsorption” is the adhesion of atoms, ions, biomolecules, or molecules of gas, liquid, or dissolved solids to a surface. This process creates a film of the adsorbate (the molecules or atoms being accumulated) on the surface of the adsorbent. It differs from absorption, in which a fluid permeates or is dissolved by a liquid or solid. Similar to surface tension, adsorption is generally a consequence of surface energy. The exact nature of the bonding depends on the details of the species involved, but the adsorption process is generally classified as physisorption (characteristic of weak van der Waals forces) or chemisorption (characteristic of covalent bonding). It may also occur due to electrostatic attraction.
“At least one”, “one or more”, and “and/or” are open-ended expressions that are both conjunctive and disjunctive in operation. For example, each of the expressions “at least one of A, B and C”, “at least one of A, B, or C”, “one or more of A, B, and C”, “one or more of A, B, or C” and “A, B, and/or C” means A alone, B alone, C alone, A and B together, A and C together, B and C together, or A, B and C together. When each one of A, B, and C in the above expressions refers to an element, such as X, Y, and Z, or class of elements, such as X1-Xn, Y1-Ym, and Z1-Zo, the phrase is intended to refer to a single element selected from X, Y, and Z, a combination of elements selected from the same class (e.g., X1 and X2) as well as a combination of elements selected from two or more classes (e.g., Y1 and Zo).
The term “automatic” and variations thereof, as used herein, refers to any process or operation, which is typically continuous or semi-continuous, done without material human input when the process or operation is performed. However, a process or operation can be automatic, even though performance of the process or operation uses material or immaterial human input, if the input is received before performance of the process or operation. Human input is deemed to be material if such input influences how the process or operation will be performed. Human input that consents to the performance of the process or operation is not deemed to be “material”.
“Biomass” refers to biological matter from living or recently living organisms. Examples of biomass include, without limitation, wood, waste, (hydrogen) gas, seaweed, algae, and alcohol fuels. Biomass can be plant matter grown to generate electricity or heat. Biomass also includes, without limitation, plant or animal matter used for production of fibers or chemicals. Biomass further includes, without limitation, biodegradable wastes that can be burnt as fuel but generally excludes organic materials, such as fossil fuels, which have been transformed by geologic processes into substances such as coal or petroleum. Industrial biomass can be grown from numerous types of plants, including miscanthus, switchgrass, hemp, corn, poplar, willow, sorghum, sugarcane, and a variety of tree species, ranging from eucalyptus to oil palm (or palm oil).
“Coal” refers to a combustible material formed from prehistoric plant life. Coal includes, without limitation, peat, lignite, sub-bituminous coal, bituminous coal, steam coal, waste coal, anthracite, and graphite. Chemically, coal is a macromolecular network comprised of groups of polynuclear aromatic rings, to which are attached subordinate rings connected by oxygen, sulfur, and aliphatic bridges.
The term “computer-readable medium” as used herein refers to any computer-readable storage and/or transmission medium that participate in providing instructions to a processor for execution. Such a computer-readable medium can be tangible, non-transitory, and non-transient and take many forms, including but not limited to, non-volatile media, volatile media, and transmission media and includes without limitation random access memory (“RAM”), read only memory (“ROM”), and the like. Non-volatile media includes, for example, NVRAM, or magnetic or optical disks. Volatile media includes dynamic memory, such as main memory. Common forms of computer-readable media include, for example, a floppy disk (including without limitation a Bernoulli cartridge, ZIP drive, and JAZ drive), a flexible disk, hard disk, magnetic tape or cassettes, or any other magnetic medium, magneto-optical medium, a digital video disk (such as CD-ROM), any other optical medium, punch cards, paper tape, any other physical medium with patterns of holes, a RAM, a PROM, and EPROM, a FLASH-EPROM, a solid state medium like a memory card, any other memory chip or cartridge, a carrier wave as described hereinafter, or any other medium from which a computer can read. A digital file attachment to e-mail or other self-contained information archive or set of archives is considered a distribution medium equivalent to a tangible storage medium. When the computer-readable media is configured as a database, it is to be understood that the database may be any type of database, such as relational, hierarchical, object-oriented, and/or the like. Accordingly, the disclosure is considered to include a tangible storage medium or distribution medium and prior art-recognized equivalents and successor media, in which the software implementations of the present disclosure are stored. Computer-readable storage medium commonly excludes transient storage media, particularly electrical, magnetic, electromagnetic, optical, magneto-optical signals.
A “computer readable storage medium” may be, for example, but not limited to, an electronic, magnetic, optical, electromagnetic, infrared, or semiconductor system, apparatus, or device, or any suitable combination of the foregoing. More specific examples (a non-exhaustive list) of the computer readable storage medium would include the following: an electrical connection having one or more wires, a portable computer diskette, a hard disk, a random access memory (RAM), a read-only memory (ROM), an erasable programmable read-only memory (EPROM or Flash memory), an optical fiber, a portable compact disc read-only memory (CD-ROM), an optical storage device, a magnetic storage device, or any suitable combination of the foregoing. In the context of this document, a computer readable storage medium may be any tangible medium that can contain, or store a program for use by or in connection with an instruction execution system, apparatus, or device.
A computer readable signal medium may be any computer readable medium that is not a computer readable storage medium and that can communicate, propagate, or transport a program for use by or in connection with an instruction execution system, apparatus, or device. A computer readable signal medium may convey a propagated data signal with computer readable program code embodied therein, for example, in baseband or as part of a carrier wave. Such a propagated signal may take any of a variety of forms, including, but not limited to, electromagnetic, optical, or any suitable combination thereof. Program code embodied on a computer readable signal medium may be transmitted using any appropriate medium, including but not limited to wireless, wireline, optical fiber cable, RF, etc., or any suitable combination of the foregoing.
The terms “determine”, “calculate” and “compute,” and variations thereof, as used herein, are used interchangeably and include any type of methodology, process, mathematical operation or technique.
A “dynamic mixer” or “dynamic mixing device” is a device for the continuous or substantially continuous mixing of fluid materials. Dynamic mixers can be used to mix liquid and/or gas streams, disperse gas into liquid, or blend immiscible liquids. The energy needed for mixing comes primarily from movement of mixing elements in the dynamic mixer. Typical construction materials for dynamic mixer components include stainless steel, polypropylene, Teflon™, polyvinylidene fluoride (“PVDF”), polyvinyl chloride (“PVC”), chlorinated polyvinyl chloride (“CPVC”) and polyacetal.
“High alkali coals” refer to coals having a total alkali (e.g., calcium) content of at least about 20 wt. % (dry basis of the ash), typically expressed as CaO, while “low alkali coals” refer to coals having a total alkali content of less than 20 wt. % and more typically less than about 15 wt. % alkali (dry basis of the ash), typically expressed as CaO.
“High iron coals” refer to coals having a total iron content of at least about 10 wt. % (dry basis of the ash), typically expressed as Fe2O3, while “low iron coals” refer to coals having a total iron content of less than about 10 wt. % (dry basis of the ash), typically expressed as Fe2O3. As will be appreciated, iron and sulfur are typically present in coal in the form of ferrous or ferric carbonates and/or sulfides, such as iron pyrite.
“High sulfur coals” refer to coals having a total sulfur content of at least about 3 wt. % (dry basis of the coal) while “medium sulfur coals” refer to coals having between about 1.5 and 3 wt. % (dry basis of the coal) and “low sulfur coals” refer to coals having a total sulfur content of less than about 1.5 wt. % (dry basis of the coal).
The “hydraulic diameter” is a commonly used term when handling flow in noncircular tubes and channels. The hydraulic diameter is defined as four times the cross-sectional area of the channel divided by the inside perimeter of the channel.
“Laminar flow” (or streamline flow) occurs when a fluid flows in substantially parallel layers, with little or no disruption between the layers. At low flow velocities, the fluid tends to flow without lateral mixing, and adjacent layers slide past one another like playing cards. There are commonly no cross currents perpendicular to the direction of flow, nor eddies or swirls of fluids. In laminar flow, the motion of the particles of fluid is very orderly with all particles moving in straight lines parallel to the pipe walls. In fluid dynamics, laminar flow is a flow regime characterized by high momentum diffusion and low momentum convection. When a fluid is flowing through a closed channel such as a pipe or between two flat plates, either of two types of flow may occur depending on the velocity of the fluid: laminar flow or turbulent flow. Laminar flow tends to occur at lower velocities, below the onset of turbulent flow.
“Lime” refers to a caustic alkaline earth metal substance, such as calcium hydroxide (Ca(OH)2), calcium oxide, and mixtures thereof produced by heating limestone.
A “load profile” refers to a graph of the variation in the electrical load versus time. A load profile will generally vary according to customer type (typical examples include residential, commercial and industrial), temperature and holiday seasons. Power producers use this information to plan how much electricity they will need to make available at any given time. Load profiles are typically determined by direct metering and/or inferred from customer billing or other data. In a load research calculation, a utility uses a transformer's maximum demand reading and accounting for the known number of each customer type supplied by the transformers. Actual demand can be collected at strategic locations to perform more detailed load analysis, which can be beneficial to both distribution and end-user customers looking for peak consumption. Smart grid meters, utility meter load profilers, data logging sub-meters and portable data loggers accomplish this task by recording readings at a set interval.
“Particulate” refers to fine particles, such as fly ash, unburned carbon, contaminate-carrying powdered activated carbon, soot, byproducts of contaminant removal, excess solid additives, and other fine process solids, typically entrained in a mercury-containing gas stream.
“Means” as used herein shall be given its broadest possible interpretation in accordance with 35 U.S.C., Section 112, Paragraph 6. Accordingly, a claim incorporating the term “means” shall cover all structures, materials, or acts set forth herein, and all of the equivalents thereof. Further, the structures, materials or acts and the equivalents thereof shall include all those described in the summary of the disclosure, brief description of the drawings, detailed description, abstract, and claims themselves.
The term “module” as used herein refers to any known or later developed hardware, software, firmware, artificial intelligence, fuzzy logic, or combination of hardware and software that is capable of performing the functionality associated with that element.
“Pressure drop” refers to the difference in pressure between two points of a fluid carrying network. Pressure drop occurs when frictional forces, caused by the resistance to flow, act on a fluid as it flows through the tube. Pressure drop is determined by measuring the absolute or gauge pressure at the two points and determining the difference. Alternatively, differential pressure can be directly measured for the two points. Devices used to measure pressure include pressure gauges and manometers. Examples of pressure gauges include hydrostatic pressure gauges, piston-type gauges, liquid columns (using the pressure head equation), McLeod gauges, aneroid gauges (e.g., Bourdon pressure gauges, diaphragm gauges, and bellows gauges), magnetic coupling gauges, spinning rotor gauges, electronic pressure sensors, thermal conductivity gauges, Pirani gauges, two-wire gauges, ionization gauges (e.g., hot cathode gauges and cold cathod gauges), and the like.
“Separating” and cognates thereof refer to setting apart, keeping apart, sorting, removing from a mixture or combination, or isolating. In the context of gas mixtures, separating can be done by many techniques, including electrostatic precipitators, baghouses, scrubbers, and heat exchange surfaces.
A “sorbent” is a material that sorbs another substance; that is, the material has the capacity or tendency to take it up by sorption.
“Sorb” and cognates thereof mean to take up a liquid or a gas by sorption.
“Sorption” and cognates thereof refer to adsorption and absorption, while desorption is the reverse of adsorption.
A “static mixer” or “static mixing device” is a device for the continuous or substantially continuous mixing of fluid materials. Static mixers can be used to mix liquid and/or gas streams, disperse gas into liquid, or blend immiscible liquids. The energy needed for mixing comes primarily from a loss in pressure as fluids flow through the static mixer. One common design of static mixer is the plate-type mixer. Another common design includes mixer elements contained in a cylindrical (tube) or squared housing. Typical construction materials for static mixer components include stainless steel, polypropylene, Teflon™, polyvinylidene fluoride (“PVDF”), polyvinyl chloride (“PVC”), chlorinated polyvinyl chloride (“CPVC”) and polyacetal.
“Turbulent flow” is a less orderly flow regime that is characterized by eddies or small packets of fluid particles which result in lateral mixing.
Unless otherwise noted, all component or composition levels are in reference to the active portion of that component or composition and are exclusive of impurities, for example, residual solvents or by-products, which may be present in commercially available sources of such components or compositions.
All percentages and ratios are calculated by total composition weight, unless indicated otherwise.
It should be understood that every maximum numerical limitation given throughout this disclosure is deemed to include each and every lower numerical limitation as an alternative, as if such lower numerical limitations were expressly written herein. Every minimum numerical limitation given throughout this disclosure is deemed to include each and every higher numerical limitation as an alternative, as if such higher numerical limitations were expressly written herein. Every numerical range given throughout this disclosure is deemed to include each and every narrower numerical range that falls within such broader numerical range, as if such narrower numerical ranges were all expressly written herein. By way of example, the phrase from about 2 to about 4 includes the whole number and/or integer ranges from about 2 to about 3, from about 3 to about 4 and each possible range based on real (e.g., irrational and/or rational) numbers, such as from about 2.1 to about 4.9, from about 2.1 to about 3.4, and so on.
The preceding is a simplified summary of the disclosure to provide an understanding of some aspects of the disclosure. This summary is neither an extensive nor exhaustive overview of the disclosure and its various aspects, embodiments, and configurations. It is intended neither to identify key or critical elements of the disclosure nor to delineate the scope of the disclosure but to present selected concepts of the disclosure in a simplified form as an introduction to the more detailed description presented below. As will be appreciated, other aspects, embodiments, and configurations of the disclosure are possible utilizing, alone or in combination, one or more of the features set forth above or described in detail below.
The accompanying drawings are incorporated into and form a part of the specification to illustrate several examples of the present disclosure. These drawings, together with the description, explain the principles of the disclosure. The drawings simply illustrate preferred and alternative examples of how the disclosure can be made and used and are not to be construed as limiting the disclosure to only the illustrated and described examples. Further features and advantages will become apparent from the following, more detailed, description of the various aspects, embodiments, and configurations of the disclosure, as illustrated by the drawings referenced below.
It should be understood that the diagrams are provided for example purposes only, and should not be read as limiting the scope of the disclosure. Many other configurations, including multiple sorbent injection points and/or use of multiple static mixers, are fully contemplated and included in the scope of the disclosure.
The current disclosure is directed to an additive introduction system to introduce one or more liquid and/or solid additives to control contaminant emissions from contaminant evolving facilities, such as smelters, autoclaves, roasters, steel foundries, steel mills, cement kilns, power plants, waste incinerators, boilers, and other contaminated gas stream producing industrial facilities. Although any contaminant may be targeted by the additive introduction system, typical contaminants include one or more of acid gases (e.g., sulfur-containing compounds (such as sulfur dioxide and trioxide produced by thermal oxidation of sulfides), nitrogen oxides (such as nitrogen monoxide and dioxide), hydrogen sulfide (H2S), hydrochloric acid (HCl), and hydrofluoric acid (HF)), mercury (elemental and/or oxidized forms), carbon oxides (such as carbon monoxide and dioxide), halogens and halides, particulates (e.g., fly ash particles and other types of unburned carbon), and the like. Although the contaminant is typically evolved by combustion, it may be evolved by other oxidizing reactions, reducing reactions, and other thermal processes such as roasting, pyrolysis, and autoclaving, that expose contaminated materials to elevated temperatures.
The feed material 1408 is heated in thermal unit 1400 to produce a contaminated gas stream 1412. The thermal unit 104 can be any heating device, including, without limitation, a dry or wet bottom furnace (e.g., a blast furnace, puddling furnace, reverberatory furnace, Bessemer converter, open hearth furnace, basic oxygen furnace, cyclone furnace, stoker boiler, cupola furnace, a fluidized bed furnace, arch furnace, and other types of furnaces), boiler, incinerator (e.g., moving grate, fixed grate, rotary-kiln, or fluidized or fixed bed, incinerators), calciners including multi-hearth, suspension or fluidized bed roasters, intermittent or continuous kiln (e.g., ceramic kiln, intermittent or continuous wood-drying kiln, anagama kiln, bottle kiln, rotary kiln, catenary arch kiln, Feller kiln, noborigama kiln, or top hat kiln), or oven.
The contaminated gas stream 1412 generally includes a number of contaminants. A common contaminated gas stream 108 includes mercury, particulates (such as fly ash), sulfur oxides, nitrogen oxides, hydrochloric acid (HCl), other acid gases, carbon oxides, and unburned carbon.
The contaminated gas stream 1412 is optionally passed through the (pre)heater 200 to transfer some of the thermal energy of the contaminated gas stream 1412 to air 1416 prior to input to the thermal unit 1400. The heat transfer produces a common temperature drop in the contaminated gas stream 1420 of from about 500° C. to about 300° C. to produce a cooled contaminated gas stream 1420 temperature commonly ranging from about 100 to about 400° C.
The cooled contaminated gas stream 1420 next passes into the additive injection system 1424, which injects an additive, such as a sorbent, into the cooled contaminated gas stream 1420, to form an additive-containing gas stream 1428. The additive injection system 1424 can be any suitable liquid or solid additive injection system including that described in copending U.S. application Ser. No. 13/045,076, filed Mar. 10, 2011, and Ser. No. 13/645,138, filed Oct. 4, 2012, each of which are incorporated fully herein by this reference. Other examples include spray dry and dry injection systems optionally using one or more lances, compressors or pumps, educators, etc. Commonly, the additive is injected through an array of lances positioned upstream of a particulate control device, typically an electrostatic precipitator or fabric filter.
The additive controls emissions of the selected or targeted contaminant in a treated gas stream 1432. Typically, the additive 1436 is entrained in a carrier fluid, such as a carrier liquid or gas, when introduced by additive introduction system 1424. To entrain the additive particles effectively, the additive particles typically have a mean, median, and P90 size of no more than about 100 microns and even more typically ranging from about 2 to about 50 microns. The additive-containing fluid (which is mixture of the entrained additive particles and carrier gas) typically includes from about 0.10 to about 6.0 lbm material to lbm air (at standard temperature and pressure).
The additive 1436 employed depends on the contaminant targeted and can be in any form before and after injection, whether a liquid, a solid, or semi-solid. By way of example, an acid gas controlling sorbent can include an alkaline material, such as (hydrated) lime or an alkaline earth or alkali metal bicarbonate, to control emissions of nitrogen oxides (NOX), sulfur oxides (SOX), hydrochloric acid (HCl), and/or hydrofluoric acid (HF) and an alkaline or alkali metal (e.g., sodium) sesquicarbonate (e.g., trona) to control emissions of sulfur oxides (SOX), hydrogen sulfide (H2S), hydrochloric acid (HCl), and/or hydrofluoric acid (HF). Other acid gas controlling sorbents include metal oxides, such as magnesium oxide or magnesium hydroxide, alkaline earth and alkali metal carbonates, such as sodium carbonate (“soda ash”), and alkaline earth and alkali metal bicarbonates. The byproduct of the reaction between the acid gas controlling sorbent and acid gas is typically a particulate that is removed by a particulate control device. A mercury capture sorbent 400 can include halogens and/or halides. As will be appreciated, halogens and halides can oxidize elemental mercury and the resulting oxidized mercury can be collected on a particulate and/or powdered activated carbon (“PAC”) for subsequent removal by a particulate control device. Another mercury capture sorbent 400 is PAC, which can control not only mercury but also a variety of other contaminants, such as gaseous heavy metals dioxins, furans, and hydrocarbons, and which itself is removed as a particulate by a particulate control device. Often, the additive includes both acid gas controlling and mercury capture sorbents. The presence of acid gases can interfere with mercury sorption on carbon-based mercury sorbents. As will be appreciated, other additives may be used depending on the contaminant(s) targeted.
In other examples, the additive 1436 can be one or more flue gas conditioning agent(s), such as compounds comprising one or more nitrates and nitrites. Exemplary flue gas conditioning agents include those in U.S. Pat. Nos. 6,001,152; 5,833,736; 5,893,943; 5,855,649; 6,267,802; and 6,797,035, each of which is incorporated herein by reference in their entireties.
Although the carrier fluid for the additive can be any substantially (chemically) inert fluid (relative to the additive), a common carrier gas is water or air. Typically, the carrier fluid includes a minor amount, more typically no more than about 400 ppmv, and even more typically no more than about 390 ppmv of an additive reactive component, such as carbon dioxide, that reacts with the additive. For example, carbon dioxide reacts with lime to produce calcium carbonate.
The distribution of sorbent is typically non-ideal (non-uniform) in the additive-containing gas stream. An increase in lance coverage of the additive injection system or additional additive injection often fails to provide a more uniform distribution due to mass transfer limitations. For such situations, a fixed (static) gas mixing device installed upstream or downstream of additive injection can improve particle distribution without requiring long duct runs and higher plant capital costs. In particular, the mixing device is typically located immediately upstream of the additive injection for a liquid additive as the liquid additive can deposit on the mixing device, thereby adversely hindering its performance over time in the absence of cleaning. For a solid additive, the mixing device can be located not only immediately upstream but also downstream of the additive injection system.
In the latter plant configuration, the additive-containing gas stream 1428 passes a static mixing device 300, which causes additive mixing in the gas stream, thereby providing a mixed gas stream 1440 having, compared to the additive-containing gas stream 1428, an increased uniformity through the gas stream not only of additive distribution but also of temperature and/or velocity profile. This can be true for either single-phase or multiphase gas streams. As will be appreciated, a single-phase gas flow contains multiple gases while a multiphase flow contains at least one gas and at least one particulate solid, typically a sorbent additive. While
There are a variety of static mixing devices 300 designed to achieve better gas mixing, temperature de-stratification, and more uniform velocity profile with minimal pressure drop. The static mixing device 300, for example, can be an arrangement of stationary, fixed, and/or static fan-type blades (or mixing elements) that induce turbulence and encourage mixing in the gas stream. The static mixing device 300 can be a plurality of stationary, fixed, and/or static baffles or plates (or mixing elements) on the interior wall of a duct that extend into the duct. The baffles may be straight or curved and may be offset in the flow direction or in plane. Of course, the static mixing device also may be a combination of these embodiments or any other design that would encourage mixing in the gas stream.
An example of a static mixing device 300 is the Series IV Air Blender™ or Blender Box™ manufactured by Blender Products, Inc. This static mixing device 300 is described in U.S. Pat. No. 6,595,848, which is incorporated herein by this reference. As described in U.S. Pat. No. 6,595,848, the static mixing device has multiple radially extending vanes (or mixing elements) diverging away from a center of an enclosure and terminating at outer distal ends of the vanes positioned adjacent to the enclosure. The vanes can have an inner section traversing a first distance from the center and an outer section connected to the inner section along a leading radial edge of the vane. The outer section traverses a remaining distance from the inner section to the enclosure. The inner section curves rearwardly in a first direction away from the leading radial edge, and the outer section curves rearwardly in a second direction away from the leading radial edge.
The static mixing device 300 typically is a housed-elements design in which the static mixing device elements include a series of stationary, fixed, rigid, and/or static mixing elements made of metal, ceramic, and/or a variety of materials stable at the temperature of the contaminated gas stream. Similarly, the mixing device housing, which is commonly the duct for transporting the contaminated waste gas, can be made of the same materials. Two streams of fluids, namely the contaminated gas stream and the injected sorbent stream are introduced into the static mixing device 300. As the streams move through the mixing device, the non-moving or stationary mixing elements continuously blend the components of the streams to form a mixed gas stream having a substantially homogeneous composition. Complete mixing commonly depends on many variables including the fluids' properties, tube inner diameter, number of elements and their design.
The mixing elements, particularly when helically-shaped, can simultaneously produce patterns of flow division and radial mixing. With reference to
With reference to
In most applications, the additive-containing gas stream 1428, at the input to the mixing device, has laminar flow, and the number of mixing elements in the static mixing device 300 is typically at least one, more typically at least two, and even more typically ranges from about three to about fifty. Both flow division and radial mixing normally occur in power plant flue gas treatment applications. In such applications, the flue gas velocity typically ranges from about 5 to about 50 m/s and more typically from about 12 to about 20 m/s for a power plant. In other applications, the additive-containing gas stream 1428, at the input to the mixing device, has turbulent flow, and only radial mixing (and substantially no flow division) occurs.
The static mixing device 300 is typically positioned a distance upstream (or downstream) of the particulate removal device to allow adequate mixing and contaminant-additive particle interaction and a distance (upstream or) downstream of the point(s) of additive injection by the additive injection system 1424 to allow time for adequate dispersion of the additive particles in the gas stream. In the mixed gas stream, the distance from an output of the static mixing device to an input of a downstream particulate control device can be at least about one times the hydraulic diameter of the pipe or duct. While determined by the configuration of the power plant, the maximum distance from the output of the static mixing device to the input of the particulate control device is commonly no more than about ten times the hydraulic diameter. The distance from an upstream point of introduction of the additive into the contaminated gas stream to an input to the static mixing device (or from an output of the static mixing device to a downstream point of introduction of the additive into the contaminated gas stream) is typically no more than about one times the hydraulic diameter, more typically no more than about 0.75 times the hydraulic diameter, and more typically no more than about 0.50 times the hydraulic diameter. While determined by the configuration of the power plant, the minimum distance from the point of introduction of the additive into the contaminated gas stream to the downstream input (or upstream output) to the static mixing device is commonly at least about 0.1 times the hydraulic diameter.
Referring again to
The treated gas stream 1432 is emitted, via gas discharge 1450 (e.g., stack), into the environment.
A number of exemplary configurations of the above process will now be discussed with reference to
In some embodiments, the static mixing device 300 will be utilized in combination with Dry Sorbent Injection (“DSI”)/Activated Carbon Injection (“ACI”) dual injection. In this configuration, the static mixing device 300 is placed in the mercury and acid gas-containing gas stream 110 between the location of injection by the additive injection system (not shown) of a first injected sorbent 410 and the location of injection by the additive injection system (not shown) of a second injected sorbent 400. In this configuration, the first injected sorbent 410 is an alkaline sorbent, and the second injected sorbent 400 is activated carbon. As noted above, the sorbent 410 can be any other acid-controlling sorbent or mixture of acid gas-controlling sorbents. This embodiment will allow for maximal utilization of alkaline material and reduction of acid gases such as SO3 prior to activated carbon injection for mercury control. Ultimately, this can reduce sorbent usage for a given sorbent injection rate, thereby reducing operating costs and/or achieving maximal combined removal of acid gases and mercury. As shown by the dashed line 504, the mercury capture sorbent can also or alternatively be injected at a location downstream of the static mixing device 300.
With reference to
Other configurations are possible involving downstream sorbent injection and reduced sized mixing devices, such as mixing device 1500, substituted for the mixing devices of
Not shown, but contemplated by the disclosure, are additional configurations utilizing hot-side injection of one or more sorbents and a hot-side ESP (or other particulate removal device), with the static mixing device 300 placed in between and upstream or downstream of the additive injection location. The static mixing device 300, whether reduced or full sized relative to the duct, may be helpful with hot-side injection applications, that is, applications where a sorbent is injected upstream of the air (pre)heater 200. While such configurations generally benefit from increased residence time and the associated improvement in sorbent distribution, the static mixing device 300 can contribute an even more complete sorbent distribution.
With any hot-side sorbent injection application, the static mixing device 300 could be placed either upstream or downstream of the air (pre)heater. Typically, the plant configuration will dictate the appropriate location. Variables include length of flow path available, requirements for distribution of the sorbent or velocity and temperature profiles, and location of the particulate control device (including hot-side or cold-side ESP).
Further contemplated is the use of a static mixing device 300 with other wet or dry sorbents (e.g., wet flue gas desulfurization additives), that were not specifically named in this disclosure, including sorbents applied to the fuel and sorbents injected into the furnace in any of a gas, liquid, or solid phase. Although the disclosure specifically targets dry sorbent (including activated carbon and DSI) injection, it is contemplated that use of a static mixing device 300 would further improve uniformity of distribution for these sorbents, as a well as offering uniformity benefits to velocity and temperature profiles of the resulting contaminated gas stream.
Referring to
Referring to
Referring to
A number of other exemplary configurations of the rotatable static mixing device system will now be discussed with reference to
The number of mixing devices in an N×M array depends on the application. Each of N and M typically ranges from 1 to 25, more typically from 2 to 20, more typically from 2 to 15, and more typically from 2 to 10. In an example of a 20′×20′ duct, 4′ square mixing devices can be placed in a 5×5 array to cover substantially the cross section of the duct (see
While the various mixing systems of
The system may be controlled with a computer operated monitoring and feedback control system. A properly configured control system could measure peak load demands and open/close the mixing device array at times lower pressure drop is needed (i.e., peak load in summer time when users are running the air conditioning units). The actuator operating this configuration also may be controlled by a properly configured control system with appropriately placed sensors.
The load profile meter 2404 determines when electricity (and corresponding output at the power plant) is in high demand or peak conditions. This can be done using a load profile that plots variation in the electrical load versus time.
The other sensor(s) 2408 can be one or more sensors to determine one or more of: the pressure drop of the mixing system, sorbent consumption levels, and/or sensed contaminant concentration in the gas stream prior to, during, or after treatment. For example, in a system utilizing activated carbon for mercury control, the static mixing devices or mixing elements can be “closed” to create a higher pressure drop (and more mixing) if sorbent consumption needs to be reduced. The same action could be taken if mercury emissions were running above target for a given quantity of sorbent consumption (closing the mixing elements, increasing pressure drop, and increasing mixing), which would lower mercury emissions for the same quantity of sorbent.
The sensor to determine degree of rotation of the mixing device/mixing element relative to gas flow direction can be any suitable sensor for determining angular displacement relative to a selected reference point. Any position sensor can be used that permits angular position measurement. It can either be an absolute position sensor or a relative one (displacement sensor). An example is a rotary encoder, also called a shaft encoder, which is an electromechanical device that converts the angular position or motion of a shaft or axle to an analog or digital code.
The mapping data structures 2416 are maintained in a computer readable medium and can take many forms. In one form, the mapping data structures are a two- or more dimensional lookup table that maps one or more sensed parameters, such as current power load, pressure drop, sorbent consumption, and/or sensed contaminant concentration, against angular rotation or displacement of the mixing device and/or mixing elements relative to the direction of gas flow. A second mapping table can map the angular rotation or displacement to a command to the mixing device and/or element rotation system 2420 to cause the desired level of angular displacement. As will be appreciated, the lookup table is an array that replaces runtime computation with a simpler array indexing operation. The indexing operation can be one or more of a simple lookup in an array, an associative array, or a linked list, a binary search in an array or an associative array, a trival hash function, and the like. The savings in terms of processing time can be significant, since retrieving a value from memory is often faster than undergoing an expensive computation or input/output operation. Other forms of mapping data structures can be employed depending on the application. Alternatively, the mapping data structures 2416 can be computationally determined in substantial real time, as in runtime computation.
The mixing device and/or element rotation system can be any actuator system that effects angular displacement by one or more of mechanical, electromechanical, electromagnetic, magnetic, or hydraulically actuation.
The control system 2424 handles user input and output, supervises the operation of the other system components, applies rules or policies, and issues commands to each of the components to effect desired operations. For example, the control system 2424, in response to determining, from the load profile meter, that the power plant and electrical output are in high demand or peak conditions high demand peak load condition or state, can reduce the pressure drop.
The various components are in communication with one another via a network 2428, which can be a wired or wireless local area or wide area network depending on the application.
In step 1700, the control system 2424 detects a stimulus to change an orientation of a mixing device and/or mixing element. As noted, the stimulus can be one or more of current power load, pressure drop, sorbent consumption, and/or sensed contaminant concentration, against angular rotation or displacement of the mixing device and/or mixing elements relative to the direction of gas flow.
In optional step 1704, the control system 2424 determines a current power load if not detected as a stimulus.
In step 1708, the control system 2424, using the mapping data structures 2416, determines a desired maximum flow resistance and/or pressure drop across the mixing device and/or elements.
In step 1712, the control system 2424 determines, from the mapping data structures 2416, a degree of rotation of the mixing device and/or elements relative to a direction of gas flow to produce the desired maximum flow resistance and/or pressure drop. As noted, the pressure drop is not simply bimodal, namely a maximum and minimum value. In some applications, the mixing device and/or elements can be finely tuned to any one of various angular displacements to produce a desired pressure drop while maintaining a desired degree of turbulent flow and mixing. For example, the angular orientation of the mixing device or elements is not simply one of 0 or 90 degrees relative to a direction of gas flow but can be any angle between those endpoints.
In step 1716, the control system 2424 generates and transmits, via network 2828, a command to the rotation system 2420 to rotate the mixing device and/or elements to the desired degree of rotation or angular displacement relative to the direction of gas flow.
In optional step 1720, the control system 2424 measures the flow resistance or pressure drop by a sensor to confirm that the degree of rotation and/or desired flow resistance result is correct.
The microprocessor in the control system then returns to step 1700.
A number of variations and modifications of the disclosure can be used. It would be possible to provide for some features of the disclosure without providing others.
For example, while ESP and baghouse particulate control devices are discussed with reference to particulate removal, one or more other or alternative particulate and/or contaminant removal devices can be employed as particulate control devices, such as wet and/or dry scrubbers.
The present disclosure, in various aspects, embodiments, and configurations, includes components, methods, processes, systems and/or apparatus substantially as depicted and described herein, including various aspects, embodiments, configurations, subcombinations, and subsets thereof. Those of skill in the art will understand how to make and use the various aspects, aspects, embodiments, and configurations, after understanding the present disclosure. The present disclosure, in various aspects, embodiments, and configurations, includes providing devices and processes in the absence of items not depicted and/or described herein or in various aspects, embodiments, and configurations hereof, including in the absence of such items as may have been used in previous devices or processes, e.g., for improving performance, achieving ease and\or reducing cost of implementation.
The foregoing discussion of the disclosure has been presented for purposes of illustration and description. The foregoing is not intended to limit the disclosure to the form or forms disclosed herein. In the foregoing Detailed Description for example, various features of the disclosure are grouped together in one or more, aspects, embodiments, and configurations for the purpose of streamlining the disclosure. The features of the aspects, embodiments, and configurations of the disclosure may be combined in alternate aspects, embodiments, and configurations other than those discussed above. This method of disclosure is not to be interpreted as reflecting an intention that the claimed disclosure requires more features than are expressly recited in each claim. Rather, as the following claims reflect, inventive aspects lie in less than all features of a single foregoing disclosed aspects, embodiments, and configurations. Thus, the following claims are hereby incorporated into this Detailed Description, with each claim standing on its own as a separate preferred embodiment of the disclosure.
Moreover, though the description of the disclosure has included description of one or more aspects, embodiments, or configurations and certain variations and modifications, other variations, combinations, and modifications are within the scope of the disclosure, e.g., as may be within the skill and knowledge of those in the art, after understanding the present disclosure. It is intended to obtain rights which include alternative aspects, embodiments, and configurations to the extent permitted, including alternate, interchangeable and/or equivalent structures, functions, ranges or steps to those claimed, whether or not such alternate, interchangeable and/or equivalent structures, functions, ranges or steps are disclosed herein, and without intending to publicly dedicate any patentable subject matter.
The present application is a divisional of U.S. patent application Ser. No. 14/951,211, filed Nov. 24, 2015, which claims the benefit of U.S. Provisional Application Ser. No. 62/084,413, filed Nov. 25, 2014, which is incorporated herein by this reference in its entirety. Cross reference is made to U.S. patent application Ser. No. 13/951,167, filed Jul. 25, 2013, entitled “PROCESS TO ENHANCE MIXING OF DRY SORBENTS AND FLUE GAS FOR AIR POLLUTION CONTROL” (now U.S. Pat. No. 8,974,756), which is incorporated herein by this reference in its entirety.
| Number | Name | Date | Kind |
|---|---|---|---|
| 174348 | Brown | Mar 1876 | A |
| 202092 | Breed | Apr 1878 | A |
| 208011 | Eaton | Sep 1878 | A |
| 224649 | Child | Feb 1880 | A |
| 229159 | McCarty | Jun 1880 | A |
| 298727 | Case | May 1884 | A |
| 346765 | McIntyre | Aug 1886 | A |
| 347078 | White | Aug 1886 | A |
| 367014 | Wandrey et al. | Jul 1887 | A |
| 537998 | Spring et al. | Apr 1895 | A |
| 541025 | Gray | Jun 1895 | A |
| 625754 | Garland | May 1899 | A |
| 647622 | Vallet-Rogez | Apr 1900 | A |
| 685719 | Harris | Oct 1901 | A |
| 688782 | Hillery | Dec 1901 | A |
| 700888 | Battistini | May 1902 | A |
| 744908 | Dallas | Nov 1903 | A |
| 846338 | McNamara | Mar 1907 | A |
| 894110 | Bloss | Jul 1908 | A |
| 896876 | Williams | Aug 1908 | A |
| 911960 | Ellis | Feb 1909 | A |
| 945331 | Koppers | Jan 1910 | A |
| 945846 | Hughes | Jan 1910 | A |
| 1112547 | Morin | Oct 1914 | A |
| 1167471 | Barba | Jan 1916 | A |
| 1167472 | Barba | Jan 1916 | A |
| 1183445 | Foxwell | May 1916 | A |
| 1788466 | Lourens | Jan 1931 | A |
| 1955574 | Benner et al. | Apr 1934 | A |
| 1984164 | Stock | Dec 1934 | A |
| 2016821 | Nelms | Oct 1935 | A |
| 2059388 | Nelms | Nov 1936 | A |
| 2089599 | Crecelius | Aug 1937 | A |
| 2511288 | Morrell et al. | Jun 1950 | A |
| 2844112 | Muller | Jul 1958 | A |
| 3004836 | Thompson | Oct 1961 | A |
| 3194629 | Dreibelbis et al. | Jul 1965 | A |
| 3288576 | Pierron et al. | Nov 1966 | A |
| 3332755 | Kukin | Jul 1967 | A |
| 3437476 | Dotson et al. | Apr 1969 | A |
| 3557020 | Shindo et al. | Jan 1971 | A |
| 3599610 | Spector | Aug 1971 | A |
| 3628727 | Gjerde | Dec 1971 | A |
| 3662523 | Revoir et al. | May 1972 | A |
| 3725530 | Kawase et al. | Apr 1973 | A |
| 3764496 | Hultman et al. | Oct 1973 | A |
| 3803803 | Raduly et al. | Apr 1974 | A |
| 3823676 | Cook et al. | Jul 1974 | A |
| 3838190 | Birke et al. | Sep 1974 | A |
| 3849267 | Hilgen et al. | Nov 1974 | A |
| 3849537 | Allgulin | Nov 1974 | A |
| 3896746 | Pirsh | Jul 1975 | A |
| 3907674 | Roberts et al. | Sep 1975 | A |
| 3932494 | Yoshida et al. | Jan 1976 | A |
| 3947354 | Swanson et al. | Mar 1976 | A |
| 3956458 | Anderson | May 1976 | A |
| 3961020 | Seki | Jun 1976 | A |
| 3970434 | Gasior et al. | Jul 1976 | A |
| 3974254 | de la Cuadra Herrera et al. | Aug 1976 | A |
| 4040802 | Deitz et al. | Aug 1977 | A |
| 4042664 | Cardwell et al. | Aug 1977 | A |
| 4051316 | Wing et al. | Sep 1977 | A |
| 4057398 | Bennett | Nov 1977 | A |
| 4075282 | Storp et al. | Feb 1978 | A |
| 4083783 | Wing et al. | Apr 1978 | A |
| 4089507 | Arai et al. | May 1978 | A |
| 4094777 | Sugier et al. | Jun 1978 | A |
| 4101631 | Ambrosini et al. | Jul 1978 | A |
| 4115518 | Delmon et al. | Sep 1978 | A |
| 4133759 | Ikeda et al. | Jan 1979 | A |
| 4148613 | Myers | Apr 1979 | A |
| 4173454 | Heins | Nov 1979 | A |
| 4174373 | Yoshida et al. | Nov 1979 | A |
| 4196173 | DeJong et al. | Apr 1980 | A |
| 4226601 | Smith | Oct 1980 | A |
| 4230460 | Maust, Jr. | Oct 1980 | A |
| 4233274 | Allgulin | Nov 1980 | A |
| 4238329 | Zievers | Dec 1980 | A |
| 4272250 | Burk, Jr. et al. | Jun 1981 | A |
| 4276431 | Schnegg et al. | Jun 1981 | A |
| 4280817 | Chauhan et al. | Jul 1981 | A |
| 4305726 | Brown, Jr. | Dec 1981 | A |
| 4308241 | deVries | Dec 1981 | A |
| 4308242 | Horton | Dec 1981 | A |
| 4322218 | Nozaki | Mar 1982 | A |
| 4364818 | Schmid et al. | Dec 1982 | A |
| 4372227 | Mahoney et al. | Feb 1983 | A |
| 4377118 | Sadowski | Mar 1983 | A |
| 4377599 | Willard, Sr. | Mar 1983 | A |
| 4385891 | Ligotti | May 1983 | A |
| 4387653 | Voss | Jun 1983 | A |
| 4394354 | Joyce | Jul 1983 | A |
| 4420892 | Braun et al. | Dec 1983 | A |
| 4427630 | Aibe et al. | Jan 1984 | A |
| 4438709 | Borio et al. | Mar 1984 | A |
| 4440100 | Michelfelder et al. | Apr 1984 | A |
| 4472278 | Suzuki | Sep 1984 | A |
| 4474896 | Chao | Oct 1984 | A |
| 4498402 | Kober et al. | Feb 1985 | A |
| 4500327 | Nishino et al. | Feb 1985 | A |
| 4514256 | Kober et al. | Apr 1985 | A |
| 4519807 | Nishino et al. | May 1985 | A |
| 4519995 | Schrofelbauer et al. | May 1985 | A |
| 4527746 | Molls et al. | Jul 1985 | A |
| 4552076 | McCartney | Nov 1985 | A |
| 4555392 | Steinberg | Nov 1985 | A |
| 4564374 | Hofmann | Jan 1986 | A |
| 4572085 | Hepworth | Feb 1986 | A |
| 4577566 | Merrell | Mar 1986 | A |
| 4578256 | Nishino et al. | Mar 1986 | A |
| 4582936 | Ashina et al. | Apr 1986 | A |
| 4586443 | Burge et al. | May 1986 | A |
| 4598652 | Hepworth | Jul 1986 | A |
| 4602918 | Steinberg et al. | Jul 1986 | A |
| 4629721 | Ueno | Dec 1986 | A |
| 4668429 | Najjar | May 1987 | A |
| 4671804 | Najjar | Jun 1987 | A |
| 4693731 | Tarakad et al. | Sep 1987 | A |
| 4706579 | Merrell | Nov 1987 | A |
| 4708853 | Matviya et al. | Nov 1987 | A |
| 4716137 | Lewis | Dec 1987 | A |
| 4729882 | Ide et al. | Mar 1988 | A |
| 4741278 | Franke et al. | May 1988 | A |
| 4753632 | Hofmann et al. | Jun 1988 | A |
| 4758418 | Yoo et al. | Jul 1988 | A |
| 4764219 | Yan | Aug 1988 | A |
| 4765258 | Zauderer | Aug 1988 | A |
| 4784670 | Najjar | Nov 1988 | A |
| 4786483 | Audeh | Nov 1988 | A |
| 4796548 | Merrell et al. | Jan 1989 | A |
| 4804521 | Rochelle et al. | Feb 1989 | A |
| 4807542 | Dykema | Feb 1989 | A |
| 4824441 | Kindig | Apr 1989 | A |
| 4830829 | Craig, Jr. | May 1989 | A |
| 4831942 | Morimoto et al. | May 1989 | A |
| 4843980 | Markham et al. | Jul 1989 | A |
| 4873930 | Egense et al. | Oct 1989 | A |
| 4886519 | Hayes et al. | Dec 1989 | A |
| 4886521 | Khan | Dec 1989 | A |
| 4889698 | Moller et al. | Dec 1989 | A |
| 4892567 | Yan | Jan 1990 | A |
| 4895603 | Semp et al. | Jan 1990 | A |
| 4915818 | Yan | Apr 1990 | A |
| 4917862 | Kraw et al. | Apr 1990 | A |
| 4919826 | Alzner | Apr 1990 | A |
| 4933158 | Aritsuka et al. | Jun 1990 | A |
| 4936047 | Feldmann et al. | Jun 1990 | A |
| 4940010 | Kubln et al. | Jul 1990 | A |
| 4964889 | Chao | Oct 1990 | A |
| 5001994 | Morimoto et al. | Mar 1991 | A |
| 5013358 | Ball et al. | May 1991 | A |
| 5017135 | Meyer | May 1991 | A |
| 5022329 | Rackley et al. | Jun 1991 | A |
| 5024171 | Krigmont et al. | Jun 1991 | A |
| 5046265 | Kalb | Sep 1991 | A |
| 5049163 | Huang et al. | Sep 1991 | A |
| 5052312 | Rackley et al. | Oct 1991 | A |
| 5114578 | Sundström | May 1992 | A |
| 5116793 | Chao et al. | May 1992 | A |
| 5124135 | Glrrbach et al. | Jun 1992 | A |
| 5126300 | Pinnavaia et al. | Jun 1992 | A |
| 5137854 | Segawa et al. | Aug 1992 | A |
| 5141724 | Audeh et al. | Aug 1992 | A |
| 5162598 | Hutchings et al. | Nov 1992 | A |
| 5179058 | Knoblauch et al. | Jan 1993 | A |
| 5190566 | Sparks et al. | Mar 1993 | A |
| 5196648 | Jones | Mar 1993 | A |
| 5202301 | McNamara | Apr 1993 | A |
| 5207164 | Breen et al. | May 1993 | A |
| 5209062 | Vollenweider | May 1993 | A |
| 5238488 | Wilhelm | Aug 1993 | A |
| 5282430 | Nehls, Jr. | Feb 1994 | A |
| 5288306 | Aibe et al. | Feb 1994 | A |
| 5307743 | Jones | May 1994 | A |
| 5313915 | McDowell et al. | May 1994 | A |
| 5320051 | Nehls, Jr. | Jun 1994 | A |
| 5320817 | Hardwick et al. | Jun 1994 | A |
| 5324336 | Child | Jun 1994 | A |
| 5328673 | Kaczur et al. | Jul 1994 | A |
| 5333558 | Less, Jr. | Aug 1994 | A |
| 5336835 | McNamara | Aug 1994 | A |
| 5342592 | Peter-Hoblyn et al. | Aug 1994 | A |
| 5346674 | Weinwurm et al. | Sep 1994 | A |
| 5350728 | Cameron et al. | Sep 1994 | A |
| 5352647 | Suchenwirth | Oct 1994 | A |
| 5354363 | Brown, Jr. et al. | Oct 1994 | A |
| 5357002 | Lezzi et al. | Oct 1994 | A |
| 5364421 | Westby et al. | Nov 1994 | A |
| 5368617 | Kindig | Nov 1994 | A |
| 5372619 | Greinke et al. | Dec 1994 | A |
| 5379902 | Wen et al. | Jan 1995 | A |
| 5403548 | Aibe et al. | Apr 1995 | A |
| 5409522 | Durham et al. | Apr 1995 | A |
| 5435980 | Felsvang et al. | Jul 1995 | A |
| 5447703 | Baer et al. | Sep 1995 | A |
| 5460643 | Hasenpusch et al. | Oct 1995 | A |
| 5505746 | Chriswell et al. | Apr 1996 | A |
| 5505766 | Chang | Apr 1996 | A |
| 5569436 | Lerner | Oct 1996 | A |
| 5571490 | Bronicki et al. | Nov 1996 | A |
| 5575982 | Reiss et al. | Nov 1996 | A |
| 5577910 | Holland | Nov 1996 | A |
| 5587003 | Bulow et al. | Dec 1996 | A |
| 5607496 | Brooks | Mar 1997 | A |
| 5613851 | Trawöger et al. | Mar 1997 | A |
| 5618508 | Suchenwirth et al. | Apr 1997 | A |
| 5635150 | Coughlin | Jun 1997 | A |
| 5658487 | Carey et al. | Aug 1997 | A |
| 5659100 | Lin | Aug 1997 | A |
| 5670122 | Zamansky et al. | Sep 1997 | A |
| 5672323 | Bhat et al. | Sep 1997 | A |
| 5678959 | Griffard et al. | Oct 1997 | A |
| 5679259 | Bolser | Oct 1997 | A |
| 5695726 | Lerner | Dec 1997 | A |
| 5733360 | Feldman et al. | Mar 1998 | A |
| 5733516 | DeBerry | Mar 1998 | A |
| 5738834 | DeBerry | Apr 1998 | A |
| 5741397 | Ver | Apr 1998 | A |
| 5785932 | Helfritch | Jul 1998 | A |
| 5787823 | Knowles | Aug 1998 | A |
| 5795159 | Ralls et al. | Aug 1998 | A |
| 5797742 | Fraker | Aug 1998 | A |
| 5809911 | Feizollahi | Sep 1998 | A |
| 5810910 | Ludwig et al. | Sep 1998 | A |
| 5819672 | Radway et al. | Oct 1998 | A |
| 5827352 | Altman et al. | Oct 1998 | A |
| 5833736 | Durham et al. | Nov 1998 | A |
| 5855649 | Durham et al. | Jan 1999 | A |
| 5871703 | Alix et al. | Feb 1999 | A |
| 5885076 | Ralls et al. | Mar 1999 | A |
| 5888256 | Morrison | Mar 1999 | A |
| 5893943 | Durham et al. | Apr 1999 | A |
| 5894806 | Smyrniotis et al. | Apr 1999 | A |
| 5897688 | Voogt et al. | Apr 1999 | A |
| 5899678 | Thomson et al. | May 1999 | A |
| 5900042 | Mendelsohn et al. | May 1999 | A |
| 5910292 | Alvarez, Jr. et al. | Jun 1999 | A |
| 5972066 | Lehtinen | Oct 1999 | A |
| 5989506 | Markovs | Nov 1999 | A |
| 6001152 | Sinha | Dec 1999 | A |
| 6022216 | Cattani | Feb 2000 | A |
| 6024931 | Hanulik | Feb 2000 | A |
| 6027551 | Hwang et al. | Feb 2000 | A |
| 6027552 | Ruck et al. | Feb 2000 | A |
| 6083289 | Ono et al. | Jul 2000 | A |
| 6083306 | Cattani | Jul 2000 | A |
| 6117403 | Alix et al. | Sep 2000 | A |
| 6132692 | Alix et al. | Oct 2000 | A |
| 6136281 | Meischen et al. | Oct 2000 | A |
| 6136749 | Gadkaree | Oct 2000 | A |
| 6139751 | Bogaer et al. | Oct 2000 | A |
| 6165366 | Sarangapani | Dec 2000 | A |
| 6200543 | Allebach et al. | Mar 2001 | B1 |
| 6206685 | Zamansky et al. | Mar 2001 | B1 |
| 6221001 | Comer et al. | Apr 2001 | B1 |
| 6240859 | Jones, Jr. | Jun 2001 | B1 |
| 6248217 | Biswas et al. | Jun 2001 | B1 |
| 6250235 | Oehr et al. | Jun 2001 | B1 |
| 6258334 | Gadkaree et al. | Jul 2001 | B1 |
| 6258456 | Meyer | Jul 2001 | B1 |
| 6267802 | Baldrey et al. | Jul 2001 | B1 |
| 6284199 | Downs et al. | Sep 2001 | B1 |
| 6284208 | Thomassen | Sep 2001 | B1 |
| 6328939 | Amrhein | Dec 2001 | B1 |
| 6368511 | Weissenberg et al. | Apr 2002 | B1 |
| 6372187 | Madden et al. | Apr 2002 | B1 |
| 6375909 | Dangtran et al. | Apr 2002 | B1 |
| 6401449 | Hofmann et al. | Jun 2002 | B1 |
| 6447740 | Caldwell et al. | Sep 2002 | B1 |
| 6471506 | Zamansky et al. | Oct 2002 | B1 |
| 6475451 | Leppin et al. | Nov 2002 | B1 |
| 6475461 | Ohsaki et al. | Nov 2002 | B1 |
| 6484651 | Shepard, Jr. et al. | Nov 2002 | B1 |
| 6514907 | Tsutsumi et al. | Feb 2003 | B2 |
| 6521021 | Pennline et al. | Feb 2003 | B1 |
| 6524371 | El-Shoubary et al. | Feb 2003 | B2 |
| 6528030 | Madden et al. | Mar 2003 | B2 |
| 6533842 | Maes et al. | Mar 2003 | B1 |
| 6547874 | Eck et al. | Apr 2003 | B2 |
| 6558454 | Chang et al. | May 2003 | B1 |
| 6582497 | Maes et al. | Jun 2003 | B1 |
| 6589318 | El-Shoubary et al. | Jul 2003 | B2 |
| 6595848 | Robinson | Jul 2003 | B1 |
| 6610263 | Pahiman et al. | Aug 2003 | B2 |
| 6613110 | Sanyal | Sep 2003 | B2 |
| 6638347 | El-Shoubary et al. | Oct 2003 | B2 |
| 6638485 | Lida et al. | Oct 2003 | B1 |
| 6649082 | Hayasaka et al. | Nov 2003 | B2 |
| 6719828 | Lovell et al. | Apr 2004 | B1 |
| 6726888 | Lanier et al. | Apr 2004 | B2 |
| 6729248 | Johnson et al. | May 2004 | B2 |
| 6732055 | Bagepalli et al. | May 2004 | B2 |
| 6737031 | Beal et al. | May 2004 | B2 |
| 6773471 | Johnson et al. | Aug 2004 | B2 |
| 6787742 | Kansa et al. | Sep 2004 | B2 |
| 6790420 | Breen et al. | Sep 2004 | B2 |
| 6790429 | Ciampi | Sep 2004 | B2 |
| 6797035 | Baldrey et al. | Sep 2004 | B2 |
| 6808692 | Oehr | Oct 2004 | B2 |
| 6827837 | Minter | Dec 2004 | B2 |
| 6841513 | El-Shoubary et al. | Jan 2005 | B2 |
| 6848374 | Srinivasachar et al. | Feb 2005 | B2 |
| 6864008 | Otawa et al. | Mar 2005 | B2 |
| 6878358 | Vosteen et al. | Apr 2005 | B2 |
| 6916762 | Shibuya et al. | Jul 2005 | B2 |
| 6939523 | D'Alesandro | Sep 2005 | B2 |
| 6942840 | Broderick | Sep 2005 | B1 |
| 6945925 | Pooler et al. | Sep 2005 | B2 |
| 6953494 | Nelson, Jr. | Oct 2005 | B2 |
| 6960329 | Sellakumar | Nov 2005 | B2 |
| 6962617 | Simpson | Nov 2005 | B2 |
| 6969494 | Herbst | Nov 2005 | B2 |
| 6972120 | Holste et al. | Dec 2005 | B2 |
| 6974562 | Ciampi et al. | Dec 2005 | B2 |
| 6974564 | Biermann | Dec 2005 | B2 |
| 6975975 | Fasca | Dec 2005 | B2 |
| 7118720 | Mendelsohn et al. | Oct 2006 | B1 |
| 7141091 | Chang | Nov 2006 | B2 |
| 7151199 | Martens et al. | Dec 2006 | B2 |
| 7153481 | Bengtsson et al. | Dec 2006 | B2 |
| 7156959 | Herbst | Jan 2007 | B2 |
| 7250387 | Durante et al. | Jul 2007 | B2 |
| 7312300 | Mitchell | Dec 2007 | B2 |
| 7331533 | Bayer et al. | Feb 2008 | B2 |
| 7332002 | Johnson et al. | Feb 2008 | B2 |
| 7361209 | Durham et al. | Apr 2008 | B1 |
| 7381380 | Herbst | Jun 2008 | B2 |
| 7381387 | Lissianski et al. | Jun 2008 | B2 |
| 7384615 | Boardman et al. | Jun 2008 | B2 |
| 7387719 | Carson et al. | Jun 2008 | B2 |
| 7413719 | Digdon | Aug 2008 | B2 |
| 7416137 | Hagen et al. | Aug 2008 | B2 |
| 7435286 | Olson et al. | Oct 2008 | B2 |
| 7452392 | Nick et al. | Nov 2008 | B2 |
| 7473303 | Higgins et al. | Jan 2009 | B1 |
| 7476324 | Ciampi et al. | Jan 2009 | B2 |
| 7479215 | Carson et al. | Jan 2009 | B2 |
| 7479263 | Chang et al. | Jan 2009 | B2 |
| 7494632 | Klunder | Feb 2009 | B1 |
| 7507083 | Comrie | Mar 2009 | B2 |
| 7514052 | Lissianski et al. | Apr 2009 | B2 |
| 7517445 | Carson et al. | Apr 2009 | B2 |
| 7517511 | Schofield | Apr 2009 | B2 |
| 7524473 | Lindau et al. | Apr 2009 | B2 |
| 7531708 | Carson et al. | May 2009 | B2 |
| 7544339 | Lissianski et al. | Jun 2009 | B2 |
| 7779777 | Shiobara et al. | Aug 2010 | B2 |
| 7862646 | Carruthers et al. | Jan 2011 | B2 |
| 8124036 | Baldrey et al. | Feb 2012 | B1 |
| 8221532 | Carruthers et al. | Jul 2012 | B2 |
| 8372362 | Durham et al. | Feb 2013 | B2 |
| 8383071 | Dillon et al. | Feb 2013 | B2 |
| 8439989 | Baldrey et al. | May 2013 | B2 |
| 8784757 | Dillon et al. | Jul 2014 | B2 |
| 8974756 | Martin | Mar 2015 | B2 |
| 9017452 | Hanson et al. | Apr 2015 | B2 |
| 9149759 | Dillon et al. | Oct 2015 | B2 |
| 10350545 | Hanson et al. | Jul 2019 | B2 |
| 20020068030 | Nolan et al. | Jun 2002 | A1 |
| 20020114749 | Cole | Aug 2002 | A1 |
| 20020121482 | Ciampi et al. | Sep 2002 | A1 |
| 20020162322 | Ganzmann et al. | Nov 2002 | A1 |
| 20030065236 | Vosteen et al. | Apr 2003 | A1 |
| 20030079411 | Kansa et al. | May 2003 | A1 |
| 20030164309 | Nakamura et al. | Sep 2003 | A1 |
| 20030166988 | Hazen et al. | Sep 2003 | A1 |
| 20030206843 | Nelson, Jr. | Nov 2003 | A1 |
| 20040013589 | Vosteen et al. | Jan 2004 | A1 |
| 20040016377 | Johnson et al. | Jan 2004 | A1 |
| 20040129607 | Slater et al. | Jul 2004 | A1 |
| 20040208809 | D'Alesandro | Oct 2004 | A1 |
| 20040256247 | Carson et al. | Dec 2004 | A1 |
| 20050020828 | Therkelsen | Jan 2005 | A1 |
| 20050026008 | Heaton et al. | Feb 2005 | A1 |
| 20050039598 | Srinivasachar et al. | Feb 2005 | A1 |
| 20050056548 | Minter | Mar 2005 | A1 |
| 20050090379 | Shibuya et al. | Apr 2005 | A1 |
| 20050132880 | Chang | Jun 2005 | A1 |
| 20060027488 | Gauthier | Feb 2006 | A1 |
| 20060029531 | Breen et al. | Feb 2006 | A1 |
| 20060051270 | Brunette | Mar 2006 | A1 |
| 20060124444 | Nakamura et al. | Jun 2006 | A1 |
| 20060185226 | McDonald et al. | Aug 2006 | A1 |
| 20060204418 | Chao et al. | Sep 2006 | A1 |
| 20060205592 | Chao et al. | Sep 2006 | A1 |
| 20060210463 | Comrie | Sep 2006 | A1 |
| 20060266391 | Wang | Nov 2006 | A1 |
| 20070051239 | Holmes et al. | Mar 2007 | A1 |
| 20070156288 | Wroblewski et al. | Jul 2007 | A1 |
| 20070167309 | Olson | Jul 2007 | A1 |
| 20070179056 | Baek et al. | Aug 2007 | A1 |
| 20070180990 | Downs et al. | Aug 2007 | A1 |
| 20070184394 | Comrie | Aug 2007 | A1 |
| 20080060519 | Maly et al. | Mar 2008 | A1 |
| 20080069749 | Liu et al. | Mar 2008 | A1 |
| 20080107579 | Downs et al. | May 2008 | A1 |
| 20080115704 | Berry et al. | May 2008 | A1 |
| 20080121142 | Comrie | May 2008 | A1 |
| 20080233238 | Roney et al. | Sep 2008 | A1 |
| 20090007785 | Kimura et al. | Jan 2009 | A1 |
| 20090031929 | Boardman et al. | Feb 2009 | A1 |
| 20090047199 | Arrol et al. | Feb 2009 | A1 |
| 20090081092 | Yang et al. | Mar 2009 | A1 |
| 20090104097 | Dunson, Jr. | Apr 2009 | A1 |
| 20090117019 | Comrie | May 2009 | A1 |
| 20090136401 | Yang et al. | May 2009 | A1 |
| 20100068111 | Walsh, Jr. | Mar 2010 | A1 |
| 20100221166 | Muggli | Sep 2010 | A1 |
| 20110206586 | Mooney | Aug 2011 | A1 |
| 20110223088 | Chang | Sep 2011 | A1 |
| 20130160643 | Pilats | Jun 2013 | A1 |
| 20130192542 | Gries | Aug 2013 | A1 |
| 20140202497 | Kreis et al. | Jul 2014 | A1 |
| 20150013603 | Morioka et al. | Jan 2015 | A1 |
| Number | Date | Country |
|---|---|---|
| 2003220713 | Feb 2004 | AU |
| 1140572 | Feb 1983 | CA |
| 2150529 | Dec 1995 | CA |
| 2418578 | Aug 2003 | CA |
| 2435474 | Jan 2004 | CA |
| 1052838 | Jul 1991 | CN |
| 2548845 | May 1976 | DE |
| 2713197 | Oct 1978 | DE |
| 2917273 | Nov 1980 | DE |
| 3615759 | Nov 1987 | DE |
| 3628963 | Mar 1988 | DE |
| 3711503 | Oct 1988 | DE |
| 3918292 | Apr 1990 | DE |
| 4218672 | Aug 1993 | DE |
| 4308388 | Oct 1993 | DE |
| 4422661 | Jan 1996 | DE |
| 19520127 | Dec 1996 | DE |
| 19850054 | May 2000 | DE |
| 10233173 | Jul 2002 | DE |
| 60019603 | Apr 2006 | DE |
| 0115634 | Aug 1984 | EP |
| 0208036 | Jan 1987 | EP |
| 0220075 | Apr 1987 | EP |
| 0254697 | Jan 1988 | EP |
| 0433674 | Nov 1990 | EP |
| 0433677 | Jun 1991 | EP |
| 0435848 | Jul 1991 | EP |
| 0628341 | Dec 1994 | EP |
| 0666098 | Aug 1995 | EP |
| 0709128 | May 1996 | EP |
| 0794240 | Sep 1997 | EP |
| 0908217 | Apr 1999 | EP |
| 1213046 | Oct 2001 | EP |
| 1199354 | Apr 2002 | EP |
| 1271053 | Jan 2003 | EP |
| 1386655 | Feb 2004 | EP |
| 1570894 | Sep 2005 | EP |
| 1671706 | Jul 2006 | EP |
| 0009699 | Apr 1980 | ER |
| 1394547 | Apr 1965 | FR |
| 1394847 | Apr 1965 | FR |
| 1121845 | Jul 1968 | GB |
| 11-94234 | Jun 1905 | JP |
| 49-53590 | May 1974 | JP |
| 49-53591 | May 1974 | JP |
| 49-53592 | May 1974 | JP |
| 49-53593 | May 1974 | JP |
| 49-53594 | May 1974 | JP |
| 49-66592 | Jun 1974 | JP |
| 51-5586 | Jan 1976 | JP |
| 59-10343 | Jan 1984 | JP |
| 59-76537 | May 1984 | JP |
| 59-160534 | Sep 1984 | JP |
| 63-100918 | May 1988 | JP |
| 09-239265 | Sep 1997 | JP |
| 10-109016 | Apr 1998 | JP |
| 2000-197811 | Jul 2000 | JP |
| 2000-205525 | Jul 2000 | JP |
| 2001-347131 | Dec 2001 | JP |
| 2002-355031 | Dec 2002 | JP |
| 2003-065522 | Mar 2003 | JP |
| 2004-066229 | Mar 2004 | JP |
| 2005-230810 | Sep 2005 | JP |
| 2004-0010276 | Jan 2004 | KR |
| WO 8604602 | Aug 1986 | WO |
| WO 9109977 | Jul 1991 | WO |
| WO 9630318 | Oct 1996 | WO |
| WO 9717480 | May 1997 | WO |
| WO 9815357 | Apr 1998 | WO |
| WO 9958228 | Nov 1999 | WO |
| WO 0128787 | Apr 2001 | WO |
| WO 0138787 | May 2001 | WO |
| WO 03093518 | Nov 2003 | WO |
| WO 2005092477 | Oct 2005 | WO |
| 2003-05568 | Jul 2004 | ZA |
| Entry |
|---|
| “ADA-ES Tests New Boiler Product,” Coal Daily, Apr. 18, 2000, 1 page. |
| “Air Blender,” Blender Products, Inc., 2006, retrieved from www.airblender.com/ProdApp.php?pk=24, 2 pages. |
| “Bromine” webpage, http://www2.gtz.de/uvp/publika/English/vol318.htm, printed Sep. 14, 2006, 4 pages. |
| “Burning PRB Coals ADA Environmental Offers Flyash Solutions,” Western Coal Advisory, Summer/Autumn 1999, 1 page. |
| “Chlorine” webpage, http://www2.gtz.de/uvp/publika/English/vol324.htm, printed Sep. 14, 2006, 4 pages. |
| “Cyclone Furnaces,” Chapter 10 of Steam/Its Generation and Use, Babcock & Wilcox, 1972, 38th Edition, pp. 10-11 to 10-8. |
| “DOE Announces Further Field Testing of Advanced Mercury Control Technologies, Six Projects Selected in Round 2 to Address Future Power Plant Mercury Reduction Initiatives,” TECHNews From the National Energy Technology Laboratory, Nov. 5, 2004, available at http://www.netl.doe.gov/publications/TechNews/tn_mercury-control.html, printed on Jun. 3, 2009, pp. 1-2. |
| “DrägerSenor CI2—68 08 865 Data Sheet,” Dräger Product Information, Apr. 1997, pp. 1-6 (with English translation). |
| “Enhanced Mercury Control: KNX™ Coal Additive Technology,” Alstom Power Inc., printed Aug. 3, 2006, 1 page. |
| “Evaluation of Sorbent Injection for Mercury Control at Great River Energy Coal Creek Station,” ADA Environmental Solutions, Nov. 16-20, 2003 Final Report, Electric Power Research Institute, issued Mar. 3, 2004, 32 pages. |
| “File: Static Mixer Flow Division.png,” Wikipedia, Mar. 24, 2009, Attribution: Ambanmba at en.wikipedia, available at www.en.wikipedia.org/wiki/File:Static_Mixer_Flow_Division.png, 3 pages. |
| “Fuel Ash Effects on Boiler Design and Operation,” Chapter 21 of Steam/Its Generation and Use, Babcock & Wilcox Company, 2005, 41st Edition, pp. 21-1 to 21-27. |
| “Fuel-ash Effects on Boiler Design and Operation,” Chapter 15 of Steam/Its Generation and Use, Babcock and Wilcox Company, 1972, 38th Edition, pp. 15-1 to 15-26. |
| “Gas Phase Filtration,” Vaihtoilma White Air Oy, date unknown, 3 pages. |
| “Handling Hydrated Lime from a Lime Supplier's Perspective,” Workshop 25, 2010 APC Round Table & Expo Presentation, Reinhold Enviromental Ltd., Jul. 18-20, 2010, 33 pages. |
| “Impregnated Activated Carbon,” Products and Technologies Website, as early as 1999, available at http://www.calgoncarbon.com/product/impregnated.html, printed on Dec. 18, 1999, p. 1. |
| “Incineration: Taking the heat out of complex waste,” Bayer Industry Services website, as early as 2005, available at http://web.archive.org/web/20060318115553/www.entsorgung.bayer.com/index.cfm?PAGE_ID=299, pp. 1-2, printed on Jun. 4, 2009. |
| “Iron- and Steelmaking,” date unknown, pp. 646-660. |
| “Protecting Human Health. Mercury Poisoning,” US EPA Website, as early as Oct. 8, 1999, available at http://www.epa.gov/region02/health/mercury/, printed on Feb. 5, 2002, pp. 1-4. |
| “Static Mixer,” Wikipedia, 2013, available at www.en.wikipedia.org/wiki/Static__mixer, 3 pages. |
| “Static Mixer (Engineering Design Guideline),” KLM Technology Group, 2012, available at www.klmtechgroup.com, 24 pages. |
| “Texas Genco, EPRI, and URS Corporation Test Innovative Mercury Control Method at Limestone Station—Technology Aims to Capture More Mercury from Power Plant Exhaust,” News Release, Jan. 11, 2005, available at http://amptest.epri.com/corporate/discover__epri/news/2005/011105_mercury.html, printed on Apr. 24, 2009, pp. 1-2. |
| Aldrich Chemical Catalog, Aldrich Chemical Co., Inc., 1996, pp. 863-866. |
| Anders et al., “Selenium in Coal-Fired Steam Plant Emissions,” Environmental Science & Technology, 1975, vol. 9, No. 9, pp. 856-858. |
| Bansal et al., Active Carbon, Marcel Dekker, Inc., New York, 1989, pp. 1-3, 24-29, 391-394, 457. |
| Benson et al., “Air Toxics Research Needs: Workshop Findings,” Proceedings of the 1993 So2 Control Symposium, U.S. EPA, vol. 2, Session 6A, Aug. 24-27, 1993, pp. 1-17, Boston, MA. |
| Biswas et al., “Control of Toxic Metal Emissions from Combustors Using Sorbents: A Review,” J. Air & Waste Manage. Assoc., Feb. 1998, vol. 48, pp. 113-127. |
| Biswas et al., “Introduction to the Air & Waste Management Association's 29th Annual Critical Review,” Journal of the Air & Waste Management Association, Jun. 1999, pp. 1-2. |
| Bloom, “Mercury Speciation in Flue Gases: Overcoming the Analytical Difficulties,” presented at EPRI Conference, Managing Hazardous Air Pollutants, State ofthe Arts, Washington D.C., Nov. 1991, pp. 148-160. |
| Brown et al., “Mercury Measurement and Its Control: What We Know, Have Learned, and Need to Further investigate,” J. Air & Waste Manage. Assoc, pp. 1-97 (Jun. 1999). |
| Buschmann et al., “The KNX™ Coal Additive Technology A Simple Solution for Mercury Emissions Control,” Alstom Power Environment, Dec. 2005, pp. 1-7. |
| Bustard et al., “Full-Scale Evaluation of Sorbent Injection for Mercury Control on Coal-Fired Power Plants” Air Quality III, ADA Environmental Solutions, LLC (Arlington, VA) (Sep. 12, 2002). |
| Calgon Carbon product and bulletin webpages, 11 pages (undated). |
| Carey et al., “Factors Affecting Mercury Control in Utility Flue Gas Using Activated Carbon,” J. Air & Waste Manage. Assoc., Dec. 1998, vol. 48, pp. 1166-1174. |
| De Vito et al., “Sampling and Analysis of Mercury in Combustion Flue Gas,” Presented at the Second International Conference on Managing Hazardous Air Pollutants, Washington, DC. Jul. 13-15, 1993, pp. VII39-VII-65. |
| Declaration of Richard Schlager; Sep. 18, 2002. |
| Donnet et al., eds., Carbon Black: Science and Technology, 2nd Edition, Marcel Dekker, New York, 1993, pp. 182-187, 218-219. |
| Dunham et al., “Investigation of Sorbent Injection for Mercury Control in Coal-Fired Boilers,” Energy & Environmental Research Center, University of North Dakota (Sep. 10, 1998). |
| Durham et al., “Full-Scale Evaluation of Mercury Control by Injecting Activated Carbon Upstream of ESPS,” Air Quality IV Conference, ADA Environmental Solutions (Littleton, Colorado) (Feb. 10, 2003). |
| Edwards et al., “A Study of Gas-Phase Mercury Speciation Using Detailed Chemical Kinetics,” in Journal of the Air and Waste Management Association, vol. 51, Jun. 2001, pp. 869-877. |
| Fabian et al., “How Bayer incinerates wastes,” Hydrocarbon Processing, Apr. 1979, pp. 183-192. |
| Felsvang et al., “Activated Carbon Injection in Spray Dryer/ESP/FF for Mercury and Toxics Control” (Feb. 10, 1993). |
| Felsvang, K. et al., “Air Toxics Control by Spray Dryer,” Presented at the 1993 SO2 Control Symposium, Boston, MA, Aug. 24-27, 1993, 16 pages. |
| Felsvang, K. et al., “Control of Air Toxics by Dry FGDSystems,” Power-Gen '92 Conference, 5th International Conference & Exhibition for the Power Generating Industries. Orlando, FL, Nov. 17-19, 1992, pp. 189-208. |
| Galbreath et al., “Mercury Transformations in Coal Combustion Flue Gas,” Fuel Processing Technology, 1999, vol. 65-66, pp. 291-292. |
| Gale et al., “Mercury Speciation as a Function of Flue Gas Chlorine Content and Composition in a 1 MW Semi-industrial Scale Coal-Fired Facility,” In Proceedings of the Mega Symposium and Air & Waste Management Association's Specialty Conference, Washington, DC, May 19-22, 2003, Paper 28, 19 pages. |
| Gale, “Mercury Adsorption and Oxidation Kinetics in Coal-Fired Flue Gas,” Proceedings of the 30th International Technical Conference on Coal Utilization & Fuel Systems, 2005, pp. 979-990. |
| Gale, “Mercury Control with Calcium-Based Sorbents and Oxidizing Agents,” Final Report of Southern Research institute, Jul. 2005, 137 pages. |
| Gale, “Mercury Control with Calcium-Based Sorbents and Oxidizing Agents,” Southern Research Institute, Mercury Control Technology R&D Program Review Meeting, Aug. 12-13, 2003, 25 pages, in multiple parts. |
| Geiger et al., “Einfluß des Schwefels auf Die Doxin- und Furanbuilding bei der Klärschlammverbrennung,” VGB Kraftwerkstechnik, 1992, vol. 72, pp. 159-165. |
| Ghorishi et al., “Effects of Fly Ash Transition Metal Content and Flue Gas HCl/SO2 Ratio on Mercury Speciation in Waste Combustion,” in Environmental Engineering Science, Nov. 2005, vol. 22, No. 2, pp. 221-231. |
| Ghorishi et al., “In-Flight Capture of Elemental Mercury by a Chlorine-Impregnated Activated Carbon,” presented at the Air & Waste Management Association's 94h Annual Meeting & Exhibition, Orlando, FL, Jun. 2001, pp. 1-14. |
| Granite et al., “Novel Sorbents for Mercury Removal from Flue Gas,” National Energy Technology Laboratory (Apr. 10, 2000). |
| Griffin, “A New Theory of Dioxin Formation in Municipal Solid Waste Combustion,” Chemosphere, 1986, vol. 15, Nos. 9-12, pp. 1987-1990. |
| Gullet, B.K. et al., “The Effect of Sorbent Injection Technologies on Emissions of Coal-Based, Based, Metallic Air Toxics,” Proceedings of the 1993 S02 Control Symposium, vol. 2, U.S. EPA (Research Triangle Park, NC) Session 6A, Boston, MA, Aug. 24-27, 1993, 26 pages. |
| Gullett, B. et al., “Bench-Scale Sorption and Desorption of Mercury with Activated Carbon,” Presented at the 1993 International Conference on Municipal Waste Combustion, Williamsburg, VA, Mar. 30-Apr. 2, 1993, pp. 903-917. |
| Gullett, B. et al., “Removal of Illinois Coal-Based Volatile Tracy Mercury,” Final Technical Report, Sep. 1, 1996 through Aug. 31, 1997. |
| Guminski, “The Br—Hg (Bromine-Mercury) System,” Journal of Phase Equilibria, Dec. 2000, vol. 21, No. 6, pp. 539-543. |
| Hall et al., “Chemical Reactions of Mercury in Combustion Flue Gases,” Water, Air, and Soil Pollution 56:3-14,1991. |
| Hein, K.R.G. et al., Research Report entitled, “Behavior of Mercury Emission from Coal Sewage Sludge Co-combustion Taking into Account the Gaseous Species,” Förderkennzeichen: PEF 398002, Apr. 2001 (English Abstract). |
| Henning et al., “Impregnated activated carbon for environmental protection,” Gas Separation & Purification, Butterworth-Heinemann Ltd., vol. 7, No. 4 (Feb. 9, 1993). |
| Hirschberg, “Static mixers for flue gas treatment applications,” Sulzer Chemtech, 2011, 11 pages. |
| Ismo et al., “Formation of Aromatic Chlorinated Compounds Catalyzed by Copper and Iron,” Chemosphere vol. 34, No. 12, pp. 2649-2662 (1997). |
| Jozewicz et al., “Bench-Scale Scale Investigation of Mechanisms of Elemental Mercury Capture by Activated Carbon,” Presented at the Second International Conference on Managing Hazardous Air Pollutants, Washington, D.C., Jul. 13-15, 1993, pp. VII-85 through VII-99. |
| Kellie et al., “The Role of Coal Properties on Chemical and Physical Transformation on Mercury in Post Combustion,” presented at Air Quality IV Conference, Arlington, VA, Sep. 2003, pp. 1-14. |
| Kilgroe et al., “Fundamental Science and Engineering of Mercury Control in Coal-Fired Power Plants,” presented at Air Quality IV Conference, Arlington, VA, Sep. 2003. |
| Kobayashi, “Japan EnviroChemicals, Ltd. Overview,” Feb. 3, 2002, 3 pages. |
| Kramlich, “The Homogeneous Forcing of Mercury Oxidation to Provide Low-Cost Capture,” Abstract, University of Washington, Department of Mechanical Engineering, Mar. 25, 2004, available at http://www.netl.doe.gov/publications/proceedings/04/UCR-HBCU/abstracts/Kramlich.pdf, pp. 1-2. |
| Krishnan et al., “Mercury Control by Injection of Activated Carbon and Calcium-Based Based Sorbents,” Solid Waste Management: Thermal Treatment and Waste-to-Energy Technologies, U.S. EPA and AWMA, Washington, DC, Apr. 18-21, 1995, pp. 493-504. |
| Krishnan et al., “Mercury Control in Municipal Waste Combustors and Coal Fired Utilities,” Environmental Progress, ProQuest Science Journals, Spring 1997, vol. 16, No. 1, pp. 47-53. |
| Krishnan et al., “Sorption of Elemental Mercury by Activated Carbons,” Environmental Science and Technology, 1994, vol. 28, No. 8, pp. 1506-1512. |
| Lee et al.,, “Mercury Control Research: Effects of Fly Ash and Flue Gas Parameters on Mercury Speciation,” U.S. Environmental Protection Agency National Risk Management Research Laboratory and ARCADIS, as early as 1998, Geraghy & Miller, Inc., pp. 221-238, Research Triangle Park, NC. |
| Lemieux et al., “Interactions Between Bromine and Chlorine in a Pilot-Scale Hazardous Waste Incinerator,” paper presented at 1996 International Incineration Conference, Savannah, GA, May 6-10, 1996. |
| Linak et al., “Toxic Metal Emissions from Incineration: Mechanisms and Control” Progress in Energy & Combustion Science, 1993, vol. 19, pp. 145-185. |
| Lissianski et al., “Effect of Coal Blending on Mercury Removal,” presented at the Low Rank Fuels Conference, Billings, MT, Jun. 24-26, 2003, pp. 1-9. |
| Livengood et al,, “Enhanced Control of Mercury Emissions Through Modified Speciation,” for Presentation at the Air & Waste Management Association's 90th Meeting & Exhibition, Jun. 8-13, 1997, 14 pages. |
| Livengood et al., “Development of Mercury Control Techniques for Utility Boilers,” for Presentation at the 88th Air & Waste Management Association Annual Meeting & Exhibit, Jun. 18-23, 1995, pp. 1-14. |
| Livengood et al., “Investigation of Modified Speciation for Enhanced Control of Mercury,” Argonne National Laboratory, 1998, available at http://www.netl.doe.gov/publications/proceedings/97/97ps/ps_pdf/PS2B-9.pdf, pp. 1-15. |
| Luijk et al., “The Role of Bromine in the De Novo Synthesis in a Model Fly Ash System,” Chemosphere, 1994, vol. 28, No. 7, pp. 1299-1309. |
| Madsen, “CFD Modeling of Sorbent Injection at AmerenUE's Meramec plant, St. Louis (MO),” Fluent Inc., Morgantown, WV, Feb. 10, 2005, 19 pages. |
| Martel, K., “Brennstoff- und lastspezifische Untersuchungen zum Verhalten von Schwermetallen in Kohlenstaubfeuerungen [Fuel and load specific studies on the behavior of heavy metals in coal firing systems ],” Fortschritt-Berichte VDI, Apr. 2000, pp. 1-240. |
| Mccoy et al., “Full-Scale Mercury Sorbent Injection Testing at DTE Energy's St. Clair Station,” Paper #97, DTE Energy, as early as 2004, pp. 1-9. |
| Mills Jr., “Techline: Meeting Mercury Standards,” as early as Jun. 18, 2001, available at http://www.netl.doe/publications/press/2001/tl_mercuryel2.html, printed on Feb. 5, 2002, pp. 1-3. |
| Niessen, Combustion and Incineration Processes, 2002, Marcel Dekker, 3rd Edition, p. 25. |
| Niksa et al., “Predicting Mercury Speciation in Coal-Derived Flue Gases,” presented at the 2003 Combined Power Plant Air Pollutant Control Mega Symposium, Washington, D.C., May 2003, pp. 1-14. |
| Nucon International, Inc., “Nusorb Mersorb Family of Adsorbents for Mercury Control,” as early as Jan. 2002, 3 pages. |
| Oberacker et al., “Incinerating the Pesticide Ethylene Dibromide (EDB)—A field-Scale Trail Burn Evaluation of Environmental Performance,” Report EPA/600/D-88/198, Oct. 1988, pp. 1-11. |
| Olson et al., “An Improved Model for Flue Gas-Mercury Interactions on Activated Carbons,” presented at Mega Symposium May 21, 2003, Energy & Environmental Research Center publication, Paper # 142, pp. 1-8. |
| Olson et al., “Oxidation Kinetics and the Model for Mercury Capture on Carbon in Flue Gas,” presented at Air Quality V Conference, Sep. 21, 2005, pp. 1-7. |
| Oppenheimer et al., “Thermische Entsorgung von Produktionsabfällen,” Entsorgungs-Praxis, 2000, vol. 6, pp. 29-33. |
| Pavlish et al., “Status Review of Mercury Control Options for Coal-Fired Power Plants,” Fuel Processing Technology, Aug. 2003, vol. 82, pp. 89-165. |
| “RBHG 4 Combats Mercury Pollution,” Know-How, Norit, vol. 6(2), 2003, 3 pages. |
| Revised Declaration of Richard Schlager, Aug. 19, 2003. |
| Richardson et al., “Chemical Addition for Mercury Control in Flue Gas Derived from Western Coals,” presented at the 2003 Combined Power Plant Air Pollutant Control Mega Symposium, Washington D.C., May 2003, Paper # 63, pp. 1-16. |
| Sage et al., “Relationship of Coal-Ash Viscosity to Chemical Composition,” Journal of Engineering for Power, Apr. 1960, pp. 145-155. |
| Samaras et al., “PCDD/F Prevention by Novel Inhibitors: Addition of Inorganic S- and N-Compounds in the Fuel before Combustion,” Environmental Science and Technology, 2000, vol. 34, No. 24, pp. 5092-5096. |
| Senior et al., “Gas-Phase Transformations of Mercury in Coal-Fired Power Plants,” Fuel Processing Technology, vol. 63, 2000, pp. 197-213. |
| Senior, “Behavior of Mercury in Air Pollution Control Devices on Coal-Fired Utility Boilers,” Power Production in the 21st Century: Impacts of Fuel Quality and Operations, Engineering Foundation Conference, Snowbird, UT (Oct. 28-Nov. 2, 2001). |
| Singer, J., ed., “Development of Marine Boilers,” Combustion Fossil Power, Combustion Engineering, Inc., Windsor, CT, 1991, Ch. 3, pp. 10-14-10-14. |
| Sjostrom, “Evaluation of Sorbent Injection for Mercury Control,” ADA-ES, Inc. Topical Report for Basin Electric Power Cooperative's Laramie River Station, Jan. 16, 2006, 49 pages. |
| Sjostrom, “Evaluation of Sorbent Injection for Mercury Control,” ADA-ES, Inc. Topical Report for AmerenUE's Meramec Station Unit 2, Oct. 1, 2003-Sep. 30, 2005, 586 pages, in multiple parts. |
| Sjostrom, “Evaluation of Sorbent Injection for Mercury Control,” Topical Report for Sunflower Electric's Holcomb Station, U.S. DOE Cooperative Agreement No. DE-FC26-03NT41986, Topical Report No. 41986R07, Jun. 2005, 85 pages. |
| Sjostrom et al., “Full-Scale Evaluation of Mercury Control at Great River Energy's Stanton Generating Station Using Injected Sorbents and a Spray Dryer/Baghouse,” Air Quality III Conference, Session A3b (Feb. 10, 2002). |
| Sjostrom et al., “Full-Scale Evaluation of Mercury Control by Injecting Activated Carbon Upstream of a Spray Dryer and Fabric Filter,” Presented at the 2004 combined power plant air pollutant control mega symposium, Washington, D.C., Aug. 2004, 18 pages. |
| SKC, “The Essential Reference for air sampling,” 1997 Comprehensive Catalog & Air Sampling Guide (4 pages). |
| Sliger et al., “Towards the Development of a Chemical Kinetic Model for the Homogeneous Oxidation of Mercury by Chlorine Species,” Fuel Processing Technology, vol. 65-66, 2000, pp. 423-438. |
| Speight, ed., The Chemistry and Technology of Coal, CRC Press, 1994, pp. 152-155. |
| Starns et al., “Full-Scale Evaluation of TOXECON II™ on a Lignite-Fired Boiler” presented at US EPA/DOE/EPRI Combiner Power Plant Air Pollutant Control Symposium: The Mega Symposium, Washington, DC (Aug. 30-Sep. 2, 2004). |
| Steele “Dense-Phase Pneumatic Conveying Systems,” Powder/Bulk solids, Jan. 2007, 5 pages. |
| Sudhoff, “Anticipated Benefits of the TOXECON Retrofit for Mercury and Multi-Pollutant Control Technology,” National Energy Technology Laboratory, Nov. 19, 2003, available at http://www.netl.doe.gov/technologies/coalpower/cctc/pubs/Benefits_TOXECON_111903.pdf, pp. 1-20. |
| Teller et al., “Mercury Removal from Incineration Flue Gas,” Air and Water Technologies Co., for presentation at the 84th Annual Meeting & Exhibition Vancouver, British Columbia, Jun. 16-21, 1991. |
| United States Environmental Protection Agency, “Study of Hazardous Air Pollutant Emissions from Electric Tility Steam Generating Units,” Report to Congress, vol. 1-2, EPA-453/R-98-004a&b, Feb. 1998, pp. 1-165. |
| United States Environmental Protection Agency, EPA-452/R-97-010, “Mercury Study Report to Congress' vol. VIII-—An Evaluation of Mercury Control Technologies and Costs,” Dec. 1997. |
| Urabe et al., “Experimental Studies on Hg Vapour Removal Using Corona Discharge for Refuse Incinerator,” Chemical Abstracts, Oct. 1997, vol. 109, 37 pages (includes translation). |
| Urano, S., “Studies on Bleaching Powder, VII. The Decomposition of Calcium Hypochlorite by Heat in the Presence of Calcium Chloride,” Journal of the Society of Chemical Industry of Japan, vol. 31, 1928, pp. 46-52 (no translation). |
| Verhulst et al., “Thermodynamic behaviour of metal chlorides and sulfates under the conditions of incineration furnaces,” Environmental Science & Technology, 1996, vol. 30, No. 1, pp. 50-56. |
| Vidic et al., “Uptake of Elemental Mercury Vapors by Activated Carbons;,” Journal of the Air & Waste Management Association, 1996, vol. 46, pp. 241-250. |
| Vidic et al., “Vapor-phase elemental mercury adsorption by activated carbon impregnated with chloride and cheltinq agents,” Carbon, 2001, vol. 39, pp. 3-14. |
| Vosteen et al., “Bromine Enhanced Mercury Abatement from Combustion Flue Gases—Recent Industrial Applications and Laboratory Research,” VGB PowerTech, International Journal for Electricity and Heat Generation, 2006, vol. 86, No. 3, pp. 70-75. |
| Vosteen, et al., “Mercury-Related Chemistry in Waste Incineration and Power Generation Flue Gases,” Sep. 2003, Air Quality IV, pp. 1-8. |
| Wanke et al., “The influence of flame retarded plastic foams upon the formation of Br containing dibenzo-p-dioxins and dibenzofurans in a MSWI,” Organohalogen Compounds, 1996, vol. 28, pp. 530-535. |
| “Specialty Impregnated Carbons,” Waterlink/Barnebey Sutcliff, copyright 2000, 5 pages. |
| Weber et al., “The Role of Copper(II) Chloride in the Formation of Organic Chlorine in Fly Ash,” Chemosphere, 2001, vol. 42, pp. 479-582. |
| White et al., “Field Test of Carbon Injection for Mercury Control at Camden County Municipal Waste Combustor,” EPA-600/R-93-181 (NTIS PB94-101540), Sep. 1993, pp. 1-11. |
| Working project report for period Oct. 1, 1999 to Sep. 30, 2001 from Institut fur Verhrenstechnik und Dampfkesselwessen (IVD), Universitat Stuttgart, dated Mar. 28, 2002, pp. 14-38. |
| Zygarlicke et al., “Flue gas interactions of mercury, chlorine, and ash during coal combustion,” Proceedings of the 23rd International Technical Conference on Coal Utilization and Fuel Systems, Clearwater, Florida, Mar. 9-13, 1998, pp. 517-526 (ISBN 0-03206602302). |
| Official Action for U.S. Appl. No. 14/951,211, dated Feb. 1, 2018 6 pages Restriction Requiremnt. |
| Official Action for U.S. Appl. No. 14/951,211, dated Jul. 18, 2018 13 pages. |
| Notice of Allowance for U.S. Appl. No. 14/951,211, dated Feb. 28, 2019 26 pages. |
| Number | Date | Country | |
|---|---|---|---|
| 20190275463 A1 | Sep 2019 | US |
| Number | Date | Country | |
|---|---|---|---|
| 62084413 | Nov 2014 | US |
| Number | Date | Country | |
|---|---|---|---|
| Parent | 14951211 | Nov 2015 | US |
| Child | 16423672 | US |
