WO2001055642A1 - Conditionnement homogene de gaz de fumee - Google Patents

Conditionnement homogene de gaz de fumee Download PDF

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Publication number
WO2001055642A1
WO2001055642A1 PCT/US2001/002636 US0102636W WO0155642A1 WO 2001055642 A1 WO2001055642 A1 WO 2001055642A1 US 0102636 W US0102636 W US 0102636W WO 0155642 A1 WO0155642 A1 WO 0155642A1
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WO
WIPO (PCT)
Prior art keywords
fluid
exhaust duct
molecules
accordance
nozzles
Prior art date
Application number
PCT/US2001/002636
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English (en)
Other versions
WO2001055642A9 (fr
Inventor
David J. Bayless
Original Assignee
Bayless David J
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Bayless David J filed Critical Bayless David J
Priority to AU2001234586A priority Critical patent/AU2001234586A1/en
Publication of WO2001055642A1 publication Critical patent/WO2001055642A1/fr
Publication of WO2001055642A9 publication Critical patent/WO2001055642A9/fr

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Classifications

    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23G—CREMATION FURNACES; CONSUMING WASTE PRODUCTS BY COMBUSTION
    • F23G7/00—Incinerators or other apparatus for consuming industrial waste, e.g. chemicals
    • F23G7/06—Incinerators or other apparatus for consuming industrial waste, e.g. chemicals of waste gases or noxious gases, e.g. exhaust gases
    • F23G7/08—Incinerators or other apparatus for consuming industrial waste, e.g. chemicals of waste gases or noxious gases, e.g. exhaust gases using flares, e.g. in stacks
    • F23G7/085—Incinerators or other apparatus for consuming industrial waste, e.g. chemicals of waste gases or noxious gases, e.g. exhaust gases using flares, e.g. in stacks in stacks
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23C—METHODS OR APPARATUS FOR COMBUSTION USING FLUID FUEL OR SOLID FUEL SUSPENDED IN  A CARRIER GAS OR AIR 
    • F23C6/00—Combustion apparatus characterised by the combination of two or more combustion chambers or combustion zones, e.g. for staged combustion
    • F23C6/04—Combustion apparatus characterised by the combination of two or more combustion chambers or combustion zones, e.g. for staged combustion in series connection
    • F23C6/042—Combustion apparatus characterised by the combination of two or more combustion chambers or combustion zones, e.g. for staged combustion in series connection with fuel supply in stages
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23G—CREMATION FURNACES; CONSUMING WASTE PRODUCTS BY COMBUSTION
    • F23G7/00—Incinerators or other apparatus for consuming industrial waste, e.g. chemicals
    • F23G7/06—Incinerators or other apparatus for consuming industrial waste, e.g. chemicals of waste gases or noxious gases, e.g. exhaust gases
    • F23G7/061—Incinerators or other apparatus for consuming industrial waste, e.g. chemicals of waste gases or noxious gases, e.g. exhaust gases with supplementary heating
    • F23G7/065—Incinerators or other apparatus for consuming industrial waste, e.g. chemicals of waste gases or noxious gases, e.g. exhaust gases with supplementary heating using gaseous or liquid fuel
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23J—REMOVAL OR TREATMENT OF COMBUSTION PRODUCTS OR COMBUSTION RESIDUES; FLUES 
    • F23J15/00—Arrangements of devices for treating smoke or fumes
    • F23J15/02—Arrangements of devices for treating smoke or fumes of purifiers, e.g. for removing noxious material
    • F23J15/022—Arrangements of devices for treating smoke or fumes of purifiers, e.g. for removing noxious material for removing solid particulate material from the gasflow
    • F23J15/025—Arrangements of devices for treating smoke or fumes of purifiers, e.g. for removing noxious material for removing solid particulate material from the gasflow using filters
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23J—REMOVAL OR TREATMENT OF COMBUSTION PRODUCTS OR COMBUSTION RESIDUES; FLUES 
    • F23J2217/00—Intercepting solids
    • F23J2217/10—Intercepting solids by filters
    • F23J2217/102—Intercepting solids by filters electrostatic

Definitions

  • This invention relates generally to the removal of unwanted matter from the exhaust gas of a coal-burning process. It more specifically relates to an apparatus and a method for burning a carbon monoxide or hydrocarbon fluid within the exhaust gas of a coal-burning facility. This converts some S0 molecules in the exhaust gas into S0 3, which enhances the removal of fly ash particles from the exhaust gas in an electrostatic precipitator .
  • Coal has been burned in power plants to generate electricity for many years.
  • the exhaust stream of coal -burning power facilities contains particulate matter, such as fly ash, that can be harmful to humans and to the environment .
  • electrostatic precipitators ESPs
  • ESPs electrostatic precipitators
  • ESPs use a plurality of charged electrodes to attract particles in the exhaust gas to a collecting electrode's surface. Fly ash particles found in the gas stream attain their charge through attachment of ions generated by the charging electrodes. Once charged, the electric field in the precipitator drives the particles to the collecting electrode. Once they reach the plate's surface, charged particles surrender their charge to the electrode. Each subsequently arriving particle surrenders its charge to the particles previously arriving on the electrode. And through a series of earlier-arriving particles, each particle's charge is conducted to the electrode. The particles form a coating on the plate that is then collected and disposed of, typically through rapping. All coal contains at least some sulfur.
  • S0 2 and S0 3 When sulfur is oxidized during the coal-burning process, it forms S0 2 and S0 3 in an equilibrium that depends upon temperature . As temperature decreases, the equilibrium tends toward more S0 3 . Both S0 2 and S0 3 cause problems if released into the atmosphere, but the release of S0 3 causes more significant problems than the release of S0 2 . S0 3 is unstable and reactive. It normally only lasts milliseconds before reacting with other atoms .
  • Power plants that were designed for high sulfur, low ash coal have ESPs, which are not able to remove the greater amount of ash from low sulfur coals.
  • These ESPs were not designed for the burning of low sulfur, high ash Western coal. But it is not just the greater amount of ash in the coal that causes the problems with ash collection; the difficulties are also due to the lower amount of sulfur and the mechanism by which ash is collected, as will now be explained.
  • an ESP removes fly ash by attracting charged ash/ion particles to a charged electrode and causing the electron on the particle to be conducted over to the collecting electrode through previously arriving particles.
  • fly ash is highly resistive, and therefore, conduction of an electron to the electrode cannot occur through the lattice of the ash particle. Instead, it must be conducted around the surface of the particle.
  • S0 3 is present in the gas stream in an amount that is small, but significant. This S0 3 combines with water vapor in the exhaust gas to form sulfuric acid, which is highly conductive. The sulfuric acid coats the fly ash particles, creating a highly conductive coating, permitting a charge to be conducted to the electrode, regardless of which side of the particle contacts the plate . Because low sulfur coal normally has higher ash content, the amount of fly ash in the gas stream is greater, and the amount of S0 3 is less than in the gas stream from burning high sulfur, low ash coal. This increase in ash and decrease in S0 3 causes difficulties in removing fly ash from the gas stream.
  • Another conventional solution which is still very expensive, is to inject S0 3 back into the gas stream. This is accomplished conventionally by burning elemental sulfur to form S0 2 and then converting some amount of the S0 2 to S0 3 using a catalyst. Because constituents in the exhaust gas of the coal burning process rapidly consume the catalyst, the formation of S0 3 must take place outside of the exhaust duct and be injected back into the exhaust duct, thereby consuming precious space in the power plant facility. Additionally, it can be expensive and seemingly contradictory to the overall environmental protection effort to switch to a lower sulfur coal to remove excess sulfur, but then inject sulfur back into the system to remove the higher ash content .
  • S0 3 injection Another problem with S0 3 injection is that the amount of S0 3 in the gases exiting the stack is difficult to control because the fly ash and sulfur content of the coal vary. If the operator sets the amount of S0 3 being injected and it works, but then the amount of fly ash or sulfur content in the coal changes, the amount of S0 3 being injected must be changed to accommodate this change. The amount of S0 3 must be monitored to keep the S0 3 from becoming so high that its release into the atmosphere becomes a problem that the initial switch to low sulfur coal was intended to preven .
  • the invention is an apparatus that injects a fluid, preferably a hydrocarbon gas, and most preferably methane gas, into the exhaust stream of the coal -burning plant just upstream of the ESP.
  • the apparatus preferably comprises a peripheral ring of fluid nozzles positioned around the exhaust gas duct and pointed upstream and substantially toward the center of the exhaust gas duct. Methane, from a fluid supply in fluid communication with the nozzles, streams out of the nozzles, combusting at the temperatures greater than that of the exhaust gas, and converges at or near the center of the exhaust gas duct under the downstream flow of exhaust gases, thereby forming a wall of flames that the exhaust gas must pass through .
  • the invention also contemplates a method of providing nozzles in the exhaust duct of a coal- burning power plant just upstream of an electrostatic precipitator (ESP) .
  • the method includes the step of injecting the fluid through the nozzles into the exhaust gas in a direction that has at least a component upstream.
  • ESP electrostatic precipitator
  • the burning of the fluid causes atomic oxygen to be formed, and the oxygen atoms react with S0 2 in the gas stream to form S0 3 .
  • the lifetime of the S0 3 is very short, on the order of a few hundred milliseconds to over a second. During that lifetime the S0 3 combines with water vapor contained in the exhaust gas and that which is also formed by burning the methane to form sulfuric acid (H 2 S0 4 ) . This creates a conductive coating needed on the fly ash to lower ash resistivity and enhance collection of the fly ash by the ESP.
  • the S0 3 that does not combine with water vapor converts back to S0 2 before it is released into the atmosphere. Excess water vapor causes the fly ash particles to agglomerate, which makes removal by the normal ESP apparatus easier.
  • Fig. 1 is a schematic side view in section illustrating the preferred apparatus of the present invention.
  • Fig. 2 is a schematic end view in section illustrating the embodiment of Fig. 1 through the lines 2-2.
  • the apparatus 10 injects fluid into the exhaust gas duct 12, as shown in Fig. 1, of a conventional coal -burning power plant.
  • the apparatus 10 has a plurality of fluid nozzles 14, 16, 18, 20, 22, etc. mounted circumferentially around the inner surface 24 of the duct 12.
  • the duct 12 is shown to be circular, but of course the invention would work in a duct that is rectangular or any other conventional exhaust duct shape.
  • the nozzles are preferably mounted upstream of, and preferably on the order of approximately one foot from, where the downstream end of the duct 12 adjoins the upstream end of the electrostatic precipitator (ESP) 26.
  • the nozzles are conventional fluid, and preferably gas, nozzles in fluid communication with a fluid supply 21.
  • the fluid supply includes a fluid supply tube 23 in fluid communication with a fluid reservoir 25.
  • the fluid reservoir could be a tank containing the fluid or, for example, a natural gas well connected to the nozzles by a gas line.
  • the fluid supplied to the nozzles is preferably pressurized so that the fluid is injected rapidly into the exhaust duct 12 through the nozzles, forming a flame in the exhaust duct 12 coming from each nozzle.
  • upstream and downstream are used in their normal sense to correspond to the direction of flow of the exhaust gases, which is from a more upstream location to a more downstream location.
  • the terms contain the words “up” and “down,” the terms do not necessarily correspond to the normal meaning of the words “up” and “down” as those words are often related to the direction of the force due to gravity.
  • the gases in the exhaust duct could be flowing downstream and in a direction opposite the direction of the force due to gravity.
  • the fluid used is one that, when combusted, releases oxygen atoms .
  • the fluids that are known to work are carbon monoxide and any hydrocarbon. Hydrocarbons burn to form carbon monoxide in the presence of oxygen, which is then converted to oxygen atoms as described below.
  • the hydrocarbons that are contemplated include propane, natural gas, alcohol, and many other gaseous or liquid hydrocarbon fuels. Methane is preferred, and where methane is described as the flammable fluid in the description below, it is understood that it could be substituted, making modifications understood by those with ordinary skill in the art, with any other hydrocarbon fluid or carbon monoxide .
  • the exhaust gases flowing through the exhaust duct 12 flow at a rate on the order of 80 feet per second for an exhaust duct that is 8 to 12 feet in diameter.
  • the ESP 26 connected to the exhaust duct 12 includes a very large increase in cross sectional area at the inlet to the ESP from the duct 12. This slows down the exhaust gases to decrease the gas turbulence and give the fly ash particles more time to migrate over to the collecting electrodes of the ESP.
  • the speed of the exhaust gases in the exhaust duct 12 can cause the burning methane flames to bend significantly.
  • the nozzles are also pointed upstream to compensate for the bending effect that the rapidly flowing exhaust gases in the exhaust gas duct 12 have on the flames coming out of the nozzles.
  • the flames coming out of the nozzles begin to flow upstream as they come out of the nozzles, but are bent downstream along the length of the flame due to the rapid downstream flow of exhaust gases in the duct 12.
  • the methane is burned in a "ring of fire" with nozzles injecting methane gas at multiple circumferentially spaced sites around the normally round exhaust duct 12, most of the exhaust gases that pass through the duct 12 at the apparatus 10 pass through the flame. This is desired, because at the flame, O atoms are created as discussed below.
  • the radical O atoms react with S0 2 molecules in the exhaust gases to form S0 3 molecules. Because the oxygen atoms do not react with S0 2 molecules for a finite time period, there will be an "S0 3 front" just downstream of the flame. Therefore, because the methane flame is just upstream of the ESP, it provides S0 3 right where it is desired - in the ESP.
  • the primary mechanism for flame-based formation of S0 3 is interaction of S0 2 with O in the presence of a third body (M) , given by:
  • Third bodies (M) can be virtually any non- reacting species, including fly ash.
  • Typical third bodies include H 2 0, N 2 , and C0 2 .
  • collision efficiency factors 10 for H 2 0, and 1.3 for N 2 were used, along with an estimate of 3 for C0 2 .
  • the primary source of O atoms in Reaction 1 is the oxidation of CO, described by CO + OH ⁇ C0 2 + H and H + 0 2 - O + OH, which is crucial if significant dissociation of 0 2 is not necessary to promote S0 3 formation. Therefore, if cost were not a factor it would be preferred that the flammable fluid burned in the exhaust duct be CO.
  • the preferred fluid is methane or another hydrocarbon, which forms CO upon combustion in the presence of oxygen.
  • Low bulk gas temperatures should not drastically inhibit S0 3 formation if a stable flame can be generated.
  • the flame burns at a temperature hotter than the exhaust gases, such as at about 2000K.
  • the combustion reaction of methane with the exhaust gases may have to be started with an ignition source, such as a sparking device, to form the flame.
  • the sparking device is positioned to create a spark near one or more nozzles' outlets into the exhaust duct. Once begun, the combustion reaction will ordinarily maintain the flame .
  • S0 3 molecules react with water in the exhaust gas, and water formed by combustion of the methane, to form sulfuric acid by: H 2 0 + S0 3 ⁇ H 2 S0 4
  • the sulfuric acid coats the fly ash particles and creates a highly conductive coating as described above.
  • the water vapor formed by the combustion of methane also causes agglomeration of the fly ash and enhances the conductivity of the particles . This has the desirable effect of fly ash conducting the charge of other fly ash particles, so that much more of the fly ash can be collected on the collecting electrodes of the ESP than without the methane flame described above.
  • Exhaust gas in a conventional ESP travels at between about 4 and 10 feet per second, and conventional ESP fields are normally about 10 to 15 feet long.
  • the S0 3 created by the preferred embodiment lasts for about the first field of the ESP. Because the first field of the ESP is where the vast majority of the fly ash particles are collected, this timing is very effective for overcoming the problems normally associated with burning low sulfur, high ash coal in power plants designed to burn high sulfur, low ash coal.
  • the S0 3 that is formed lasts momentarily before reacting with oxygen and hydrogen atoms to form S0 2 , as given by S0 3 + 0 ⁇ S0 2 + 0 2 , (3!
  • the amount of time the S0 3 lasts can vary based upon many factors, including temperature.
  • the preferred apparatus for use in conventional ESPs forms S0 3 molecules that last for a time in the range of approximately a few hundred milliseconds to more than one second, and it has been determined that 1.2 seconds is typical . In that time the S0 3 molecules convert water vapor to sulfuric acid, which coats the fly ash to make a conductive outer coating.
  • Rate constants for Reaction 3 (k 3 ) vary with the assumed activation energy of Reaction 1. Activation energies for Reaction 2 vary from 6-16 kcal in literature. This work assumed the results of Smith et al . to be more realistic for fast bimolecular reactions, establishing k 3 to be
  • S0 3 also can dissociate through third body collision to S0 2 and O as given by the equation:
  • Nettleton and Stirling estimated k 9 to be 10 8 cm 3 mol "1 sec "1 at 1740K.
  • S0 2 gas is a problem, inasmuch as it causes acid rain, but it is a problem that is preferred over having S0 3 or fly ash exit the stack.
  • the present invention uses only the existing sulfur in the flue gases to aid in electrostatically removing the fly ash, no increase in sulfur release is possible.
  • the amount of S0 3 created which can be controlled to fractions of parts per million with the present invention, is much easier to control because all excess S0 3 molecules convert back to S0 2 molecules before leaving the stack.

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  • Engineering & Computer Science (AREA)
  • Environmental & Geological Engineering (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Chemical & Material Sciences (AREA)
  • Combustion & Propulsion (AREA)
  • Treating Waste Gases (AREA)

Abstract

L'invention concerne un appareil (10) qui injecte du fluide, de préférence, un gaz d'hydrocarbures, tel que du méthane, dans le courant de gaz d'échappement d'une installation de brûlage de charbon. Le méthane brûle en dégageant des atomes d'oxygène qui réagissent avec les molécules de SO2 du courant de gaz d'échappement, de manière que des molécules transitoires de SO3 soient formées. Au cours de leur brève existence, de l'ordre de quelques centaines de millisecondes jusqu'à une seconde, à une température de 450K à 1 000K, les molécules de SO3 réagissent avec la vapeur d'eau du gaz d'échappement et la vapeur d'eau issue de la combustion du méthane avec l'oxygène, de manière que de l'acide sulfurique soit formé. L'acide sulfurique recouvre les cendres volantes du gaz d'échappement, créant une couche conductrice permettant à un dispositif de précipitation électrostatique (26) de collecter la plupart des cendres volantes. Le SO3 restant est converti en SO2 avant qu'il sorte du conduit d'évacuation (12).
PCT/US2001/002636 2000-01-26 2001-01-26 Conditionnement homogene de gaz de fumee WO2001055642A1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
AU2001234586A AU2001234586A1 (en) 2000-01-26 2001-01-26 Homogenous flue gas conditioning

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US17823500P 2000-01-26 2000-01-26
US60/178,235 2000-01-26

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WO2001055642A1 true WO2001055642A1 (fr) 2001-08-02
WO2001055642A9 WO2001055642A9 (fr) 2002-10-17

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WO (1) WO2001055642A1 (fr)

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US9694317B2 (en) 2012-05-03 2017-07-04 Altira Technology Fund V L.P. Multi-pollutant abatement device and method

Citations (9)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3463599A (en) * 1967-03-01 1969-08-26 Exxon Research Engineering Co Combustion process for coal fired boilers
US3668833A (en) * 1970-08-25 1972-06-13 William Francis Cahill Jr Apparatus and method for incinerating rubbish and cleaning the smoke of incineration
US3884162A (en) * 1973-01-23 1975-05-20 Steinmueller Gmbh L & C Incinerator plant for pre-treated industrial wastes
US4332206A (en) * 1980-05-09 1982-06-01 The Boeing Company Afterburner for combustion of starved-air combustor fuel gas containing suspended solid fuel and fly ash
US4676177A (en) * 1985-10-09 1987-06-30 A. Ahlstrom Corporation Method of generating energy from low-grade alkaline fuels
US5311829A (en) * 1990-12-14 1994-05-17 Aptech Engineerig Services, Inc. Method for reduction of sulfur oxides and particulates in coal combustion exhaust gases
US5908003A (en) * 1996-08-15 1999-06-01 Gas Research Institute Nitrogen oxide reduction by gaseous fuel injection in low temperature, overall fuel-lean flue gas
US5980610A (en) * 1997-09-25 1999-11-09 The United States Of America As Represented By The United States Department Of Energy Apparatus and method for improving electrostatic precipitator performance by plasma reactor conversion of SO2 to SO3
US6058855A (en) * 1998-07-20 2000-05-09 D. B. Riley, Inc. Low emission U-fired boiler combustion system

Patent Citations (9)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3463599A (en) * 1967-03-01 1969-08-26 Exxon Research Engineering Co Combustion process for coal fired boilers
US3668833A (en) * 1970-08-25 1972-06-13 William Francis Cahill Jr Apparatus and method for incinerating rubbish and cleaning the smoke of incineration
US3884162A (en) * 1973-01-23 1975-05-20 Steinmueller Gmbh L & C Incinerator plant for pre-treated industrial wastes
US4332206A (en) * 1980-05-09 1982-06-01 The Boeing Company Afterburner for combustion of starved-air combustor fuel gas containing suspended solid fuel and fly ash
US4676177A (en) * 1985-10-09 1987-06-30 A. Ahlstrom Corporation Method of generating energy from low-grade alkaline fuels
US5311829A (en) * 1990-12-14 1994-05-17 Aptech Engineerig Services, Inc. Method for reduction of sulfur oxides and particulates in coal combustion exhaust gases
US5908003A (en) * 1996-08-15 1999-06-01 Gas Research Institute Nitrogen oxide reduction by gaseous fuel injection in low temperature, overall fuel-lean flue gas
US5980610A (en) * 1997-09-25 1999-11-09 The United States Of America As Represented By The United States Department Of Energy Apparatus and method for improving electrostatic precipitator performance by plasma reactor conversion of SO2 to SO3
US6058855A (en) * 1998-07-20 2000-05-09 D. B. Riley, Inc. Low emission U-fired boiler combustion system

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US9694317B2 (en) 2012-05-03 2017-07-04 Altira Technology Fund V L.P. Multi-pollutant abatement device and method

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Publication number Publication date
WO2001055642A9 (fr) 2002-10-17
AU2001234586A1 (en) 2001-08-07

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