Classifications

• • B—PERFORMING OPERATIONS; TRANSPORTING
  • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
  • B01D—SEPARATION
  • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
  • B01D53/34—Chemical or biological purification of waste gases
  • B01D53/46—Removing components of defined structure
  • B01D53/48—Sulfur compounds
  • B01D53/50—Sulfur oxides
  • B01D53/508—Sulfur oxides by treating the gases with solids

Definitions

• the present invention relates to the purification of gases, and more particularly to a method of purifying flue gases which contain noxious gases such as SO 3 .
• SO3 is a noxious gas that is produced from the combustion of sulfur- containing fuel. When present in flue gas, the SO 3 can form an acid mist that condenses in electrostatic precipitators, ducts or bag houses, causing corrosion. SO3 at concentrations as low as 5-10 ppmin exhaust gas can also result in white, blue, purple, or black plumes from the cooling of the hot stack gas in the cooler air in the atmosphere.
• SCRs selective catalytic reactors
• SO3 in the flue gas absorbs onto the fly ash particles and lowers fly ash resistivity, thereby enabling the ESP to capture the particle by electrostatic means.
• Many plants actually inject SO 3 to lower fly ash resistivity when ash resistivity is too high.
• SO3 reacts with water vapor in the flue gas ducts of the coal power plant and forms vaporous H2SO4. A portion of this condenses out in the air heater baskets. Another portion of the sulfuric acid vapor can condense in the duct if the duct temperature is too low, thereby corroding the duct.
• the remaining acid vapor condenses either when the plume is quenched when it contacts the relatively cold atmosphere or when wet scrubbers are employed for flue gas desulfurization (FGD), in the scrubber's quench zone.
• FGD flue gas desulfurization
• the rapid quenching of the acid vapor in the FGD tower results in a fine acid mist.
• the droplets are often too fine to be absorbed in the FGD tower or to be captured in the mist eliminator. Thus, there is only limited SO 3 removal by the FGD towers. If the sulfuric acid levels emitted from the stack are high enough, a secondary plume appears.
• Dry sorbent injection has been used with a variety of sorbents to remove SO3 and other gases from flue gas.
• DSI has typically been done in the past at temperatures lower than around 370° F because equipment material, such as baghouse media, cannot withstand higher temperatures.
• equipment material such as baghouse media
• many sorbent materials sinter or melt at temperatures greater than around 400° F, which makes them less effective at removing gases.
• Another problem is that under certain temperature and gas concentration conditions the reaction products of many sorbent materials adhere to equipment and ducts, which requires frequent cleaning of the process equipment.
• a method of removing SO 3 from a flue gas stream having increased amounts Of SO 3 formed by a NO x removal system includes injecting a sorbent composition into the flue gas stream.
• the sorbent composition includes an additive and a sodium sorbent such as mechanically refined trona or sodium bicarbonate.
• the additive is selected magnesium carbonate, calcium carbonate, magnesium hydroxide, calcium hydroxide, and mixtures thereof. The concentration of the SO3 in the flue gas stream is reduced and the formation of a liquid phase NaHSO 4 reaction product is minimized.
• a method of delivering a dry sorbent for flue gas injection includes providing trona.
• a sorbent composition is formed by combining with the trona an additive selected from magnesium carbonate, calcium carbonate, magnesium hydroxide, calcium hydroxide, and mixtures thereof.
• the sorbent composition is transported in a vessel to the location of a flue gas injection.
• the sorbent composition is offloaded out of the vessel and injected into the flue gas stream.
• Sufficient amounts of additive are combined with the trona to enhance the flowability of the sorbent composition out of the vessel.
• FIG. 1 is a phase diagram showing the reaction products of trona with SO 3 as a function of flue gas temperature and SO3 concentration.
• FIG. 2 is a schematic of one embodiment of a flue gas desulfurization system.
• Dry sorbent injection has been used as a low cost alternative to a spray dry or wet scrubbing system for the removal of SO 3 .
• the sorbent is stored and injected dry into the flue duct where it reacts with the acid gas.
• the reaction product of the sorbent and the acid gas is a sticky ash.
• the sticky ash tends to stick to the process equipment and ducts, thus requiring frequent cleaning.
• Trona is a mineral that contains about 85-95% sodium sesquicarbonate (Na 2 CO 3 -NaHCO 3 ⁇ H 2 O).
• a vast deposit of mineral trona is found in southeastern Wyoming near Green River.
• the term "trona” includes other sources of sodium sesquicarbonate.
• Another sorbent that may be used is sodium bicarbonate.
• flue gas includes the exhaust gas from any sort of combustion process (including coal, oil, natural gas, etc.). Flue gas typically includes acid gases such as SO 2 , HCl, SO 3 , and NO x . When heated at or above 275°F, sodium sesquicarbonate undergoes rapid calcination of contained sodium bicarbonate to sodium carbonate, as shown in the following reaction:
• Sodium bisulfate is an acid salt with a low melt temperature and is unstable at high temperatures, decomposing as indicated in the following reaction:
• FIG. 1 is a phase diagram showing the typical reaction products of trona with SO 3 as a function of flue gas temperature and SO 3 concentration.
• the reaction product can be solid NaHSO 4 , liquid NaHSO 4 , Na 2 SO 4 , or Na 2 S 2 O 7 , depending on the flue gas temperature.
• Liquid NaHSO 4 is particularly undesirable because it is "sticky" and tends to adhere to the process equipment, and cause other particulates, such as fly ash, to also stick to the equipment. Thus, it may be desirable to operate the process under conditions where the amount of liquid NaHSO 4 reaction product is minimized.
• log[SO 3 ] is the log base 10 of the SO 3 concentration in ppm
• T is the flue gas temperature in 0 F.
• a sorbent composition comprising mechanically refined trona and an additive minimizes the amount of sticky ash formed in the process.
• Sodium bicarbonate may be used in place of trona.
• the additive is selected from the group consisting of magnesium carbonate, calcium carbonate, magnesium hydroxide, calcium hydroxide, and mixtures thereof.
• the additive preferably includes magnesium carbonate, calcium carbonate, or mixtures thereof, and most preferably includes calcium carbonate.
• the additive is preferably between 0.1% and 5%, most preferably between 0.5% and 2%, by weight of the trona or other sodium sorbent.
• the sorbent composition is injected into the flue gas stream.
• the sorbent composition is maintained in contact with the flue gas for a time sufficient to react a portion of the sorbent composition with a portion of the SO 3 to reduce the concentration of the SO3 in the flue gas stream.
• formation of a liquid phase NaHSO 4 reaction product is minimized so that little sticky ash is formed. While not intending to be bound by theory, it is believed that the additive reacts with the H2SO4 present in the flue gas stream to remove it thereform, thus minimizing the production of liquid phase NaHSO 4 .
• the system may be operated in a range of temperatures and SO3 concentrations where liquid phase NaHSO 4 would form in the absence of the additive.
• the temperature of the flue gas where the trona is injected is between about 370° F and about 500° F.
• the temperature of the flue gas is preferably greater than about 370° F, and more preferably greater than about 385° F.
• the temperature of the flue gas is preferably less than about 500° F, more preferably less than about 450° F, and most preferably less than about 415° F.
• the temperature of the flue gas is most preferably between about 385° F and about 415° F.
• the temperature range can be expressed as a function of the SO3 concentration.
• the process may be operated at a temperature and SO3 concentration where log[SO3]>0.009135T-2.456, where [SO3] is the SO3 concentration in ppm and T is the flue gas temperature in 0 F.
• the SO3 concentration of the flue gas stream to be treated is generally at least about 3 ppm, and commonly between about 10 ppm and about 200 ppm.
• the desired outlet SO3 concentration of the gas stack is preferably less than about 50 ppm, more preferably less than about 20 ppm, more preferably less than about 10 ppm, and most preferably less than about 5 ppm.
• the byproduct of the reaction is collected with fly ash.
• Trona like most alkali reagents, will tend to react more rapidly with the stronger acids in the gas stream first, and then after some residence time it will react with the weaker acids.
• gas constituents as HCl and SO3 are strong acids and trona will react much more rapidly with these acids than it will with a weak acid such as SO 2 .
• the injected sorbent composition can be used to selectively remove SO3 without substantially decreasing the amount of SO 2 in the flue gas stream.
• FIG. 2 A schematic of one embodiment of the process is shown in FIG. 2.
• the furnace or combustor 10 is fed with a fuel source 12, such as coal, and with air 14 to burn the fuel source 12.
• a fuel source 12 such as coal
• air 14 to burn the fuel source 12.
• the combustion gases are conducted to a heat exchanger or air heater 30.
• Ambient air 32 may be injected to lower the flue gas temperature.
• a selective catalytic reduction (SCR) device 20 may be used to remove NO x gases.
• a bypass damper 22 can be opened to bypass the flue gas from the SCR.
• the outlet of the heat exchanger or air heater 30 is connected to a particulate collection device 50.
• the particulate collection device 50 removes particles made during the combustion process, such as fly ash, from the flue gas before it is conducted to an optional wet scrubber vessel 54 and then to the gas stack 60 for venting.
• the particulate collection device 50 may be an electrostatic precipitator (ESP).
• ESP electrostatic precipitator
• Other types of particulate collection devices, such as a baghouse, may also be used for solids removal.
• the baghouse contains filters for separating particles made during the combustion process from the flue gas.
• the SO 3 removal system includes a source of sorbent composition 40.
• the sorbent composition includes an additive and a sodium sorbent such as trona or sodium bicarbonate.
• the sodium sorbent is preferably trona.
• the trona is preferably provided as particles with a mean particle size between about 10 micron and about 40 micron, most preferably between about 24 micron and about 28 micron.
• the mean particle size of the additive may be generally about the same size as the trona and is preferably between about 10 micron and about 25 micron.
• the sorbent composition is preferably in a dry granular form.
• a suitable trona source is T-200® trona, which is a mechanically refined trona ore product available from Solvay Chemicals.
• T-200® trona contains about 97.5% sodium sesquicarbonate and has a mean particle size of about 24-28 micron.
• the system may also include a ball mill pulverizer, or other type of mill, for decreasing and/or otherwise controlling the particle size of the trona or other sorbent compositions. It has also been found that the additive may improve the flow properties of the trona when added thereto.
• a method of delivering a dry sorbent for flue gas injection includes combining the additive and trona to form a sorbent composition.
• the additive may be magnesium carbonate, calcium carbonate, magnesium hydroxide, calcium hydroxide, and mixtures thereof.
• the sorbent composition is transported in a vessel to the location of a flue gas injection.
• the sorbent composition is offloaded out of the vessel and injected into the flue gas stream, wherein sufficient amounts of additive are combined with the trona to enhance the flowability of the sorbent composition out of the vessel.
• the sorbent composition is conveyed from the sorbent composition source 40 to the injector 42.
• the sorbent composition may be conveyed pneumatically or by any other suitable method.
• the injection apparatus 42 introduces the sorbent composition into flue gas duct section 44, which is disposed at a position upstream of the baghouse inlet and preferably downstream of the heat exchanger outlet.
• the injection system is preferably designed to maximize contact of the sorbent composition with the SO 3 in the flue gas stream.
• Any type of injection apparatus known in the art may be used to introduce the sorbent composition into the gas duct. For example, injection can be accomplished directly by a compressed air-driven eductor.
• the process requires no slurry equipment or reactor vessel if the sorbent composition is stored and injected dry into the flue duct 44 where it reacts with the acid gas.
• the process may also be used with humidification of the flue gas or wet injection of the sorbent composition.
• the particulates can be collected wet through a wet scrubber vessel 54 should the process be used for trim scrubbing of acid mist.
• the flue gas desulfurization system may be operated so that the SO 3 removal is accomplished by injecting the sorbent composition into the flue gas, while the majority of the SO 2 is removed by the wet scrubber 54.
• the process may also be varied to control the flue gas temperature.
• the flue gas temperature upstream of the trona or other sodium sorbent may be adjusted to obtain the desired flue gas temperature where the sorbent composition is injected.
• ambient air 32 may be introduced into the flue gas stream to lower the flue gas temperature and the flue gas temperature monitored where the sorbent composition is injected.
• Other possible methods of controlling the flue gas temperature include using heat exchanges and/or air coolers.
• the process may also vary the trona injection location or include multiple locations for sorbent composition injection.
• the sorbent composition is preferably injected at a rate with respect to the flow rate of the SO3 to provide a normalized stoichiometric ratio (NSR) of sodium to sulfur of about 1.0 or greater.
• NSR normalized stoichiometric ratio
• the NSR is a measure of the amount of reagent injected relative to the amount theoretically required.
• the NSR expresses the stoichiometric amount of sorbent required to react with all of the acid gas. For example, an NSR of 1.0 would mean that enough material was injected to theoretically yield 100 percent removal of the SO3 in the inlet flue gas; an NSR of 0.5 would theoretically yield 50 percent SO 3 removal.
• the reaction of SO 3 with the sodium carbonate is very fast and efficient, so that a NSR of only about one is generally required for SO 3 removal.
• the sorbent composition preferentially reacts with SO 3 over SO 2 , so SO 3 will be removed even if large amounts of SO 2 are present.
• an NSR of less than 2.0 or more preferably less than 1.5 is used such that there is no substantial reduction of the SO 2 concentration in the flue gas caused by reaction with excess sorbent.
• NO x removal systems tend to oxidize existing SO 2 into SO 3
• the injection system may also be combined with an NO x removal system.
• the trona injection system may also be combined with other SO x removal systems, such as sodium bicarbonate, lime, limestone, etc.
• An electric generation plant uses a hot side electrostatic precipitator (ESP) and no baghouse.
• the plant uses a catalyst for NO x removal, which causes elevated SO 3 levels in the flue gas.
• the SO 3 concentration in the flue gas is between about 100 ppm and about 125 ppm.
• T-200® trona from Solvay Chemicals is injected to remove SO 3 from the flue gas.
• trona is injected at a temperature of 400° F with no additive at NSR values of about 1.5.
• the perforated plates of the ESP in the plant exhibit significant solids buildup which requires frequent cleaning.
• a sorbent composition comprising trona and 1% calcium carbonate is injected into flue gas at a temperature of 400° F at NSR values of about 1.5.
• a perforated plate of an ESP in the plant after operation of the SO 3 removal system is relatively free of solids buildup.
• using an additive reduces the amount of sticky waste products in the SO 3 removal process, compared to a process using trona without an additive under the same processing conditions.

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• 2006
  • 2006-09-14 CN CN200680033934.9A patent/CN101262929B/zh active Active
  • 2006-09-14 JP JP2008530530A patent/JP2009507632A/ja not_active Ceased
  • 2006-09-14 EP EP06793512A patent/EP1937391A1/de not_active Withdrawn
  • 2006-09-14 EA EA200800829A patent/EA015416B1/ru not_active IP Right Cessation
  • 2006-09-14 CA CA2622549A patent/CA2622549C/en not_active Expired - Fee Related
  • 2006-09-14 WO PCT/EP2006/066359 patent/WO2007031552A1/en active Application Filing
  • 2006-09-14 BR BRPI0616068-9A patent/BRPI0616068A2/pt not_active IP Right Cessation

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