Process for removing SOx from a gaseous mixture

Abstract: A gas desulfurization process is provided in which a gaseous mixture (10), comprising sulfur oxides is contacted in an absorption zone (12), at absorption conditions, with an aqueous composition (14) comprising ammonium carbonate, or ammonium bicarbonate or mixtures thereof, in an amount such that the product of the partial pressures of the sulfur oxides and ammonia over said aqueous composition is below a specified limit, to produce a gaseous product (18) having a decreased content of sulfur oxides and a decreased appearance of blue haze. A combination nitrogen oxides removal (deNO x ) and desulfurization (deSO x ) process is also provided.

Description: BACKGROUND OF THE INVENTION 1. Field of the Invention The present invention relates to a process for removing sulfur oxides from gaseous mixtures. 2. Description of Information Disclosures It is known to use ammonia or ammonia precursors to remove sulfur oxides from gaseous mixtures, such as combustion effluents. U.S.-A-4,029,752 discloses a method for removing sulfur oxides from gaseous mixtures utilizing ammonia to produce elemental sulfur. The gaseous mixture containing sulfur oxides is reacted first with ammonia to form ammonium salts, such as ammonium sulfate or ammonium sulfite, and subsequently the recovered ammonium salts are decomposed at elevated temperatures to form elemental sulfur. U.S.-A-4,288,420 discloses a process for removing nitrogen oxides and sulfur oxides from a flue gas by reaction in the presence of a catalyst, with excess ammonia to reduce the nitrogen oxides and form ammonium sulfate which is collected with the coal ash particles. The gas leaving the collector passes to a desulfurization unit. The coal ash particles containing ammonium sulfate are heated to release some of their contained ammonia for recycle to the NO x removal step. U.S.-A-4,400,363 discloses first removing SO x and thereafter removing NO x from flue gases by reaction with ammonia. See column 3, line 45 to column 4, line 3. The NO x removal reaction is catalytic. U.S.-A-4,272,497 discloses simultaneously removing NO x and SO x from waste gases by reacting the gases with ammonia as shown in Figure 5. The NO x removal reaction is catalytic. In catalytic deNO x reaction processes, such as those of U.S.-A-4,400,363 and U.S.-A-4,272,497, the excess ammonia for the deNO x reaction could not be usefully employed for the SO x removal stage. U.S.-A-4,051,225 discloses a process in which flue gas is treated, catalytically or non-catalytically, with ammonia to remove NO x and SO x to produce nitrogen and ammonium hydrogen sulfate. The molar ratio of ammonia to SO₃ and the steam concentrations are maintained within specified amounts, thereby severely limiting the amount of excess ammonia available for the deNO x step. Such a process has a high steam requirement which also results in a high water content in the treated flue gas. U.S.-A-3,900,554 discloses a method for removing NO from a combustion gas in the presence of oxygen by reaction with ammonia. Although the reaction can be conducted with as little asd 0.4 mole NH₃ per mole NO, if it is desired to reduce less than 100% of the NO present in the gas, it is preferred to use a higher mole ratio of ammonia per mole NO and thereby provide an excess amount of ammonia to obtain better results. After the reaction, the excess ammonia must be removed or utilized. See also U.S.-A-4,507,269. U.S.-A-4,325,713 discloses scrubbing SO x from a flue gas with an aqueous ammonium or sodium alkali SO x sorbent liquor selected from ammonium carbonate, ammonium bicarbonate, sodium hydroxide, sodium carbonate, sodium bicarbonate and mixtures thereof. See also U.S.-A-4.620,856. U.S.-A-4,321,241 discloses a process for the desulfurization of flue gas using an ammonia containing aqueous washing solution to which ammonia has been added. The addition of ammonia is controlled to provide a predetermined amount of ammonium carbonate in the washing solution. Allowed U.S.-A-4,853,193 issued August 1, 1989, sets forth a combination denitrogenation and desulfurization process in which the nitrogen oxides in a gaseous mixture comprising nitrogen oxides (NO x ) and sulfur oxides (SO x ) are reacted with excess ammonia or ammonia precursors, and the resulting gaseous product comprising unreacted ammonia and SO x is passed to a gas desulfurization zone into which supplemental ammonia may be added. U.S.-A-3,808,324 discloses a process for the selective removal of SO₂ from a gas stream, for example flue or stack gas streams produced in electrical power generating stations. The process includes the steps of scrubbing the input gas stream with an aqueous absorbent stream containing an alkaline reagent such as ammonium carbonate and/or ammonium bicarbonate, treating the resulting absorbent stream with a gaseous mixture of H₂S and CO₂ to convert the sulfite compound contained therein to the corresponding thiosulfate compound and to produce a gas stream enriched in CO₂ content, and then catalytically reducing the thiosulfate compound with hydrogen to produce a liquid stream containing the corresponding sulfide compound. The problem with the processes in which ammonia or aqueous ammonium compound-containing compositions having a high ammonia partial pressure are used to remove sulfur oxides from gaseous mixtures is the appearance of a blue haze in the gaseous effluent of the gas desulfurization zone. The blue haze is believed to be caused by the dispersion in the gaseous effluent of submicron ammonium sulfite and/or sulfate particles formed in the gas phase reaction of ammonia with the sulfur oxides. It has now been found that the appearance of a blue haze can be decreased or eliminated if the SO x -containing gas is treated with an absorbent aqueous composition comprising specified ammonium salts in an amount such that the product of the partial pressures of the SO x and NH₃ over the aqueous composition is below a specified limit. Therefore, the tendency for SOx to react with ammonia in the gas phase is expected to be minimized since the reaction of SO x with the ammonium salts will proceed predominantly in the liquid phase. SUMMARY OF THE INVENTION In accordance with the invention, there is provided a process for absorbing sulfur oxides from a gaseous mixture containing the same, which comprises contacting, in an absorption zone, at absorption conditions, said gaseous mixture with an aqueous absorption composition comprising an ammonium salt selected from the group consisting of ammonium carbonate, ammonium bicarbonate, and mixtures thereof, (and optionally containing ammonia), in an amount such that the product of the partial pressure of said sulfur oxides and ammonia over said aqueous composition, measured at 60°C (140 degrees F), is not greater than 0.0889 (kPa)² (5 (mm Hg)²), in said absorption zone, to produce a gaseous product having a decreased content of said sulfur oxides. In accordance with the invention, there is also provided a process in which the above described SO x removal step is integrated with a nitrogen oxides removal step (deNOx). BRIEF DESCRIPTION OF THE DRAWING The Figure is a schematic flow plan of one embodiment of the invention. DESCRIPTION OF THE PREFERRED EMBODIMENTS One embodiment of the invention will be described with reference to the Figure. Referring to the Figure, a gaseous mixture comprising one or more types of sulfur oxides, hereinafter designated SO x , to be purified, is introduced by line 10 into an absorption zone 12, such as a countercurrent gas-liquid contacting zone. The contacting zone may contain contacting means such as trays, packed beds or other contacting devices. The gaseous mixtures to be treated by the process of the invention may contain from about 50 to about 50,000 parts per million (ppm) SO x based on the total gaseous mixture to be treated. The SO x -containing gaseous mixture of line 10 may be derived from any source, such as combustion gases, gases obtained from acid sludge decomposition, smelter gases and the like. The process is particularly suited to treat combustion effluents, that is, gases which flow out from a region of combustion. An aqueous absorbent composition comprising an ammonium salt selected from the group consisting of ammonium carbonate, ammonium bicarbonate, and mixtures thereof, is introduced into absorption zone 12 by line 14. Preferably, a mixture of ammonium carbonate and ammonium bicarbonate is present in the initial (fresh or unused) aqueous absorbent composition. The absorbent aqueous composition may be a solution or a slurry. The concentration of the ammonium salt (or salts) in the initial aqueous composition and the mole ratio of ammonium salt to sulfur oxides in the gaseous mixture to be treated is selected to be such that the product of the partial pressures of said sulfur oxides and ammonia over the aqueous composition, measured at 60°C (140°F) is not greater than 0.0889 (kPa)² (5 (mm Hg)²), preferably less than about 0.0355 (kPa)² (2(mm Hg)², more preferably less than about 0.0177 (kPa)² (mm Hg)²) anywhere in absorption sone 12. Suitable concentration ranges include from about 15 to 65, preferably from about 25 to about 60 weight percent, calculated as if all the salt or salts existed as ammonium carbonate, or stated differently, such that the ammonium salt, calculated on the basis of the mole ratio of CO₂ to NH₃ in the initial absorbent composition is at least about least about 0.5:1, preferably at least least 0.75:1 The absorbent composition may be introduced as a solution or as a slurry of saturated solution and undissolved carbonate salt. A sufficient amount of the aqueous absorbent composition is introduced into absorption zone 12 to provide a mole ratio of at least 1.0 mole of ammonia contained in the ammonium salt per mole of sulfur oxide present in the gaseous mixture, preferably a mole ratio of ammonia in said salt to sulfur oxide ranging from about 1:1 to 10:1, more preferably from about 1.0:1 to about 6:1. The large excess above 1.0:1 is for the purpose of providing an ammonia reserve for the contingency of large fluctuations in SO x and thus, permit reasonable process control as shown in U.S.-A-4,321,241. Optionally, water may introduced into the upper portion of absorption zone 12 by line 16 for the purpose of recovering ammonia in the scrubbed flue gas to minimize the loss of this material and to avoid pollution problems due to ammonia in the absorption zone effluent. The absorption zone is maintained at absorption conditions so that contact of SO x -containing gaseous mixture with the ammonium salt-containing aqueous absorbent composition removes at least a portion of the sulfur oxides (SO₂ and/or SO₃) from the gaseous mixture of line 10 by formation of ammonium sulfate and/or ammonium sulfite in the absorbent composition and evolution of gaseous carbon dioxide, thereby producing a gaseous product (absorption zone effluent) having a decreased amount of SO x and containing the carbon dioxide formed by the reaction in the absorption zone. In conventional flue gas desulfurization processes in which an ammonia-comprising aqueous solution is used as absorption composition (i.e. scrubbing composition), the partial pressure of ammonia over the solution is very high. In contrast, the partial pressure of ammonia over the ammonium salt solution of the present is significantly lower. This can be seen from Table I which shows calculated ammonia partial pressures at 60°C (140 degrees°F) over aqueous solution comprising 5 wt. % total ammonia (free and combined) as follows: (a) ammonium hydroxide as sole component (b) CO₂/NH₃ mole ratio of 0.5/1, i.e. ammonium carbonate (c) CO₂/NH₃ mole ratio of 0.75/1, i.e. equimolal ammonium carbonate/ammonium bicarbonate mixture. When the total ammonia in the solution is decreased, the partial pressure of ammonia above the solution will also be lowered, thus 2 wt.% total NH₃ solutions will exhibit only 40% of the partial pressure of 5 wt.% solutions; 1 wt.% NH₃ solutions will exert only 20% of the NH₃ partial pressure shown for 5 wt.% solutions, etc. Therefore, making the absorbent solution more dilute is a method of decreasing the ammonia partial pressure over the solutions. As previously mentioned, a problem with the use of ammonia-based flue gas desulfurization processes is that they exhibit an undesirable blue haze (visible plume) in the atmosphere believed to be caused by the gas phase formation of solid ammonium sulfite-bisulfite and ammonium sulfate/bisulfate crystals during the treating step. The resulting solid-in-gas suspension is very difficult to eliminate, and intensive water scrubbing of the suspension is required to solubilize the highly dispersed salt particles. The finely dispersed salts are believed to be formed by the gas phase reaction of the sulfur oxides with ammonia present in the vapor phase. When the salt is formed in the liquid phase, no such blue haze appears, nor can it be generated from a concentrated ammonium sulfite/sulfate solution except by spray drying with a nozzle generating a highly atomized spray. The latter does not occur in a countercurrent absorption zone (i.e. gas scrubbing tower), pointing to the direct gas phase formation of the above mentioned salts as the source of the blue haze formation. The gas phase formation of solid ammonium salts is a function of the temperature and the partial pressure of the reactants, SO₂, SO₃, NH₃, and H₂O. Temperature is important since the ammonium salts involved, sulfite as well as sulfate are thermally unstable and will decompose above certain temperatures. The sulfate only decomposes at relatively elevated temperatures, so this is less of a consideration, but then only 10% or less of the total SO x in the flue gas is in the form of SO₃ which leads to sulfate formation. In contrast, the ammonium sulfite salts are very thermally unstable and will decompose (as well as not form) above about 68-75°C (155-160 °F). Consequently, the formation of solid ammonium sulfite/bisulfite, the believed source of blue haze will be very dependent on the SO₂ and NH₃ partial pressure. This would be so even if the actual composition of the solids making up the blue haze were principally ammonium sulfate, since this sulfate is easily produced by air oxidation of the solid ammonium sulfite once it is formed. Formation of solid ammonium sulfite-bisulfite under given conditions in the absorption zone (i.e. SO x removal zone) are expected to be decreased or eliminated, if the partial pressures of the main reactants, namely, ammonia and sulfur oxides, are kept below the level where a gas phase reaction can occur. The limiting condition can be expressed by specifying that the product of the partial pressures, expressed in (kPa)² millimeters of mercury squared (mm Hg)²), of the sulfur oxides in the gaseous mixture being treated and the ammonia over the aqueous absorbent composition, measured at 60°C (140° F) is not greater than about 0.0889 (kPa)² (5 (mm Hg)²), preferably not greater than about 0.0355 (kPa)² (2 (mm Hg)²), more preferably not greater than 0.0177 (kPa)² (1 (mm Hg)²), in the absorption zone. It is expected that solid formation can be prevented by using this partial pressure product limitation in conducting the absorption step under conditions in which there is a relatively high NH₃ partial pressure, provided the SO x partial pressure is very low, as well as at high SO x pressures, provided the ammonia partial pressure is very low. The SO₂ partial pressure in the gas entering the gas-liquid contacting zone (i.e. scrubber tower) is fixed, depending solely on the sulfur content of the fuel and the combustion conditions (excess air and percent conversion of the fuel sulfur into gaseous SO x ). Thus a 3% residual oil fuel burning with 10 to 20% excess air will produce a flue gas comprising 1400 ppm SO x . This means that the partial pressure of the SO x in the gas entering the atmospheric pressure absorption zone 12 via line 10 will be 0.133 kPa (1 mm H g ). The SO₂ partial pressure of the gas leaving gas-liquid contacting zone 12 via line 18, assuming 90% or more removal of the SO x will be 0.013 kPa (0.1 mm Hg) or less. The ammonia partial pressure over the aqueous absorbent composition descending absorption zone 12 between inlet 14 and exit 20 will not change significantly since, in order to assure good SO₂ removal, an excess of NH₃-comprising aqueous absorbent composition (e.g. treating solution) is used and the solution is frequently recirculated from 20 back to the top at 14. Consequently, the most critical point for blue haze formation is expected to be at the bottom of the absorption zone, and will be dependent on the ammonia partial pressure over the aqueous absorption composition. As shown in Table I, the ammonia partial pressure over an aqueous ammonia solution is more than tenfold that over an ammonium carbonate/and or bicarbonate solution comprising the same amount of total ammonia. Furthermore, since the SO x are anhydrides of stronger acids than CO₂, the neutralizing capacity of the ammonia in the aqueous ammonia solution is exactly as high as that in the ammonium carbonate/bicarbonate solution, since the SO x will completely replace the CO₂ in the latter Consequently, the carbonate/bicarbonate solution is as good an SO x -acrubbing solution as aqueous ammonia but with a much lower NH₃ partial pressure. It should be noted that the aqueous absorption composition at the bottom of absorption zone 12, believed to be the most critical region for the formation of blue haze solid salt particles, will not be aqueous ammonia or siionium carbonate/bicarbonate, but solutions in which some of the ammonium basicity is neutralized by SO x , such as SO₂. The extent to which the ammonia in these solutions is neutralized by SO₂ will depend on the specific operating conditions, the amount of recycle, the extent of ammonia utilisation per pass, but the ammonia partial pressure depressing effect of the carbonate and/or bicarbonate system is evident from the values given in Table II, which again shows systems at 60°C (140°F), 5 wt.% total NH₃, but now with some ammonia neutralized with varying amounts of SO₂. System comprising 0; 0.20, and 0.4 mole SO₂ per mole NH₃ are tabulated, again showing the calculated partial pressures over the following three different solutions: (a) assuming the NH₃ not tied up by the SO₂ to be free ammonia. (b) assuming the above untied NH₃ to be in the form of ammonium carbonate. (c) assuming the above untied NH₃ to be in the form of a 1/1 ammonium carbonate/ammonium bicarbonate composition. Note that the values for the zero mole/mole SO₂/NH₃ solutions are the same as those in Table I. Table II. Partial pressure, kPa (mmHg), of NH₃ over aqueous solutions comprising NH₃, CO₂ and SO₂ at 60°C (140°F). All solutions contain 5 wt.% total NH₃. Table II shows that in solutions containing SO₂, the addition of CO₂ has a such more pronounced depressing effect on the NH₃ partial pressure than in the non-SO₂-containing systems shown in Table I. However, it should be noted that some of the high CO₂-containing sytems in Table II have total pressures exceeding 101 kPa (760 mm Hg), and will, therefore, tend to evolve CO₂ to reach vapor pressure equilibrium. In summary, the addition of CO₂ to the aqueous absorbent compositions depresses the NH₃ partial pressure over the solution, whether it contains SO₂ or not, and this reduction in the NH₃ partial pressure at the most critical portion of the absorption zone, namely, at the bottom of the absorption zone where the incoming flue gas first meets the absorbent composition is believed to be sufficient to minimize formation of a blue haze. Moreover, it is known that the aqueous ammonia solution contacting a flue gas will absorb CO₂ as well as SO₂. However, it is well known that the absorption of SO₂ into an aqueous alkaline solution is rapid, while the absorption of CO₂ is very slow. Consequently, although a certain amount of ammonium carbonate will buildup in the circulating solution as a result of this CO₂ absorption, if free ammonia is added to the fresh absorbent entering absorption zone 12 at 14, free ammonia will be left in the solution at the bottom of the absorption zone, unless the amount of NH₃ added at the top is less than the stoichiometric amount required to neutralize the SO₂ absorbed in the absorption zone. It can be seen from Table II that if free NH₃ (not tied up with SO₂ nor with CO₂) is left in the solution, its NH₃ partial pressure will be quite high. The best way to avoid this undesired occurrence is to make up fresh ammonia reagent not in the form of anhydrous or aqueous ammonia, but in the form of ammonium carbonate, ammonium bicarbonate or mixtures thereof. In that case, the possibility of the presence of free ammonia with its concomitant high NH₃ partial pressure, at the critical bottom of the gas-liquid absorption zone, will be minimized, even when some CO₂ is given off from the solution during its descent through the absorption zone. Systems in which ammonium hydroxide is the scrubbing agent (i. e. absorbent), and circulating ammonium carbonate system where make-up ammonia is in the form of anhydrous or aqueous ammonia operate with the continuous emission of a blue haze. Systems where the circulating solution is an ammonium carbonate and/or bicarbonate solution also comprising sulfite and sulfate, and where the Make up consists of carbonate/bicarbonate, are not expected to exhibit a blue haze formation. In a further embodiment of the invention, not all the make-up ammonia has to be supplied in the form of carbonate-bicarbonate. If some of it is introduced at the top in the form of free ammonia, it will react with the SO₂ and to some extent with the CO₂ in the flue gas and form ammonium sulfite and some ammonium carbonate, leaving very little free ammonia at the bottom of the absorption zone to exert an appreciable NH₃ partial pressure and result in blue haze. There will be enough ammonium sulfite-ammonium carbonate in the system to prevent a high ammonia partial pressure. It is expected that 50 to 75% of the average required ammonia can be introduced into the solution 14 at the top of the absorption zone as ammonia, the remainder as ammonium carbonate or ammonium bicarbonate or mixtures thereof. However, this procedure can only be used if novhere in the absorption zone (e.g. tower) there exists blue haze forming conditions, which has been defined as the product of the SO X partial pressure and the ammonia partial pressure measured above the solution at 60°C (140°F), both expressed in kPa (mm Hg), which should not exceed about 0.0889 (kPa)² (5 (mm Hg)²), preferably not more than 0.0355 (kPa)² (2 (mm Hg)²). This definition allows for flexibility in the allowable ammonia partial pressure of the absorbent composition as it progresses through the countercurrent absorption zone. At the bottom portion of the absorpt ion zone, where the SO X concentration and partial pressures are a maximum of about 1400 ppm or about 0.133 kPa (1 mm Hg) at atmospheric pressure, the ammonia partial pressure must be a minimum, that is, not more than 0.667 kPa (5mm Hg), preferably not more than 0.267 kPa (2 mm Hg). Based on the data in Table II, this rules out any free ammonia, and at least a CO₂/NR₃ mole ratio corresponding to ammonium carbonate for the ammonia not tied up with SO x . Thus, when the SO₂/NH₃ ratio is 0.4, meaning that 40% of the NH₃ is tied up as (NH₄) H SO₃ in the solution, the remainder 60% of the NH₃ should be present at least as (NH₄)₂CO₃, preferably as a 1:1 mixture of (NH₄)₂CO₃ and (NH₄)HCO₃, which will keep the ammonia partial pressure over the solution below 0.267 kPa (2 mm Hg), preferably below 0.133 kPa (1 mm Hg). Thus, the product of SO₂ and NH₃ partial pressures at the bottom of the absorption zone will be less than 0.0355 (kPa)² (2(mm Hg)²). Near the top of the absorption zone where the SO x partial pressure is sharply reduced as a result of the absorption occurring in the contacting zone, the SO x partial pressure may be 0.0133 kPa (0.1 mm Hg) or less, depending on the SO x clean-up. Thus, the ammonia partial pressure at the top of the absorption zone can be as high as 6.67 kPa (50 mm Hg), preferably below 2.67 kPa (20 mm Hg), in order for the product to stay below 0.0889 and 0.0355 (kPa)² (5 and 2 (mm Hg)²), respectively. Referring to Table II, and assuming that the result of some recirculation of the aqueous absorbent composition from the absorption zone bottom to top, the SO₂/NH₃ ratio of the absorbent composition at the top is 0.2/1, the ammonia in the absorbent composition not tied up as (NH₄) H SO₃ should be present as ammonium carbonate or as a mixture of ammonium carbonate and a small amount of ammonia. In these circumstances the NH₃ partial pressure over the absorbent composition will be 11 mn Hg or a little higher which will give a satisfactory partial pressure product of less than 0.0889 or 0,0355 (kPa)²(5 or 2 (mm Hg)²). It is important to consider what happens to this solution as it progresses down through the absorption zone, as it absorbs both SO x such as SO₂ rapidly and CO₂, only slowly, as it contacts countercurrently the flue gas. The SO₂/CO₂/NH₃ composition at the top is 0.2/0.4/1.0. As the aqueous absorbent composition descends through the absorption zone, it will absorb the SO X , such as SO₂, in the flue gas, and the SO₂ content of the absorbent composition will increase from a SO₂/NH₃ ratio of 0.2/1 to 0.4/1. This would leave the CO₂/NH₃ ratio at 0.4/1 unless CO₂ is either absorbed into the absorbent composition or evolved from it. If a small amount of CO₂ is absorbed from the CO₂-rich flue gas, the CO₂ content may increase from 0.4 to 0.45/1 CO₂/NH₃, indicating a 1:1 ammonium carbonate to bicarbonate split in the NH₃ not tied up by the SO₂. However, it also be possible that some CO₂ is evolved from the descending solution, leaving it with a CO₂/NH₃ ratio below 0.4;1. This would indicate a greater than 1:1 ammonium carbonate to bicarbonate split in the NH₃ not tied up with the SO₂. If sufficient CO₂ is released from the solution to depress the CO₂/NH₃ ratio to 0.3/1 in the absorbent composition at the bottom of the absorption zone, then this indicates a mixture of ammonium bisulfite and only ammonium carbonate at the bottom of the absorption zone. Whether the absorbent composition releases or absorbs CO₂ in the absorption zone will depend on absorption temperature, initial composition of the aqueous absorbent composition, extent of spent absorbent composition, recycle from bottom to top of the absorption zone and the SO₂/SO₃ ratio in the SO X in the flue gas. It is evident that if the fresh absorbent composition introduced into the absorption zone in line 14 is aqueous ammonia or mixture of ammonia and ammonium sulfite (as a result of recycle of spent absorbent composition from bottom to top), the spent absorbent composition at the bottom of the absorption zone will have very little CO₂ in it (CO₂ absorbs very slowly into alkaline aqueous solutions) for example, 0 to 0.05 CO₂/NH₃, while the SO₂/NH₃ ratio will be, for example, 0.2 to 0.4. Under these conditions, the ammonia partial pressure will be 17.3 to 6.27 kPa (130 to 47 mm Hg), too high to give satisfactory NH₃·SO₂ partial pressure product of below 0,0889 or 0,0355 (kPa)² (5 or 2( mm Hg)²) anywhere in the absorption zone. This shows that the fresh ammonia make-up must be, to a considerable extent, in the form of ammonium carbonate or possibility of the appearance of a blue haze from the absorption process, the make-up ammonia introduced at the top of the absorption zone should be in the form of an ammonia/ammonium carbonate-bicarbonate mixture wherein not more than 25% of the ammonia is not neutralized by a carbonate ion, preferably where all the ammonia is tied up as a carbonate ion, and most preferably where about half the carbonate exits as carbonate and the other half as bicarbonate ion. In the latter case, two thirds of the ammonia is neutralized by carbonate and one third by bicarbonate ions. Some flue gas purification processes are conducted in an apparatus which comprises a device in which the liquid absorbent composition and the gas are contacted by energetic mising of the two phases in single stage contact followed by separation of the purified gas from the spent liquid, instead of being conducted in countercurrent gas-liquid absorption tower. A Venturi scrubber is an example of such a type of gas-liquid contacting process. The process of the present invention need not be conducted in a countercurrent gas-liquid contacting zone and may be conducted in an apparatus such a Venturi scrubber When such an apparatus is used to conduct the gas desulfurization process of the present invention, the fresh absorbent composition or fresh absorbent composition admixed with recycle spent absorbent composition contacts the gaseous mixture comprising the sulfur oxides to be purified. Since the gaseous mixture may have a SO x content as high as 1400 ppm or more, the SO x partial pressure may be 0.133 kPa (1 mm Hg) or more. In order to minimize the possibility of forming a blue haze during the gas desulfurization process, the NH₃ partial pressure of the absorbent composition injected into such an apparatus as described above must be below about 0.667 kPa (5 mm Hg), preferably below about 0.267 kPa (2 mm Hg), so that the partial pressure product remains below 0.0889 or 0.0355 (kPa)² (5 or 2 (mm Hg)²), as previously set forth. Consequently, referring to Table II and assuming the fresh and recycle liquid absorbent composition being injected into the Venturi scrubber has SO₂/NH₃ mole ratio of 0.2:1, the make-up NH₃ must be at least in the form of a 1:1 ammonium carbonate/bicarbonate, and preferably 0.5:1 so that the NH₃ partial pressure be sufficiently low to minimize the formation of a blue haze. It should be noted that for reasons such as convenience of supply, it may be easier to obtain and use anhydrous ammonia or its aqueous solution rather than an ammonium carbonate and/or ammonium bicarbonate absorbent composition; however, the use of anhydrous ammonia or its aqueous solutions in gas desulfurization processes exhibits the undesired blue haze in the atmosphere, whereas the use of the absorbent composition of the present invention with its low ammonia partial pressures will minimize the possibility of the formation of blue haze. Nevertheless, it is still possible to use aqueous ammonia in the process of the present invention by inserting a CO₂-absorption step in the absence of SO x . In such an embodiment of the invention, the CO₂ absorption step can be performed on a small portion of the total scrubbed, essentially SO x -free gaseous mixture either in a separate tower or in a portion of the main gas-liquid contacting zone (main tower) of the desulfurization stage. Only a small portion of the total gaseous mixture (e.g. flue gas), of the order of 1 to 10% of the total gas, is required for this step, since the CO₂ concentration in the gaseous mixture (flue gas) is of the order of 100 times the level of the SO x concentration. While the SO x concentration may be of the order of 1400 ppm or 0.14%, the CO₂ level is generally of the order of 10 to 15%, depending on the fuel, excess air, etc. However, due to the slow rate of absorption of CO₂ into alkaline aqueous solutions, sufficient liquid residence time must be built into this absorption system to ensure the required CO₂-NH₃ reaction in the liquid phase. While a contact time of the order of 30 seconds to 2 minutes is generally sufficient for the liquid in the scrubber tower to remove the SO x , a higher residence time, of the order of 10 to 30 minutes is required in the CO₂-absorber to accomplish satisfactory conversion of the aqueous ammonia in the feed to ammonium carbonate/bicarbonate to be used in the SO x -scrubber. Good contacting and sufficient contact time in the CO₂ scrubbing step may be achieved, for example, by recirculating the absorbent composition from the bottom of the CO₂-scrubber back to the top. This also minimizes the NH₃ partial pressure at the top of the tower, and reduces the load on any water washing step at the top of that tower to minimize the loss of ammonia in the CO₂-depleted flue gas portion leaving the top of that tower. Suitable SO x absorption conditions include an inlet temperature of the absorbent composition during the absorption step ranging from about 38 to about 60°C (about 100 °F. to about 150 °F), preferably from about 41 to about 60°C (about 105 °F to about 140 °F). Pressures may vary widely. Typically, the absorption process is conducted at atmospheric pressure. The absorption zone effluent comprising a decreased amount of sulfur oxides relative to the amount of sulfur oxides present in the gaseous mixture of line 10 and including the CO₂ formed by reaction with the absorbent composition, is removed overhead from the absorption zone by line 18. An aqueous medium (solution or aqueous slurry) comprising an ammonium salt of an inorganic acid of sulfur, such as ammonium sulfate, ammonium sulfite, ammonium hydrogen sulfate, ammonium hydrogen sulfite and mixtures thereof, as well as unreacted ammonium carbonate and/or bicarbonate, is removed from the bottom of absorption zone 12 by line 20 for possible recycle to the top of the absorption zone and for further processing, such as evaporation, oxidation, briquetting, conversion to elemental sulfur, etc. In an other embodiment of the invention, the sulfur oxides removal step (i.e. desulfurization) is integrated with a nitrogen oxides (NO x ) removal step to purify a gaseous mixture comprising sulfur oxides as well as nitrogen oxides, as described in the following description. The gaseous mixture so which the content of one or more types of nitrogen oxides (hereinafter designated NO x ) and one or more types of sulfur oxides (hereinafter designated SO x ) can be decreased with the integrated process of the present invention include exhaust gases from internal combustion engines either stationary or mobile, tail gases from nitric acid plants or chemical nitration operations, exhaust gases from combustion of fossil fuels in power plants, industrial boilers, etc. Preferably, the gaseous mixture is a combustion effluent, i.e., an effluent derived from a combustion process. The exhaust gases may comprise from about 20 vppm to about 1 volume percent NO x and from about 0.005 to about 5 volume percent sulfur oxides. When the exhaust gas is derived from a combustion process, the gas may comprise from about 0 to about 20 volume percent O₂, typically from 0.1 to 6 volume percent O₂. A gaseous mixture of the type described above, for example, a combustion effluent comprising one or more types of nitrogen oxides and one or more types of sulfur oxides is contacted, in the presence of oxygen, and in the absence of a catalyst, with a reducing agent at conditions to reduce the nitrogen oxides selectively to N₂. The reducing agent comprises an excess amount of ammonia or ammonia precursor such as ammonium hydroxide, ammonium formate, ammonium oxalate, ammonium carbonate, ammonium bicarbonate and mixtures thereof, and aqeuous solutions thereof. Preferably, at least a portion of the ammonia is provided by using an aqueous composition comprising an ammonium salt selected from the group consisting of ammonium carbonate, ammonium bicarbonate and mixtures thereof. More preferably, at least a portion of the ammonia is provided by using an aqueous composition comprising the same ammonium salt or salts as the one used in the subsequent desulfurization step. The aqueous composition comprising an ammonium salt selected from the group consisting of ammonium carbonate, ammonium bicarbonate and mixtures thereof is sprayed into the gaseous mixture in the deNO x contacting zone. By "excess amount" is intended herein a molar ratio of ammonia to NO x greater (i.e., in excess) than the molar ratio required to reduce all the NO x present in the gaseous mixture being treated to N₂. The stoichiometric NH₃/NO x ratio is 1/1. Suitable molar amounts of ammonia may be equal to the sum of about 1.0 to 3.0 times the number of moles of NO x plus about 0.01 to 2.0 times the number of moles of SO x present in the gaseous mixture being treated, typically from the sum of about the moles of NO x plus 0.02 times the moles of sulfur oxides to the sum of 2.5 times the moles of nitrogen oxides plus the moles of sulfur oxides. The excess amount of ammonia which may be used will depend to a large extent on the NO x to SO x mole ratio in the gas to be treated. For example, when this ratio is 1/3, and it is desired to remove the SO x as the ammonium sulfite/sulfate salt, 2 moles of NH₃ per mole of SO x will be required for the SO x removal. Since, in this example, the NO x /SO x ratio in the gas is 1/3, and the stoichiometric NH₃/NO x ratio is 1/1, the excess amount of NH₃ which can be usefully employed in the SO x removal step is 6 moles of NH₃/mole NO, indicating that a NH₃/NO x ratio in the feed gas of 7 can be employed in both the NO x and SO x removal steps. In general, the total moles of ammonia added to the process, both for nitrogen oxides removal and sulfur oxides removal, will range from about 1.0 to 2.5 times the sum of the total number of moles of said nitrogen oxides and said sulfur oxides. However, as will be described subsequently, it is advantageous not to add all the stoichiometrically required NH₃ for the SO x removal step as excess amount of NH₃ in the feed gas to the NO x removal step since there may be some undesired thermal decomposition of a fraction of this ammonia during the deNO x step, as well as some NH₃ oxidation. Therefore, the excess amount of NH₃ added to the raw feed gas to the deNO x step, is limited to the marginal optimum excess amount, defined as the excess amount above which no improvement in the degree of denitrogenation is achieved. This marginal optimum excess amount of NH₃ is in the range of about 0.1 NH₃/NO x mole ratio to about 5.0, typically 1.0 to 3.0. While excess amounts of NH₃ above this marginal optimum amount can effectively be used up in the SO x removal step, their presence does not significantly improve the NO x removal efficiency and may lead to potentially excessive NH₃ loss due to thermal and oxidative decomposition. Therefore, if the NO x /SO x ratio is such that the required NH₃ for the SO x removal would indicate a tolerable excess amount of NH₃ fo 5/1, NH₃/NO x mole ratio, i.e., a 6/1 NH₃/NO x ratio in the feed gas to the deNO x step and if the marginal optimum excess amount is only 1/1, then it is preferred to operate as closely as possible to an excess amount of 1/1, i.e., have an NH₃/NO x mole ratio of 2/1 in the feed to the deNO x step, but add the additional NH₃ as part of the deSO x step, so that the temperatures will be lower and the NH₃ losses due to thermal and oxidative decomposition will be minimized. To reduce all the NO x present in the gas to N₂, at least 1 mole NH₃ per mole NO x is required. The ammonia may be derived from a suitable precursor. The NO x reduction step may be conducted at a temperature ranging from about 704 to about 1204°C (about 1300 to about 2200 °F). When ammonia alone is used as reducing agent, the preferred temperature may range from 871 to 1204°C (1600 to 2200°F). When ammonia is used with the additional reducing agent, such as hydrogen, a temperature ranging from about 704 to about 871°C (about 1300 to about 1600°F ) may be used. Suitable amounts of molecular oxygen in the NO x reduction step include at least about 0.1 volume percent, preferably a range from about 0.1 to 20 volume percent, typically from 0.1 to 6 volume percent based on the gaseous mixture to be treated. The molecular oxygen may be present in the gas to be treated such as in combustion effluents or a suitable amount of oxygen may be added to give the desired amount. Suitable additional reducing agents include paraffins, olefins, aromatic hydrocarbons, oxygenated hydrocarbons, nitrogenated hydrocarbons, sulfonated hydrocarbons, carbon monoxide and hydrogen. Hydrogen is the preferred additional reducing agent suitably added at a hydrogen to ammonia ratio of less than 10, preferably less than 3. However, it should be noted that compared to a stand-alone (i.e., non-integrated) deNO x process, there is less need for the use of an additional reducing agent in the integrated deNO x /deSO x process of the present invention because the excess ammonia can be used advantageously to reduce the amount of an additional reducing agent, since the combined operation disposes of the excess NH₃ which is presently unused in the effluent of the deNO x step. It should be noted, however, that the ability to use higher molar ratios of NH₃/NO x than in stand-alone deNO x processes also permits the use of wider ratios of additional reducing agents to ammonia than would be possible in stand-alone operations. The pressure during the NO x reduction step may range from 10.1 to 1031 kPa (0.1 atmosphere to 100 atmospheres). The residence time of the reaction of the NO x and SO x -containing feed gas with the ammonia may range from 0.001 to 10 seconds. Contact of the feed gas with the ammonia (or ammonia precursor) at the NO x reduction conditions produces a gaseous effluent comprising unreacted ammonia, sulfur oxides, nitrogen and H₂O. The effluent from the denitrogenation zone may pass through one or several energy recovery steps before being introduced into the desulfurization zone. These energy recovery steps may be heat recovery, e.g. for the purpose of raising steam, or gas expansion, e.g. for the purpose of direct power generation from the hot flue gas. At least a portion of the entire NO x reduction zone gaseous effluent comprising unreacted ammonia then is passed to an absorption zone (desulfurization zone) to contact an aqueous absorbent composition comprising an ammonium salt selected from the group consisting of ammonium carbonate, ammonium bicarbonate and mixtures thereof. The concentration of the ammonium salt in the absorbent composition may range from about 15 to about 65 wt.%, calculated as if all the salt or salts existed as ammonium carbonate. A sufficient amount of the aqueous ammonium salt absorbent composition is introduced into the absorption zone to provide a mole ratio of at least 0.5 mole of ammonium salt (expressed as ammonium carbonate) per mole of sulfur oxide present in the gaseous effluent, preferably a mole ratio of salt to sulfur oxide ranging from about 0.5:1 to about 5:1, more preferably from about 0.55:1 to about 1.2:1. The concentration of the ammonium salt (or salts) in the initial composition and the mole ratio of ammonium salt to sulfur oxides in the gaseous mixture to be treated are selected in such a manner that the product of the partial pressure of said sulfur oxides and ammonia over the aqueous composition, measured at 60°C (140 °F), is not greater than about 0.0889 (kPa)² (5(mm Hg)²), preferably less than about 0.0355 (kPa)² (2 (mm Hg)²), more preferably less than about 0.0177 (kPa)² (1 (mm Hg)²) anywhere in the absorption zone. The same constraints as to permissible NH₃ partial pressure over the absorbent composition as described relative to the SO x -only removal operation (i.e. non-integrated desulfurization process), apply to the combined deNO x -deSO x operation to minimize the possibility of blue haze formation. It should be noted that the excess NH₃ (unreacted NH₃) present in the deNO x stage effluent of the order of 500 ppm or less, is far too low to cause blue haze formation shead of the deSO x absorption zone. At atmospheric pressure, 500 ppm NH₃ corresponds to a partial pressure of about 0.4 mm Hg, so that the partial pressure product of NH₃ and SO₂, which must be below 0.0889 (kPa)² (5(mm Hg)²), preferable below 0.0355 (kPa)² (2 (mm Hg)², will only be 0.00711 (kPa)² (0.4 (mm Hg)²), when the SO₂ content is 1400 v ppm (partial pressure of 0.141 kPa (1.06 mm Hg)). Therefore, the excess (unreacted) NH₃ in the deNO x effluent does not, by itself, cause a blue haze problem, but if additional ammonia is added as such or as aqueous ammonia, then the ammonia partial pressure would exceed tolerable limits and the formation of blue haze would be expected to occur. However, addition of the stoichiometrically required NH₃ in the form of aqueous ammonium carbonate and/or ammonium bicarbonate solution will provide a sufficiently low NH₃ partial pressure to minimize formation of a blue haze It should be noted that the presence of some NH3, the unreacted ammonia from the deNO x step, in the feed to the deSO x absorption tower does not affect the liquid absorbent concentration and composition consideration at the bottom of the absorption tower, such as set forth above. The NH₃ in the feed gas and the ammonia in the vapor phase above the solution as a result of the ammonia vapor pressure are not additive but are fixed by vapor pressure considerations. However, to ensure that the composition of the absorbent solution at the bottom of the absorption tower in the combined deNO x -deSO x process, has as high a CO₂/NH₃ ratio as in the absorpt ion tower of the deSO x alone (non-integrated) embodiment, additional CO₂ may be introduced into the absorption zone with the fresh absorbent composition entering at 14. This additional CO₂ should be at least 1 mole/mole NH₃ entering the bottom of the absorption zone as excess (unreacted) NH₃, preferably 1.5 mole/mole NH₃.Therefore, if the unreacted NH₃ from the deNO x stage represents x% of the total stoichiometric NH₃ requirement for deSO x absorption stage, and a stand-alone (i.e. non-integrated) deSO x would require for its NH₃ make-up to be fed as 0 5/l CO₂/NH₃ solution, the integrated deSO x -deNO x process's deSO x -absorption zone make-up should be 0.5/(1-0.01x) CO₂/NH₃, preferably 0. 5/(1-0.015x) CO₂/NH₃. Thus, if the unreacted NH3 from deNO x represents 20% of the total NH₃ required for deSO x -absorption, and previously mentioned considerations would have required that, for the stand-alone (non-integrated) deSO x process, the ammonia be fed as ammonium carbonate i.e. CO₂/NH₃=0.5/1, then for the integrated deNO x -deSO x process, the top of the absorption zone should be fed a make-up NH₃ solution with a CO₂/NH₃ mole ratio of at least 0.5/(1-0.20)=0.625/1 The treated gas product, having a decreased amount of SO x , is removed from the absorption zone and may be vented to the atmosphere. Suitable conditions in the absorption zone include a temperature ranging from about 38 to about 66 °C about 100 to about 150 °F), preferably a temperature ranging from about 41 to about 60°C (about 105 to about 140 °F), at atmospheric pressure. The reaction of the sulfur oxides with the ammonium carbonate and/or ammonium bicarbonate at these conditions results in the formation of ammonium salts of inorganic acids of sulfur in the aqueous liquid medium and evolution of carbon dioxide gas. The latter is removed from the absorption zone with the treated gaseous effluent. The aqueous liquid medium (solution or slurry) comprising the ammonium salts of inorganic acids of sulfur is removed from the absorption zone. It may be desirable to remove a substantial portion of the water associated with the ammonium salts. The ammonium salts may be recovered and used as such for further use or the recovered salts may be decomposed to form elemental sulfur. When the ammonium salts are to be recovered as such for use, for example, as fertilizer or as a component of a fertilizer composition, it may be desirable to convert any ammonium sulfite that may be present in the recovered ammonium salts to ammonium sulfate by oxidation in a conventional way such as, for example, by air blowing of the salt solution. When it is desired to produce elemental sulfur, the ammonia to SO x mole ratio in the recovered ammonium salts should be at least equal to the stoichiometric quantity for conversion of the chemically combined sulfur in the recovered ammonium salts to elemental sulfur, for example, a mole ratio of at least 4/3 when all the sulfur in the salts is present as sulfite. When all the sulfur in the recovered salts is present as sulfate, the stoichiometric ratio is 2/1. The decomposition of the ammonium salts to elemental sulfur may be performed according to any known method. A method is described in U.S.-A-4,029,752, the teachings of which are hereby incorporated by reference, in which the ammonium salts are decomposed by high temperature oxidation-reduction reaction into a mixture comprising elemental nitrogen and elemental sulfur in one or two steps. In the one step method, the ammonium salts are introduced into a high temperature reaction zone maintained at a temperature of 260 to 1649 °C (500 to 3000 °F), preferably 482 to 816°C (900 to 1500 °F) and, optionally, in the presence of a catalyst. When the decomposition of the ammonium salts to elemental sulfur is thermal, a preferred decomposition temperature is above 649°C (1200 °F), more preferably from about 816 to about 1649°C (about 1500 to about 3000 °F). When the decomposition of the ammonium salts to elemental sulfur is performed in the presence of a conventional catalyst, the decomposition temperature may range preferably from about 260 to about 1094 °C (about 500 to about 2000 °F), more preferably from about 482 to 816°C (about 900 to about 1500 °F). Alternatively, the ammonia salts may be decomposed in two steps by first decomposing the ammonium salts thermally et a temperature ranging from 107 to 427 °C (225 to 800 °F) into a gaseous mixture comprising ammonia, sulfur oxides (SO₂ and SO₃) and water vapor. The gas mixture resulting from the first step, if desired after removal of water vapor, is subsequently introduced into a high temperature reaction zone where the ammonia reacts with the sulfur oxides at a temperature ranging from 260 to 1649°C (500 to 3000 °F) to form a reaction product comprising nitrogen and elemental sulfur. The following prophetic examples and comparative examples, all of which are paper examples, are presented to illustrate the invention. Comparative Example A A flue gas from the combustion of a 3% sulfur residual oil, comprising 1400 vppm SO x , is contacted (scrubbed) with an aqueous solution comprising 5 wt.% NH₃ to remove 95% of the contained SO x For purpose of this example, it is assumed that the SO x is considered to be all SO₂. Contacting is performed at 60°C (140 °F) by mixing a 20% stoichiometric excess of the ammonia solution together with any water effluent from an NH₃ absorption tower, with the flue gas which has been cooled to 60°C (140 °F), separating the two phases, and recovering any ammonia in the treated flue gas by scrubbing with water in a countercurrent NH₃ absorption tower. The treated flue gas leaving the unit will exhibit a blue haze (visible plume) believed to be the result of the formation of colloidal ammonium sulfite/bisulfite suspension, which is not removed by countercurrent water scrubbing in the NH₃ absorption tower. In this operation, the SO₂ partial pressure in the contacting zone starts at 0.141 kPa (1.06 mm Hg) and drops to 5% of this value, or 0.0071 kPa (0.053 mm Hg). The NH₃ partial pressure of the initial 5 wt. % aqueous NH₃ solution is over 28.7 kPa (215 mm Hg), and drops to about 5.33 kPa (40 mm Hg), since over 80% of the NH₃ is neutralized by the SO₂. The NH₃ and SO₂ partial pressure products in the contactor are: Initial P SO 2 x P NH 3 = 0.141 kPa x 28.7 kPa = 4.05 (kPa)² (1.06 mm Hg x 215 mm Hg = 228 (mm Hg)²) Final P SO 2 x P NH 3 = 0.0071 kPa x 5.33 kPa = 0.0378 (kPa)² (0.053 mm Hg x 40 mm Hg= 2.1 (mm Hg)²) Comparative Example B The same flue gas as in Comparative Example A is again treated with a 20% excess of a 5 wt.% aqueous NH₃ solution, but treatment is carried out in a multistage countercurrent contacting tower provided with a top scrubbing section where water is used, as previously. to recover NH₃ left in the treated flue gas. Again, a blue haze is found which persists throughout the scrubbing system and leaves the plant with the treated flue gas. The partial pressure of NH₃ and SO₂ and the partial pressure product, at the top and bottom of the SO₂ removal tower are given in Table III. It should be noted that the partial pressure product in the contactor, as in Comparative Example A, is above the upper limit of 0.0889 (kPa)² (5 (mm Hg)²) specified in the present application for this operation. Comparative Example C The same operation as in Comparative Example B is performed, except that the treating solution is a mixture of aqueous ammonia and ammonium carbonate in which only one half the ammonia is introduced as carbonate. Thus, the CO₂/NH₃ mole ratio at the top of the SO₂-scrubber is 0.25/1, and it may increase or decrease as the solution proceeds down the tower absorbing SO₂ depending on whether the CO₂ is released into or absorbed from the CO₂-containing flue gas, a complex interplay between CO₂ partial pressures of NH₃-CO₂-SO₂-H₂O solutions and the flue gas composition and operating temperature. Consider the case in which the CO₂ content of the solution stays unchanged The composition at the bottom of the tower will be SO₂/CO₂/NH₃=0.417/0.25/1.0, since the NH₃ introduced at the top is in 20% stoichiometric excess. Again, it is expected that a blue haze would appear in the gaseous effluent of the tower. The partial pressure of NH₃ and SO₂ and the partial pressure products at top and bottom will be as shown in Table IV. Again, the partial pressure product is above the upper limit of 0.0889 (kPa)² 5 (mm Hg)² specified in the present application. Example 1 The treating conditions and flue gas are the same as those given in the Comparative Examples, except that ammonia is introduced as ammonium carbonate i.e. with a CO₂/NH₃ mole ratio of 0.5/1. Some CO₂ is assumed to be evolved from the descending absorbent solution as the SO₂ is being absorbed, resulting in bottom composition of SO₂/CO₂/NH₃ of 0.417/0.4/1. Blue haze is not expected to occur in this operation. The partial pressure and the partial pressure products are as shown in Table V. The partial pressure product in Example 1 is within the range required by the present invention. Comparative Example D The flue gas conditions of comparative Example D are typical of combustion products from a boiler firing a medium sulfur-containing coal. For such processes, it is generally desirable to achieve high deNO x rates with less than 10 vppm residual NH₃ in the flue gas. As can be seen from Table VI, the deNO x rate to maintain less than 10 vppm residual NH₃ is calculated to be a low value of less than 40%. However, if the residual NH₃ can be increased to approximately 150 vppm, then the deNO x rate of greater than 90%, is expected to be achieved. In this case, a residual NH₃ concentration of at least 1400 vppm (equal to the SO₂ concentration) could be used since an NH₃-based deSO x process downstream will consume the excess NH₃. It should also be noted that Table VI shows that it is desirable to add the bulk of the excess NH₃ just upstream of the deSO x process where the flue gas is colder to conserve consumption of NH₃. As shown by the calculated results for NH₃/NO x = 2.5 and 3.0, there is an increase in the NH₃ injection rate of 200 vppm, but the NH₃ residual increases only 190 vppm (from 497.5 to 687.5 vppm). Under these two conditions, the NO x reduction remains essentially constant. Thus, the amount of ammonia which should be injected for NO x removal purposes should be between 2.5 and 3.0 times the NO xi concentration of 400 vppm, or between 1000 and 1200 vppm. This amount is, as previously specified, between the sum of the moles of NO x (i.e., 1 x 400 = 400 vppm), plus 0.02 times the moles of SO x (0.02 x 1800 = 36 vppm), or 436 vppm, and the sum of 2.5 times the moles of NO x (2.5 x 400 = 1000 vppm), plus the moles of SO x (1 x 1800 = 1800 vppm), or 2800 vppm. When a NH₃/NO xi of 2.5 is used, i.e., 1000 vppm of NH₃, the residual NH₃ in the deNO x zone effluent, per Table VI, is 497.5 vppm; to remove 1400 moles of SO₂ quantitatively as (NH₄)₂SO₃, 2800 vppm of NH₃ will be required. Since about 500 vppm are already in the gas, only about 2300 vppm additional ammonia has to be added to accomplish the SO x removal. The flue gas leaving the NO x removal zone when 1000 vppm NH₃ are injected will comprise 497.5, about 500 vppm of residual NH₃ and (0.015) x 400 or 6 vppm NO x . Sulfur oxides, such as SO₂, are not affected by the NO x removal and are still at 1400 vppm. The partial pressure product of this gas, prior to entering the SO x scrubbing tower, is 0,141 kPa x 0,057 kPa = 0,0071 (kPa)²(1.06 mm Hg x 0.38 mm Hg = 0.4 (mm Hg)²) or below the pressure range in which blue haze formation is expected. When this gas is introduced into a SO x scrubber utilizing aqueous ammonia as absorbent composition, conditions in the scrubber will be as in Comparative Example B, Table III, and the conditions will be within the range in which formation of a blue haze would be expected. Example 2 The operation of Comparative Example D is repeated except that instead of using aqueous ammonia as absorbent composition, an aqueous ammonium carbonate/bicarbonate absorbent composition is used having a CO₂/NH₃ mole ratio of 0.5/(1-0.2) = 0.625/1. The 0.2 represents the 20% of the ammonia required for SO₂ absorption which is present in the flue gas as unreacted (excess) ammonia left over from the deNO x operation. The conditions at the bottom of the tower will be the same as in Example 1, since the excess ammonia from the deNO x operation will be absorbed into the descending aqueous absorbent composition, or alternatively, the equivalent amount of NH₃ will not be released from the aqueous absorbent composition to meet its NH₃ partial pressure requirement. Furthermore, some CO₂ will be released as the aqueous absorbent composition descends in the tower. The composition of the aqueous absorbent at the top is, therefore, 0/0.625/1 SO₂/CO₂/NH₃, and 0.417/0.4/1 SO₂/CO₂/NH₃ at the bottom. The partial pressures and partial pressure products are shown in Table VII. Under the conditions shown in Table VII, a blue haze is not expected to form since the conditions fall within the ranges defined in the present invention. Note that the effluent flue gas comprises 6 vppm NO x and 70 vppm SO x which is well within even the most stringent emissions limitations presently imposed.

Claims: A process for absorbing sulfur oxides from a gaseous mixture containing the same, which comprises contacting, in an absorption zone, at absorption conditions, said gaseous mixture with an aqueous absorption composition comprising an ammonium salt selected from the group consisting of ammonium carbonate, ammonium bicarbonate, and mixtures thereof, in an amount such that the product of the partial pressures of said sulfur oxides and ammonia over said aqueous composition, measured at 60°C (140°F), is not greater than 0.0889 (kPa)² (5 (mm Hg)²), preferably less than about 0.0355 (kpa)² (2 (mm Hg)²), in said absorption zone, to produce a gaseous product having a decreased content of said sulfur oxides. The process of claim 1, wherein said sulfur oxides-containing gaseous mixture is contacted with said ammonium salt-containing aqueous composition in an amount sufficient to provide a mol ratio of at least 1 mol of ammonia contained in said salt per mol of said sulfur oxides, preferably a mol ratio of ammonia in said salt to said sulfur oxides ranging from about 1:1 to about 10:1. The process of claim 1 or claim 2, wherein said aqueous composition has a CO₂/NH₃ mol ratio of at least 0.5:1, preferably at least 0.75:1. The process of claim 3, wherein said aqueous composition having a CO₂/NH₃ mol ratio of at least 0.5:1 is prepared by scrubbing at least a portion of said scrubbed, essentially sulfur oxide-free gaseous mixture with an aqueous ammonia solution. The process of any one of claims 1 to 4, wherein said absorption conditions include a temperature ranging from about 38°C (100°F) to about 66°C (150°F), A combination denitrogenation and desulfurization process which comprises the steps of: (a) contacting a gaseous mixture comprising nitrogen oxides and sulfur oxides in the presence of oxygen and in the absence of a catalyst, with ammonia in a molar amount equal to the sum of about 1.0 to about 3.0 times the mols of said nitrogen oxides plus about 0.01 to about 2.0 times the mols of said sulfur oxides to reduce said nitrogen oxides to nitrogen, at a temperature ranging from about 704 to about 1204°C (1300 to 2200°F); (b) subjecting the gaseous product resulting from step (a) comprising nitrogen, said sulfur oxides and unreacted ammonia to a process according to any one of claims 1 to 5, to produce a gaseous effluent having a decreased amount of said sulfur oxides, and an ammonium salt of an acid of sulfur; and (c) recovering said ammonium salt of an acid of sulfur. The process of claim 6, wherein in step (b), the aqueous absorption composition has a CO₂/NH₃ mol ratio of at least 0.5/(1-0.01x), preferably at least 0.5/(1-0.015x), wherein x is the % of NH₃ required for SO x removal supplied by said unreacted ammonia of said gaseous product resulting from step (a). The process of claim 6 or claim 7 wherein said ammonia in step (a) is present in a molar amount ranging from the sum of about the mols of said nitrogen oxides plus 0.02 times the mols of said sulfur oxides to the sum of 2.5 times the mols of said nitrogen oxides plus the mols of said sulfur oxides. The process of any one of claims 6 to 8 wherein in step (a) said gaseous mixture is contacted with said ammonia and with an additional reducing agent and wherein said temperature in step (a) ranges from about 704 to about 871°C (1300 to about 1600°F). The process of any one of claims 6 to 9 wherein said recovered ammonium salt is heated to a temperature ranging from about 260 to about 1649°C (500 to 3000°F) to produce elemental sulfur. The process of any one of claims 6 to 9 wherein said recovered ammonium salt is decomposed at a temperature ranging from about 107 to 427°C (225 to 800°F) into a gaseous mixture comprising ammonia and sulfur oxides and, subsequently, the resulting sulfur oxides and ammonia are reacted at a temperature ranging from about 260 to about 1649°C (500 to 3000°F) to produce elemental sulfur. The process of any one of claims 6 to 9 wherein said recovered ammonium salt comprises ammonium sulfite and wherein said ammonium sulfite is subjected to oxidation to form ammonium sulfate. The process of any one of claims 6 to 12 wherein said gaseous mixture of step (a) is a combustion effluent.

Inventors: CAHN ROBERT PAUL, HURST BOYD EDWARD, CAHN, ROBERT PAUL, HURST, BOYD EDWARD
Applicants: EXXON RESEARCH ENGINEERING CO, EXXON RESEARCH AND ENGINEERING COMPANY
Application year: 1990
Main classification: B01D53
IPC codes: B01D53, C01C1, C01B17