AU2001265303A1

AU2001265303A1 - Low nitrogen oxides emissions using three stages of fuel oxidation and in-situ furnace flue gas recirculation

Info

Publication number: AU2001265303A1
Application number: AU2001265303A
Authority: AU
Inventors: Robert A. Ashworth
Original assignee: Clearstack Combustion Corp
Current assignee: Clearstack Combustion Corp
Priority date: 2000-06-08
Filing date: 2001-06-01
Publication date: 2002-03-07
Anticipated expiration: 2021-06-01

Description

TITLE

LOW NITROGEN OXIDES EMISSIONS USING THREE STAGES OF FUEL OXIDATION AND IN-SITU FURNACE FLUE GAS RECIRCULATION

Continuation-in-Part

This application is a continuation-in-part of patent application Serial No. 09/243,501 filed

February 3, 1999, now U.S. Patent No. 6,085,674.

BACKGROUND OF THE INVENTION

1. Field of The Invention

This invention relates to a method that uses combustion techniques to reduce nitrogen

oxides from the combustion of carbonaceous fuels to very low levels. More particularly, it refers

to a combustion technique that uses two sequential stages of partial oxidation followed by a final stage of complete oxidation. In-situ furnace flue gas recirculation is incorporated in the second

stage of partial oxidation to effect a cooler oxidation zone with lower localized oxygen

concentrations.

2. Description of The Prior Art

There are several patents that describe staged combustion techniques to reduce nitrogen

oxides emissions from the combustion of fuels containing nitrogen. U.S. Patent No. 3,727,562

describes a three stage process for reducing nitrogen oxides (NO_x) emissions wherein the first stage of combustion is operated with a deficiency of air and the unbumed fuel from this stage is

separated and burned in a second zone with excess air and then the first and second stage gases

are burned in a third excess air stage. U.S. Patent No. 4,343,606 describes a multi-stage combustion process wherein fuel gas produced in a first stage partial oxidation zone, operated at

a stoichiometric air to fuel ratio of 0.50 to 0.625, followed by a second stage of oxidation

operated at an air to fuel stoichiometric ratio of 1.0 or slightly greater. Following this, additional

air is added to insure that the fuel is completely oxidized. Other patents describe external flue gas recirculation such as U.S. Patent 5,002,484 for reducing NOx emissions. Still others use flue

gas recirculation within the burners proper, e.g. U.S. Patents 5,316,469 and 5,562,438 to reduce NOx emissions. While these methods accomplish their intended purposes, they do not provide the NOx reduction required under current U.S. Environmental Protection Agency (EPA)

regulations.

The Clean Air Act Amendments of 1990 set NOx emission limits for coal-fired utility

boilers to be met in the year 2000, that range from 0.40 to 0.86 lb NOx/10⁶ Btu depending on

boiler type and many ofthe patented techniques mentioned above could have been used to meet

these limits. However, in response to the Ozone Transport Assessment Group (OTAG) State Implementation Plan (SIP) call to Eastern and Mid- Western States in 1998, the U.S. EPA has

promulgated new rules for nitrogen oxides emissions for all types of coal-fired boilers that will

require emissions of 0.15 lb NOJ 0⁶ Btu or less during the ozone season (May through

September) in the year 2003.

The combustion technologies commercially available today cannot meet this limit. The

only technology available to the carbonaceous fuel fired utility boiler industry that will guarantee

this low level of NOx emissions is the Selective Catalytic Reduction (SCR) technology. The

SCR method uses ammonia addition and a downstream catalyst to destroy the NOx produced in the coal combustion process. This approach is expensive both from capital and operating cost perspectives. Further, arsenic in the coal can poison the catalyst, shortening its life. Also, ammonium sulfites/sulfates and calcium sulfates from the combustion process can blind the catalyst, thereby reducing its effectiveness.

Therefore, it would be very advantageous to have an improved combustion process that

will yield nitrogen oxide emissions, when firing carbonaceous nitrogen containing fuels, of 0.15

lb NOJ 0⁶ Btu or less. Such a system will also provide a lower cost per ton of NO_x reduced compared to SCR to provide the electric utility industry an economical technology to meet the newly promulgated level of nitrogen oxides emissions.

The staged combustion with in-situ furnace flue gas recirculation method ofthe present

invention is less costly than SCR technology in achieving these reductions and since catalyst,

which can be poisoned from the products of carbonaceous fuel combustion, is not required,

staged combustion with in-situ furnace flue gas recirculation represents a more reliable

technology.

SUMMARY OF THE INVENTION

I have discovered a process employing staged combustor and in-situ furnace flue gas

recirculation techniques into one system that will reduce NO_x emissions to the Year 2003

regulated limit of < 0.15 lb. NOx/10⁶ Btu. To accomplish staged combustion, any ofthe first stages of existing staged combustors can be used wherein the air to fuel stoichiomeliic ratio (SR)

can be operated in the 0.50 to 0.70 range. These types of staged combustors are described for

example in U.S. Patent Nos. 4,423,702; 4,427,362; 4,685,404; 4,765,258 and 5,458,659, each of

which is hereby incorporated by reference herein. Such staged combustion methodologies may

also add alkali compounds to reduce the coal ash slag viscosity and/or to capture sulfur in the molten slag. Although any staged combustor type could be used, the preferred types are those that remove molten slag from the combustor proper to minimize ash carryover and reduce slag fouling in the boiler furnace. Further, cyclone furnaces that operate under excess air conditions

may be retrofitted to implement the three stage combustion technique.

Typically, coal is fired in the first stage ofthe combustors under a stoichiometric ratio (SR) of air to coal of about 0.50 to 0.70 to minimize the NO_x produced from the oxidation of fuel bound nitrogen. A fuel gas is produced and molten slag separated out. In the second stage of

combustion, preheated second stage combustion air is introduced into the fuel gas produced in the first stage using a plug flow method of coal/air mixing, an air rate being added to yield an

overall SR at this point of about 0.85 to 0.99. The hot second stage air is preferably delivered in an outer annulus surrounding a pipe carrying the fuel gas, and is coned inward to the outlet ofthe

central fuel gas pipe entering the furnace. This method of air entry provides for rapid mixing and

high localized flame temperatures under a reducing atmosphere to yield the high temperature

condition that provides for high combustion efficiency (defined as low unbumed carbon content

in ash). Alternatively, the second stage combustion air can be added through one or two concentric air swirl entries around the central fuel gas pipe entering the furnace. Since the flame

zones for both second stage air introduction methods are reducing (oxygen deficient), minimal

thermal NO_x is produced in the second stage partial oxidation zone. The second stage

combustion jet is designed to effect in-furnace flue gas recirculation (FGR) that allows part of

the oxygen for the second stage partial oxidation to be provided by the FGR. This provides for

lower localized oxygen concentrations that helps to minimize NOx formation.

The second stage products of partial combustion rise up through the boiler furnace and

are cooled by radiant heat transfer to the furnace water-walls. When the flue gases have been cooled down to a range of about 2300° to 2700°F, overfire air (OF A) is added to bring the overall SR at this point to a range of approximately 1.05 to 1.25 to complete the combustion

process. NO_x production is greatly reduced in this OF A zone because the temperatures are

relatively low and thermal NOx production reactions are not favored.

BRIEF DESCRIPTION OF THE DRAWINGS

Narious other objects, features and advantages ofthe invention will become more apparent by reading the following detailed description in conjunction with the drawings, which are shown by way of example only, where:

Fig. 1 is a pictorial description for the staged combustion process applied to a wall-fired

electric utility boiler furnace;

Fig. 2 shows a preferred embodiment for the second stage coned air entry design;

Fig. 3, consisting of Figures 3 a, 3b and 3 c, shows alternative embodiments for the second stage air entry, comprising a cone plus air swirl, dual air swirl, and one air swirl design,

respectively;

Fig. 4 is a graph showing the hydrogen cyanide, ammonia and NO thermochemical equilibria as a function ofthe first stage air.fuel stoichiometric ratio;

Fig. 5 is a graph showing the second stage NO reducing reaction thermochemical

equilibria;

Fig. 6 is a graph showing the third stage NO thermochemical equilibria as a function of temperature; and

Fig. 7 is a pictorial description for applying a three-stage combustion technique to cyclone-fired units wherein the cyclone barrels are used for the first stage of combustion. DETAILED DESCRIPTION OF THE INVENTION

To achieve deep levels of NOx reduction using staged combustion for the firing of carbonaceous

fuels requires that the stoichiometric air to fuel ratios be less than 1.0 during the process until the gases are cool enough to preclude thermal NOx production. I have discovered a process employing such a three-stage combustion technique, with second stage flue gas recirculation (FGR), that will reduce NO_x

emissions preferably to a level less than 0.15 lb NOx/10⁶ Btu.

To implement this three-stage combustion technique, any ofthe first stages of existing

staged combustors mentioned previously can be used wherein the air to fuel stoichiometric ratio

(SR) can be operated in the 0.50 to 0.70 range. Such combustion technologies may add alkali

compounds to reduce the coal ash slag viscosity and/or to capture sulfur in the molten slag.

Steam may also be added to the first stage of combustion to improve carbon burnout, as

described in U.S. Patent No. 5,458,659. Although any staged combustor type could be used, the

most preferred are those that remove molten slag from the combustor or bottom ofthe furnace to

minimize ash carryover and reduce slag fouling in the boiler furnace. Excess air cyclone-fired units may also be converted to the three-stage operation by adding secondary air at the re-entrant throat where the cyclone barrel fuel gases enter the furnace, or alternatively at points in the

furnace below and/or above the re-entrant throats.

Coal is fired into the first stage ofthe combustor under a sub-stoichiometric air condition that reduces the NO_x produced from released fuel nitrogen oxidation. The first stage

temperatures achieved are dependent on the fuel analysis, rate of steam or water addition, the

temperature ofthe pre-heated air, air to fuel ratio, and the heat removal designed into the combustor or cyclone barrel. The first stage temperatures will typically be in the range of 2600°

to 3000°F. The SR in this stage will typically be in the range of about 0.50 to 0.70. The first stage of combustion should preferably have a residence time of at least about 0.1 to 0.3 sec to

provide for lower production of ammonia and hydrogen cyanide that are NO_x precursors under subsequent high temperature, more oxidizing conditions. A fuel gas is produced and the molten

slag removed, either from the combustor proper or from the bottom ofthe boiler furnace.

In a second stage of combustion, preheated second stage combustion air is introduced into

the fuel gas from the first stage in a plug flow fashion. Second stage combustion air is added at a

rate to yield an overall SR at this point in the range of about 0.85 to 0.99. The hot second stage

air, in an outer annulus, is coned inward to the outlet ofthe central fuel gas pipe entering the furnace. This method of air entry provides for rapid mixing and high localized flame

temperatures that yield high temperatures, under reducing conditions, to provide for high combustion efficiency (low carbon in ash) and increase the kinetic rates of NO_x destruction reactions. Alternatively the second stage combustion air can be added through one or two

concentric horizontal air swirl entries around the central fuel gas pipe entering the furnace, or a

cone entry in the inner concentric air zone and a horizontal swirl entry in the outer air zone.

Since the flame zones for both second stage air introduction methods are overall reducing

(oxygen deficient), minimal thermal NO_x is produced. The second stage combustion fuel gas and air jets are designed to effect in-situ furnace flue gas recirculation (FGR) that allows part ofthe

oxygen to be provided by the FGR so that the rate of preheated atmospheric air to the second stage may be reduced. This provides for lower localized oxygen concentrations to help minimize NO_x formation. Each specific boiler will require modeling to be completed to determine the

optimum jet velocity and orientation ofthe second stage flame to create the desired FGR effect.

The SR used in this second stage of partial oxidation is similar to the SR used in

conventional Reburn technology, wherein fuel is added to combustion flue gases in the hot part ofthe furnace, above and with some separation from the conventional burners, to reduce the furnace SR at the Rebum fuel injection point from the 1.10 to 1.20 range supplied by the burners

entering the zone, down to an SR of about 0.90. The nominal 0.90 SR provides a reducing gas condition that converts nitric oxide (NO) that was formed in the excess air burner flames, back to

atmospheric or diatomic nitrogen (N₂). With the staged combustion technique ofthe present

invention, the NO_x and NO_x precursor compounds exiting the first stage (typically a SR = 0.60)

will be much lower than that of conventional burners that yield an overall excess air condition

(SR > 1.0). Since NO_x production is greatly influenced by the oxygen partial pressure in the combustion zone, the higher the oxygen concentration, the higher the NO_x production. By firing

the coal in the first stage at an SR of 0.60 and by firing the fuel gas as it exits the first stage and

enters the furnace at an SR of about 0.90, minimal NO_x is formed, because the reducing gases

produced have the tendency to convert any NO_x that has formed to N₂. The in-situ furnace FGR

also helps minimize localized oxygen concentrations. The hydrocarbon radicals (CH_X), carbon monoxide (CO) and hydrogen (H₂) produced in the first two stages of partial oxidation are

favored to convert NO to N₂ in accord with the following overall simplified reaction examples:

NO + [CH] -» ^N₂ + CO + ^ H₂,

NO + CO → N₂ + CO₂ , and

NO + H₂ → ^N₂ + H₂O. The partial combustion gaseous products from the second stage rise up through the boiler

furnace and are cooled by radiant and convective heat transfer to the furnace water-walls. When

the slightly reducing flue gases have cooled down to a range of about 2300° to 2700°F, overfire

air (OF A) is added to complete the combustion process. NO_x production is minimal in this OFA excess air zone because the temperatures are low and thermal NO_x reactions are less favored than that for higher furnace temperatures.

Throughout the following detailed process description, the same reference numerals refer

to the same elements in the various figures.

A typical example ofthe process ofthe present invention, preferably using the Florida

Power Corporation staged combustor (U.S. Patent Nos. 4,423,702 and 5,458,659), is shown

schematically in Fig. 1. It will be understood by those skilled in the art, that certain variations

from this schematic could be made with such variations still being within the context ofthe present invention. In the embodiment shown in Fig. 1, a first stage combustor 10 is located in

front ofthe entry 12 into the furnace 14. Openings 16 into each ofthe combustors receive a

conventional fuel such as pulverized coal (for example) and an alkaline product such as lime or

limestone (not shown) with the carrier primary air 8 or the preheated air 17. Controlled partial

oxidation ofthe coal takes place in the combustor by regulation ofthe preheated (400° to 700°F)

secondary air flow 18. The air to fuel stoichiometric ratio (SR) in first stage combustor 10 is

maintained at about 0.50 to 0.70 (SRj) through control ofthe preheated air flow 17, and most preferably at about 0.60. In an alternative embodiment, the injection of steam or water 20 into the combustor 10 may be used, adding steam or water to yield a 0.1 to 0.3 steam or water to fuel

weight ratio to enhance the partial oxidation or gasification reactions. With the first stage combustor 10, the products of partial combustion in the form of a fuel gas and the molten slag

from the ash portion ofthe coal plus the inorganic alkali compounds are separated in the partial

oxidation chamber 22, and a molten slag eutectic 24 containing alkali compounds and coal ash exit through the bottom opening 26 ofthe first stage combustor 10. The molten slag is quenched in a water quench sluice system 28 and the ash is sluiced to a collection tank from where it is pumped to a settling pond, or otherwise disposed of according to conventional known methods.

The staged combustor 10 has a partial oxidation zone where mixing at a temperature of

about 2200° to 3000°F provides intimate contact between the coal and air. Through the use of a

staged combustor 10 that has incorporated molten slag removal, a high percentage (75-90%) of

the molten slag produced during partial oxidation ofthe coal is removed from the gas prior to entry into the furnace 14, and prior to further partial oxidation at entry 12. The residence time in

the first stage combustor, to minimize the production of hydrogen cyanide (HCN) and ammonia (NH₃), which are NO_x precursors at high temperatures under excess air conditions, should be in

the range of at least about 0.1 seconds to 0.3 seconds. The hot fuel gas products leave the

combustor 10 and pass via pipe 29 to the entry 12 into the boiler furnace 14. Tertiary air is

admitted through a coned entry (Fig. 2) which forms a second stage of partial oxidation 30 into

the furnace to yield rapid mixing of fuel gas with air to create a hot flame zone where the

production of NO_x is minimized due to the reducing condition in this zone (SR₂ = 0.85 to 0.99). Optionally, tertiary air plus quaternary air may be used in this second stage of combustion as

described more fully hereinafter. The jet effect ofthe products of combustion 38 is set within a certain velocity range to provide for recirculation of furnace flue gases into the second stage jet

stream. The velocity will vary depending on furnace geometry and number of furnace burners. With this effect, the preheated atmospheric air introduced in the second stage is reduced. The oxygen in the recirculated flue gases that are pulled down from the upper part ofthe furnace,

which is an oxidizing atmosphere, makes up the rest ofthe oxygen required to maintain the desired SR of or about 0.85 to 0.99.

Gaseous fuel products from the second stage of partial oxidation 31, rise up through the radiant section ofthe furnace 14 and are cooled by radiant and convective heat transfer to the

furnace water- walls 36 to a temperature of 2400° to 2700°F, wherein the gases have been

maintained in a reducing atmospheric condition for about 0.25 seconds to 0.50 seconds or

greater. At this point, overfire air (OF A) is introduced into the furnace at inlet 32 forming a third

stage combustion technique to complete the combustion process, air being added to bring the

stoichiometric ratios in this zone to an excess air condition of about 1.05 to 1.25 (SR₃). OFA injection may be accomplished through any commercially available design to provide for

intimate and rapid mixing ofthe air with the furnace gases so as to provide complete combustion

ofthe fuel components in the second stage gas stream.

The second stage combustion technique shown in Fig. 2 is designed to introduce the

tertiary air through a concentric pipe annulus 33 with an exit cone 34 that surrounds the inner hot

fuel gas pipe 29 exiting the first stage combustor 10, the terminal end of which forms the entry

12. The cone angle 35, measured from the tertiary air pipe wall 37 into the furnace 14, is

preferably in the range of 25° to 50° and should be designed in a way to provide for rapid plug flow mixing ofthe hot fuel gas (flowing through fuel gas pipe 29) with the partial oxidation air

(flowing through tertiary air annulus 33). The air rate is controlled to bring the overall SR in the

second stage to 0.85 to 0.99 (SR₂). The alternative second stage combustion techniques shown in the various embodiments of Fig. 3 are designed to introduce both tertiary and quaternary air.

Three alternative approaches may be used in this embodiment. The first approach, as shown in

Fig. 3 a, is to introduce the tertiary air through the annulus 40 formed from tertiary air pipe wall 42 with a coned exit 44 that surrounds the inner fuel gas pipe 29. The cone angle 46, measured

from the tertiary air pipe wall 42, is preferably in the range of about 25° to 50° and should be designed in a way to provide for rapid plug flow mixing ofthe hot fuel gas with the combustion

air. Quaternary air is added through the annulus 48 of a concentric pipe 50 that surrounds the

tertiary air pipe 42, and preferably includes internal angled baffles 52 that swirl the air. The

quaternary air swirl is designed to be adjustable to shorten or lengthen the overall flame length,

more swirl reducing the length ofthe flame and less swirl elongating the flame. The total air rate

is controlled to bring the overall SR in the second stage to a range of approximately 0.85 to 0.99 (SR₂).

The second approach, as shown in Fig. 3b, is to introduce the tertiary and. quaternary, air

through two concentric pipe annuluses 54, 56 that surround the inner fuel gas pipe 29,. with one or both of these cylinders preferably containing internal adjustable angled baffles 58, 60,

respectively, to provide for air swirl. Tertiary air is introduced through the annulus 54 of a

concentric pipe 43 that surrounds the inner hot fuel gas pipe 29 exiting the first stage partial

oxidation unit 10 and terminating in furnace entry 12. Quaternary air is added through the annulus 56 of a concentric pipe 64 that surrounds the tertiary air. pipe 43. By changing the relative air flow rates and air swirl intensity between these two zones, the flame may be shaped

to provide for a long flame that radiates energy away from it, providing for a cooler flame. If

necessary, this type of second stage entry could be used effectively in the case when the overfire air system is not in use to provide for low NO_x emissions, but it is known that it will generally

not be as low as that when the OFA system is in service. The total air rate is controlled to bring

the overall stoichiometric ratios in the second stage to 0.85 to 0.99 (SR₂). If desired, steam or water may be added at this stage as well.

In the third embodiment, as shown in Fig. 3 (c), tertiary air is introduced through one concentric pipe annulus 66 of a concentric pipe 68 that surrounds the inner hot fuel gas pipe 29 exiting the first stage partial oxidation unit 10 and terminating in furnace entry 12. The tertiary

air is designed to provide air swirl 67. The total air rate is controlled to bring the overall SR in

the second stage to a range of approximately 0.85 to 0.99 (SR₂). The third stage combustion

technique (overfire air) 32 is completed after the fuel gas 31 from the second stage has been

cooled to a range of to 2300° to 2700°F.

A One Dimensional Flame (ODF) kinetics model was used to evaluate the three-stage

pulverized coal combustion technique. The ODF model treats the combustion system as a series of one-dimensional reactors. Each reactor may be perfectly mixed (well stirred) or unmixed

(plug flow). Each ODF reactor may also be assigned a variety of thermodynamic characteristics,

including adiabatic, isothermal, or specified profiles of temperature or heat flux, and/or pressure.

Further, process streams may be added over any interval ofthe plug flow reactor, with arbitrary

mixing profiles along the reactor length. Input data include initial species concentrations and

conditions, description ofthe conditions for each reactor, the chemical species and reaction mechanism including rate parameters, and model control parameters. A separate input file provides the thermodynamic property database for the chemical species. Output data include

concentration profiles at specified locations along the reactor chain. The chemistry within each reactor is calculated using detailed reaction mechanisms based on data from experimental

literature that was validated by comparison with experimental results. The solution ofthe detailed reaction mechanisms uses an implicit solution algorithm applicable to systems of many coupled equations. Specialized sub-models allow for the phenomena of pulverized coal

combustion and gas-phase radiation. The ODF model has been validated against experimental data from several sources. It was therefore used to evaluate the three-stage combustion technique

ofthe present invention.

In the three stage combustion technique analyzed, a coal, sorbent (and optionally steam)

mixture was introduced at the start ofthe first plug flow reactor at a stoichiometric ratio of about

0.60 (SRj) and a set initial temperature (2600°F to 3000°F). Plug flow, with an SR of 0.60 was used in the first stage to increase localized flame temperatures, under reducing conditions, to

reduce the formation ofthe nitrogen oxide precursors - specifically, hydrogen cyanide and

ammonia, see Fig. 4. After a residence time of about 0.20 seconds, the second stage starts with

the addition of air, bringing the second stage stoichiometric ratio to about 0.88 to 0.96 (SR₂).

The residence time ofthe second stage was set at 0.5 sec, which is believed to be a reasonable

time for electric utility boiler furnace applications. Second stage flame temperature and fuel

gas/air mixing time had the most dramatic effects on final NO_x emissions. The lower the second stage flame temperature, the lower the NO_x produced. Lower NO_x is produced with steam

injection compared to no steam injection primarily due to lower flame temperatures. All other parameters being equal, with steam injection, the second stage flame temperature is reduced by

60°F as compared to no steam injection. Therefore, cooling the fuel gas in the first stage vessel either with steam or with greater heat removal, prior to second stage firing, is seen to be beneficial in lowering NO_x emissions. Based on identical firing temperatures, steam addition

itself, at a rate of about 0.30 lb steam/lb coal lowered NO_x emissions some 10%, as compared to

using three stages of combustion with no steam injection.

In addition, the longer the residence time of fuel gas/air mixing in the second stage, the lower the localized flame temperatures and therefore the lower the final NO_x emissions. The

NOx reducing thermochemical equilibria ofthe second stage are shown in Fig. 5. After

maintaining the second stage reducing condition for a time of 0.5 sec, overfire air (OFA) is added

to bring the third stage stoichiometric ratio to about 1.14 (SR₃) to provide for a 3.2% (dry)

oxygen concentration. This zone was also set for a residence time of 0.5 sec. before entering the

cooling (superheat/reheat) passes in the upper furnace. Since air is being added after the second

stage fuel gas has been cooled, the flame temperatures in the OFA combustion zone are fairly

low (2400° to 2700°F). As shown in Fig. 6, thermal NO_x production is less favored at lower

temperatures. For example, the equilibrium coefficient for the thermal NO_x production reaction

(N₂ + 0₂ → 2 NO) at 2400°F is less than one-tenth ofthe equilibrium constant at 2700°F.

A value of 0.07 seconds was assumed for the second stage and third stage mixing times

based on experimental data. The stages were operated taking into consideration flame radiation

and dissociation losses with heat extractions added to match the mass and energy balances developed. The flue gases, from the point of OFA injection until entering the furnace superheater/reheater areas, should have a residence time of at least about 0.25 seconds and more

preferably 0.50 seconds or greater.

Table 1 shows the projected overall NO_x emissions for various second stage stoichiometric ratios (SR₂) when operating with and without steam. As shown, by operating the second stage at stoichiometric ratios in the range of about 0.88 to 0.97, the three-stage

combustion technique can yield NO_x emissions of about 0.15 lb/million Btu and less. At the low

stoichiometric ratios, NO_x emissions as low as 0.067 to 0.088 lb/million Btu were projected. This

data does not take into account the FGR phenomenon that will help to lower NOx even further.

TABLE 1. THREE STAGE COAL COMBUSTION

Steam addition to 1st stage* No steam addition to 1st Stage

SR_t = 0.60 and 0.2 sec. Residence time SR, = 0.60 and 0.2 sec. Residence time SR₂ = 0.89 - 0.95 and 0.5 sec. Residence time SR₂ = 0.88 - 0.96 and 0.5 sec. Residence time SR, = 1.14 and 0.5 sec. Residence time SR, = 1.14 and 0.5 sec. Residence time

Overall NO. Emissions Overall NO. Emissions ppmvd ppmvd

SR, tø>,3% O lb/10⁶ Btu SR, ((a)3% O ) lb/10⁶ Btu

0.89 46 0.067 0.88 61 0.088 0.93 61 0.088 0.91 86 0.120 0.95 75 0.109 0.93 113 0.157 0.96 175 0.244

* 0.30 lb steam/lb coal fired

While stoker-fired, wall-fired and tangentially fired boilers would require the addition of

a first-stage partial oxidation unit to implement the three-stage oxidation technique ofthe present

invention, cyclone-fired boilers would not. As shown in Fig. 7, the existing combustor barrels on

a cyclone-fired unit 70 could be modified to operate under the first stage partial oxidation

conditions ofthe present invention. The difference between the conventional two-stage

combustion systems and the cyclone-fired units 70 is that they fire pulverized coal (typically

70% minus 200 mesh) and the cyclone units' fire ground coal 72 (typically -V in size).

Recently, certain electric utilities have added overfire air 74 to their cyclone units so that

the cyclone barrels 76 can be run under slightly reducing conditions (SR = 0.90 to 0.95). This

resulted in NO_x reductions of up to 60%. Cyclones, operating under conventional excess air

conditions in the barrels 76, are typically high NO_x emitting units, usually in the range of 1.0 to 2.0 lb. NO_X/10⁶ Btu. To implement the three-stage technique to a cyclone unit 70 that already has overfire air 74 capability, additional preheated air 78 would be added at the re-entrant throat

location(s) 82 where the hot gases 91 from the barrel(s) 76 enter the main furnace. The first stage unit, the cyclone barrel 76, would then be operated under the stoichiometric air:fuel conditions described for conventional two stage combustion units (SR of about 0.50 to 0.70), adding preheated air 80 and 78 into the barrel through lines 87 (primary air), 88(secondary air)

and 89 (tertiary air). Preheated air 78 would be added at the barrel re-entrant throat locations 82

to increase the SR to about 0.85 to 0.99 in the lower part 84 ofthe furnace. This second stage air

could be introduced around the re-entrant throats 90 where the first stage fuel gas 91 from the

barrels 76 enters the furnace, or above and/or below 83 the re-entrant throat openings on the same furnace wall as the re-entrant throats or on the opposite or side walls ofthe furnace or

combinations thereof. The second stage air, no matter where located will be done so as to effect an in-situ furnace flue gas recirculation, as shown by direction arrows 93 and or 92. Overfire air

74 is added in the upper part 86 ofthe furnace to complete the combustion process, raising the

SR at this point typically to about 1.10 to 1.20 to provide for adequate carbon burnout. .

The modifications required to implement the three stage technique to any existing

cyclone-fired unit, would include the following: 1) boiler tubewall penetrations, air ducting and

injectors to supply air for a second stage of combustion at the re-entrant throat location 82; 2) probable addition of limestone to decrease the molten ash viscosity (preferably a viscosity of

about 10 poise) so that the slag will tap from the bottom ofthe furnace easily; 3) possible

replacement ofthe existing refractory layer on the studded barrel waterwalls to a refractory that

performs better under reducing atmospheric conditions; and 4) the addition of ducting and

overfire air 74 injectors to supply air to the upper part 86 ofthe furnace (if not in place). For cyclone-fired units that are equipped with a flue gas recycle (FGR) system, wherein flue gas is

injected into the furnace directly above the re-entrant throat locations, it may be possible to use the existing FGR ports for second stage air addition to eliminate the need for added tubewall

penetrations.

Further, the steam and/or water addition technique could be applied to these modified

cyclone units, if required for low reactivity fuels such as low volatile bituminous coal, anthracite

or petroleum coke, to increase carbon burnout. This is accomplished through the carbon- water

reaction (C + H₂O -» CO + H₂), which at high temperatures (e.g. 2600°F), has a rate of reaction

similar to the carbon-oxygen reactions. Steam and/or water injection is a proven technique that

has been practiced for decades in the coal gasification industry.

While specific embodiments ofthe invention have been described in detail, it will be

appreciated by those skilled in the art that various modifications and alterations would be developed in light ofthe overall teachings ofthe disclosure. For example, any type of

carbonaceous fuel such as one or more ofthe class consisting of anthracite, bituminous, sub-

bituminous and lignite coals; tar and emulsions thereof, bitumen and emulsions thereof,

petroleum coke, petroleum oils and emulsions thereof, and water and/or oil slurries of coal, paper

mill sludge solids, sewage sludge solids, and combinations and mixtures thereof of all the fuels within this class can be used. Accordingly, the particular arrangements disclosed are meant to be

illustrative only and not limiting as to the scope ofthe invention which is to be given the full breadth ofthe appended claims and in any and all equivalents thereof.

Claims

CLAIMS:

1. A method for reducing nitrogen oxide (NO_x) emissions formed during the

combustion of a carbonaceous fuel, said method comprising the steps of:

a) introducing a carbonaceous fuel containing fuel bound nitrogen into first stage partial

oxidation unit, wherein primary carrier air and preheated secondary air are added and mixed with

the carbonaceous fuel to produce a fuel gas;

b) introducing the fuel gas into a second stage of partial oxidation and introducing

preheated tertiary air into the fuel gas to create in-situ furnace flue gas recirculation;

c) introducing the fuel gas and preheated tertiary air into a boiler furnace, flowing through

a radiant section ofthe boiler furnace to produce a slightly reducing flue gas; and

d) introducing said flue gas into a third stage of oxidation where preheated overfire air is

introduced into the furnace boiler to substantially complete the combustion process.

2. The method according to claim 1 comprising carbonaceous fuels within the class

consisting of anthracite, bituminous, sub-bituminous and lignite coals, tar and emulsions thereof,

bitumen and emulsions thereof, petroleum coke, petroleum oils and emulsions thereof, and water

and/or oil slurries of coal, paper mill sludge solids, sewage sludge solids, and combinations and

mixtures thereof of all the fuels within this class.

3. The method according to claim 1 wherein the primary carrier air and preheated

secondary air are added to the first stage partial oxidation unit operated at a stoichiometric air to

fuel ratio of about 0.50 to 0.70.

4. The method according to claim 1 further including the step of adding an alkali or

combinations of alkalis thereof from the class consisting of lime, hydrated lime, limestone,

dolomite, nacholite, trona, and potash with the carbonaceous fuel.

5. The method according to claim 1 further comprising the step of adding steam or

water with the carbonaceous fuel to yield a 0.1 to 0.3 steam or water to fuel weight ratio.

6. The method according to claim 1 wherein the first stage partial oxidation fuel

gases have a residence time in the first stage oxidation unit of about 0.1 to 0.3 seconds.

7. The method according to claim 1 further comprising the step of separating molten

slag from the fuel gas in the first stage partial oxidation unit to produce solidified ash particles

using a water quench system and exiting the fuel gas from the unit through a pipe into a boiler

furnace.

8. The method according to claim 1 wherein the preheated secondary air is added at

a temperature in the range of about 400°F to 700°F.

9. The method according to claim 1 wherein the fuel gas and tertiary air are mixed in

a plug flow fashion through introduction of preheated air through a concentric pipe in an outer

annulus that is coned inward to the outlet ofthe central first stage fuel gas pipe entering the furnace, the cone angle from the axial plane ofthe cylinder wall, being in the range of about 25°

to 50°.

10. The method according to claim 1 wherein preheated tertiary air is added at a rate

to yield an overall air to fuel stoichiometric ratio in the second stage of oxidation of about 0.85 to

0.99.

11. The method according to claim 1 wherein the fuel gas is mixed with both

preheated tertiary and preheated quaternary air.

12. The method according to claim 11 wherein preheated tertiary and preheated

quaternary air is added at a rate to yield an overall air to fuel stoichiometric ratio in the second

stage of oxidation of about 0.85 to 0.99.

13. The method according to claim 1 wherein the method is performed in an excess

air cyclone-fired furnace modified to operate in a three stage combustor mode by adding a

preheated air system that provides for air introduction into said cyclone-fired furnace at the

cyclone barrel re-entrant throat location followed by overfire air introduction in the upper part of

the furnace to complete the combustion process.

14. The method according to claim 11 wherein the preheated tertiary air is introduced

through a concentric cylinder that surrounds the inner fuel gas pipe from the first stage of partial

oxidation.

15. The method according to claim 14 wherein the exit ofthe concentric cylinder has

a coned opening, angled inward toward the first stage fuel gas pipe, the cone angle from the axial

plane ofthe cylinder wall, being in the range of about 25° to 50°.

16. The method according to claim 14 wherein the cylinder contains internal

adjustable angled baffles to provide for air swirl.

17. The method according to claim 14 wherein the preheated quaternary air is

introduced through a concentric cylinder that surrounds the tertiary air pipe.

18. The method according to claim 17 wherein the cylinder contains internal

adjustable angled baffles to provide for air swirl.

19. The method according to claim 14 wherein the velocities ofthe first stage fuel gas

and tertiary air are set to create, for a specific boiler furnace design, the desired in-situ furnace

flue gas recirculation rate.

20. The method according to claim 14 and claim 17 wherein the velocities ofthe first

stage fuel gas, tertiary air and quaternary air are set to create, for a specific boiler furnace design,

the desired in-situ furnace flue gas recirculation rate.

21. The method according to claim 1 wherein the flue gas from the second stage of

partial oxidation is cooled to a temperature of about 2400° to 2700°F.

22. The method according to claim 1 wherein the flue gas from the second stage of

partial oxidation is maintained in a reducing atmospheric condition for about 0.25 seconds to

0.50 seconds or greater.

23. The method according to claim 1 wherein the flue gas from the second stage of

partial oxidation is maintained in a reducing atmospheric condition for at least 0.50 seconds.

24. The method according to claim 1 wherein preheated air in a third stage of

oxidation is introduced into the cooled furnace flue gas to complete the combustion process.

25. The method according to claim 1 , wherein the flue gas is a reducing flue gas.

26. The method according to claim 25 wherein preheated air in a third stage of

oxidation is added into cooled furnace reducing flue gas to establish an air to fuel stoichiometric

ratio of about 1.05 to 1.30.

27. The method according to claim 25 wherein preheated air in a third stage of oxidation is added using any overfire air furnace injection technique at the point where the

reducing flue gas has been cooled to a temperature of about 2400 to 2700°F.

28. The method according to claim 4, wherein the step of adding said alkali or

combinations of alkalis comprises adding said alkali or combination of alkalis into the primary air carrier and/or the preheated secondary air injected into the first stage partial oxidation unit.

29. A method for reducing nitrogen oxide (NO_x) emissions formed during the

combustion of a carbonaceous fuel, said method comprising the steps of:

a) introducing a carbonaceous fuel containing fuel bound nitrogen into a first stage partial

the carbonaceous fuel to produce a fuel gas;

preheated tertiary air into the fuel gas;

a radiant section ofthe boiler furnace to produce a flue gas; and

introduced into the boiler furnace to substantially complete the combustion process.

30. The method according to claim 29 wherein the primary carrier air and preheated

secondary air are added to the first stage partial oxidation unit operated at a stochiometric air to

fuel ratio of about 0.50 to 0.70.

31. The method according to claim 30 further including the step of adding an alkali or

dolomite, nacholite, trona, and potash with the carbonaceous fuel.

32. The method according to claim 30 further comprising the step of adding steam or

33. The method according to claim 32 wherein the first stage partial oxidation fuel

34. The method according to claim 33 wherein the preheated secondary air is added at

a temperature in the range of about 400°F to 700°F.

35. The method according to claim 29 wherein the fuel gas is introduced into the

second stage of partial oxidation at a velocity of about 35 to 70 ft/sec.

36. The method according to claim 34 wherein the fuel gas and tertiary air are mixed

in a plug flow fashion through introduction of preheated air through a concentric pipe in an outer

annulus that is coned inward to the outlet ofthe central first stage fuel gas pipe entering the

furnace, the cone angle from the axial plane ofthe cylinder wall, being in the range of about 25°

to 50°.

37. The method according to claim 35 wherein the preheated tertiary air entry velocity

into the said fuel gas is in the range of about 50 to 100 ft/sec.

38. The method according to claim 36 wherein preheated tertiary air is added at a rate

to yield an overall air to fuel stochiometric ratio in the range of about 0.85 to 0.99.

39. The method according to claim 29 wherein the fuel gas is mixed with both

preheated tertiary and preheated quaternary air.

40. The method according to claim 29 wherein the method is performed in an excess

cyclone barrel re-entrant throat location followed by overfire air introduction to complete the

combustion process.

41. The method according to claim 39 wherein the preheated tertiary air is introduced

oxidation.

42. The method according to claim 41 wherein the tertiary air velocity through the

cylinder is in the range of about 20 to 50 ft/sec.

43. The method according to claim 41 wherein the preheated quaternary air is introduced through a concentric cylinder that surrounds the tertiary air pipe.

44. The method according to claim 43 wherein the quaternary air velocity through the

cylinder is in the range of about 75 to 125 ft/sec.

45. The method according to claim 38 wherein the flue gas from the second stage of

partial oxidation is cooled to a temperature of about 2400° to 2700°F.

46. The method according to claim 45 wherein the flue gas from the second stage of

0.50 seconds or greater.

47. The method according to claim 46 wherein preheated air in a third stage of

48. The method according to claim 47 wherein preheated air in a third stage of

oxidation is added into cooled furnace reducing flue gas to establish an air to fuel stochiometric

ratio of about 1.05 to 1.30.

49. The method according to claim 48 wherein preheated air in a third stage of

oxidation is added using any overfire air furnace injection technique at the point where the

reducing flue gas has been cooled to a temperature of about 2400 to 2700°F.