TOPICAL REPORT NUMBER 5 SEPTEMBER 1996

Reducing Emissions

of Nitrogen Oxides via

Low-NOX Burner Technologies

A report on projects conducted jointly

under cooperative agreements between:

The U.S. Department of Energy and

• The Babcock & Wilcox Company

• Southern Company Services, Inc.

• Public Service Company of Colorado
Reducing Emissions

of Nitrogen Oxides via

Low-NOX Burner Technologies

Cover image:

 Inside a wall-fired boiler.

Introduction and Executive Summary ......................................................................... 1

Background ................................................................................................................ 2

NOX Control Technologies ......................................................................................... 2

NOX Regulations under the Clean Air Act Amendments of 1990 .............................. 3

Wall-Fired Boiler Applications .................................................................................. 6

T-Fired Boiler Applications ....................................................................................... 9

Vertically Fired Boiler Applications ......................................................................... 12

Cell Burner Boiler Applications ................................................................................ 14

Artificial Intelligence for NOX Control ..................................................................... 17

Performance and Economic Comparison ................................................................... 20

Bibliography .............................................................................................................. 21

List of Acronyms and Abbreviations ......................................................................... 22

Contacts for CCT Projects and U.S. DOE CCT Program ......................................... 23

T E C H N O L O G Y
Introduction and

Executive Summary

The Clean Coal Technology (CCT)

Demonstration Program is a government and

industry co-funded effort to demonstrate a new

generation of innovative coal utilization

processes in "showcase" projects conducted

across the country. These projects are on a

scale sufficiently large to demonstrate

commercial worthiness and generate data for

design, construction, operation, and

technical/economic evaluation of full-scale

commercial applications.

The goal of the CCT program is to furnish

the U.S. energy marketplace with advanced,

more efficient, and environmentally responsive

coal-utilizing technologies. These technologies

will mitigate some of the economic and

environmental impediments that limit the full

utilization of coal as a continuing viable energy

resource.

To achieve this goal, a multi-phased effort

consisting of five separate solicitations was

administered by the U.S. Department of Energy

(DOE). Projects selected through these

solicitations have demonstrated technology

options with the potential to meet the needs of

energy markets and respond to relevant

environmental requirements.

Part of this program is the demonstration of

technologies designed to reduce emissions of

oxides of nitrogen (NOx) from existing coalfired utility boilers. NOx is an acid rain

precursor and a contributor to atmospheric (i.e.,

tropospheric) ozone formation, which is a

health hazard and is also related to smog

formation. NOx emissions are regulated under

the provisions of the Clean Air Act and

particularly the Clean Air Act Amendments

(CAAA) of 1990.

This report discusses CCT demonstration

projects that reduce NOx emissions by

combustion modifications using low-NOx

burners (LNBs). In some cases. LNBs are

Summary of Demonstration Projects

used in conjunction with overfire air (OFA).

Separate projects involve use of LNBs with

four different boiler types: wall-fired,

tangentially fired (T-fired), vertically fired, and

cell burner units. All of these boiler types are

subject to CAAA regulations. These CCT

projects have been administered by DOE

through its Pittsburgh Energy Technology

Center (PETC).

Summary of Results

The results of these demonstration projects

are summarized in the table above.

Several of the LNB technologies tested in

these demonstration projects are being used

successfully in commercial retrofits and new

boilers.

Economics have been estimated by the

project participants for the cases involving

wall-fired, T-fired, and cell burner boilers. The

economics assume a baseloaded power plant

with a 65% capacity factor and a 15-year

project life. The estimated capital cost for these

technologies is less than $10/kW and the

levelized cost on a current dollar basis is in the

range of $100 - $125/ton of NOx removed. The

costs for application of LNBs to vertically fired

boilers are expected to be significantly higher

than for wall-fired, T-fired, and cell burner

units as a result of the extensive boiler

modifications required.

1

Boiler Type Wall-Fired T-Fired Vertically Fired Cell Burner

Technology LNB LNB LNB + OFA LNB

Utility Georgia Gulf Public Service Dayton Power

Power Power of Colorado & Light

Power Plant Hammond Smith Arapahoe J.M. Stuart

Unit No. 4 24 4

Size, MWe 500 200 100 605

NOX Reduction 48 37 69 55

at FuIl Load, %
Reducing Emissions

of Nitrogen Oxides via

Low-NOX Burner Technologies

Overview

 The CCT Program NOX

reduction projects discussed in this

report involve the use of LNBs,

either alone or in combination with

other technologies. These projects

provide retrofit alternatives to reduce

NOX without the need to replace the

boiler or install expensive postcombustion controls. The results

obtained from these projects have

been reported to the utility industry,

to the public, and to EPA to guide

them in establishing NOX control

regulations and selection of

technology options.

The technology applications

are: (1) a wall-fired boiler project at

Plant Hammond, operated by

Georgia Power Company; (2) a

 T-fired boiler project at Plant Smith,

operated by Gulf Power Company;

(3) a vertically fired boiler project at

Arapahoe Station, operated by

Public Service Company of

Colorado; and (4) a cell burner

boiler project conducted by

Babcock & Wilcox at J. M. Stuart

Station, operated by Dayton Power

& Light. Projects 1 and 2 were

conducted by Southern Company

Services.

2

Background

The Clean Coal Technology (CCT)

Demonstration Program, which is sponsored by

the U.S. Department of Energy (DOE), is a

government and industry co-funded technology

development effort conducted since 1985 to

demonstrate a new generation of innovative

coal utilization processes. In a parallel effort,

the U.S. Environmental Protection Agency

(EPA) is in the process of promulgating new

regulations, authorized by the 1990

Amendments to the Clean Air Act (CAAA),

concerning emissions from a variety of

stationary sources, including coal-burning

power plants.

A major issue of concern is emissions of

nitrogen oxides (NO and NO2, collectively

referred to as NOX). Low-NOX burners

and environmentally responsive coalutilizing technologies. These technologies

will mitigate some of the economic and

environmental impediments that inhibit

utilization of coal as a viable energy source.

The CCT Program also has opened a

channel to policy-making bodies by providing data from cutting-edge technologies

to aid in formulating regulatory decisions.

DOE and participants in several CCT

projects have provided the EPA with data to

confirm NOX emissions targets for coal-fired

power plants subject to compliance under

the CAAA.

(LNBs) are one means of effectively reducing

NOx emissions. This report describes a variety

of LNB technologies demonstrated under the

CCT Program.

The CCT Program involves a series of

"showcase" projects, conducted on a scale

sufficiently large to demonstrate commercial

worthiness and generate data for design,

construction, operation, and

technical/economic evaluation of full scale

commercial applications. The goal of the CCT

Program is to furnish the U.S. energy

marketplace with advanced, more efficient,

NOX Control

Technologies

NOX Emissions Regulations

Current and proposed EPA regulations

for NOX emissions are summarized on

page 3. As noted, separate limits apply to

the different boiler types covered in this

report.

Combustion Modifications for

Reducing NOX Emissions

NOx control can be achieved by:

a) boiler combustion controls, b) postcombustion controls, or c) a combination
NOX Regulations under the Clean Air Act Amendments of 1990

NOX emissions are

generated primarily from

transportation, utility, and

other industrial sources.

They are reported to

contribute to a variety of

environmental problems,

including acid rain and

acidification of aquatic

systems, ground level

ozone (smog), and

visibility degradation. For

these reasons, NOX

emissions are regulated in

many ways by different

levels of government

throughout the country.

Ozone Non-Attainment

Table 1. Coal-Fired Boiler NOX Emissions Limits,

lb/106 Btu (Title IV)

Phase l Phase ll

Implementation Period 1996-2000 2000+

Status of Regulations Promulgated Proposed

Group 1 Boilers

Dry Bottom Wall-Fired 0.50 0.45

Tangentially Fired 0.45 0.38

Group 2 Boilers

Wet Bottom Wall-Fired NA 0.86

Cyclone-Fired NA 0.94

Vertically Fired NA 0.80

Cell Burner NA 0.68

Fluidized Bed NA 0.29

NA = Not applicable

Title I of the CAAA requires the states to apply the same

limits to major stationary sources of NOX as are applied to

major stationary sources of volatile organic compounds. In

general, these new NOX provisions require (1) existing major

stationary sources to apply reasonably available control

technologies (RACT), (2) new or modified major stationary

sources to offset their new emissions and install controls

representing the lowest achievable emission rate, and (3) each

state with an ozone nonattainment region in it to develop a

State Implementation Plan (SIP) that, in most cases, will

include reductions in stationary source NOX emissions beyond

those required by the RACT provisisions of Title I. These

requirements apply in certain ozone nonattainment areas and

ozone transport regions.

Mobile Sources

Title II of the CAAA calls for reductions in motor vehicle

emissions. Emission limits for new vehicles constitute the

majority of reductions from vehicles. Emission limits for

various classes of vehicles will be implemented throughout

this decade.

Acid Rain

Title IV of the CAAA focuses on a particular set of NOX

emitting sources—coal-fired electric utility plants—and uses a

two-part strategy to reduce emissions. The first stage of the

program, promulgated on April 13, 1995, will reduce NOX

emissions in the United States by over 400,000 tons/yr

between 1996 and 1999

(Phase I). These reductions are achieved by

dry bottom wall-fired

boilers and tangentially

fired (T-fired) boilers

(Group 1). In Phase II,

which begins in 2000,

EPA may establish more

stringent standards for

Group 1 boilers and

establish regulations for

other boilers known as

Group 2 (boilers applying

cell-burner technology,

cyclone boilers, wet

bottom boilers, and other

types of coal-fired

boilers). Currently, EPA

has proposed a rule that would set lower Phase II, Group 1

emission limits and establish limits for Group 2, resulting in

an additional reduction of 820,000 tons/yr.

Implementation

The table outlines Title IV NOX emissions limits. The EPA has

established emissions limits for the 169 Phase I, Group I, boilers

(110 plants) identified for control in the CAAA. These limits will

not change in Phase II. Emissions limits for the 195 Group 2

boilers will be established in Phase II. In addition to the 169

Phase I, Group 1 boilers, there are another 580 tangentially fired

and wall-fired boilers that must meet the applicable NOX

emissions limits by January 1, 2000.

As shown above, the emission limitations proposed by

EPA under Title IV for Phase II, Group 1 boilers are more

stringent than the Phase I standards. EPA states that this is

because more effective NOX reduction technology has

become available since promulgation of Phase I regulations.

The statute requires that emission control costs for Group 2

be comparable to those for Group 1.

EPA has the authority to set Title IV NOX limitations at

higher levels if a utility can demonstrate that a boiler could not

meet the standard by using LNB technology. The regulations

also allow for emissions averaging in which the emissions

levels established by EPA are applied to an entire group of

boilers owned or operated by a single company. Averaging is

not limited geographically.

3
of these techniques. Postcombustion control processes

being studied in the CCT

Program include selective

catalytic reduction (SCR) and

selective noncatalytic

reduction (SNCR). The

present report focuses on

combustion controls.

Low-NO

X combustion

systems are designed to

reduce the availability of

oxygen in the primary

combustion zone. This is

achieved either by staged

combustion using LNB or

LNB in combination with

overfire air (OFA). In

addition, supplemental fuel

can be used (coal, oil, or

natural gas). This is

referred to as reburning.

4

Staged combustion minimizes the

formation of NO

X by reducing the amount

of combustion air going to the burners.

The remaining air, required for complete

combustion, is introduced either in the

burner as secondary (and possibly tertiary)

air, or above the burner as overfire air.

Conventional coal-fired burners operate

with 15 to 20% excess air (compared to the

theoretical, or stoichiometric, requirement).

Staging involves reducing the percentage of

excess air in the primary combustion zone.

Reburning decomposes NO

X once it is

formed. The majority of the coal is burned

in the primary combustion zone at or near

stoichiometric conditions. Additional fuel

is injected, and further burning occurs in

another zone higher in the boiler with

additional air; under the reducing

conditions in the reburn zone, some of the

NO

X, already formed is converted to

molecular nitrogen.

Boiler Types

This report discusses NO

X emissions

reduction for four types of boilers: wallfired, T-fired, vertically fired, and cell burner

units, using LNBs (with or without OFA) as

the NO

X control technology. Wall-fired

boilers most commonly use circular burners,

in which each burner nozzle is surrounded by

water tubes. Cell burners represent a

variation in which two (or occasionally

three) circular burners are grouped closely

together, surrounded with water tubes. Wallfired burners produce an intense, turbulent

flame, with consequent high levels of NO

X

formation. T-fired boilers consist of a

vertical array of coal nozzles and air ports

mounted in each corner of the furnace. The

resulting lower temperature and diminished

turbulence lead to inherently lower NO

X

formation than is the case in wall-fired

burners.

These differences in design cause different boiler systems to produce varying levels

of uncontrolled NO

X. Because the boilers

studied were designed and built before the
establishment of New Source Performance

Standards (NSPS) in 1971, they are

referred to as pre-NSPS boilers.

Most of these units produce levels of

NOX well above the current Title IV emissions regulations. These differences are

important for retrofit technologies because

a majority of the 192,000 MWe pre-NSPS

coal boiler capacity consists of boilers that

produce the highest levels of NOX (e.g.,

wall-fired dry and wet bottom boilers,

cyclone boilers, and cell burners). T-fired

boilers constitute 43%, wall-fired 26%,

cyclone 13%, and cell burners 13% of the

pre-NSPS boiler population in the United

States. The remaining 5% consist of other

boiler types. In addition, over 70,000

MWe of U.S. boiler capacity is subject to

NSPS requirements. Cyclone and cell

units represent more than 50% of the NOX

generated by pre-NSPS coal-fired boilers.

Low-NOX Burners

The principle of LNB

operation involves

decreasing the amount of

air introduced into the

primary combustion zone,

thereby creating a fuelrich, reducing environment and lowering the

temperature, both of

which generally suppress

NOX formation. The

remaining air required for

complete burnout of combustibles is added after

the primary combustion

zone, where the temperature is sufficientlyFull-load NOX emissions for pre-NSPS coal-fired

U.S. utility boiler configurations.

 Cell Burners

Arrangement of circular and cell burners in the furnace

wall. Source: lEA

Overfire Air (OFA)

Under circumstances

where NOX emissions

exceed desired levels

despite the use of

LNBs, it may be

necessary to more

deeply stage

combustion, followed

by introduction of the

remaining air required

for combustion through

separate ports at higher

elevations in the boiler,

again at lower temperatures, thus limiting

production of

additional NOX. This

is the principle of OFA

operation.

5

Circular Two-Cell Three-Cell

low so that additional NOX formation is

minimized. All of the combustion air is

delivered to the furnace via the LNBs.
Potential Problems with

Low-NOX Burners

Operation of LNBs with reduced air in

the primary combustion zone can lead to

economic losses as a result of increased

amounts of unburned carbon (UBC),

increased slagging in the combustion

zone, and accelerated corrosion. To

counteract these tendencies, UBC losses

can be minimized by increasing coal

fineness and by careful control of air/fuel

distribution.

Burner design, arrangement, and operation

can be modified to minimize UBC,

slagging, and corrosion. Also, tubes in the

burner zone can be coated with

corrosion-resistant materials. Increased

UBC can impact the performance of

particulate control systems. The expected

increase in UBC is a function of boiler

design and operating parameters and the

coal burned. Increased carbon levels

change the electrostatic properties of the

fly ash, adversely affecting the

performance of electrostatic precipitators

(ESP). The marketability of the fly ash is

also limited by UBC levels. Fly ash can

be sold for use in cement manufacture and

as road construction material, provided

that the UBC content is below prescribed

levels.

In any given retrofit application of

NOX reduction technologies, the available

burner opening must be taken into

account. Insufficient space can require

additional boiler modifications at

increased cost.

Wall-Fired Boiler

Applications

The CCT project at Georgia Power

Company’s Plant Hammond Unit 4 was

designed to demonstrate two combustion

control techniques for NOX reduction in

wall-fired boilers: advanced overfire air

(AOFA) and LNB. These technologies

were tested both singly and in

combination. The project was managed

by Southern Company Services (SCS) on

behalf of DOE and the project’s industry

co-funders, Southern Company and the

Electric Power Research Institute (EPRI).

The project has been expanded to include

a study of the effects of advanced

instrumentation and intelligent control on

NOX reduction performance. This

extension is discussed in the section on

artificial intelligence.
Test Site

Hammond Unit 4, a pre-NSPS unit

having a gross rating of 500 MWe, was

placed into commercial operation in 1970.

The boiler, designed by the Foster Wheeler

Energy Corporation (FWEC), is fired from

opposed walls. Design steam conditions

are 2500 psig and superheat/reheat

temperatures of 1000°F/1000°F. The unit

was designed for pressurized-furnace

operation but was converted to balanced

draft operation in 1977.

The unit is equipped with a cold-side

electrostatic precipitator (ESP) and utilizes

two regenerative preheaters each for the

primary and secondary air. Prior to the

LNB retrofit, six FWEC Planetary Roller

and Table type mills provided pulverized

coal to 24 pre-NSPS, Intervane burners,

arranged in a matrix of 12 burners on

opposing walls. The fuel is an eastern

bituminous coal having 33% volatile

matter, 10% ash, 4% moisture, 1.7%

sulfur, and 1.3% nitrogen with a higher

heating value of 12,900 Btu/lb on an

as-received basis.

Advanced Overfire Air (AOFA)

AOFA incorporates two principles for

achieving NOX reduction: (1) depletion of

the air from the flame core of the burner

zone to form a fuel-rich, reducing

environment to minimize NOX formation;

and (2) better mixing and control of OFA

with the furnace gases above the flame

zone to achieve complete combustion.

For this project, FWEC designed an

eight-port AOFA system. This system

diverts air from the secondary air

ductwork and incorporates four flowcontrol dampers at the corners of the OFA

windbox and four OFA ports on both the

front and rear furnace walls. To improve

mixing, the AOFA system increases the

velocity of OFA injection compared with

other types of OFA systems.

How NOX Is Formed in a Boiler

Most of the NOX formed during the combustion process is the result of two

oxidation mechanisms: (1) reaction of nitrogen in the combustion air with

excess oxygen, referred to as thermal NOx; and (2) reaction of nitrogen that

is chemically bound in the coal, referred to as fuel NOX. Thermal NOX

generally represents about 25% of the total and fuel NOX about 75%. In

addition, minor amounts of NOX are formed through complex interaction of

molecular nitrogen with hydrocarbons in an early phase of the flame front;

this is referred to as prompt NOX.

The quantity of NOX formed depends primarily on the "three t’s:"

temperature, time, and turbulence. In other words, flame temperature and

the residence time of the fuel/air mixture, along with the nitrogen content of

the coal and the quantity of excess air used for combustion, determine NOX

levels in the flue gas. Combustion modifications delay the mixing of fuel and

air, thereby reducing temperature and initial turbulence, which minimizes

NOX formation.

Typically, OFA introduces air into the

furnace in stages by diverting 10 to 25% of

the total combustion air to ports located

above the primary combustion zone. AOFA

improves this approach by introducing the

overfire air through separated ductwork at

higher velocities and with more control.

The resulting system provides staging of the

7
NOX emissions results for wall-fired boiler.

Low-NOX burner installed

at Plant Hammond.

Split Flame Coal Nozzle

(Variable Velocity)

8

combustion process, combined with

accurate measurement of the AOFA flow.

To reduce slagging (deposition of

molten mineral matter from coal on the

furnace surfaces) and corrosion, the system

is designed so that some of the combustion

air is passed over furnace walls and tube

surfaces. This provides a boundary of air

that maintains an oxidizing atmosphere

close to the boiler tube walls.

Low-NOX Burners

The 24 existing Intervane burners were

replaced with FWEC Controlled Flow/ Split

Flame low-NOX burners. In these burners,

secondary combustion air is divided

between inner- and outer-flow registers. A

sliding-sleeve damper regulates the total

secondary air flow entering the burner and is

used to balance the air flow distribution

among the burners. An adjustable outer

register assembly divides the secondary air

into two concentric paths and also imparts

swirl to the air.

The secondary air that traverses the inner

path flows across an adjustable inner

register assembly that, by providing a

variable pressure drop, apportions the flow

between the inner- and outer-flow paths.

The inner register also controls the degree

of additional swirl imparted to the coal/air

mixture in the near-throat region of the

burner. The outer-air flow, which enters the

furnace axially, provides the remaining air

necessary to complete combustion. An

axially movable inner sleeve tip provides a

means to vary the velocity of the primary air

while maintaining a constant mass flow.

The split-flame nozzle segregates the

coal/air mixture into four concentrated

streams, each of which forms an individual

flame when entering the furnace. This

segregation minimizes mixing between the

coal and primary air, thereby assisting in

staging of the combustion process to

minimize the formation of NOX.
Test Results

With AOFA alone, the average longterm

NOX emissions were reduced by 24% from

baseline values. For LNB alone, the reduction was 48%, while for LNB + AOFA

the reduction was 68%. An unexpected

consequence of installing LNBs was a decrease in furnace slagging and an increase

in the amount of particulates (about 25%).

Because of the reduced slagging, some

portion of the mineral matter that would

normally become molten slag in the boiler

instead becomes fly ash. These factors had

an adverse impact on ESP performance,

leading to increased particulate emissions,

which was a factor in the decision to install

a new ESP at this site. Other sites may not

require ESP replacement. Several on-line

carbon-in-ash monitors are being evaluated

as to their reliability, maintenance

requirements, accuracy, repeatability,

The Clean Coal Technology (CCT)

Program is a unique partnership between the federal government and

industry that has as its primary goal the

successful introduction of new clean coal

utilization technologies into the energy

marketplace. With its roots in the acid

rain debate of the 1980s, the program is

on the verge of meeting its early

objective of broadening the range of

technological solutions available to

eliminate acid rain concerns associated

with coal use. Moreover, the program

has evolved and has been expanded to

address the need for new, highefficiency power-generating technologies that will allow coal to continue

to be a fuel option well into the 21st

century.

Begun in 1985 and expanded in 1987

consistent with the recommendation of

the U.S. and Canadian Special

and suitability for use in this project.

These instruments provide information that

enhances boiler control capabilities.

T-Fired Boiler

Applications

The SCS NOX control project for T-fired

boilers used an approach similar to that

used on the wall-fired project. However,

the T-fired technology is, by definition,

different from the wall-fired system. The

retrofits to this boiler involved installing air

and coal inlet nozzles in three different

configurations that change the way in which

coal, primary air, secondary air, and OFA

are injected into the boiler.

As indicated previously, conventional

T-fired systems use vertical stacks of burners

The Clean Coal Technology Program

Envoys on Acid Rain, the program has

been implemented through a series of

five nationwide competitive solicitations.

Each solicitation has been associated

with specific government funding and

program objectives. After five

solicitations, the CCT Program

comprises a total of 40 projects located

in 18 states with a capital investment

value of nearly $6.0 billion. DOE’s share

of the total project costs is about $2.0

billion, or approximately 34 percent of

the total. The projects’ industrial

participants (i.e., the non-DOE

participants) are providing the

remainder- nearly $4.0 billion.

Clean coal technologies being demonstrated under the CCT Program are

establishing a technology base that will

enable the nation to meet more

stringent energy and environmental

goals. Most of the demonstrations are

Low-NOX Concentric Firing System

(LNCFSTM).

being conducted at commercial scale,

in actual user environments, and under

circumstances typical of commercial

operations. These features allow the

potential of the technologies to be

evaluated in their intended commercial applications. Each application

addresses one of the following four

market sectors:

• Advanced electric power

generation

• Environmental control devices

• Coal processing for clean fuels

• Industrial applications

Given its programmatic success,

the CCT Program serves as a model

for other cooperative government/

industry programs aimed at introducing new technologies into the

commercial marketplace.

T-Fired Burners

(in each corner of boiler)

9
at each comer of the furnace. The coal and

air nozzles are alternated and angled to

direct the air and fuel inward toward the

middle of the furnace in a tangential firing

circle. By offsetting the nozzles slightly,

the combustion gases are made to swirl.

Southern Company Services’ Plant Smith, site of a T-fired project designed to

demonstrate three variations of LNCFSTM technologies for NOX reduction.

NOX, emissions results for T-fired boiler.

10

The nozzles can also be tilted vertically to

control temperature throughout the furnace

to meet steam requirements.

Test Site

The Plant Smith project consisted of

retrofitting low-NOX burners on a T-fired

boiler at Unit No. 2, which has a capacity

of 200 MWe. The boiler is an ABB/CE

radiant reheat, natural circulation steam

generator, with five elevations of burners.

The unit was originally designed for

pressurized-furnace operation, but was

converted to balanced draft operation in

1976.

The fuel burned in the test program was

an eastern bituminous coal with about

35% volatile matter, 8% ash, 9% moisture,

2.8% sulfur, and 1.4% nitrogen with a

higher heating value of 12,000 Btu/lb on

an as-received basis.

Low-NOX Concentric Firing System

(LNCFTM)

LNCFSTM allows improved control of

coal/air mixing by directing the secondary

air in a circle outside of the circle formed

by the coal and primary air. This configuration produces a stable flame front and a

fuel-rich (oxygen-deficient) flame core in

which coal-bound nitrogen is converted to

molecular nitrogen.

LNCFSTM was specifically developed

for retrofitting to T-fired furnaces. The

major components of LNCFSTM are OFA,

offset secondary air, and flame attachment

coal nozzle tips. As defined previously,

OFA refers to air introduced into the

furnace above the top coal nozzle. Two

types of OFA are employed in the

LNCFSTM technology. Close-coupled

overfire air (CCOFA) is introduced

immediately above the top coal nozzle

using the main windbox. Separated

overfire air (SOFA) is introduced through

a windbox and air nozzles separated from

the main windbox.
Offset secondary air is introduced between the coal nozzles. This air is injected

through concentric auxiliary nozzle tips

installed on the air nozzles in the main

windbox. The angle of these nozzles can

be adjusted both horizontally (yaw) and

vertically (pitch). In general, these nozzles

are adjusted to direct the air toward the

furnace walls to reduce fouling and corrosion. This produces two concentric circular combustion regions. Most of the coal

is contained in the fuel-rich inner zone,

which is surrounded by a fuel-lean outer

zone containing combustion air. The size

of the outer zone can be varied by adjusting

the yaw and pitch of the offset air nozzles.

Flame attachment tips are installed on

the coal nozzles to stabilize and ignite the

coal stream close to the nozzles to devolatilize the coal as quickly as possible and

release the fuel nitrogen in an oxygen poor

region of the flame. This helps minimize

formation of fuel NOX.

Test Results

All three levels of LNCFSTM technology

were successful in lowering NOX levels at

full load of 200 Mew. Levels I and II

averaged 37% reduction, while Level III

averaged 45% reduction. As load was reduced, NOX reduction remained relatively

constant down to a load of about 100 MWe

(about 50% of rated capacity). As load

was further reduced, however, NOX

emissions rapidly increased, reaching

baseline levels at 50-70 MWe.

LNCFSTM technology is potentially

applicable to a wide range of T-fired utility

and industrial boilers throughout the

United States and abroad. There are nearly

600 U.S. pulverized-coal T-fired utility

units. These units range in electric

generating capacity from 25 MWe to 950

MWe. A wide range of coals, from lowvolatile bituminous through lignite, are

being fired in these units. LNCFSTM

technology can be used in retrofit as well

as new boiler applications.

Three variations of LNCFSTM were demonstrated in the Plant Smith project:

Level 1, Level 11, and Level Ill. These levels represent different ways of using the

coal and air to provide reductions in NOX emissions. The three levels differ

from each other as follows:

• Level I involves CCOFA but does not include SOFA. CCOFA is integrated

directly into the existing windbox by exchanging the locations of the top coal

and air nozzles. LNCFSTM I is the easiest and cheapest to install, because it

does not require the addition of the SOFA windbox. It provides the NOX -

reducing advantages of an OFA system without major pressure part modifications to the boiler.

• Level II includes a SOFA system while maintaining the original arrangement of

coal and air nozzles. Thus, it includes SOFA but does not include CCOFA.

Like Level I, Level II uses secondary or offset air to provide an oxygen-rich

environment near the water wall, which prevents slagging and corrosion.

Because of the need for the SOFA windbox, the capital cost for Level II is

higher than for Level I. Also, for some furnaces, depending on the furnace size

and configuration, it may be difficult to install the SOFA windbox.

• Level Ill is a combination of Level I and Level II in that it uses both CCOFA and

SOFA to achieve the greatest degree of NOX reduction. The capital cost for

Level Ill is only slightly higher than for Level II.

11

Baseline LNCFS I LNCFS 11 LNCFS Ill

Source: Southern Company Services, Inc.
An advantage is that boiler operation with

these in-furnace technologies does not

require intensive retraining of the

operating staff.

Public Service Company of Colorado’s Arapahoe Station, site of a vertically fired boiler

project designed to demonstrate LNB+OFA technology for NOX reduction.

Vertically Fired Boiler

Applications

The LNB concept is being evaluated as

part of a CCT project entitled Integrated

Dry NOX/SO2 Emissions Control System,

conducted by Public Service Company of

Colorado at its Arapahoe Station, Unit No.

4 in Denver. The technologies include: 1)

LNB+OFA, 2) in-furnace urea injection for

additional NOX removal, and 3) in-duct

injection of dry sorbents for sulfur dioxide

removal. For this report, only the

LNB+OFA option is discussed.

Test Site

Unit 4, the largest of four vertically fired

boilers located at the Arapahoe Station, is

rated at 100 MWe. The unit was built in the

early 1950’s and was designed to bum

Colorado lignite or natural gas. Currently,

the main fuel source for the station is a

Colorado low-sulfur bituminous coal having

34% volatile matter, 10% ash, 10% moisture,

0.4% sulfur, and 1.3% nitrogen with a

higher heating value of 10,600 Btu/lb on an

as-received basis.

The original furnace configuration was a

vertically fired system employing 12

intertube burners located on the roof and

arranged in a single row across the width of

the furnace. A single division wall separates

the furnace into two halves, each with six

burners.

This demonstration project uses Babcock

& Wilcox (B&W) Dual Register BurnerAXially Controlled Low-NOX (DRB-XCL®)

burners. Most LNBs reduce the formation of

NOX through the use of air staging. The

B&W DRB-XCL® burner achieves

increased effectiveness by incorporating fuel

and air staging.

Combustion air to each burner is measured and regulated to provide balanced fuel

/air distribution for optimum NOX reduction

12
and combustion efficiency. The burner

assembly is equipped with two sets of

adjustable spin vanes that provide swirl

for fuel/air mixing and flame stabilization.

The remaining air for complete combustion is introduced through a set of NOX

ports. Conventional single-jet OFA ports

are not capable of providing adequate

mixing across the entire furnace. The

B&W dual-zone NOX ports, however,

incorporate a central zone that produces an

air jet that penetrates across the furnace and

a separate outer zone that diverts and

disperses the air in the area of the furnace,

near the NOX port. The central zone is

provided with a manual air control disk for

flow control, and the outer zone

incorporates manually adjustable spin

vanes for swirl control. Each OFA port

contains two separate air flow measurement

devices to assist in balancing the two

different areas. Because the furnace is a

down-flow design, the NOX ports actually

supply underfire air rather than overfire air.

Test Results

NOX reduction ranged from 63 to 69%

over a boiler load range of 60 MWe to

100 MWe. Over the range of OFA flow

rates investigated, the majority of the NOX

reduction was obtained with LNBs, with

little additional NOX reduction provided

by OFA at equivalent excess air levels.

Dayton Power & Light’s J.M. Stuart Station, where B&W conducted a demonstration of

Low-NOX CellTM Burner (LNCBTM) technology.

13

NOX emissions results for vertically fired boiler.

B&W Dual Zone NOX Port.

Source: The Babcock & Wilcox Company
However, because port temperature limitations precluded testing at OFA flow rates

below 15%, it was not possible to totally

separate the effects of LNBs and OFA.

Emissions of carbon monoxide (CO)

were not affected by the retrofit, but significant reductions were seen with increasing

OFA flow rates. This was contrary to what

was expected, and is attributed to increased

OFA penetration and mixing at the higher

flow rates.

14

No major operating problems have developed, although the retrofit combustion

system has resulted in a decrease in furnace

exit gas temperature of approximately

200°F. This has resulted in a small increase

in the amount of excess air required to

maintain adequate steam temperatures at

reduced boiler loads.

Cell Burner Boiler

Applications

B&W conducted a demonstration of

Low-NOX CellTM Burner (LNCBTM) technology, with Dayton Power & Light

(DP&L) as the host and cosponsor. There

are 38 cell burner boilers in the U.S., having a total capacity of about 26,700 MWe.

This comprises about 13% of pre-NSPS

U.S. coal fired generating capacity.

Test Site

The host site was DP&L's J.M. Stuart

Station, Unit 4, located in Aberdeen, Ohio,

rated at 605 MWe. The unit is a oncethrough, positive-pressure cell burner

boiler, with two rows of six two-nozzle cell

burners in both its front and rear walls, for a

total of 48 coal-fired burners in 24 cells.

Fuel for the test program was a

midwestern bituminous coal with about

33% volatile matter, 14% ash, 5% moisture,

1.1% sulfur, and 1.3 % nitrogen with a

higher heating value of 11,900 Btu/lb on an

as-received basis.

Cell Burner Boilers

Most cell burner boilers use two-nozzle

cell burners (a few use three-nozzle cell

burners), which fire pulverized coal under

high-intensity combustion conditions. The

resulting high temperatures lead to formation of significant amounts of NOX.

Economic considerations, which dominated boiler design during the 1960's, led to
the development of cell burners for

achieving high system efficiency in compactly designed utility boilers. Cell

burners are designed for rapid mixing of

fuel and air to achieve high rates of

combustion. The tight burner spacing and

rapid fuel/air mixing minimize flame size

while maximizing heat release rates and

overall unit efficiency.

In a standard two-nozzle cell burner,

each cell consists of two circular register

burners mounted in close proximity to each

other within one vertical assembly. These

assemblies are located on opposite walls of

the lower furnace. A mixture of coal and

primary air enters each burner and is dispersed radially outward into the secondary

air stream by means of an impeller located

at the furnace end of the nozzle. Secondary

air from the windbox passes through an

adjustable register into an annular passage

around the coal nozzle. The register acts as

both a flow control device and a swirl

generator.

Retrofitting conventional low-NO

X

burners in cell burner boilers requires

major boiler pressure part modifications.

This is because the cell burner throat openings are too small to permit the low burner

air velocities required for delayed combustion. Further, optimum NOX reduction is

achieved by conventional low-NO

X burners

when the heat release rate per unit furnace

volume is low. This is not readily achievable in a typical cell burner configuration

where the burners are closely spaced.

Low-NO

X CellTM Burner Technology

B&W developed the LNCBTM technology as an alternative approach to conventional LNBs. In this system, a standard

two-nozzle cell burner is replaced with an

LNCBTM, which consists of a single lower

coal nozzle and an upper secondary air

port. The secondary air port, used for OFA,

is designated by B&W as the NO

X port.

Approximately 60-70% of the air theoreti

-

cally required for complete combustion is

provided to the lower nozzle, along with

the coal. The remainder of the air is introduced through the NOX port.

In the LNCBTM, the lower coal nozzle is

a B&W S-type low-NO

X burner, with its

burner throat enlarged so that it has the

same fuel input capacity as the two burner

nozzles it replaces. An impeller mounted at

the exit of the lower burner radially

disperses the fuel rich coal/air mixture. The

impeller angle controls the flame shape and

length.

The NOx port is equipped with a sliding

disk to regulate air flow and louvers at the

outlet to control mixing of the air with the

15
fuel-rich flame. Adjustable spin vanes in

the lower burner barrel control the swirl of

the secondary air to aid in shaping the

flame.

Because the LNCBTM concept was

designed specifically to fit standard twonozzle cell burner openings and spacings,

no major modifications to boiler pressure

NOX Emissions from Coal-Fired Boilers in the U.S.

The following table summarizes NOX emissions from coal-fired utility plants

in the U.S. prior to enactment of the Clean Air Act Amendments of 1990,

categorized by boiler type.

NOX Emissions

Boiler No. of Capacity, % of Total 1000 Tons/ % of

Type Boilers GWe Capacity Year Total

Dry Bottom Wall-Fired 411 120.7 36.9 2,147 35.8

Wet Bottom Wall-Fired 39 8.6 2.6 277 4.6

Tangentially Fired 423 138.3 42.3 2,053 34.2

Cyclone Fired 89 27.6 8.5 732 12.2

Vertically Fired 33 4.8 1.5 100 1.7

Cell Burner 36 24.1 7.4 679 11.3

Fluidized Bed 5 0.7 0.2 2 0.1

Other 27 1.9 0.6 6 0.1

Total 1063 326.7 100.0 5,996 100.0

16

parts are required. These two factors constitute the key attraction of the technology.

A laboratory test program conducted by

B&W in the early 1980's showed that

LNCBTM burners maintain a stable flame

throughout the operating range and that the

expected reduction in NOX emissions is

about 50%. B&W concluded that LNCBTM

retrofit technology could be applied to all of

the two-nozzle cell burner boilers in the

United States. However, the LNCBTM retrofit technology is not applicable to threenozzle cell burner boilers. The purpose of

the CCT project was to demonstrate

LNCBTM technology on a commercial scale.

In initial operation of the full-scale

retrofit, excessive concentrations of carbon

monoxide and hydrogen sulfide were found

in the boiler hopper. Application of B&W's

mathematical combustion models led to

design of a modified firing configuration

that mitigated this problem. The revised

configuration involves inverting alternating

LNCBsTM in the bottom burner rows on

both faces of the furnace. DP&L has

accepted the technology and continues to

run it on a routine basis.

Test Results

Reaching the emissions target for the

test program initially required replacing

the 24 burner impellers with impellers

having a more shallow angle than used

originally. At full load of 605 Mwe,

uncontrolled NOX emissions averaged

1.18 lb/106

 Btu. With LNCBTM , NOX

emissions decreased to 0.53 lb/106 Btu,

representing a reduction of 55%.

At intermediate load (460 MWe) the

NOX reduction averaged 55%, while at low

load (350 MWe) it was 47%. This

represents an acceptable turndown ratio for

boiler operation.

Maximum unit load was not affected,

and the impact on furnace exit gas temperature was negligible. In general, boiler efficiency when operating with the LNCBTM

Load (MWe)

 NOX emissions results for cell burner boiler.

NOX Emissions, lb/106 Btu
retrofit showed very little change from that at

baseline conditions. Only minor changes

were found in the cleanliness of convective

pass heat transfer surfaces. An area of high

corrosion was found during the test program, but corrosion rates were not significantly higher than those measured under

baseline cell burner operating conditions.

Coated tube materials tested in the boiler

exhibited excellent corrosion resistance.

A beneficial result of the LNCBTM retrofit was a significant reduction in the buildup

of agglomerated "popcorn" ash and associated erosion on horizontal convective pass

tubes experienced with the original cell

burner firing configuration. Required maintenance for the air heaters, fly ash handling

equipment, and bottom ash handling equipment has been reduced as a result of the

improved properties of the ash.

Artificial Intelligence for

NOX Control

Experience with several CCT projects

involving combustion modification has

shown a tendency toward increased UBC

values in the fly ash. [This is often expressed in terms of loss-on-ignition (LOI). Because the analytical procedures for determining LOI and UBC are not the same, the

terms are not strictly synonymous. However,

they are often used interchangeably.]

As mentioned previously, increased carbon content of the fly ash adversely affects

ESP performance as well as fly ash marketability. Fly ash can be sold for use in cement

manufacture and as road construction

material, among other things, provided that

the UBC content meets specifications. Although UBC can be reduced by operating

changes such as increasing coal fineness, a

significant UBC problem exists and is

receiving considerable attention.

Experience has also indicated that combustion modification leads to difficulties

in boiler optimization. This is a result of

several factors, including: (1) increased

complexity of the combustion system, and

(2) increased sensitivity of combustion

conditions to process adjustments.

The adverse impacts of applying LNB

technology can sometimes be mitigated by

burner optimization; however, these

measures are typically performed at a few

operating conditions and cannot fully

account for changes in plant operating

conditions and coal characteristics over

extended periods. Further, experience has

shown that NOX emissions vary with time

by as much as ±20% around the long-term

average. A system that reduces the magnitude of these variations and drives NOX

emissions down towards the lower end of

this range could help achieve continuous

compliance without additional controls.

Such an approach could also provide NOX

credits for averaging or trading programs.

GNOCIS

Artificial intelligence has the potential to

aid in optimizing boilers with a view to

minimizing UBC and maximizing overall

efficiency. To demonstrate this concept, the

17

Major elements of Generic NOX Control Intelligent System (GNOCIS)
Of the three areas that comprise

artificial intelligence (neural networks,

expert systems, and fuzzy logic), neural networks are considered by many to

be best suited as advisors—advanced

systems that make recommendations

based on various types of data. These

recommendations, which change

whenever a power plant's operations

change, suggest how auxiliary plant

equipment or technologies can be

optimized.

In the evolution of artificial intelligence systems, neural networks

surpass their older cousins, expert

systems and fuzzy logic. The least

specific type of artificial intelligence

software, fuzzy logic is a type of expert

system equipped with a set of

approximate rules used whenever

"close enough is good enough."

Elevators and camera autofocusing

systems are primary users of fuzzy

logic systems. Fuzzy logic stops an

elevator at a floor when it is within a

certain range, not at a specific, definite point. Expert systems, on the

other hand, "learn" by following a set

of pre-established rules written in

codes or computer language. Expert

systems are assumed to understand

the relationship between input and

output information based on detailed

knowledge of a specific process.

scope of the LNB project being conducted

by SCS at Plant Hammond Unit 4 has been

expanded to include demonstration of an

on-line enhancement tool for the power

plant’s distributed control system (DCS).

This tool, which has been termed Generic

NOX Control Intelligent System (GNOCIS),

is designed to provide recommendations

that achieve NOX reduction consistent with

economic and operational constraints.

The Evolving World of Artificial Intelligence

While it is being developed and demonstrated on coal-fired boilers, GNOCIS can

operate on units burning gas, oil, or coal

and, at least conceptually, is applicable for

all combustion firing geometries. GNOCIS

is projected to reduce NOX emissions by

10-35% from the baseline emission level

while meeting other site-specific operational constraints, such as UBC and furnace

exit gas temperature.

Neural networks are the latest type

of artificial intelligence to enter the

power plant industry. Computational

devices that use organized principles

of biological nervous systems, neural

net-works do not assume relationships.

Instead, they determine relationships

by analyzing data, learning much the

way humans do, by example and repetition. When it assigns an incorrect

output with a given input, the network

corrects itself by changing the weight

matrices. While it can take considerable time to complete this learning

curve—depend-ing on the complexity

of the problem—neural networks outperform any other current approach to

recognizing patterns. Modeled after the

human brain, made up of interconnected neurons that contain a limited

amount of information, neural networks

are constructed of simple dataprocessing units with limited capabilities. When connected together, they

form the highest artificial intelligence

system known, capable of estimating

the lifespan of mechanical parts, diagnosing malfunctions in automobiles, and

recognizing human speech. Most

importantly, they provide valuable

information that cannot be obtained any

other way.

18

Diagram of the structural relationship shared by biological and artificial

neural networks.
This scope addition complements additional

DOE Fossil Energy funding, through the

Flue Gas Cleanup Program managed by

DOE, and funding provided by a consortium of key industrial players in the United

States and the United Kingdom. Under this

project, GNOCIS was developed and first

demonstrated at a wall-fired site in Alabama and a T-fired site in England. The main

GNOCIS contractors are SCS in the United

States and PowerGen in the United Kingdom. The work in the United Kingdom is

funded by the Department of Trade and

Industry, PowerGen, and EPRI. The work

in the United States is funded by DOE,

Southern Company, and EPRI.

Implementation

GNOCIS utilizes a neural-network model

of the combustion characteristics of the

boiler that reflects both short-term and

longer-term trends.

An optimizing procedure is applied to

identify the best set points for the plant. The

recommended set points are conveyed to the

plant operators via the DCS, i.e., in an

advisory or open-loop configuration or, at

the plant’s discretion, the set points can be

implemented automatically without operator

intervention, i.e., closed-loop. The package

is designed for full-time use.

Prior to demonstrating GNOCIS in the

CCT project at Hammond, developmental

programs were conducted at PowerGen’s

500-MWe tangentially fired Kingsnorth

Unit I in the United Kingdom and Alabama

Power Company’s 250-MWe wall-fired

Gaston Unit 4. Hammond is the first full

commercial demonstration of the technology.

The Hammond Trial

The objective at Plant Hammond is to

evaluate and demonstrate the effectiveness

of advanced digital control/optimization

methodologies as applied to the NO

X

abatement technologies installed during

the CCT project (LNB + AOFA). The

major tasks for the Hammond project

include: (1) design and installation of the

DCS, (2) instrumentation upgrades, (3)

advanced controls/optimization design

and implementation, and (4) characterization of the unit both before and after

activation of the advanced strategies.

GNOCIS testing at Hammond Unit 4

commenced during the first quarter of

1996 in both open-loop-advisory and

closed-loop-supervisory modes,

representing one of the first applications

anywhere of artificial intelligence for

wide-scale power plant control.

Preliminary results at full load show

0.5% efficiency improvement, with a

1–3% reduction in UBC and a 10–15%

reduction in NO

X emissions. This efficiency improvement results in a decrease

in CO

2 emissions of about 1.5%.

GNOCIS Commercialization

After proving GNOCIS at Plant

Hammond and at other sites, SCS and

Radian International intend to commercialize the software in the United States. In its

role as commercializer, Radian has been

deeply involved in the U.S. demonstrations of GNOCIS. PowerGen and one

other as yet unnamed organization will

commercialize GNOCIS in Europe. Several U.S. utilities have already committed

to follow-on demonstration projects and

commercial installations.

19
Low-NOX Burner Retrofit Performance and Costs

Boiler Type Wall-Fired T-Fired Cell Burner

Technology LNB LNCFS I LNCB

Size, MWe 500 200 600

NOX Reduction, % 48 37 55

Capital Cost, $/kW 67 9

Performance and

Economic Comparison

The several types of LNBs tested in

these demonstration projects are being

used successfully in commercial

retrofits for NOX reduction.

Based on the results of the

demonstration projects, economics have

been estimated for full-scale commercial

operation. These economics, developed

by the project participants, assume a

baseloaded power plant with a 65%

capacity factor and a 15-year project life.

For a wall-fired unit having a capacity of

500 MWe, the capital cost of a typical

LNB retrofit is projected to be $3.0

million (1996 U.S. dollars), which is

equivalent to about $6/kW. The levelized

cost on a current dollar basis is about

$100/ton of NOX removed. Addition of

OFA increases the capital by $7/kW,

bringing the total to $13/kW.

For a T-fired boiler having a capacity

of 200 MWe, retrofitting LNCFSTM

Level I requires a capital expenditure of

$1.4 million, or about $7/kW, and the

levelized cost is $103/ton.

For a 600-MWe cell burner boiler, the

capital required for retrofitting LNCBTM

technology is $5.4 million, or $9/kW.

The levelized cost is $125/ton.

20

The capital cost of retrofitting a 300

MWe vertically fired boiler with

LNB+OFA is $11.7 million, or $39/kW,

and the levelized cost is $350/ton. These

costs are significantly higher than for other

types of boilers discussed in this report

owing to the fact that major boiler

modifications are required.

In summary, for wall-fired, T-fired,

and cell burner boilers, retrofit LNB can

be installed at a capital cost of less than

$10/kW and a levelized cost of about

$100-$125/ton. While these costs are

based on the results of the CCT projects,

they are consistent with information

obtained independently from several

commercial installations of LNB, thereby

lending credence to the figures.
Bibliography

Federal Register, Vol. 61, No. 13,

January 19, 1996, pp. 1442-1480.

J.N. Sorge and S.M. Wilson, "500 MW

Demonstration of Advanced Wall-Fired

Combustion Techniques for the Reduction of

Nitrogen Oxide Emissions from Coal-Fired

Boilers," Third Annual Clean Coal Technology

Conference. Chicago, Illinois, September

1994.

J.N. Sorge, W. Menzies, S.M. Smouse, and JW.

Stallings, "500 MW Demonstration of

Advanced Wall-Fired Combustion Techniques

for the Reduction of Nitrogen Oxide Emissions

from Coal-Fired Boilers," Fourth Annual Clean

Coal Technology Conference, Denver,

Colorado, September 1995.

R.R. Hardman, L.L. Smith, and S. Tavoulareas,

"Results from the ICCT T-Fired Demonstration

Project including the Effects of Coal Fineness

on NOX Emissions and Unburned Carbon

Levels," EPRI/EPA Joint Symposium on

Stationary Combustion NOX Controls, May

1993.

R.R. Hardman and G.G. Elia, "180 MW

Tangentially Fired Low NOX Demonstration,"

First Annual Clean Coal Technology

Conference, Cleveland, Ohio, November 1992.

R.A. Smith, L.J. Muzio, and T. Hunt,

"Integrated Dry NOX/SO2 Emissions Control

System: Low-NOX Combustion System

Retrofit Test Report," April 1994.

T. Hunt et al., "Current Progress with the

Integrated Dry NOX/SO2 Emissions Control

System," Third Annual Clean Coal

Technology Conference, Chicago, Illinois,

September 1994.

A.S. Yagiela et al., "Results of Babcock &

Wilcox’s Clean Coal Technology Combustion

Modification Projects: Coal Reburning for

Cyclone Boiler NOX Control and Low NOX

CellTM Burner Demonstrations," Second Annual

Clean Coal Technology Conference, Atlanta,

Georgia, September 1993.

A.S. Yagiela et al., "Status of Babcock &

Wilcox's Clean Coal Technology Combustion

Modification Projects: Coal Reburning for

Cyclone Boiler NOX Control and Low NOX

CellTM Burner Demonstrations," Third Annual

Clean Coal Technology Conference, Chicago,

Illinois, September 1994.

A.L. Baldwin, D.N. Smith, A.N. Mann, H.G.

McIlvried, and S.N. Rao, "Is Selective Catalytic

Reduction (SCR) an Attractive Option for NOX

Control in Coal-Fired Power Plants?," Air &

Waste Management Association's Conference

on Acid Rain & Electric Utilities, Tempe,

Arizona, January 1995.

A-K. Hjalmarsson, "NOX Control Technologies for Coal Combustion," IEA Coal

Research, IEACR/24, June 1990.

To Receive Additional

Information

To be placed on the Department of

Energy's distribution list for future

information on the Clean Coal Technology Program, the demonstration

projects it is financing, or other Fossil

Energy Programs, please contact:

C. Lowell Miller

Associate Deputy

Assistant Secretary

U.S. Department of Energy

FE-22/27OCC

Germantown, MD 20874-1290

(301) 903-9451

(301) 903-2238 fax

Patrice A. Leister

U.S. Department of Energy

Pittsburgh Energy

Technology Center

P.O. Box 10940-0940

Pittsburgh, PA 15236

(412) 892-6126

(412) 892-6127 fax

21
List of Acronyms and Abbreviations

ABB/CE ............................ Asea Brown Boveri/Combustion Engineering Services, Inc.

AOFA .............................................................................................Advanced overfire air

B&W ..................................................................................................Babcock & Wilcox

Btu .................................................................................................... British thermal unit

CAAA .....................................................................Clean Air Act Amendments of 1990

CCOFA ................................................................................... Close coupled overfire air

CCT ............................................................................................Clean Coal Technology

DCS ....................................................................................... Distributed control system

DOE ...................................................................................... U.S. Department of Energy

DP&L ...........................................................................Dayton Power & Light Company

DRB-XCL®....................... Dual Register Burner-AXially Controlled Low NOX burners

EPA .................................................................... U.S. Environmental Protection Agency

EPRI ............................................................................ Electric Power Research Institute

ESP ........................................................................................... Electrostatic precipitator

FWEC ..................................................................... Foster Wheeler Energy Corporation

GNOCIS .......................................................... Generic NOX Control Intelligent System

kW .......................................................................................................................kilowatt

LNB .....................................................................................................Low NOX burners

LNCBTM.........................................................................................Low-NOX Cell Burner

LNCFSTM ................................................................Low-NOX Concentric Firing System

LOI ......................................................................................................... Loss-on-ignition

MWe ................................................................................... Megawatts of electric power

NOX ......................................................................................................... Nitrogen oxides

NSPS .......................................................................New Source Performance Standards

OFA ............................................................................................................... Overfire air

PETC ................................................................... Pittsburgh Energy Technology Center

psig ................................................................................... Pounds per square inch gauge

PSCO .................................................................................... Public Service of Colorado

RACT .......................................................... Reasonably Available Control Technology

SCR ..................................................................................... Selective catalytic reduction

SCS ..................................................................................... Southern Company Services

NCR .............................................................................. Selective noncatalytic reduction

SOFA ............................................................................................. Separated overfire air

T-fired ........................................................................................Tangentially fired boiler

UBC.......................................................................................................Unburned carbon

22
Contacts for CCT Projects and U.S. DOE CCT Program

Team Members

Wall-Fired Boiler Project

at Plant Hammond

Participant

Southern Company Services, Inc.

Contact

John N. Sorge

Project Manager

14N-8195

P.O. Box 2625

Birmingham AL 35202-2625

205-257-7426

205-257-5367 fax

john.sorge@scsnet.com

Additional Team Members

Georgia Power Company

Electric Power Research Institute

Foster Wheeler Energy Corporation

Tangentially Fired Boiler Project

at Plant Smith

Participant

Southern Company Services, Inc.

Contact

Robert R. Hardman

Project Manager

14N-8195

P.O. Box 2625

Birmingham AL 35202-2625

205-257-7772

205-257-5367 fax

robert.r.hardman@scsnet.com

Additional Team Members

Gulf Power Company

Electric Power Research Institute

ABB/C-E Services, Inc

Vertically Fired Boiler Project

at Arapahoe Station

Participant

Public Service Company of Colorado

Contact

Terry Hunt

Project Manager

5900 East 39th Avenue

Denver CO 80207-1294

303-571-7113

303-571-7868 fax

thunt@msp.psco.com

Additional Team Members

Electric Power Research Institute

Stone and Webster Engineering Corp.

The Babcock & Wilcox Company

Fossil Energy Research Corporation

Western Research Institute

Colorado School of Mines

Noell, Inc.

Cell Burner Boiler Project

at J.M. Stuart Station

Participant

The Babcock & Wilcox Company

Contact

Tony Yagiela

Senior Marketing Specialist

1562 Beeson Street

Alliance OH 44601-2196

330-829-7403

330-829-7801 fax

anthony.s.yagiela@rdd.mcdermoff.com

Additional Team Members

The Dayton Power and Light Company

Electric Power Research Institute

Ohio Coal Development Office

Tennessee Valley Authority

New England Power Company

Duke Power Company

Allegheny Power System

Centerior Energy Corporation

This report is available on the Internet at

www.lanl.gov/projects/cctc

U.S. Department of Energy

Contacts

C. Lowell Miller

Associate Deputy Assistant Secretary

Office of Clean Coal Technology

FE-22/27OCC

Germantown MD 20874-1290

301-903-9451

301-903-2238 fax

lowell.miller@hq.doe.gov

Joseph P. Strakey

Associate Director

Office of Clean Coal Technology

Pittsburgh Energy Technology Center

P.O. Box 10940

Pittsburgh PA 15236-0940

412-892-6124

412-892-4775 fax

strakey@petc.doe.gov

Thomas A. Sarkus

Director, Project Implementation Division

Office of Clean Coal Technology

Pittsburgh Energy Technology Center

P.O. Box 10940

Pittsburgh PA 15236-0940

412-892-5981

412-892-4775 fax

sarkus@petc.doe.gov

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