# Electric Generating Utility Mercury Speciation

Profiles for the Clean Air Mercury Rule

# EPA-454/R-11-010

November 2011

Electric Generating Utility Mercury Speciation Prof iles for the

Clear Air Mercury Rule

By:

David Bullock and Shelly Johnson

Research Triangle Institute

Research Triangle Park, North Carolina

Prepared for:

Alison Eyth

Work Assignment Contracting Officer Representative

Air Quality Assessment Division

Contract No. EP-D-11-084

Work Order No. 0-04

U.S. Environmental Protection Agency

Office of Air Quality Planning and Standards

Air Quality Assessment Division

Emissions Inventory and Analysis Group

Research Triangle Park, North Carolina

# 1



# Date : November 14, 2011

Subject: EGU Mercury Speciation Profiles for the Clean Air M ercury Rule

(CAMR)

From: David Bullock

Shelly Johnson

To: Alison Eyth

OAQPS/AQAD/EIAG (C339-02)

U.S. Environmental Protection Agency

Research Triangle Park, NC 27711

I. Background

The U.S. Environmental Protection Agency (EPA) is p reparing for finalizing the National

Emission Standards for Hazardous Air Pollutants fro m Coal- and Oil-Fired Electric Utility

Steam Generating Units (EGUs) under Clean Air Act ( CAA or the Act) section 112(d)

(referred to as the Mercury and Air Toxics Standard s [MATS]). A key piece to several

aspects of the rule documentation includes emission inventory estimates for this sector at the

facility and national resolutions. Associated with the emission inventory estimates is the

application of mercury speciation profiles that wer e developed from the 1999 information

collection request (ICR) data used to support devel opment of the Clean Air Mercury Rule

(CAMR).

This memorandum describes the general process follo wed in the development of the mercury

speciation profiles.

II. Discussion

The development of the mercury speciation profiles can generally be divided into three major

elements: (1) collecting the speciated mercury data , (2) grouping the data into “bins,” and (3)

developing the average mercury speciation profiles for each bin.

These three major elements are discussed in detail in the sections which follow.

Attachment 1 provides a glossary of terms used duri ng development of the mercury

speciation profiles. These terms appear throughout the supporting spreadsheets which are

included as Attachments 2 through 4.

A. Speciated Mercury Data

Eighty mercury emissions tests were collected from 69 facilities. These data include inlet

and outlet speciated mercury concentration measurem ents (μg/dscm) for particle-bound

# 2



# (Hg

p 

# ), oxidized (Hg 2+ 

# ), and elemental (Hg 0 

# ) mercury. All emissions tests were conducted

using the Ontario hydro method and included three s ampling runs. Only the outlet data

(measurements after the last control device) were u sed to develop the mercury speciation

profiles.

In addition to the speciated mercury measurements, measurements of inlet and outlet exhaust

gas flow rate (dscm/hr), temperature (deg C), moist ure content (%), and oxygen content (%)

were reported.

Fuel flow rate measurements (kg/hr) and fuel sampli ng were conducted concurrently with

each emissions sampling run. Fuel samples were ana lyzed for heat content (HHV, Btu/lb),

percent sulfur (%), percent moisture (%), percent a sh (%), chlorine content (ppm), and

mercury content (ppm).

Where emissions sampling results were noted as belo w the method detection limit (MDL),

one-half of the MDL was substituted. These 1⁄2-MDL v alues were included and averaged

with the other run-by-run values in calculating the average speciation fractions for each bin.

In a number of instances, an excessive reagent blan k caused the emissions sampling data to

be unreliable. In other instances, one or more com ponents of the speciation were not

provided in the emission test report. In each of t hese instances, zero was substituted for the

suspect or missing values (i.e., zero is used as th e speciation fraction for all of these

instances). These “zero” values were included and averaged with the other run-by-run values

in calculating the average speciation fractions for each bin. Of the 80 emissions tests (240

test runs), 6 tests (13 test runs) were missing one of the speciation components; 1 test run was

missing two of the speciation components.

In one case, a test sample was broken, damaged, or lost during testing or in transport, such

that no mercury speciation values were available fo r one test run of this sampling program.

In this case, the speciation fractions for the two remaining valid test runs were used in the

development of mercury speciation profiles (Bin 24)

.

A summary of the run-by-run data collected (includi ng notes for non-detect values [ND],

excessive blanks [XB], missing values [NA], or lost samples [LS]) is provided as

Attachment 2.

B. Mercury Emission Reduction Bins

The bins for which mercury speciation profiles were developed were not originally

developed as mercury “speciation bins.” The mercur y emissions data collection effort was

geared toward characterizing the mercury emission r eduction potentials of existing EGU

emission control schemes and developing mercury “em ission modification factors” (EMFs)

for these control schemes. The resulting EMFs were used, in conjunction with fuel mercury

# 3



# content data, to facilitate the estimation of natio nwide mercury emissions from coal-fired

EGUs. With this purpose in mind, the boilers selec ted for emissions testing represented a

range of boiler types, fuel types, and emission con trol configurations. These three

parameters were then used as the criteria for group ing the emissions data into mercury

emission reduction bins.

As a result, the bins were developed to represent d istinct boiler type/fuel type/emission

control scenarios with differing mercury emission r eduction potentials. These same bins

were used to create average mercury speciation prof iles.

Boiler Types

Boiler types represented in the data set include:

Conventional pulverized coal

Cyclone-fired

Stoker-fired

Fluidized-bed combustor (FBC)

Integrated gasification combined cycle (IGCC)

One boiler was reported to have a boiler type of “c onventional pulverized coal, turbo-fired.”

This boiler was included with conventional pulveriz ed coal boilers (Bin 10).

Fuel Types

Fuel types represented in the data set include:

Bituminous coal

Subbituminous coal

Lignite coal

Waste anthracite

Waste bituminous

Data were also collected for boilers firing blends of fuels (primary/secondary), including:

Bituminous coal/petroleum coke

Subbituminous coal/petroleum coke

Bituminous coal/subbituminous coal

Subbituminous coal/bituminous coal

# 4



# Emission Controls

The data set used to develop the speciation data in cludes a cross-section of particulate matter

(PM), sulfur dioxide (SO 2 

# ), and nitrogen oxides (NOx) emission control techn ologies. At the

time these emissions data were collected, none of t he tested units reported the use of any

emission control technology designed specifically f or mercury emission reduction (e.g.,

activated carbon, etc.).

Particulate matter control technologies represented in the data set include:

Baghouse (fabric filter)

Electrostatic precipitator (cold-side)

Electrostatic precipitator (hot-side)

Particulate scrubber

Mechanical collector (cyclone, multicyclone)

SO 2 

# control technologies represented in the data set i nclude:

Dry sorbent injection

Spray dryer adsorber (dry scrubber)

Wet scrubber (wet flue gas desulfurization [FGD])

All fluidized bed combustor (FBC) units in the data set were reported to use limestone

injection into the fluidized bed for SO 2 

# control. Because all of the FBC’s in the data set used

limestone injection, this was not a criterion used in developing emission reduction bins for

FBC units.

NOx control technologies represented in the data se t include:

Selective non-catalytic reduction (SNCR)

Selective catalytic reduction (SCR)

Combustion NOx controls (e.g., low-NOx burners, ove rfire air, etc.) were considered to have

no effect on mercury emission reduction, and thus w ere not considered in the development of

mercury emission reduction bins.

Data Grouping

The collected mercury emission data were grouped (o r “binned”) based on primary and

secondary fuel type, boiler type, PM control, SO 2 

# control, and NOx control. This grouping

resulted in 45 bins, numbered 0 (zero) through 44. Note that bin numbers 26 and 32 were not

used (i.e., no bin type, EMF, or speciation profile was assigned to either of these numbers);

as a result, mercury EMFs and speciation profiles w ere developed for only 43 bins.

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# Attachment 3 provides a summary of the individual r uns of data used to develop the mercury

EMFs and speciation profiles for each bin.

C. Average mercury speciation profiles

After the individual runs of speciated mercury data were grouped into mercury emission

reduction bins, the speciated mercury concentration values for each emission test run were

converted to fractional values.

For example:

Hg

p 

# fraction = Hg

p 

# conc / (Hg

p 

# conc + Hg 2+ 

# conc + Hg 0 

# conc)

where: Hg

p 

# fraction = unitless fraction of mercury in the p article-bound form

Hg

p 

# conc = particle-bound mercury concentration (μg/ dscm)

Hg 2+ 

# conc = oxidized mercury concentration (μg/dscm)

Hg 0 

# conc = elemental mercury concentration (μg/dscm)

To determine the average speciation profile for eac h bin, all of the individual run values for

each speciation fraction (Hg

p 

# , Hg 2+ 

# , and Hg 0 

# ) in each bin were averaged. This yielded an

average fraction for particle-bound, oxidized, and elemental mercury for each bin. The sum

of these three fractions equals one (some profiles may not add exactly to one due to

rounding).

Forty-three EMFs and mercury speciation profiles we re developed from the eighty mercury

emissions tests. The majority of the speciation pr ofiles are based on very limited data sets.

Of the 43 bins for which EMFs and mercury speciatio n profiles were developed, 22 (51%)

were based on a single emission test; 11 (26%) were based on only two emission tests; 7

(16%) were based on only three emission tests. Onl y 3 (7%) of the 43 bins are based on

more than three emission tests. Nevertheless, these data represent the best available

information on mercury speciation from EGUs.

A summary of the mercury emission reduction bins an d the final mercury speciation profiles

is provided as Attachment 4.

III. Conclusion

Forty-three mercury emission reduction bins and the ir associated mercury speciation profiles

were developed from the eighty mercury emissions te sts collected to support the

development of the CAMR. These speciation profiles may be applied to measurements of

total mercury emissions from electric utility boile rs (taking into account boiler type, fuel

# 6



# type, and emission control schemes) to estimate the speciation of mercury (Hg

p 

# , Hg 2+ 

# , and

Hg 0 

# ) where no speciated mercury sampling data are avai lable.

Follow-on work to the mercury speciation profile de velopment conducted under CAMR

might include augmenting the small data sets for ma ny of the speciation profiles, and

collecting additional data to develop mercury speci ation profiles for units equipped with

mercury control technologies (e.g., activated carbo n injection, etc.). Additional analyses

might be conducted specifically with the goal of de veloping mercury speciation profiles,

rather than emission reduction bins.

# 7 

# ATTACHMENTS

# 8 

# ATTACHMENT 1

Glossary of Terms

# 9



# Glossary

General Terms

EMISSION MODIFICATION FACTOR (EMF) = An EMF is a fr action obtained from the

amount of Hg exiting an air pollution control devic e (APCD) divided by the amount of the Hg

entering that device. The total EMF can also be de fined as one minus the total Hg removal

fraction. For example, a total EMF of 0.68 is equa l to a mercury removal efficiency of 0.32 (or

32 %).

EIA PLANT CODE = A ten digit plant code assigned to all non-cogeneration electric utility

plants by the Department of Energy’s, Energy Inform ation Administration (DOE/EIA). An

example of an EIA Plant Code is 0154660000. Note: On DOE’s EIA Form 767 a combination of

the EIA plant code and the ORIS plant code (defined below) is used. An example would be

0154660000-00477.

ORIS PLANT CODE = This 5-digit plant code was origi nally developed for utility plants by the

Office of the Regulatory Information System (ORIS), which was a part of the Federal Power

Commission. It is now used as a unique plant ident ification code assigned by EIA. An example

of an ORIS code is 00477.

Fuel Type

ANTHRACITE = Anthracite coal is a combustible rock composed of organic and mineral

materials that has formed over time by vegetative d ecay and mineral deposition. The properties

of coal vary depending on the type of vegetative ma tter and the formation conditions (reference

ASTM D 388-82). In general, anthracite coal has a higher heating content (Btu/lb) than

bituminous coal.

BITUMINOUS = Bituminous coal is a combustible rock composed of organic and mineral

materials that has formed over time by vegetative d ecay and mineral deposition. The properties

of coal vary depending on the type of vegetative ma tter and the formation conditions (reference

ASTM D 388-82). Bituminous coal has a higher heati ng content (Btu/lb) than subbituminous

coal.

SUBBITUMINOUS = Subbituminous coal is a combustible rock composed of organic and

mineral materials that has formed over time by vege tative decay and mineral deposition. The

properties of coal vary depending on the type of ve getative matter and the formation conditions

(reference ASTM D 388-82). Subbituminous coal has a higher heating content (Btu/lb) than

lignite coal.

# 10



# LIGNITE = Lignite coal is a combustible rock compos ed of organic and mineral materials that

has formed over time by vegetative decay and minera l deposition. The properties of coal vary

depending on the type of vegetative matter and the formation conditions (reference ASTM

D 388-82). Lignite coal has the lowest higher heati ng content (Btu/lb) of the four major coal

rankings.

PET COKE = Petroleum coke is a by-product of the pe troleum refining process and is burned as

a supplemental fuel with coal.

WASTE BITUMINOUS = Waste bituminous coal reclaimed from mine waste piles.

WASTE ANTHRACITE = Waste anthracite coal reclaimed from mine waste piles.

Furnace Type

CONV/PC = Conventional, pulverized coal-firing furn ace. In pulverized-coal-fired boiler

systems, coal is pulverized in a mill to the consis tency of talcum powder (i.e., at least 70 percent

of the particles will pass through a 200-mesh sieve ). The pulverized coal is generally entrained

in primary air before being fed through the burners to the combustion chamber, where it is fired

in suspension.

FBC = Fluidized-bed combustor. In an FBC, combusti on occurs when coal, together with inert

material (e.g., sand, silica, alumina, or ash) and/ or a sorbent such as limestone, are suspended

through the action of primary combustion air distri buted below the combustor floor. "Fluidized"

refers to the state of the bed of material (fuel or fuel and inert material [or sorbent]) as gas passe s

through the bed.

COAL GAS = Integrated Coal Gasification Combined Cy cle Units. At a coal gasification power

plant the coal-fired boiler unit is replaced with a coal gasification unit coupled with a gas turbine

combustor and heat recovery boiler. The solid coal is gasified by a process in which a coal/water

slurry is reacted at high temperature and pressure with oxygen (or air) and steam in a vessel (the

gasifier) to produce a combustible gas. This combu stible gas is composed of a mixture of carbon

dioxide and hydrogen and is often referred to as a synthetic gas or “syngas”.

CYCLONE = Cyclone firing uses several water-cooled horizontal burners that produce hightemperature flames that circulate in a cyclonic pat tern. The burner design and placement cause

the ash to become a molten slag that is collected b elow the furnace.

STOKER = Stoker-fired furnace. In stoker furnaces, coal is burned on a bed at the bottom of the

furnace. The bed of coal burns on a grate. Heated air passes upward through openings in the

grate.

TURBO = Turbo-fired. This furnace is a specialized form of a conventional, pulverized

coal-fired furnace.

# 11



# WET or DRY = Furnaces are classified as either dry or wet bottom, depending on the ash

removal technique. Dry bottom furnaces fire coals with high ash fusion temperatures, and dry

ash removal techniques are used. In wet bottom (sl ag tap) furnaces, coal with a low ash fusion

temperature is used, and molten ash is drained from the bottom of the furnace.

Nitrogen Oxides control technology

NOX = Combustion NO X 

# controls. A variety of combustion control practic es can be used

including low NO

x 

# burners, overfire air, off-stoichiometric firing, selective or biased burner

firing, reburning, and burners-out-of-service. Con trol of NO X 

# can also be achieved through

staged combustion (also called air staging).

NONOX = No combustion NO X 

# controls on furnace.

SCR = Selective Catalytic Reduction (a post combust ion, add-on, NO X 

# control device). The

selective catalytic reduction (SCR) process uses a catalyst with ammonia gas (NH 3 

# ) to reduce the

NO and NO 2 

# in the flue gas to molecular nitrogen and water.

SNCR = Selective Noncatalytic Reduction (a post com bustion, add-on, NO X 

# control device).

The selective noncatalytic reduction (SNCR) process is based on the same basic chemistry of

reducing the NO and NO 2 

# in the flue gas to molecular nitrogen and water as the SCR but does

not require the use of a catalyst to prompt these r eactions.

Sulfur Dioxide control technology

WETSCRUB = A flue gas desulfurization wet scrubber (FGD, [lime or limestone]), in which

flue gas containing SO 2 

# is brought into contact with a limestone-water slu rry. The SO 2 

# is

absorbed into the slurry and reacts with limestone to form an insoluble sludge.

COMP COAL = Compliance coal has a specifically desi red low sulfur content to bring

emissions into compliance with SO 2 

# regulations. Compliance coal may be obtained thro ugh the

mining of low-sulfur coals, coal washing, and/or coal blendin g.

SDA = Dry lime/spray dryer adsorber followed by a b aghouse. In an SDA, flue gas is contacted

with fine spray droplets of hydrated lime slurry in a spray dryer vessel. The SO 2 

# is absorbed in

the slurry and reacts with the hydrated lime reagen t to form solid calcium sulfite and calcium

sulfate as in a wet lime scrubber. The water is ev aporated by the heat of the flue gas. The dried

solids are entrained in the flue gas, along with fl y ash, and are collected in a baghouse.

FBC = In an SO 2 

# control context, FBC refers to the use of a sorben t such as limestone in the

furnace’s fluidized bed for SO 2 

# control.

SORBENT INJ = Dry injection process, dry powdered l ime (or another suitable sorbent) is

directly injected into the ductwork upstream of a P M control device.

# 12



# Particulate matter control technology

ESP- CS = Electrostatic precipitator, cold-side (me aning this ESP is installed at a location

downstream of the air preheater). ESPs operate by imparting an electrical charge to incoming

particles, then attracting the particles to opposit ely charged plates for collection. The collected

particles are periodically dislodged in sheets or a gglomerates by rapping or otherwise vibrating

the plates.

BAGHOUSE = Baghouses are fabric filters that collec t PM by placing a fabric barrier in the flue

gas path. Gas passes freely through the fabric, bu t particles are trapped and retained for periodic

removal.

ESP- HS = Electrostatic precipitator, hot-side (mea ning this ESP is installed at a location

upstream of the air preheater). ESPs operate by im parting an electrical charge to incoming

particles, then attracting the particles to opposit ely charged plates for collection. The collected

particles are periodically dislodged in sheets or a gglomerates by rapping or otherwise vibrating

the plates.

ESP- CS/BAGHOUSE = A cold-side ESP followed by a fa bric filter.

MECH = Mechanical collector (assumed to be a cyclon e collector in this screening tool). Flue

gas entering a cylinder tangentially to the wall is imparted with a circular motion around the

cylinder’s axis. Particles in the gas stream are f orced toward the wall by centrifugal force, then

downward through a conical discharge at the bottom of the cylinder.

PARTSCRUB = Particulate scrubber. Particulate scru bbers operate by shattering streams of

water into small droplets that collide with and tra p solid particles contained in the flue gas or by

forcing the gases into intimate contact with water films. The particle-laden droplets or water

films coalesce and are collected in a sump at the b ottom of the scrubber.

MECH/PARTSCRUB = A mechanical collector followed by a particulate scrubber.

# 13 

# ATTACHMENT 2

Hg_speciation_data_CAMR.xls

(Tab: 02_Raw_Data_Table)123456789101112131415161718192021222324252627282930313233343536373839404142434445464748495051525354555657585960AB C D E F G H I JPlant NameEIA Plant CodeUnit No.RunNumberCoalFlowRateHHVpctSulphurpctMoisturepctAshChlorine& ORIS Code(kg/hr), dryBtu/lb%%%mg/kg or ppmAES Cayuga (NY) (formerly NYSEG Milliken) 0135110000-02535 2 1 50040.96 13731 2.51 4.81 9.41 840AES Cayuga (NY) (formerly NYSEG Milliken) 0135110000-02535 2 2 51915.19 13791 2.55 5.77 9.01 955AES Cayuga (NY) (formerly NYSEG Milliken) 0135110000-02535 2 3 52215.01 13661 2.33 5.93 9.69 850AES Hawaii, Inc.10673 AB 1 32884 12742 0.67 12.72 8.17 60AES Hawaii, Inc.10673 AB 2 33360 12743 0.65 12.79 8.04 ND(50)AES Hawaii, Inc.10673 AB 3 33485 12625 0.66 13 8.85 52Antelope Valley Station0013070000-06469 B1 1 433349 10180 1.09 37.64 15.3 140Antelope Valley Station0013070000-06469 B1 2 419526 10280 1.24 35.95 15.93 84Antelope Valley Station0013070000-06469 B1 3 413661 10400 1.05 36.67 14.39 97Bailly0137560000-00995 7 and 8 1 177627 12725 3.16 14.25 8.87 713Bailly0137560000-00995 7 and 8 2 179853 12735 3.12 14.78 8.88 459Bailly0137560000-00995 7 and 8 3 175369 12813 2.5 15.0 9.86 766Bay Front Plant Generating0137810000-03982 5 1 3911 12790 0.65 13.77 7.57 110Bay Front Plant Generating0137810000-03982 5 2 3913 12635 0.65 13.73 7.51 119Bay Front Plant Generating0137810000-03982 5 3 3934 12597 0.66 13.26 7.56 152Big Bend0184540000-00645 BB03 1 133914 12730 3.15 9.55 11 1800Big Bend0184540000-00645 BB03 2 132229 12790 3.22 9.58 10.6 1800Big Bend0184540000-00645 BB03 3 132805 12980 3.08 9.69 10.2 1700Big Brown0443720000-03497 1 1 310664 8690 1.01 25 23.7 100Big Brown0443720000-03497 1 2 312513 8720 1.03 25.5 23 100Big Brown0443720000-03497 1 3 298538 9050 1 26.1 21 200Brayton Point0134330000-01619 1 1 76292 13684 0.83 6.56 7.6 300Brayton Point0134330000-01619 1 2 75446 13756 0.73 6.03 7.6 700Brayton Point0134330000-01619 1 3 76493 13754 0.76 6 7.43 700Brayton Point0134330000-01619 3 1 163357 13521 0.82 5.97 10.56 900Brayton Point0134330000-01619 3 2 157296 13583 0.76 6.48 10 1100Brayton Point0134330000-01619 3 3 178153 13875 0.77 6.04 8.14 900Bruce Mansfield0147160000-06094 1 1 277790 13163 4.29 5.49 12.1 800Bruce Mansfield0147160000-06094 1 2 279761 13678 4.54 5.98 8.57 700Bruce Mansfield0147160000-06094 1 3 270273 13237 4.6 5.42 11.2 800Charles R. Lowman0001890000-00056 2 1 77844 13352 0.53 12 4.65 400Charles R. Lowman0001890000-00056 2 2 76370 13356 0.52 12.1 5.29 400Charles R. Lowman0001890000-00056 2 3 77844 13352 0.53 12 4.93 300Cholla0008030000-00113 2 1 125445.6 11222 0.495 5.68 18.8 ND(100)Cholla0008030000-00113 2 2 123908.4 10955 0.51 6.13 20.49 ND(100)Cholla0008030000-00113 2 3 127224 11134 0.525 5.76 19.44 ND(100)Cholla0008030000-00113 3 1 116562.6 11863 0.43 7.49 11.94 ND(100)Cholla0008030000-00113 3 2 120860.6 12172 0.42 7.74 9.06 ND(100)Cholla0008030000-00113 3 3 121240.5 12135 0.42 7.46 9.91 ND(100)Clay Boswell0126470000-01893 2 1 21481 12158 0.62 26.6 7.31 ND(100)Clay Boswell0126470000-01893 2 2 21590 12087 0.62 26.5 7.97 ND(100)Clay Boswell0126470000-01893 2 3 21620 12100 0.68 26.4 8.12 ND(100)Clay Boswell0126470000-01893 3 1 125453 12072 0.61 26.1 7.67 ND(100)Clay Boswell0126470000-01893 3 2 119812 12052 0.75 28.3 7.13 ND(100)Clay Boswell0126470000-01893 3 3 120910 11972 0.68 27.8 8.54 ND(100)Clay Boswell0126470000-01893 4 1 195911 12075 0.54 26.7 7.27 ND(100)Clay Boswell0126470000-01893 4 2 197038 12197 0.57 26.3 7.44 ND(100)Clay Boswell0126470000-01893 4 3 200509 11888 0.6 25 8.62 ND(100)Cliffside0054160000-02721 1 1 15852 13803 0.85 7.34 9.16 1400Cliffside0054160000-02721 1 2 15818 13181 0.77 7.83 8.31 1400Cliffside0054160000-02721 1 3 15838 13804 0.85 7.26 8.44 1400Clifty Creek0092690000-00983 6 1 71060 12494 0.86 22.69 8.08 430Clifty Creek0092690000-00983 6 2 69626 12578 0.86 22.74 8.66 374Clifty Creek0092690000-00983 6 3 74180 12632 0.99 21.52 8.98 519Clover Power Station0198760000-07213 2 1 143480 13089.39 NA 4.35 NA 418.19Clover Power Station0198760000-07213 2 2 143553 13605.30 NA 3.42 NA 517.71Clover Power Station0198760000-07213 2 3 142146 13568.31 NA 3.82 NA 623.83Colstrip0128250000-06076 3 1 370938 10779 0.72 11.4 16.8 ND(100)12AB C D E F G H I JPlant NameEIA Plant CodeUnit No.RunNumberCoalFlowRateHHVpctSulphurpctMoisturepctAshChlorine& ORIS Code(kg/hr), dryBtu/lb%%%mg/kg or ppm616263646566676869707172737475767778798081828384858687888990919293949596979899100101102103104105106107108109110111112113114115116117118Colstrip0128250000-06076 3 2 373615 10568 0.74 12 18 ND(100)Colstrip0128250000-06076 3 3 366517 10688 0.76 11.4 17.3 100Columbia0208560000-08023 1 1 205968 12261 0.43 30.43 6.49 292Columbia0208560000-08023 1 2 210060 12120 0.43 29.09 6.2 347Columbia0208560000-08023 1 3 208610 12182 0.42 29.77 5.38 303Comanche0154660000-00470 2 1 133163 11891.63 0.43 27.1 6.45 ND(100)Comanche0154660000-00470 2 2 130385 11891.63 0.43 27.1 6.45 ND(100)Comanche0154660000-00470 2 3 135158 11891.63 0.43 27.1 6.45 ND(100)Coronado0615720000-06177 U1B 1 159600 11187 0.53 13.26 17.76 100Coronado0615720000-06177 U1B 2 158800 11439 0.49 13.62 17.08 ND(100)Coronado0615720000-06177 U1B 3 162900 11262 0.51 13.53 18.25 200Coyote0128190000-08222 1 1 180563 11080 1.33 35.23 11.1 ND(200)Coyote0128190000-08222 1 2 184283 106.73 2.07 35.12 13.26 ND(200)Coyote0128190000-08222 1 3 179437 10904 1.76 35.11 12.68 ND(200)Craig0301510000-06021 C1 1 155754 12322 0.52 15.84 8.02 400Craig0301510000-06021 C1 2 159979 12447 0.52 14.81 8.17 200Craig0301510000-06021 C1 3 155324 12451 0.58 18.08 6.37 200Craig0301510000-06021 C3 1 157201 12549 0.47 17.09 6.63 100Craig0301510000-06021 C3 2 156035 12624 0.44 17.11 5.96 ND(100)Craig0301510000-06021 C3 3 153356 12562 0.49 17.94 6.4 200Dunkirk0135730000-02554 2 1 32714 13907 2.31 5.76 7.4 811Dunkirk0135730000-02554 2 2 32650 14022 2.23 5.1 7.8 925Dunkirk0135730000-02554 2 3 31910 13819 2.25 6.6 8.92 880Dwayne Collier Battle Cogeneration Facility 10384 2B 112432 13820 0.73 4.5 7.16 1500Dwayne Collier Battle Cogeneration Facility 10384 2B 212391 13900 0.76 4.37 6.94 1800Dwayne Collier Battle Cogeneration Facility 10384 2B 311888 13930 0.77 4.43 6.42 1800Gaston0001950000-00026 1 1 82264 13560 0.8 6.97 13.2 300Gaston0001950000-00026 1 2 78015 13300 1.03 6.58 13.8 300Gaston0001950000-00026 1 3 72147 13640 0.83 7.33 12.1 400George Neal south0123410000-07343 4 1 312422 12003 0.42 27.89 7.6 200George Neal south0123410000-07343 4 2 305364 12014 0.44 28.31 7.61 100George Neal south0123410000-07343 4 3 312314 11901 0.44 30.03 8.64 273Gibson Generating Station (10/99 testing) 0154700000-06113 3 1 209510 12530 1.71 13.6 13.1 1900Gibson Generating Station (10/99 testing) 0154700000-06113 3 2 216693 12570 1.74 12.6 12.9 2200Gibson Generating Station (10/99 testing) 0154700000-06113 3 3 215173 12570 1.71 12.8 13.1 2200Gibson Generating Station (03/00 testing) 0154700000-06113 3 1 248127 11640 1.45 7.38 12.2 1700Gibson Generating Station (03/00 testing) 0154700000-06113 3 2 240702 11630 1.45 7.81 12.9 1700Gibson Generating Station (03/00 testing) 0154700000-06113 3 3 230739 11550 1.57 8.19 13.9 2200GRDA0074900000-00165 2 1 192022 12091 0.71 24.16 8.11 379GRDA0074900000-00165 2 2 184341 12186 0.73 24.9 8.04 386GRDA0074900000-00165 2 3 211706 12096 0.88 24.25 8.46 431Intermountain0112080000-06481 2SGA 1 281058 12986 0.68 7.52 9.16 300Intermountain0112080000-06481 2SGA 2 279461 13022 0.67 7.77 9.36 200Intermountain0112080000-06481 2SGA 3 284219 12949 0.63 7.31 9.36 100Jack Watson0126860000-02049 4 1 80122 13080 1.02 4 6.84 833Jack Watson0126860000-02049 4 2 80893 13080 1.06 3.4 6.97 725Jack Watson0126860000-02049 4 3 81111 13070 1.03 3.34 7.12 724Jim Bridger0143540000-08066 BW 74 1 NA 11821 0.71 19.03 11.83 ND(100)Jim Bridger0143540000-08066 BW 74 2 NA 11963 0.64 19.51 11.45 ND(100)Jim Bridger0143540000-08066 BW 74 3 NA 11973 0.69 19.55 10.85 ND(100)Kline Township Cogen Facility50039 GEN1 1 165225.69 5110 0.43 9.51 58.3 300Kline Township Cogen Facility50039 GEN1 2 171535.06 5050 0.44 8.54 58.7 200Kline Township Cogen Facility50039 GEN1 3 176051.86 4930 0.38 7.94 61 300La Cygne0100000000-01241 1 1 290481 11800 1.22 25.5 11.4 300La Cygne0100000000-01241 1 2 277548 11740 1.31 24.7 11.7 300La Cygne0100000000-01241 1 3 284632 11800 1.2 23.4 10.8 300Laramie River Station0013070000-06204 1 1 207045 11860 0.52 31.05 7.84 87Laramie River Station0013070000-06204 1 2 197203 11940 0.52 31.21 7.63 7812AB C D E F G H I JPlant NameEIA Plant CodeUnit No.RunNumberCoalFlowRateHHVpctSulphurpctMoisturepctAshChlorine& ORIS Code(kg/hr), dryBtu/lb%%%mg/kg or ppm119120121122123124125126127128129130131132133134135136137138139140141142143144145146147148149150151152153154155156157158159160161162163164165166167168169170171172173174175176Laramie River Station0013070000-06204 1 3 195728 11890 0.54 31.29 8.1 57Laramie River Station0013070000-06204 3 1 208000 11820 0.49 30.8 7.4 86Laramie River Station0013070000-06204 3 2 213000 11990 0.49 30.83 7.51 66Laramie River Station0013070000-06204 3 3 210000 12070 0.47 30.98 7.06 79Lawrence0002250000-01250 4 1 36186 12280 0.58 16.9 8.62 400Lawrence0002250000-01250 4 2 38541 12260 0.45 18.3 7.03 200Lawrence0002250000-01250 4 3 38095 12340 0.44 17.5 6.68 200Leland Olds Station0013070000-02817 2 1 229813 10500 0.8 36.03 11.27 91Leland Olds Station0013070000-02817 2 2 187931 10700 1.07 36.26 10.73 104Leland Olds Station0013070000-02817 2 3 315756 10890 0.91 36.37 9.46 77Lewis & Clark0128190000-06089 B1 1 28727 10427 0.89 37.42 15.29 ND(200)Lewis & Clark0128190000-06089 B1 2 27281 10435 0.7 37.35 15.18 ND(200)Lewis & Clark0128190000-06089 B1 3 25593 10391 0.87 37.03 15.91 ND(200)Limestone0089010000-00298 LIM1 1 332740.50 10422 1.37 31.62 18.95 ND(100)Limestone0089010000-00298 LIM1 2 336256.88 10700 1.52 31.79 17.44 ND(100)Limestone0089010000-00298 LIM1 3 344827.24 10574 1.54 31.66 18.48 ND(100)Logan Generating Plant10043 Gen 1 1 75400 13758 1.13 1.08 10.21 1500Logan Generating Plant10043 Gen 1 2 75526 13767 1.08 1.02 10.06 1500Logan Generating Plant10043 Gen 1 3 75351 13757 1.08 1.12 9.95 1500Mecklenburg Cogeneration Facility52007 GEN 1 1 25138 14042 1.25 5.43 6.97 1901Mecklenburg Cogeneration Facility52007 GEN 1 2 26151 13877 1.55 5.64 7.73 1852Mecklenburg Cogeneration Facility52007 GEN 1 3 25488 13867 1.38 7.12 7.7 1925Meramec0194360000-02104 4 1 126826 13254 0.89 14.09 7.75 3200Meramec0194360000-02104 4 2 112566 13499 1.29 10.55 8.18 3860Meramec0194360000-02104 4 3 105878 13415 1.27 11.95 7.85 3800Monticello0443720000-06147 1 1 314734 8220 0.58 22.8 21.2 200Monticello0443720000-06147 1 2 319432 8340 0.64 22.9 19.5 100Monticello0443720000-06147 1 3 315757 7740 1.55 23.3 27.5 200Monticello0443720000-06147 3 1 430100 8680 0.66 22.4 19.8 100Monticello0443720000-06147 3 2 447000 8250 0.57 25 25.2 200Monticello0443720000-06147 3 3 434600 8740 0.63 24.8 22.1 100Montrose0100000000-02080 1 1 69976 10440 0.2 16.6 4.81 200Montrose0100000000-02080 1 2 70645 10300 0.2 15.7 5.72 100Montrose0100000000-02080 1 3 68841 10500 0.21 17.4 5 100Navajo0165720000-04941 3 1 277000 12771 0.53 11.53 7.8 200Navajo0165720000-04941 3 2 277300 12700 0.57 12.13 7.74 200Navajo0165720000-04941 3 3 278500 12850 0.56 12.35 7.11 ND(100)Nelson Dewey0208560000-04054 1 1 39446 13006 1.48 22.4 5.04 141Nelson Dewey0208560000-04054 1 2 37930 13052 1.37 21.52 4.83 151Nelson Dewey0208560000-04054 1 3 37886 12984 1.35 23.56 4.93 95Newton0032530000-06017 2 1 206681 11025 0.44 24.31 9.15 178Newton0032530000-06017 2 2 204152.16 11105 0.4 27.64 7.36 ND(50)Newton0032530000-06017 2 3 202528.83 11019 0.38 28.56 7.73 ND(50)Northern States Power - Sherburne County GeneratingPlant 0137810000-06090 #3 1 331255 11770 0.81 26.67 11.31 85Northern States Power - Sherburne County GeneratingPlant 0137810000-06090 #3 2 336080 11670 0.68 25.5 10.99 93Northern States Power - Sherburne County GeneratingPlant 0137810000-06090 #3 3 341562 11541 0.78 25.46 12.23 128Platte0406060000-00059 1 1 35418 12230 0.45 31.68 7.63 177Platte0406060000-00059 1 2 37782 12211 0.43 29.14 6.94 174Platte0406060000-00059 1 3 33011 12284 0.42 31.22 7.11 191Polk Power0184540000-07242 1 1 91456 11965 3.11 9.99 13.1 1100Polk Power0184540000-07242 1 2 88709 12934 3.12 10.7 10.1 1000Polk Power0184540000-07242 1 3 71375 12958 3.36 11.1 9.67 1100Port Washington0208470000-04040 4 1 29740 14025 1.49 2.43 7.4 1148Port Washington0208470000-04040 4 2 30173 13947 1.55 2.46 7.42 1241Port Washington0208470000-04040 4 3 29648 13982 1.5 2.15 7.44 1257Presque Isle0208470000-01769 5 1 31232 12771.62 1.01 5.29 9.80 180.55Presque Isle0208470000-01769 5 2 30874 12798.90 1.02 5.07 9.94 220.16Presque Isle0208470000-01769 5 3 31922 12765.62 1.04 5.41 10.38 170.2112AB C D E F G H I JPlant NameEIA Plant CodeUnit No.RunNumberCoalFlowRateHHVpctSulphurpctMoisturepctAshChlorine& ORIS Code(kg/hr), dryBtu/lb%%%mg/kg or ppm177178179180181182183184185186187188189190191192193194195196197198199200201202203204205206207208209210211212213214215216217218219220221222223224225226227228229230231232233234Presque Isle0208470000-01769 6 1 36121 12765.62 0.41 21.39 7.02 209.90Presque Isle0208470000-01769 6 2 36399 12026.46 0.42 20.55 6.99 250.47Presque Isle0208470000-01769 6 3 36525 12066.71 0.42 20.51 7.08 210.09Presque Isle0208470000-01769 9 1 27400 12051.83 1.02 5.17 10.28 200.36Presque Isle0208470000-01769 9 2 27636 12694.30 1.04 5.1 10.05 209.69Presque Isle0208470000-01769 9 3 27550 12772.39 1.04 5.1 9.99 180.19R. D. Morrow Sr. Generating plant 0175680000-06061 2 171013 13145 1.11 1.41 10.1 900R. D. Morrow Sr. Generating plant 0175680000-06061 2 273853 12982 1.11 1.71 11 900R. D. Morrow Sr. Generating plant 0175680000-06061 2 368743 12876 1.05 1.83 11.6 700R.M. Heskett Station0128190000-02790 B2 1 36399 10828 1.63 34.77 11.85 ND(200)R.M. Heskett Station0128190000-02790 B2 2 35751 10887 1.14 34.96 10.24 ND(200)R.M. Heskett Station0128190000-02790 B2 3 36658 10666 1.19 34.49 12.03 ND(200)Rawhide0151430000-06761 101 1 111122 11867 0.31 20.51 7.26 133Rawhide0151430000-06761 101 2 103104 12003 0.3 25.55 7.31 118Rawhide0151430000-06761 101 3 105518 11932 0.3 23.44 7.48 129Salem Harbor0134330000-01626 3 1 49538 13889 0.7 9.59 5.42 100Salem Harbor0134330000-01626 3 2 48150 13850 0.69 9.64 5.72 100Salem Harbor0134330000-01626 3 3 48689 13707 0.74 8.63 6.53 100Sam Seymour0112690000-06179 3 1 136862 11773.31 0.54 23.42 7.25 22Sam Seymour0112690000-06179 3 2 136755 11897.54 0.47 23.48 6.91 19Sam Seymour0112690000-06179 3 3 138096 11964.54 0.47 22.73 7.86 19San Juan0154730000-02451 2 1 157925 9976 0.67 5.71 29.97 200San Juan0154730000-02451 2 2 142879 10946 0.73 5.35 23.78 100San Juan0154730000-02451 2 3 148399 10354 0.82 5.17 27.55 200Scrubgrass Generating Company L. P. 50974 GEN1 1 59438 8509 1.49 10.47 39.74 600Scrubgrass Generating Company L. P. 50974 GEN1 2 59438 8520 1.52 11.21 37 600Scrubgrass Generating Company L. P. 50974 GEN1 3 61826 7996 1.4 9.06 43.05 600SEI - Birchwood Power Facility54304 1 1 76807 12650 0.77 5.77 13.3 846SEI - Birchwood Power Facility54304 1 2 75641 12570 0.79 6.05 13.8 954SEI - Birchwood Power Facility54304 1 3 76065 12440 0.83 5.47 14.7 952Shawnee Fossil Plant0186420000-01379 3 1 46649 12882 0.48 12.2 8.78 200Shawnee Fossil Plant0186420000-01379 3 2 48001 12714 0.5 13.4 9.69 200Shawnee Fossil Plant0186420000-01379 3 3 47095 12777 0.49 12.5 9.68 100St Clair Power Plant0051090000-01743 4 1 65723 12430 0.94 22.6 7.4 400St Clair Power Plant0051090000-01743 4 2 65129 12670 0.96 23.3 6.36 300St Clair Power Plant0051090000-01743 4 3 64469 12580 0.96 22.9 6.24 300Stanton Station0195140000-02824 1 1 91172 10674 1.21 36.3 9.79 ND(70)Stanton Station0195140000-02824 1 2 91172 10749 1.68 37.5 10.95 ND(70)Stanton Station0195140000-02824 1 3 91625 10703 1.01 37.3 10.03 81Stanton Station0195140000-02824 10 1 22582 10621 1.33 36.9 10.49 ND(60)Stanton Station0195140000-02824 10 2 22877 10448 1.26 36.4 11.49 ND(60)Stanton Station0195140000-02824 10 3 22762 10529 1.31 36.8 12.37 ND(50)Stockton Cogen Company10640 GEN1 1 17000 12334 0.64 6.12 13.07 668Stockton Cogen Company10640 GEN1 2 13746 12935 0.59 3.87 9.71 612Stockton Cogen Company10640 GEN1 3 14990 12254 0.56 1.16 12.78 470TNP-One0400510000-07030 U2 1 75449 9520 1.27 29.4 26.1 300TNP-One0400510000-07030 U2 2 72195 9810 1.26 28.5 23.1 ND(100)TNP-One0400510000-07030 U2 3 78013 9000 1.43 30.2 30.7 ND(100)Valley0208470000-04042 2 1 27746 13318 0.85 8.7 7.88 124Valley0208470000-04042 2 2 27687 13269 0.85 8.35 7.82 134Valley0208470000-04042 2 3 27022 13456 0.92 8.91 7.14 125Valmont0154660000-00477 5 1 59355 12299 0.29 16.1 8 ND(50)Valmont0154660000-00477 5 2 58814 12243 0.3 16.3 8.25 66Valmont0154660000-00477 5 3 55471 11607 0.49 12.1 8.76 ND(50)W. H. Sammis0139980000-02866 1 1 50494 12202 0.91 5.34 17.3 1300W. H. Sammis0139980000-02866 1 2 48308 13594 1.51 4.74 9.3 1200W. H. Sammis0139980000-02866 1 3 48049 13531 1.43 4.74 9.84 1200Wabash River Generating Station 0154700000-01010 1 +1A 1 90663 12350 2.72 14.8 13 60012AB C D E F G H I JPlant NameEIA Plant CodeUnit No.RunNumberCoalFlowRateHHVpctSulphurpctMoisturepctAshChlorine& ORIS Code(kg/hr), dryBtu/lb%%%mg/kg or ppm235236237238239240241242243244245246247248Wabash River Generating Station 0154700000-01010 1 +1A 2 89629 12530 2.75 15.7 12.7 600Wabash River Generating Station 0154700000-01010 1 +1A 3 89493 12540 2.89 15.9 13.1 600Widows Creek Fossil Plant0186420000-00050 6 1 41312 12633 0.59 8.89 11.4 400Widows Creek Fossil Plant0186420000-00050 6 2 41520 12744 0.51 9.45 10.4 300Widows Creek Fossil Plant0186420000-00050 6 3 40552 12769 0.53 9.23 10.2 300Wyodak0143540000-06101 BW 91 1 145472 11550 0.87 29.67 10.04 ND(50)Wyodak0143540000-06101 BW 91 2 145265 11677 0.84 29.77 9.4 ND(50)Wyodak0143540000-06101 BW 91 3 147351 11640 0.81 30.29 9.7 ND(50)XB = Excessive reagent blank caused the data to beunreliableNA = Data was not included in reportLS = Test sample was broken, damaged, or lost during testingor in transport123456789101112131415161718192021222324252627282930313233343536373839404142434445464748495051525354555657585960APlant NameAES Cayuga (NY) (formerly NYSEG Milliken)AES Cayuga (NY) (formerly NYSEG Milliken)AES Cayuga (NY) (formerly NYSEG Milliken)AES Hawaii, Inc.AES Hawaii, Inc.AES Hawaii, Inc.Antelope Valley StationAntelope Valley StationAntelope Valley StationBaillyBaillyBaillyBay Front Plant GeneratingBay Front Plant GeneratingBay Front Plant GeneratingBig BendBig BendBig BendBig BrownBig BrownBig BrownBrayton PointBrayton PointBrayton PointBrayton PointBrayton PointBrayton PointBruce MansfieldBruce MansfieldBruce MansfieldCharles R. LowmanCharles R. LowmanCharles R. LowmanChollaChollaChollaChollaChollaChollaClay BoswellClay BoswellClay BoswellClay BoswellClay BoswellClay BoswellClay BoswellClay BoswellClay BoswellCliffsideCliffsideCliffsideClifty CreekClifty CreekClifty CreekClover Power StationClover Power StationClover Power StationColstripK L M N OHgCoalAnalysisMethodFuelTypeInlet Flow Ratetemp_GasInmg/kg or ppmdscm/hrDeg C0.11 EPA 7471Bituminous 549382.00 134.780.11 EPA 7471Bituminous 563471.90 1370.10 EPA 7471Bituminous 560811.25 140.330.03 D3684-94 - FICVAASubbituminous 415320 137.20.03 D3684-94 - FICVAASubbituminous 427620 135.20.02 D3684-94 - FICVAASubbituminous 423900 137.20.06 EPA 7471Lignite 2166565 1540.071 EPA 7471Lignite 2143628 1510.055 EPA 7471Lignite 2100474 1540.07 ASTM 3684 Bituminous/Petroleum Coke 2404954 176.30.08 ASTM 3684 Bituminous/Petroleum Coke 2433488 167.30.06 ASTM 3684 Bituminous/Petroleum Coke 2396825 175.10.06 ASTM 3684Bituminous 232291 1360.06 ASTM 3684Bituminous 195145 1320.06 ASTM 3684Bituminous 191081 1340.177 EPA 7471Bituminous 1440752 1550.113 EPA 7471Bituminous 1440242 1550.125 EPA 7471Bituminous 1421383 1560.287 ASTM 6414Lignite 2049164 1830.29 ASTM 6414Lignite 2067102 1860.287 ASTM 6414Lignite 2108492 1850.08 ASTM 3684Bituminous 1219061 1550.05 ASTM 3684Bituminous 1228778 1530.06 ASTM 3684Bituminous 1237069 1530.1 ASTM 3684Bituminous 2836137 1230.07 ASTM 3684Bituminous 2907989 1230.07 ASTM 3684Bituminous 3025158 1190.096 ASTM 6414Bituminous 3160872 1370.079 ASTM 6414Bituminous 3183792 1440.103 ASTM 6414Bituminous 2883648 1410.084 ASTM 6414Bituminous 338513 1460.077 ASTM 6414Bituminous 344092 1460.08 ASTM 6414Bituminous 329689 1470.045 EPA 7471Subbituminous 943921 1360.04 EPA 7471Subbituminous 814490 1370.035 EPA 7471Subbituminous 915890 1370.04 ASTM 3684Subbituminous 938720 3620.04 ASTM 3684Subbituminous 962341 3580.03 ASTM 3684Subbituminous 934887 3570.078 ASTM 6414Subbituminous 240607 1790.043 ASTM 6414Subbituminous 268405 1730.049 ASTM 6414Subbituminous 251138 1750.054 ASTM 6414Subbituminous 1564633 1390.072 ASTM 6414Subbituminous 1560844 1480.063 ASTM 6414Subbituminous 1528607 1440.065 ASTM 6414Subbituminous 2133642 1540.063 ASTM 6414Subbituminous 2104866 1410.07 ASTM 6414Subbituminous 2015790 1360.07 ASTM 3684Bituminous 220456 343.90.05 ASTM 3684Bituminous 221841 342.60.06 ASTM 3684Bituminous 214583 340.80.08 ASTM 3684 Subbituminous/Bituminous 746218 3820.08 ASTM 3684 Subbituminous/Bituminous 760863 3850.08 ASTM 3684 Subbituminous/Bituminous 760318 3820.12 EPA 7471Bituminous 694552 1390.17 EPA 7471Bituminous 705133 1390.20 EPA 7471Bituminous 696696 1390.063 ASTM 6414Subbituminous 3362880 14012APlant Name616263646566676869707172737475767778798081828384858687888990919293949596979899100101102103104105106107108109110111112113114115116117118ColstripColstripColumbiaColumbiaColumbiaComancheComancheComancheCoronadoCoronadoCoronadoCoyoteCoyoteCoyoteCraigCraigCraigCraigCraigCraigDunkirkDunkirkDunkirkDwayne Collier Battle Cogeneration FacilityDwayne Collier Battle Cogeneration FacilityDwayne Collier Battle Cogeneration FacilityGastonGastonGastonGeorge Neal southGeorge Neal southGeorge Neal southGibson Generating Station (10/99 testing)Gibson Generating Station (10/99 testing)Gibson Generating Station (10/99 testing)Gibson Generating Station (03/00 testing)Gibson Generating Station (03/00 testing)Gibson Generating Station (03/00 testing)GRDAGRDAGRDAIntermountainIntermountainIntermountainJack WatsonJack WatsonJack WatsonJim BridgerJim BridgerJim BridgerKline Township Cogen FacilityKline Township Cogen FacilityKline Township Cogen FacilityLa CygneLa CygneLa CygneLaramie River StationLaramie River StationK L M N OHgCoalAnalysisMethodFuelTypeInlet Flow Ratetemp_GasInmg/kg or ppmdscm/hrDeg C0.066 ASTM 6414Subbituminous 3391696 1420.067 ASTM 6414Subbituminous 3441304 1360.1 ASTM 3684Subbituminous 2188995 4060.1 ASTM 3684Subbituminous 2159390 4030.1 ASTM 3684Subbituminous 2158955 4090.09 EPA 1631Subbituminous 1246033 142.780.10 EPA 1631Subbituminous 1252037 1500.09 EPA 1631Subbituminous 1270674 141.670.035 EPA 7371/1631Subbituminous 1405808 1360.039 EPA 7371/1631Subbituminous 1398779 1350.031 EPA 7371/1631Subbituminous 1392035 1430.088 EPA 3050/7471Lignite 2126971 1630.15 EPA 3050/7471Lignite 2111511 1760.094 EPA 3050/7471Lignite 2083307 1770.022 EPA 1631/7371Subbituminous 1842363 1210.025 EPA 1631/7371Subbituminous 1875084 1240.021 EPA 1631/7371Subbituminous 1919707 1180.011 EPA 1631/7371Subbituminous 1650793 1380.01 EPA 1631/7371Subbituminous 1651990 1460.009 EPA 1631/7371Subbituminous 1654007 1330.13 ASTM 3684Bituminous 478725 303.40.13 ASTM 3684Bituminous 460709 304.50.13 ASTM 3684Bituminous 466192 306.4ND(0.06) EPA 7471Bituminous 124965 167ND(0.06) EPA 7471Bituminous 120578 167ND(0.06) EPA 7471Bituminous 122308 1690.054 EPA 7471Bituminous 914665 3360.067 EPA 7471Bituminous 893577 3340.057 EPA 7471Bituminous 931343 3390.09 ASTM 3684Subbituminous 2633333 1490.08 ASTM 3684Subbituminous 2709436 1530.1 ASTM 3684Subbituminous 2688240 1540.134 ASTM 6414Bituminous 2343261 1580.142 ASTM 6414Bituminous 2353191 1620.141 ASTM 6414Bituminous 2371609 1630.117 ASTM 6414Bituminous 2544538 1560.115 ASTM 6414Bituminous 2525292 1570.123 ASTM 6414Bituminous 2551178 1550.1 ASTM 3684 Subbituminous/Bituminous 1795109 154.80.1 ASTM 3684 Subbituminous/Bituminous 1814982 156.60.1 ASTM 3684 Subbituminous/Bituminous 1808161 155.80.02 ASTM 3684Bituminous 3312000 1520.02 ASTM 3684Bituminous 3336000 1520.03 ASTM 3684Bituminous 3372000 1490.05 EPA 7471Bituminous 1072801 1550.052 EPA 7471Bituminous 934375 1480.059 EPA 7471Bituminous 978658 1460.08 OtherSubbituminous 2833202 1470.08 OtherSubbituminous 2701314 1460.06 OtherSubbituminous 2729912 1450.3 EPA 7471Waste Anthracite 322630 1880.4 EPA 7471Waste Anthracite 311820 1860.3 EPA 7471Waste Anthracite 327118 1890.11 ASTM 6414Subbituminous NA 1440.102 ASTM 6414Subbituminous NA 1440.098 ASTM 6414Subbituminous NA 1440.103 EPA 3051/3052/7471 Subbituminous 2330443 141.10.111 EPA 3051/3052/7471 Subbituminous 2278573 138.312APlant Name119120121122123124125126127128129130131132133134135136137138139140141142143144145146147148149150151152153154155156157158159160161162163164165166167168169170171172173174175176Laramie River StationLaramie River StationLaramie River StationLaramie River StationLawrenceLawrenceLawrenceLeland Olds StationLeland Olds StationLeland Olds StationLewis & ClarkLewis & ClarkLewis & ClarkLimestoneLimestoneLimestoneLogan Generating PlantLogan Generating PlantLogan Generating PlantMecklenburg Cogeneration FacilityMecklenburg Cogeneration FacilityMecklenburg Cogeneration FacilityMeramecMeramecMeramecMonticelloMonticelloMonticelloMonticelloMonticelloMonticelloMontroseMontroseMontroseNavajoNavajoNavajoNelson DeweyNelson DeweyNelson DeweyNewtonNewtonNewtonNorthern States Power - Sherburne County GeneratingPlantNorthern States Power - Sherburne County GeneratingPlantNorthern States Power - Sherburne County GeneratingPlantPlattePlattePlattePolk PowerPolk PowerPolk PowerPort WashingtonPort WashingtonPort WashingtonPresque IslePresque IslePresque IsleK L M N OHgCoalAnalysisMethodFuelTypeInlet Flow Ratetemp_GasInmg/kg or ppmdscm/hrDeg C0.144 EPA 3051/3052/7471 Subbituminous 2298553 136.10.118 EPA 3051/3052/7471 Subbituminous 2648783 137.70.142 EPA 3051/3052/7471 Subbituminous 2776514 140.60.114 EPA 3051/3052/7471 Subbituminous 2645760 136.10.052 ASTM 6414Subbituminous 376788 1720.044 ASTM 6414Subbituminous 382234 1570.047 ASTM 6414Subbituminous 381990 169ND(0.05) EPA 7471Lignite 1830157 1990.056 EPA 7471Lignite 1895399 201ND(0.05) EPA 7471Lignite 1826759 2050.107 7471ALignite 207448 1950.121 7471ALignite 214924 1980.13 7471ALignite 214924 2030.121 ASTM 3684Lignite 4920304 1560.171 ASTM 3684Lignite 4845548 1620.125 ASTM 3684Lignite 4818364 1670.19 ASTM 3684Bituminous 769254 1450.18 ASTM 3684Bituminous 759560 1490.17 ASTM 3684Bituminous 763218 1480.09 ASTM 3684Bituminous 225117 149.40.11 ASTM 3684Bituminous 243126 147.20.09 ASTM 3684Bituminous 227410 147.20.085 ASTM 3684 Subbituminous/Bituminous 1610937 1690.12 ASTM 3684 Subbituminous/Bituminous 1405042 1720.068 ASTM 3684 Subbituminous/Bituminous 1278496 1680.318 ASTM 6414Lignite 1925000 1780.325 ASTM 6414Lignite 2214400 1830.472 ASTM 6414Lignite 2330200 1820.388 ASTM 6414Lignite 4179262 1790.375 ASTM 6414Lignite 4120503 1750.482 ASTM 6414Lignite 4322378 1750.089 ASTM 6414Subbituminous 158080 155.50.107 ASTM 6414Subbituminous 159491 157.80.103 ASTM 6414Subbituminous 158977 161.70.040 EPA 7371/1631Bituminous 3055474 1570.024 EPA 7371/1631Bituminous 3004856 1520.027 EPA 7371/1631Bituminous 3077836 156.0.06 ASTM 3684 Subbituminous/Petroleum Coke 387802 2540.06 ASTM 3684 Subbituminous/Petroleum Coke 379100 2570.06 ASTM 3684 Subbituminous/Petroleum Coke 390626 2600.074 EPA 7473Subbituminous 1882980 1690.068 EPA 7473Subbituminous 1830477 1500.070 EPA 7473Subbituminous 1901994 1640.08 ASTM 3684Subbituminous 3344159 1450.08 ASTM 3684Subbituminous 3362593 1470.07 ASTM 3684Subbituminous 3315734 1500.11 ASTM 3684Subbituminous 382795 411.80.09 ASTM 3684Subbituminous 377498 413.20.07 ASTM 3684Subbituminous 379912 415.9ND(0.1) EPA 7471BituminousND(0.1) EPA 7471BituminousND(0.1) EPA 7471Bituminous0.09 ASTM 3684 EPA 7473 and 7471A Bituminous 344842 403.80.09 ASTM 3684 EPA 7473 and 7471A Bituminous 340791 406.70.09 ASTM 3684 EPA 7473 and 7471A Bituminous 339646 406.40.05 Proposed ASTM Method Bituminous/Petroleum Coke 407436.43 1700.04 Proposed ASTM Method Bituminous/Petroleum Coke 421072.69 172.220.04 Proposed ASTM Method Bituminous/Petroleum Coke 416619.58 174.4412APlant Name177178179180181182183184185186187188189190191192193194195196197198199200201202203204205206207208209210211212213214215216217218219220221222223224225226227228229230231232233234Presque IslePresque IslePresque IslePresque IslePresque IslePresque IsleR. D. Morrow Sr. Generating plantR. D. Morrow Sr. Generating plantR. D. Morrow Sr. Generating plantR.M. Heskett StationR.M. Heskett StationR.M. Heskett StationRawhideRawhideRawhideSalem HarborSalem HarborSalem HarborSam SeymourSam SeymourSam SeymourSan JuanSan JuanSan JuanScrubgrass Generating Company L. P.Scrubgrass Generating Company L. P.Scrubgrass Generating Company L. P.SEI - Birchwood Power FacilitySEI - Birchwood Power FacilitySEI - Birchwood Power FacilityShawnee Fossil PlantShawnee Fossil PlantShawnee Fossil PlantSt Clair Power PlantSt Clair Power PlantSt Clair Power PlantStanton StationStanton StationStanton StationStanton StationStanton StationStanton StationStockton Cogen CompanyStockton Cogen CompanyStockton Cogen CompanyTNP-OneTNP-OneTNP-OneValleyValleyValleyValmontValmontValmontW. H. SammisW. H. SammisW. H. SammisWabash River Generating StationK L M N OHgCoalAnalysisMethodFuelTypeInlet Flow Ratetemp_GasInmg/kg or ppmdscm/hrDeg C0.07 Proposed ASTM Method Bituminous/Petroleum Coke 304913.01 375.560.07 Proposed ASTM Method Bituminous/Petroleum Coke 318501.70 381.670.07 Proposed ASTM Method Bituminous/Petroleum Coke 311204.45 387.780.03 Proposed ASTM Method Subbituminous 371896.52 153.890.05 Proposed ASTM Method Subbituminous 363848.30 152.780.04 Proposed ASTM Method Subbituminous 370661.34 153.33ND(0.1) EPA 7471Bituminous 850873 166ND(0.1) EPA 7471Bituminous 869922 166ND(0.1) EPA 7471Bituminous 808602 1670.098 EPA 7471ALignite 381222 1640.088 EPA 7471ALignite 360188 1570.073 EPA 7471ALignite 338645 1660.07 ASTM 3684Subbituminous 1088760 171.20.07 ASTM 3684Subbituminous 1055239 170.50.08 ASTM 3684Subbituminous 1068097 171.10.03 ASTM 3684Bituminous 705491 1240.02 ASTM 3684Bituminous 672460 1260.03 ASTM 3684Bituminous 677049 1270.139 EPA 7471ASubbituminous 742598 1520.115 EPA 7471ASubbituminous 771746 1500.114 EPA 7471ASubbituminous 664148 1470.045 EPA 7371/1631Subbituminous 1046292 145.50.051 EPA 7371/1631Subbituminous 962604 136.60.065 EPA 7371/1631Subbituminous 964490 146.60.55 ASTM 3684Waste Bituminous 217768 1590.52 ASTM 3684Waste Bituminous 222024 1610.51 ASTM 3684Waste Bituminous 213797 1630.11 EPA 7471Bituminous 776654 1340.11 EPA 7471Bituminous 763255 1320.11 EPA 7471Bituminous 747652 1360.022 ASTM 6414 Bituminous/Subbituminous 603793 1590.039 ASTM 6414 Bituminous/Subbituminous 613149 1570.024 ASTM 6414 Bituminous/Subbituminous 616736 1570.06 ASTM 6414 Subbituminous/Bituminous 707478 1380.055 ASTM 6414 Subbituminous/Bituminous 717298 1400.069 ASTM 6414 Subbituminous/Bituminous 778622 1410.086 EPA 3051/7471Lignite 317712 173.30.105 EPA 3051/7471Lignite 292227 157.20.056 EPA 3051/7471Lignite 319411 164.40.0865 EPA 3051/7471Lignite 280334 169.10.101 EPA 3051/7471Lignite 275237 172.20.063 EPA 3051/7471Lignite 275237 186.70.026 ASTM 3684 Bituminous/Petroleum Coke 274312 1500.026 ASTM 3684 Bituminous/Petroleum Coke 268688 1480.029 ASTM 3684 Bituminous/Petroleum Coke 275359 1470.222 ASTM 6414Lignite 555305 1840.18 ASTM 6414Lignite 584340 1810.362 ASTM 6414Lignite 573407 1770.0092 ASTM 3684 EPA 7473 and 7471 Bituminous/Petroleum Coke 334586 157.00.013 ASTM 3684 EPA 7473 and 7471 Bituminous/Petroleum Coke 339094 156.60.015 ASTM 3684 EPA 7473 and 7471 Bituminous/Petroleum Coke 331724 156.40.01 MODIFIED EPA 3051/7471A Bituminous 858556 1420.0055 MODIFIED EPA 3051/7471A Bituminous 844486 1430.0083 MODIFIED EPA 3051/7471A Bituminous 849780 1560.081 ASTM 6414Bituminous 739403 1610.12 ASTM 6414Bituminous 729449 1570.117 ASTM 6414Bituminous 706103 1560.064 ASTM 6414Bituminous12APlant Name235236237238239240241242243244245246247248Wabash River Generating StationWabash River Generating StationWidows Creek Fossil PlantWidows Creek Fossil PlantWidows Creek Fossil PlantWyodakWyodakWyodakXB = Excessive reagent blank caused the data to beunreliableNA = Data was not included in reportLS = Test sample was broken, damaged, or lost during testingor in transportK L M N OHgCoalAnalysisMethodFuelTypeInlet Flow Ratetemp_GasInmg/kg or ppmdscm/hrDeg C0.068 ASTM 6414Bituminous0.07 ASTM 6414Bituminous0.029 ASTM 6414Bituminous 438532 1600.024 ASTM 6414Bituminous 436101 1620.021 ASTM 6414Bituminous 445789 1590.03 ASTM 3684Subbituminous 1928365 1620.04 ASTM 3684Subbituminous 1789047 1580.05 ASTM 3684Subbituminous 1712592 160123456789101112131415161718192021222324252627282930313233343536373839404142434445464748495051525354555657585960APlant NameAES Cayuga (NY) (formerly NYSEG Milliken)AES Cayuga (NY) (formerly NYSEG Milliken)AES Cayuga (NY) (formerly NYSEG Milliken)AES Hawaii, Inc.AES Hawaii, Inc.AES Hawaii, Inc.Antelope Valley StationAntelope Valley StationAntelope Valley StationBaillyBaillyBaillyBay Front Plant GeneratingBay Front Plant GeneratingBay Front Plant GeneratingBig BendBig BendBig BendBig BrownBig BrownBig BrownBrayton PointBrayton PointBrayton PointBrayton PointBrayton PointBrayton PointBruce MansfieldBruce MansfieldBruce MansfieldCharles R. LowmanCharles R. LowmanCharles R. LowmanChollaChollaChollaChollaChollaChollaClay BoswellClay BoswellClay BoswellClay BoswellClay BoswellClay BoswellClay BoswellClay BoswellClay BoswellCliffsideCliffsideCliffsideClifty CreekClifty CreekClifty CreekClover Power StationClover Power StationClover Power StationColstripP Q R S T Upct_StackGasMoistureInpct_StackGasO2InHg_ParticleBoundInHg_OxidizedInHg_ElementalInOutlet Flow Rate%%ug/dscmug/dscmug/dscmdscm/hr8 4.9 NA 5.25 1.91 609379.188.1 5.28 0.72 5.59 2.10 609569.478.1 5.16 1.62 4.88 2.42 616217.708.7 8.0 0.19 ND(0.056) 0.79 3998408.1 8.0 0.25 0.12 0.94 4113609.4 XB 0.26 0.077 0.72 40656015.4 5.4 ND(0.13) 0.33 6.76 191579215 5.4 ND(0.18) 0.36 6.94 193295214.8 5.4 0.14 0.14 6.81 18736578.63 5.63 0.036 2.92 2.41 20831278.22 5.7 0.05 1.95 2.65 21078008.19 6.28 0.06 2.76 2.22 20867759.82 8.7 0.52 0.53 1.48 958127.18 8.3 0.76 0.47 1.37 1104357.12 9.0 0.06 0.51 1.16 1053899.1 4.1 XB 4.56 2.25 19040699 4.4 XB 4.54 2.13 19074679 3.5 XB 4.14 2.07 189251614.67 5.6 2.22 7.14 26.73 235195313.53 5.2 0.47 9.1 23.97 234529813.79 5.2 0.2 12.41 19.25 23325507.55 6.68 1.6 2.66 0.401 10319807.7 6.8 2.06 2.88 0.318 10285958.05 7.0 1.65 2.71 0.305 10568928.9 8.1 2.11 2.75 0.39 25470859.3 7.25 1.46 2.41 0.379 25203817.45 6.85 1.05 2.55 2.39 24938817.3 7.1 0.33 6.68 1.22 30501166.69 7 0.57 7.65 1.62 30414486.66 6.3 0.34 6.81 1.39 29865667.02 6.2 XB 2.74 1.72 9614446.45 6.7 1.23 3.16 1.72 9556717.48 6.8 2.72 2.8 1.59 9634798.8 4.7 XB 0.61 4.24 9865049.2 3.8 0.95 NA 2.5 9787038.7 3.8 XB 1.21 2.86 9905179.7 3.8 XB ND(0.08) 1.84 11017019.5 3.9 XB 0.3 0.44 10853439.3 3.7 XB 0.41 0.59 107761810.5 6.0 2.29 1.51 1.33 25252710.4 6.7 1.58 1 1.16 24305411.4 6.4 0.67 0.93 2.02 23850210.8 5.4 0.01 0.22 5.25 162763912.5 5.4 ND(0.02) 0.27 5.2 166848911.4 5.5 0.05 0.53 4.49 165778610.4 5.6 0.09 0.28 4.32 219123811.5 5.2 2.62 0.94 1.29 218277310.7 5.2 2.41 0.48 1.02 21513768.71 4.3 0.16 3.45 3.07 2204568.61 4.3 0.08 3.28 4.31 2218419.01 4.4 0.07 3.83 6.7 21458312.01 3.9 0.38 2.23 10.61 98949911.62 3.8 0.02 3.42 10.64 88043011.42 3.7 ND(0.01) 3.28 11.01 9471816 4.5 0.05 0.86 0.96 16367236.15 4.7 0.03 0.94 1.09 16510906.15 4.75 0.07 1.02 0.54 16598929.58 4.6 1.62 2.09 0.98 314310612APlant Name616263646566676869707172737475767778798081828384858687888990919293949596979899100101102103104105106107108109110111112113114115116117118ColstripColstripColumbiaColumbiaColumbiaComancheComancheComancheCoronadoCoronadoCoronadoCoyoteCoyoteCoyoteCraigCraigCraigCraigCraigCraigDunkirkDunkirkDunkirkDwayne Collier Battle Cogeneration FacilityDwayne Collier Battle Cogeneration FacilityDwayne Collier Battle Cogeneration FacilityGastonGastonGastonGeorge Neal southGeorge Neal southGeorge Neal southGibson Generating Station (10/99 testing)Gibson Generating Station (10/99 testing)Gibson Generating Station (10/99 testing)Gibson Generating Station (03/00 testing)Gibson Generating Station (03/00 testing)Gibson Generating Station (03/00 testing)GRDAGRDAGRDAIntermountainIntermountainIntermountainJack WatsonJack WatsonJack WatsonJim BridgerJim BridgerJim BridgerKline Township Cogen FacilityKline Township Cogen FacilityKline Township Cogen FacilityLa CygneLa CygneLa CygneLaramie River StationLaramie River StationP Q R S T Upct_StackGasMoistureInpct_StackGasO2InHg_ParticleBoundInHg_OxidizedInHg_ElementalInOutlet Flow Rate%%ug/dscmug/dscmug/dscmdscm/hr9.54 4.6 1.77 2.16 5.8 312477410.71 4.8 1.47 2.57 4.85 315721313.48 3.8 0.02 0.89 13.64 218899513.91 4 0.03 5.5 12.66 215939011.85 4.2 0.04 0.43 13.67 215895510 5.4 1.70 2.95 4.61 12623409.4 6.5 2.15 0.87 4.27 125340010.6 5.2 4.69 0.69 3.01 129071010.05 4.94 ND(0.05) 0.88 1.95 13855189.58 4.27 ND(0.05) 0.76 1.73 138039110.27 3.97 ND(0.05) 1.03 1.77 136363713.8 8.2 0.49 1.15 9.73 212697113.7 8.3 0.83 2.1 9.81 211151114 8.2 1.2 2.18 10.6 20833078.43 7.32 ND(0.06) 0.25 2.74 17415948.33 7.24 ND(0.06) 0.22 1.93 17113267.98 7.69 ND(0.06) 0.12 1.47 17670659.74 6.57 0.46 0.52 0.24 18970899.13 6.36 0.75 0.41 0.23 19020288.66 6.36 0.73 0.19 0.18 18688388.0 5.1 0.16 7.56 2.49 4813268.83 4.9 .25 7.97 1.28 4643478.47 4.4 .32 8.43 2.91 4699107.4 4.3 2.03 ND(0.05) ND(0.17) 1351288 4.3 1.93 0.17 0.39 1327967.8 4.3 1.85 ND(0.06) ND(0.20) 1326877.9 4.2 3.99 0.8 2.46 9380798.7 4.2 2.4 0.66 3.32 9730117.5 4.1 0.4 3.7 2.66 98047812.94 5.5 0.147 4.11 5.4 263013813.04 6.2 0.058 3.57 6.78 267145312.7 6.8 ND(0.03) 2.79 2.97 26601467.92 5.6 4.77 8.84 2.15 25879374.63 5.4 23.92 3.28 1.31 29529938.20 5.2 4.09 9.67 1.62 35089607.21 6.0 1.62 26.45 3.66 31950607.92 6.2 1.03 31.29 2.4 31523657.48 6.2 1.44 36.54 1.36 318998112.59 5.4 0.22 3.83 6.73 197468211.67 5.6 0.45 2.54 5.56 200796212.53 5.2 1.0 7.71 3.26 19700527.2 4.5 ND(0.018) 0.94 0.125 33120006.7 4.4 ND(0.016) 1.05 0.127 33360006.6 5.1 ND(0.017) 1.21 0.145 33720009.1 6.7 2.86 0.97 0.73 10436098.4 6.7 3.9 0.92 0.2 9612647.9 6.8 3.66 0.47 ND(0.15) 9718149.6 5.8 0.04 2.1 4.4 21870859.0 6.0 0.37 1.7 4.55 21339739.1 5.8 0.06 1.5 3.66 21594076.4 2.4 46.02 ND(0.12) 0.47 2857717.4 2.4 44.56 ND(0.06) 0.41 2783466.4 2.1 47.22 ND(0.06) 0.36 27687710.74 5.4 5.81 3.46 1.13 287142410.78 5.3 5.69 2.91 ND(1.04) 285685810.93 5.6 5.12 ND(1.01) ND(1.04) 289794012.8 10 0.154 1.921 4.593 237602711.9 10.1 0.023 1.3058 5.055 229505312APlant Name119120121122123124125126127128129130131132133134135136137138139140141142143144145146147148149150151152153154155156157158159160161162163164165166167168169170171172173174175176Laramie River StationLaramie River StationLaramie River StationLaramie River StationLawrenceLawrenceLawrenceLeland Olds StationLeland Olds StationLeland Olds StationLewis & ClarkLewis & ClarkLewis & ClarkLimestoneLimestoneLimestoneLogan Generating PlantLogan Generating PlantLogan Generating PlantMecklenburg Cogeneration FacilityMecklenburg Cogeneration FacilityMecklenburg Cogeneration FacilityMeramecMeramecMeramecMonticelloMonticelloMonticelloMonticelloMonticelloMonticelloMontroseMontroseMontroseNavajoNavajoNavajoNelson DeweyNelson DeweyNelson DeweyNewtonNewtonNewtonNorthern States Power - Sherburne County GeneratingPlantNorthern States Power - Sherburne County GeneratingPlantNorthern States Power - Sherburne County GeneratingPlantPlattePlattePlattePolk PowerPolk PowerPolk PowerPort WashingtonPort WashingtonPort WashingtonPresque IslePresque IslePresque IsleP Q R S T Upct_StackGasMoistureInpct_StackGasO2InHg_ParticleBoundInHg_OxidizedInHg_ElementalInOutlet Flow Rate%%ug/dscmug/dscmug/dscmdscm/hr11.6 10.1 ND(0.02) 1.866 4.562 233406210.4 9.9 ND(0.032) 0.1368 0.3886 264878310.6 9.9 1.0417 0.3235 5.263 277651410.6 10.1 2.7544 0.2642 5.6211 26474678.82 6.6 0.18 1.32 3.99 4015049.43 6.4 0.43 ND(1.03) 3.58 4139389.19 7 0.19 ND(1.13) 3.86 42594612.1 5.3 0.49 0.2 2.74 181826414.4 5.6 0.22 0.39 7.53 187942814.8 5.6 LS LS LS 181843414.6 4.5 1.05 15.1 10.68 19708414.5 4.4 1.55 12.58 7.77 18689014.5 4.4 1.3 5.79 9.41 18553113.2 6.5 0.01 18.97 10.78 345236813.6 6.5 0.01 19.78 10.56 347955213.6 6.5 0.02 22.68 11.37 33300409.6 3.7 12.3 4.85 0.89 8247529.4 3.5 12.39 3.58 0.32 83516410 3.8 11.9 1.92 0.55 8150079.08 4.4 10.46 3.14 6.24 2714999.54 4.0 5.35 3.98 ND(0.171) 2757479.81 4.0 6.52 2.87 ND(0.175) 27200910.92 6.61 6.08 0.39 0.20 167034610.29 6.82 7.36 1.07 0.35 157912410.84 6.43 4.57 1.56 0.5 144808714.78 3.6 15.44 21.79 8.53 317160014.55 5.4 0.32 12.84 40.12 361300014.50 7.4 6.02 17.18 33.39 361590010.17 9.4 0.12 10.63 18.94 366424511.90 9.4 0.07 12.74 18.14 373571411.49 9.6 0.08 16.36 17.23 376493511.05 5.2 1.69 1.62 5.23 66584111.29 4.6 0.82 2.3 4.45 69274111.37 4.2 1.51 2.66 4.33 6733988.89 6.23 ND(0.05) 2.39 2.91 30002538.53 5.88 ND(0.05) 0.38 3.3 29929008.76 6.00 ND(0.045) 0.52 2.92 304716110.75 4.4 0.0224 0.45 2.95 36575710.34 4.3 0.0167 0.22 2.03 36424210.29 3.8 0.0191 0.11 1.97 37140614.98 4.0 ND(0.08) 0.55 9.16 211303114.15 4.05 ND(0.07) 0.59 9.28 205076113.82 3.96 ND(0.16) 1.56 8.77 203664411.67 3.8 ND(0.01) 0.51 10.43 345194712.02 3.6 ND(0.01) 0.22 10.56 322280612.03 4.2 ND(0.01) 0.18 9.56 335950612.38 4.5 0.03 3.8 9 40399213.61 4.2 0.03 1.79 10.56 39222815.08 2.9 0.03 4.41 11.69 4027331430191145361714140527.38 4.3 ND(0.008) 4.02 10.79 3448428.2 4.3 ND(0.02) 7.19 10.22 3407917.41 4.5 ND(0.009) 5.87 9.12 339646.009.5 5.5 3.92 0.41 0.12 308484.339.4 5 3.20 0.59 0.05 321648.279.4 4.9 4.53 0.40 0.21 337525.5312APlant Name177178179180181182183184185186187188189190191192193194195196197198199200201202203204205206207208209210211212213214215216217218219220221222223224225226227228229230231232233234Presque IslePresque IslePresque IslePresque IslePresque IslePresque IsleR. D. Morrow Sr. Generating plantR. D. Morrow Sr. Generating plantR. D. Morrow Sr. Generating plantR.M. Heskett StationR.M. Heskett StationR.M. Heskett StationRawhideRawhideRawhideSalem HarborSalem HarborSalem HarborSam SeymourSam SeymourSam SeymourSan JuanSan JuanSan JuanScrubgrass Generating Company L. P.Scrubgrass Generating Company L. P.Scrubgrass Generating Company L. P.SEI - Birchwood Power FacilitySEI - Birchwood Power FacilitySEI - Birchwood Power FacilityShawnee Fossil PlantShawnee Fossil PlantShawnee Fossil PlantSt Clair Power PlantSt Clair Power PlantSt Clair Power PlantStanton StationStanton StationStanton StationStanton StationStanton StationStanton StationStockton Cogen CompanyStockton Cogen CompanyStockton Cogen CompanyTNP-OneTNP-OneTNP-OneValleyValleyValleyValmontValmontValmontW. H. SammisW. H. SammisW. H. SammisWabash River Generating StationP Q R S T Upct_StackGasMoistureInpct_StackGasO2InHg_ParticleBoundInHg_OxidizedInHg_ElementalInOutlet Flow Rate%%ug/dscmug/dscmug/dscmdscm/hr14.8 2.1 0.05 0.01 7.04 329268.3314.1 2 ND(0.02) 0.15 7.28 328624.4113.8 2.1 ND(0.03) 0.10 6.76 331716.6110.1 4.9 2.44 0.56 1.49 299943.409.7 4.9 2.66 0.64 0.22 312538.179.8 5.2 2.60 0.54 0.15 296973.537.9 7.3 0.044 8.22 3.36 8699227.5 6.9 ND(0.013) 6.51 3.21 8888347.2 6.8 ND(0.015) 5.51 2.62 82303914 8.6 3.26 3.71 2.27 35699414.7 8.6 2.02 0.66 1.8 34071715 8.2 5.28 0.31 1.98 33320812.65 5.1 0.22 1.22 11.01 108876012.86 4.2 1.79 0.77 11.99 105523912.27 5.6 3.22 0.39 12.65 10680978.2 8.8 2.81 0.22 0.34 7303218.3 8.5 2.83 0.034 0.14 7014258.8 8.0 2.85 0.042 0.14 7110389.9 4.5 0.02 2.02 6.12 70768713.3 4.7 ND(0.01) 3.07 4.83 7274627 4.75 ND(0.01) 3.9 8.66 6565648.96 5.61 ND(0.03) 5.34 4.97 10462928.37 5.32 0.07 2.88 3.71 9626049.41 4.63 ND(0.05) 4.61 3.29 9644908.7 7.2 141.1 0.52 ND(0.12) 2330868.8 6.7 98.6 0.33 ND(0.10) 2466918.6 6.3 62.62 0.18 ND(0.12) 2488818.7 5.9 11.31 0.25 0.19 8493918.9 5.8 8 0.21 0.15 8474589.4 5.7 10.21 0.21 ND(0.27) 8674966.97 8.2 2.26 ND(0.82) ND(1.03) 6337126.74 8.2 2.14 0.7 ND(0.94) 6543826.68 8.6 2.37 ND(0.79) ND(0.92) 6452388.23 7.4 1.91 1.73 1.49 6384408.57 7.2 2.2 1.63 1.07 6860467.70 8.0 0.71 1.4 3.09 67080112.89 6.9 ND(0.21) 0.099 7.34 31771212.22 6.7 ND(0.083) 0.08 6.83 29222713.35 6.5 0.054 0.039 7.56 31941114.29 5.5 ND(0.01) 0.18 7.59 28033414.94 5.7 ND(0.004) 0.26 7.13 27523714.98 5.4 NC(0.004) 0.52 7.10 2752375.9 3.7 2.737 ND(0.136) ND(0.134) 2666846 4.36 ND(3.012) ND(0.141) ND(0.139) 2664666 3.87 2.1 ND(0.131) ND(0.148) 27566815.31 5.2 19 7.62 6.51 58512013.16 5.4 9.23 3.91 5.28 58434015.08 4.4 25.93 12.71 6.49 5876547.63 6.6 0.03 1.15 0.97 3612717.35 6.6 0.04 1.19 0.36 3721047.52 6.5 0.03 0.98 0.54 37771711.7 5.4 0.8 0.1 0.16 6928638.57 5.3 0.8 0.06 0.12 6672427.37 5.5 1.06 0.09 0.15 6482896.13 6 9.814 ND(0.80) ND(0.99) 7424506.7 6 12.788 ND(0.83) ND(0.90) 7166146.95 6 12.186 ND(0.85) ND(0.86) 699740137206412APlant Name235236237238239240241242243244245246247248Wabash River Generating StationWabash River Generating StationWidows Creek Fossil PlantWidows Creek Fossil PlantWidows Creek Fossil PlantWyodakWyodakWyodakXB = Excessive reagent blank caused the data to beunreliableNA = Data was not included in reportLS = Test sample was broken, damaged, or lost during testingor in transportP Q R S T Upct_StackGasMoistureInpct_StackGasO2InHg_ParticleBoundInHg_OxidizedInHg_ElementalInOutlet Flow Rate%%ug/dscmug/dscmug/dscmdscm/hr138588413524587.73 5.2 2.95 ND(0.78) ND(0.94) 4969767.29 5.6 2.55 ND(0.77) ND(0.87) 5001437.6 5 2.55 ND(0.83) ND(0.88) 5005329.3 8 1.8 2.8 8.2 19062789.9 8 2.2 3.4 6.8 19130749.8 7.4 1.7 2.7 8.7 1952151123456789101112131415161718192021222324252627282930313233343536373839404142434445464748495051525354555657585960APlant NameAES Cayuga (NY) (formerly NYSEG Milliken)AES Cayuga (NY) (formerly NYSEG Milliken)AES Cayuga (NY) (formerly NYSEG Milliken)AES Hawaii, Inc.AES Hawaii, Inc.AES Hawaii, Inc.Antelope Valley StationAntelope Valley StationAntelope Valley StationBaillyBaillyBaillyBay Front Plant GeneratingBay Front Plant GeneratingBay Front Plant GeneratingBig BendBig BendBig BendBig BrownBig BrownBig BrownBrayton PointBrayton PointBrayton PointBrayton PointBrayton PointBrayton PointBruce MansfieldBruce MansfieldBruce MansfieldCharles R. LowmanCharles R. LowmanCharles R. LowmanChollaChollaChollaChollaChollaChollaClay BoswellClay BoswellClay BoswellClay BoswellClay BoswellClay BoswellClay BoswellClay BoswellClay BoswellCliffsideCliffsideCliffsideClifty CreekClifty CreekClifty CreekClover Power StationClover Power StationClover Power StationColstripV W X Y Z AAtemp_GasOutpct_StackGasMoistureOutpct_StackGasO2OutHg_ParticleBoundOutHg_OxidizedOutHg_ElementalOutDeg C%%ug/dscmug/dscmug/dscm49.89 14.2 5.61 NA 0.26 2.2250.44 14.4 5.31 0.013 0.14 2.1949.94 14 5.32 0.02 0.13 2.50133.7 7.7 8.0 ND(0.003) ND(0.03) 0.42133.2 7.5 8.0 ND(0.002) ND(0.03) 0.59133.7 8.2 8.0 ND(0.002) ND(0.03) 0.3386 18.9 6 ND(0.01) 0.21 0.1682 18.4 6 0.02 0.66 6.884 18.4 5.6 0.02 0.27 5.9654.5 15.5 7.0 ND(0.002) 0.28 2.2253.9 14.5 7.0 ND(0.002) 0.24 2.0454.2 15.06 7.0 0.003 0.3 2.16135 8.10 9.0 0.79 0.4 1.27132 7.15 9.0 0.57 1.83 1.2134 7.17 9.1 0.32 2.36 1.1852 13 7.3 XB 0.16 1.6652 9.9 7.2 XB 0.09 1.3452 12.4 7.1 XB 0.18 1.58167 12.4 6 0.08 13.82 21171 12.78 6.8 0.03 13.93 20.09164 13.47 6.4 0.03 15 17.94144 6.7 7.2 0.59 2.94 0.252144 7.4 7.1 0.58 2.46 0.279141 7.4 7.4 0.58 2.28 0.261127 8.3 8.6 0.54 2.19 0.508126 7.6 9.4 0.62 1.59 0.376121 7.0 8.0 XB 2.48 2.3752 15.37 7.4 0.14 1.43 5.353 14.75 7.1 0.14 2.11 6.1552 12.76 6.8 0.13 0.96 6.54122 8.46 6.6 0.03 1.34 2.71121 7.41 6.4 0.05 1.51 2.84123 8.43 6.4 0.02 1.67 2.5986.7 13.4 5.7 XB 0.18 3.3486.7 13.5 5.9 XB 0.12 3.9286.6 13.6 5.1 XB 0.12 3.73159 8.5 6.2 XB 0.42 1.54155 8.7 5.5 XB NA 0.86159 8.6 5.7 XB 0.33 1.08169 10.4 6.6 0.059 1.01 0.11166 10.5 7.2 0.003 0.27 0.18168 11.3 7.1 ND(0.01) 0.45 0.0951 13.3 6.0 0.002 0.04 4.8551 13.8 6.4 ND(0.001) 0.05 4.3751 13.6 6.7 0.002 0.05 4.3867 13.8 5.2 0.02 0.09 4.8568 14.0 5.6 0.17 0.38 5.0469 14.3 6.0 0.23 0.49 4.64195.1 8.05 6.4 0.33 2.26 3.2196.6 8.46 6.3 0.08 1.85 1.59191.7 7.95 6.1 0.08 3.29 2.1170 9.91 6.0 0.58 3 3.89166 8.64 6.0 ND(0.01) 4.2 4.45166 8.02 6.0 0.06 4.58 3.1750.6 11.9 6.7 0.04 0.33 0.2550 12.3 6.5 ND(0.02) 0.27 0.1250 12.1 6.4 0.03 ND(0.08) 0.0989 15.6 6.2 0.114 ND(0.69) 7.5112APlant Name616263646566676869707172737475767778798081828384858687888990919293949596979899100101102103104105106107108109110111112113114115116117118ColstripColstripColumbiaColumbiaColumbiaComancheComancheComancheCoronadoCoronadoCoronadoCoyoteCoyoteCoyoteCraigCraigCraigCraigCraigCraigDunkirkDunkirkDunkirkDwayne Collier Battle Cogeneration FacilityDwayne Collier Battle Cogeneration FacilityDwayne Collier Battle Cogeneration FacilityGastonGastonGastonGeorge Neal southGeorge Neal southGeorge Neal southGibson Generating Station (10/99 testing)Gibson Generating Station (10/99 testing)Gibson Generating Station (10/99 testing)Gibson Generating Station (03/00 testing)Gibson Generating Station (03/00 testing)Gibson Generating Station (03/00 testing)GRDAGRDAGRDAIntermountainIntermountainIntermountainJack WatsonJack WatsonJack WatsonJim BridgerJim BridgerJim BridgerKline Township Cogen FacilityKline Township Cogen FacilityKline Township Cogen FacilityLa CygneLa CygneLa CygneLaramie River StationLaramie River StationV W X Y Z AAtemp_GasOutpct_StackGasMoistureOutpct_StackGasO2OutHg_ParticleBoundOutHg_OxidizedOutHg_ElementalOutDeg C%%ug/dscmug/dscmug/dscm89 15.91 6.2 0.112 ND(0.75) 9.0789 15.61 6.2 0.074 ND(0.64) 1.75149 11.7 6 0.004 2.28 9.76156 11.85 5.8 0.004 1.82 9.98157 11.88 6 0.004 2.21 9.99149.44 10.8 4.5 0.043 2.80 0.232157.78 11.1 4.5 ND(0.025) 3.38 0.537147.22 11.6 4.5 ND(0.038) 2.70 0.21448 13.7 5.71 ND(0.026) 0.037 3.0247 12.9 5.42 0.073 ND(0.061) 2.7449 13.8 5.39 0.097 0.115 2.67109 15.2 9.8 0.052 ND(0.017) 8.69596 16.8 9.7 0.09 0.152 ND(0.14)102 16.7 9.7 0.049 0.279 11.33864 10.91 7.16 ND(0.006) 0.097 1.6964 13.04 7.11 ND(0.005) 0.083 1.6158 11.48 7.18 0.009 0.072 1.5680.6 10.38 8.43 ND(0.005) ND(0.05) 0.785.6 10.3 8.27 ND(0.005) ND(0.05) 0.779.4 10.36 8.03 ND(0.005) ND(0.05) 0.66293.4 7.50 5.9 0.35 5.78 3.08295.2 8.11 5.8 .13 3.86 2.08295.8 7.74 5.7 0.05 5.44 3.2385 11.6 5 0.05 ND(0.04) ND(0.15)86 11.6 5.1 0.026 ND(0.05) ND(0.166)86 12.1 5.3 ND(0.014) ND(0.05) ND(0.17)128 6.3 7.1 0.57 3.63 1.81124 7.0 6.9 0.31 4.54 2.72128 6.1 6.5 0.93 3.81 1.64138 11.07 6.8 0.024 3.21 4.32142 11.65 7 0.048 3.58 5.34144 10.88 8.6 0.023 3.26 4.40171 6.60 5.9 ND(0.04) 5.08 4.34171 5.69 6.0 ND(0.08) 7.01 4.33173 7.26 5.8 ND(0.04) 9.31 4.02154 6.30 9.2 0.006 21 4.93154 7.11 8.8 0.007 21.83 3.93157 5.90 9.1 0.006 26.23 2.5584.0 15.81 6.1 0.01 1.28 9.24184.2 15.77 6.4 0.02 1.04 9.0284.2 15.68 6.3 0.01 0.28 8.82549 11.5 4.5 0.012 ND(0.041) 0.13949 11.5 4.4 0.0065 0.077 0.32548 11.5 5.1 0.0092 0.076 0.269157 8.9 6.3 0.02 2.1 1.53150 8.3 7.1 0.04 2.31 0.69150 8.0 6.7 ND(0.05) 2.32 0.7154 12.8 5.8 0.053 0.212 5.653 14.1 5.8 0.039 0.248 5.3854 13.4 5.8 0.028 0.168 4.87173 6.9 5.2 ND(0.006) ND(0.05) 0.07174 6.9 5.2 ND(0.006) ND(0.05) 0.07174 6.1 5.2 ND(0.006) 0.063 ND(0.075)72 13.98 7.4 0.13 ND(0.67) 6.672 14.65 7.2 0.1 ND(0.66) 5.6874 13.6 6.8 0.16 ND(0.64) 4.0264.4 15.2 10.5 XB 0.171 2.83563.3 14.9 10.0 XB 0.072 3.50112APlant Name119120121122123124125126127128129130131132133134135136137138139140141142143144145146147148149150151152153154155156157158159160161162163164165166167168169170171172173174175176Laramie River StationLaramie River StationLaramie River StationLaramie River StationLawrenceLawrenceLawrenceLeland Olds StationLeland Olds StationLeland Olds StationLewis & ClarkLewis & ClarkLewis & ClarkLimestoneLimestoneLimestoneLogan Generating PlantLogan Generating PlantLogan Generating PlantMecklenburg Cogeneration FacilityMecklenburg Cogeneration FacilityMecklenburg Cogeneration FacilityMeramecMeramecMeramecMonticelloMonticelloMonticelloMonticelloMonticelloMonticelloMontroseMontroseMontroseNavajoNavajoNavajoNelson DeweyNelson DeweyNelson DeweyNewtonNewtonNewtonNorthern States Power - Sherburne County GeneratingPlantNorthern States Power - Sherburne County GeneratingPlantNorthern States Power - Sherburne County GeneratingPlantPlattePlattePlattePolk PowerPolk PowerPolk PowerPort WashingtonPort WashingtonPort WashingtonPresque IslePresque IslePresque IsleV W X Y Z AAtemp_GasOutpct_StackGasMoistureOutpct_StackGasO2OutHg_ParticleBoundOutHg_OxidizedOutHg_ElementalOutDeg C%%ug/dscmug/dscmug/dscm63.3 15.7 7.8 XB ND(0.042) 3.28677.7 15.3 10.0 0.0158 0.0592 2.36878.9 14.8 10 0.0173 ND(0.046) 2.760978.9 14.9 9.8 0.0206 ND(0.048) 3.281168 16.94 7.2 0.09 ND(0.75) 4.8866 15.09 7.8 0.17 ND(0.77) 4.9268 15.23 7.7 0.16 ND(0.76) 4.58182 12.9 5.8 ND(0.004) 0.69 3.41182 13.1 5.8 ND(0.004) 0.92 4.44185 14 5.8 LS LS LS60 20.4 4.8 0.054 0.45 12.4760 20.9 4.7 ND(0.008) 0.32 12.8560 21.0 4.7 ND(0.008) 0.45 14.3259 18.5 8 0.03 1.94 11.5361 19.5 8 0.24 2.3 11.7259 18.7 8 0.09 0.92 12.4186.7 12.9 5.3 0.0178 0.032 0.09987 12.6 5.2 0.0162 0.052 0.08087.2 13.4 5 0.0131 0.016 0.7175.5 13.15 4.8 ND(0.027) 0.066 ND(0.137)74.4 13.59 4.4 ND(0.026) 0.065 ND(0.134)73.9 14.09 4.8 ND(0.027) ND(0.055) ND(0.138)162 9.02 7.27 ND(0.004) 0.58 0.61163 8.91 7.20 0.006 1.69 0.87150 9.25 6.17 ND(0.004) 1.24 0.65166 12.73 10.4 0.1 18.85 0.93166 13.01 11.4 0.06 41.64 7.98164 13.59 12.2 0.04 42.48 9.0990 19.91 10.4 0.18 3.83 17.3489 17.3 8.0 0.13 0.32 18.4389 17.17 8.2 0.17 5.16 16.43166.1 10.41 6.8 0.0052 2.03 4.29167.8 10.74 6.6 ND(0.005) 2.08 4.72167.8 11.17 6.0 ND(0.003) 1.92 4.7049 13.8 5.96 0.045 ND(0.06) 3.0749 13.8 5.82 0.019 ND(0.06) 3.249 14.1 5.85 0.011 ND(0.06) 3.17258 11.1 4.2 ND(0.092) 0.24 3.11258 10.78 4.2 ND(0.036) 0.15 2.24264 10.91 3.8 ND(0.035) 0.24 2.33169 13.51 5.84 ND(0.007) 1.9 6.8163 11.7 5.86 ND(0.005) 1.4 6170 14.94 5.08 ND(0.005) 1.8 7.180 11.49 6.3 0.1 0.16 6.8880 17.86 6.6 0.11 0.14 9.6781 15.02 6.5 0.22 0.19 7.93153.4 12.15 5.9 0.022 1.22 7.35158.0 14.24 5.7 0.023 0.66 14.33152.9 13.42 5.9 0.019 1.27 12.5171 7.1 12.2 ND(0.01) 0.39 3.55172 6.9 11.6 ND(0.01) 0.31 3.55171 6.9 11.9 ND(0.01) 0.13 3.55204.5 6.9 6.0 ND(0.0066) 5.34 2.55206.3 6.89 6.0 ND(0.0065) 4.87 2.54206.8 7.04 6.0 ND(0.0635) 5.43 2.53171.11 9.2 5.4 0.01 0.62 0.9225172.78 9.2 5 0.004 0.73 0.09171.67 9.3 5.2 0.04 0.62 0.8012APlant Name177178179180181182183184185186187188189190191192193194195196197198199200201202203204205206207208209210211212213214215216217218219220221222223224225226227228229230231232233234Presque IslePresque IslePresque IslePresque IslePresque IslePresque IsleR. D. Morrow Sr. Generating plantR. D. Morrow Sr. Generating plantR. D. Morrow Sr. Generating plantR.M. Heskett StationR.M. Heskett StationR.M. Heskett StationRawhideRawhideRawhideSalem HarborSalem HarborSalem HarborSam SeymourSam SeymourSam SeymourSan JuanSan JuanSan JuanScrubgrass Generating Company L. P.Scrubgrass Generating Company L. P.Scrubgrass Generating Company L. P.SEI - Birchwood Power FacilitySEI - Birchwood Power FacilitySEI - Birchwood Power FacilityShawnee Fossil PlantShawnee Fossil PlantShawnee Fossil PlantSt Clair Power PlantSt Clair Power PlantSt Clair Power PlantStanton StationStanton StationStanton StationStanton StationStanton StationStanton StationStockton Cogen CompanyStockton Cogen CompanyStockton Cogen CompanyTNP-OneTNP-OneTNP-OneValleyValleyValleyValmontValmontValmontW. H. SammisW. H. SammisW. H. SammisWabash River Generating StationV W X Y Z AAtemp_GasOutpct_StackGasMoistureOutpct_StackGasO2OutHg_ParticleBoundOutHg_OxidizedOutHg_ElementalOutDeg C%%ug/dscmug/dscmug/dscm195 14.4 4 0.00 0.54 5.95195.56 13.7 3.8 ND(0.005) 0.64 6.44196.67 13.7 3.6 ND(0.004) 0.52 6.17151.67 9.5 6.1 0.05 0.70 0.58151.11 9.5 5.8 0.02 0.85 0.78152.22 9.4 5.9 ND(0.004) 0.615 0.6883 12.8 7.6 ND(0.041) 1.53 3.7288 11.8 7.2 ND(0.024) 1.37 3.4588 12.8 7.2 ND(0.026) 0.86 3.49159 14.7 7.9 0.077 1.049 3.23153 14.6 8 0.051 0.293 3.832161 14.6 8.2 0.038 0.131 3.266103.8 12.78 6.0 0.20 0.63 9104.9 16.27 5.5 ND(0.01) 0.59 8.53103.3 16.19 6.0 0.05 0.82 7.5128 8.0 9.6 0.0419 0.1756 0.24128 8.2 8.3 0.0692 0.0491 0.11130 7.9 8.4 0.0527 0.0527 0.1457.1 17.6 8 0.04 0.16 8.2553.9 20.1 8 0.07 0.20 8.9756.1 18.1 8 0.04 0.23 8.0747.7 14.42 5.8 0.041 0.38 6.0347.7 13.73 5.7 0.071 0.32 4.0748.3 14.54 5.16 0.048 0.27 4.1156 8.4 7.3 ND(0.0043) 0.0495 ND(0.1205)157 8.5 7.0 ND(0.0043) 0.0373 ND(0.1196)158 8.3 7 ND(0.0041) 0.0313 ND(0.1141)90 12.6 6 0.009 0.29 0.1890 13 6.2 0.01 ND(0.14) 0.190 12.7 5.9 0.013 ND(0.13) ND(0.18)152 6.28 8.8 0.05 ND(0.86) 0.57149 7.39 9 0.08 ND(0.81) ND(1.01)153 6.75 9 ND(0.09) ND(0.80) ND(0.91)137 7.43 7.8 ND(0.177) 0.99 2.21142 8.25 8.4 ND(0.061) 0.97 2.62141 7.47 8.8 ND(0.113) 0.9 3.55191.1 13.36 6.4 ND(0.026) 0.28 7.35150.0 13.77 6.9 ND(0.014) 0.27 7.17158.3 14.03 6.7 ND(0.003) 0.28 7.5691.1 20.44 6.5 ND(0.01) 0.25 6.5895.0 19.17 6.4 ND(0.01) 0.11 6.9693.9 19.75 6.4 ND(0.01) ND(0.2) 7.12147 5.7 5.07 ND(0.129) ND(0.084) ND(0.086)146 5.5 5.22 ND(0.146) ND(0.097) ND(0.102)145 5.7 5.15 ND(0.136) ND(0.089) ND(0.100)177 13.33 6 0.06 10.11 3.95178 11.99 5.4 0.05 5.88 2.55171 13.54 4.8 0.04 12.19 4.56157.8 7.02 6.8 0.09 1.59 0.32158.7 7.00 6.7 0.03 1.23 0.33158.8 7.11 6.7 ND(0.008) 1.5 0.41134 8.27 5.4 ND(0.01) 0.105 0.032138 8.51 5.4 ND(0.01) 0.084 0.017148 7.57 5.5 ND(0.01) 0.178 0.027153 6.64 7.1 0.03 ND(0.76) ND(0.93)149 7.54 6.8 0.05 ND(0.93) ND(0.87)150 8.25 7 0.04 ND(0.79) ND(0.88)181.7 14.47 13.6 ND(0.05) ND(0.84) 2.5812APlant Name235236237238239240241242243244245246247248Wabash River Generating StationWabash River Generating StationWidows Creek Fossil PlantWidows Creek Fossil PlantWidows Creek Fossil PlantWyodakWyodakWyodakXB = Excessive reagent blank caused the data to beunreliableNA = Data was not included in reportLS = Test sample was broken, damaged, or lost during testingor in transportV W X Y Z AAtemp_GasOutpct_StackGasMoistureOutpct_StackGasO2OutHg_ParticleBoundOutHg_OxidizedOutHg_ElementalOutDeg C%%ug/dscmug/dscmug/dscm168.3 14.46 14.0 ND(0.05) ND(0.089) 2.6178.3 13.79 13.6 0.03 ND(0.90) 2.77162 6.95 8.2 0.1 1.05 ND(1.15)158 6.53 7.2 0.04 0.98 ND(1.04)151 6.79 7.6 0.06 ND(0.97) ND(1.00)82 13.7 8 ND(0.025) 0.048 7.0382 13.7 8 ND(0.029) 0.12 6.9881 13.2 8 ND(0.028) 0.18 6.95

# 14 

# ATTACHMENT 3

Hg_speciation_data_CAMR.xls

(Tab: 03_Data_Bin_Table)12345678910111213141516171819202122232425262728293031323334353637383940414243444546474849AB C DE FPlant IDEIA Plant Code &ORIS Plant Code orjust ORIS PlantCodeUnit No. Run NumberEmission ModificationFactor(fractional Hgretention acrosstesting locations)Testing locationsEmission control device type Bin 0Polk Power0184540000-07242 11(4)1.2338 coal to stackPolk Power0184540000-07242 12(4)1.2667 coal to stackPolk Power0184540000-07242 13(4)1.4601 coal to stackWabash River Generating Station 0154700000-01010 1 +1A 10.7153 coal to stackWabash River Generating Station 0154700000-01010 1 +1A 20.6070 coal to stackWabash River Generating Station 0154700000-01010 1 +1A 30.7017 coal to stackAverage emission modification factor0.9974Emission control device type Bin 1Brayton Point0134330000-01619 1 10.8420 across controlBrayton Point0134330000-01619 1 20.6449 across controlBrayton Point0134330000-01619 1 30.6887 across controlBrayton Point0134330000-01619 3 10.6416 across controlBrayton Point0134330000-01619 3 20.7214 across controlBrayton Point0134330000-01619 3 30.8813 across controlGibson Generating Station (03/00 testing) 0154700000-06113 3 11.0391 across controlGibson Generating Station (03/00 testing) 0154700000-06113 3 20.9003 across controlGibson Generating Station (03/00 testing) 0154700000-06113 3 30.9100 across controlGibson Generating Station (10/99 testing) 0154700000-06113 3 10.6109 across controlGibson Generating Station (10/99 testing) 0154700000-06113 3 20.4151 across controlGibson Generating Station (10/99 testing) 0154700000-06113 3 30.9023 across controlJack Watson0126860000-02049 4 10.7787 across controlJack Watson0126860000-02049 4 20.6230 across controlJack Watson0126860000-02049 4 30.7214 across controlWidows Creek Fossil Plant0186420000-00050 6 10.5589 across controlWidows Creek Fossil Plant0186420000-00050 6 20.5100 across controlWidows Creek Fossil Plant0186420000-00050 6 30.3665 across controlAverage emission modification factor0.7087Emission control device type Bin 2Presque Isle0208470000-01769 5 10.3471 across controlPresque Isle0208470000-01769 5 20.3813 across controlPresque Isle0208470000-01769 5 30.2856 across controlPresque Isle0208470000-01769 6 10.4546 across controlPresque Isle0208470000-01769 6 20.4971 across controlPresque Isle0208470000-01769 6 30.4127 across controlAverage emission modification factor0.3964Emission control device type Bin 3Salem Harbor0134330000-01626 3 10.1453 across controlSalem Harbor0134330000-01626 3 20.0748 across controlSalem Harbor0134330000-01626 3 30.0835 across control12AB C DE FPlant IDEIA Plant Code &ORIS Plant Code orjust ORIS PlantCodeUnit No. Run NumberEmission ModificationFactor(fractional Hgretention acrosstesting locations)Testing locations505152535455565758596061626364656667686970717273747576777879808182838485868788899091929394959697Average emission modification factor0.1012Emission control device type Bin 4Cliffside0054160000-02721 1 10.9914 across controlCliffside0054160000-02721 1 20.5214 across controlCliffside0054160000-02721 1 30.5749 across controlDunkirk0135730000-02554 2 10.9499 across controlDunkirk0135730000-02554 2 20.6768 across controlDunkirk0135730000-02554 2 30.8114 across controlGaston0001950000-00026 1 11.0019 across controlGaston0001950000-00026 1 21.4137 across controlGaston0001950000-00026 1 31.1000 across controlAverage emission modification factor0.8935Emission control device type Bin 5Bruce Mansfield0147160000-06094 1 10.8532 across controlBruce Mansfield0147160000-06094 1 20.8598 across controlBruce Mansfield0147160000-06094 1 30.9249 across controlAverage emission modification factor0.8793Emission control device type Bin 6Port Washington0208470000-04040 4 10.5932 across controlPort Washington0208470000-04040 4 20.4738 across controlPort Washington0208470000-04040 4 30.5863 across controlAverage emission modification factor0.5511Emission control device type Bin 7W. H. Sammis0139980000-02866 1 10.0882 across controlW. H. Sammis0139980000-02866 1 20.0735 across controlW. H. Sammis0139980000-02866 1 30.0719 across controlValmont0154660000-00477 5 10.1340 across controlValmont0154660000-00477 5 20.1089 across controlValmont0154660000-00477 5 30.1615 across controlAverage emission modification factor0.1063Emission control device type Bin 8Mecklenburg Cogeneration Facility52007 GEN 1 10.0076 across controlMecklenburg Cogeneration Facility52007 GEN 1 20.0158 across controlMecklenburg Cogeneration Facility52007 GEN 1 30.0122 across controlAverage emission modification factor0.0119Emission control device type Bin 912AB C DE FPlant IDEIA Plant Code &ORIS Plant Code orjust ORIS PlantCodeUnit No. Run NumberEmission ModificationFactor(fractional Hgretention acrosstesting locations)Testing locations9899100101102103104105106107108109110111112113114115116117118119120121122123124125126127128129130131132133134135136137138139140141142143144145SEI - Birchwood Power Facility54304 1 10.0410 across controlSEI - Birchwood Power Facility54304 1 20.0221 across controlSEI - Birchwood Power Facility54304 1 30.0161 across controlLogan Generating Plant10043 Gen 1 10.0091 across controlLogan Generating Plant10043 Gen 1 20.0101 across controlLogan Generating Plant10043 Gen 1 30.0553 across controlAverage emission modification factor0.0256Emission control device type Bin 10Big Bend0184540000-00645 BB03 10.3297 last controlBig Bend0184540000-00645 BB03 20.2579 last controlBig Bend0184540000-00645 BB03 30.3568 last controlAES Cayuga (NY) (formerly NYSEG Milliken) 0135110000-02535 2 10.3624 last controlAES Cayuga (NY) (formerly NYSEG Milliken) 0135110000-02535 2 20.2791 last controlAES Cayuga (NY) (formerly NYSEG Milliken) 0135110000-02535 2 30.3001 last controlSecond unit average emission modification factor 0.3143First unit average emission modification correctionfactor 0.7087Combined emission modification factor60.2228Emission control device type Bin 11Charles R. Lowman0001890000-00056 2 10.9402 last controlCharles R. Lowman0001890000-00056 2 20.7053 last controlCharles R. Lowman0001890000-00056 2 30.5855 last controlR. D. Morrow Sr. Generating plant 0175680000-06061 2 10.4636 last controlR. D. Morrow Sr. Generating plant 0175680000-06061 2 20.5076 last controlR. D. Morrow Sr. Generating plant 0175680000-06061 2 30.5517 last controlNavajo0165720000-04941 3 10.5800 last controlNavajo0165720000-04941 3 20.8735 last controlNavajo0165720000-04941 3 30.9182 last controlSecond unit average emission modification factor 0.6806First unit average emission modification correctionfactor 0.8935Combined emission modification factor0.6081Emission control device type Bin 12Clover Power Station0198760000-07213 2 10.3826 last controlClover Power Station0198760000-07213 2 20.2183 last controlClover Power Station0198760000-07213 2 30.1093 last controlIntermountain0112080000-06481 2SGA 10.1597 last controlIntermountain0112080000-06481 2SGA 20.3447 last controlIntermountain0112080000-06481 2SGA 30.2598 last controlSecond unit average emission modification factor 0.2457First unit average emission modification correctionfactor 0.1063Combined emission modification factor0.026112AB C DE FPlant IDEIA Plant Code &ORIS Plant Code orjust ORIS PlantCodeUnit No. Run NumberEmission ModificationFactor(fractional Hgretention acrosstesting locations)Testing locations146147148149150151152153154155156157158159160161162163164165166167168169170171172173174175176177178179180181182183184185186187188189190191192193Emission control device type Bin 13Montrose0100000000-02080 1 10.8241 across controlMontrose0100000000-02080 1 21.0234 across controlMontrose0100000000-02080 1 30.8725 across controlGeorge Neal South0123410000-07343 4 10.8538 across controlGeorge Neal South0123410000-07343 4 20.9109 across controlGeorge Neal South0123410000-07343 4 31.5235 across controlNewton0032530000-06017 2 11.0010 across controlNewton0032530000-06017 2 20.8367 across controlNewton0032530000-06017 2 30.9154 across controlAverage emission modification factor0.9735Emission control device type Bin 14Cholla0008030000-00113 3 11.2116 across controlCholla0008030000-00113 3 21.2821 across controlCholla0008030000-00113 3 31.5943 across controlColumbia0208560000-08023 1 10.9492 across controlColumbia0208560000-08023 1 20.7258 across controlColumbia0208560000-08023 1 30.9667 across controlPlatte0406060000-00059 1 10.7318 across controlPlatte0406060000-00059 1 21.3316 across controlPlatte0406060000-00059 1 31.0247 across controlPresque Isle0208470000-01769 9 10.9990 across controlPresque Isle0208470000-01769 9 21.0523 across controlPresque Isle0208470000-01769 9 31.0577 across controlAverage emission modification factor1.0772Emission control device type Bin 15Clay Boswell0126470000-01893 2 10.2394 across controlClay Boswell0126470000-01893 2 20.1255 across controlClay Boswell0126470000-01893 2 30.1581 across controlComanche0154660000-00470 2 10.3140 across controlComanche0154660000-00470 2 20.4737 across controlComanche0154660000-00470 2 30.3348 across controlAverage emission modification factor0.2742Emission control device type Bin 16Clay Boswell0126470000-01893 3 10.9284 across controlClay Boswell0126470000-01893 3 20.8619 across controlClay Boswell0126470000-01893 3 30.9475 across controlClay Boswell0126470000-01893 4 11.0308 across controlClay Boswell0126470000-01893 4 21.1825 across controlClay Boswell0126470000-01893 4 31.4440 across controlCholla0008030000-00113 2 10.7732 across control12AB C DE FPlant IDEIA Plant Code &ORIS Plant Code orjust ORIS PlantCodeUnit No. Run NumberEmission ModificationFactor(fractional Hgretention acrosstesting locations)Testing locations194195196197198199200201202203204205206207208209210211212213214215216217218219220221222223224225226227228229230231232233234235236237238239240241Cholla0008030000-00113 2 21.3339 across controlCholla0008030000-00113 2 31.0233 across controlColstrip0128250000-06076 3 11.8828 across controlColstrip0128250000-06076 3 21.0884 across controlColstrip0128250000-06076 3 30.2640 across controlLawrence0002250000-01250 4 11.0159 across controlLawrence0002250000-01250 4 21.3383 across controlLawrence0002250000-01250 4 31.1678 across controlAverage emission modification factor1.0855Emission control device type Bin 17GRDA0074900000-00165 2 11.0228 across controlGRDA0074900000-00165 2 21.2436 across controlGRDA0074900000-00165 2 30.8185 across controlLaramie River Station0013070000-06204 3 14.5534 across controlLaramie River Station0013070000-06204 3 20.4265 across controlLaramie River Station0013070000-06204 3 30.3746 across controlWyodak0143540000-06101 BW 91 10.5540 across controlWyodak0143540000-06101 BW 91 20.5738 across controlWyodak0143540000-06101 BW 91 30.5705 across controlAverage emission modification factor1.1264Emission control device type Bin 18Craig0301510000-06021 C3 10.6846 across controlCraig0301510000-06021 C3 20.6019 across controlCraig0301510000-06021 C3 30.7055 across controlRawhide0151430000-06761 101 10.8369 across controlRawhide0151430000-06761 101 20.6798 across controlRawhide0151430000-06761 101 30.5285 across controlNorthern States Power - Sherburne County GeneratingPlant 0137810000-06090 #3 10.7633 across controlNorthern States Power - Sherburne County GeneratingPlant 0137810000-06090 #3 21.1114 across controlNorthern States Power - Sherburne County GeneratingPlant 0137810000-06090 #3 30.9916 across controlAverage emission modification factor0.7670Emission control device type Bin 19Jim Bridger0143540000-08066 BW 74 10.8968 last controlJim Bridger0143540000-08066 BW 74 20.8448 last controlJim Bridger0143540000-08066 BW 74 30.9705 last controlLaramie River Station0013070000-06204 1 10.4723 last controlLaramie River Station0013070000-06204 1 20.5546 last controlLaramie River Station0013070000-06204 1 30.4242 last controlSam Seymour0112690000-06179 3 11.3143 last controlSam Seymour0112690000-06179 3 21.4656 last controlSam Seymour0112690000-06179 3 30.8297 last control12AB C DE FPlant IDEIA Plant Code &ORIS Plant Code orjust ORIS PlantCodeUnit No. Run NumberEmission ModificationFactor(fractional Hgretention acrosstesting locations)Testing locations242243244245246247248249250251252253254255256257258259260261262263264265266267268269270271272273274275276277278279280281282283284285286287288289Second unit average emission modification factor 0.8636First unit average emission modification correctionfactor 0.9735Combined emission modification factor0.8407Emission control device type Bin 20Coronado0615720000-06177 U1B 11.1295 last controlCoronado0615720000-06177 U1B 21.2141 last controlCoronado0615720000-06177 U1B 31.1130 last controlCraig0301510000-06021 C1 10.5859 last controlCraig0301510000-06021 C1 20.7705 last controlCraig0301510000-06021 C1 30.9756 last controlSan Juan0154730000-02451 2 10.6326 last controlSan Juan0154730000-02451 2 20.6865 last controlSan Juan0154730000-02451 2 30.5761 last controlSecond unit average emission modification factor 0.8537First unit average emission modification correctionfactor 1.0772Combined emission modification factor0.9197Emission control device type Bin 21Stanton Station0195140000-02824 1 10.9784 across controlStanton Station0195140000-02824 1 21.0865 across controlStanton Station0195140000-02824 1 31.0390 across controlAverage emission modification factor1.0346Emission control device type Bin 22La Cygne0100000000-01241 1 10.7792 across controlLa Cygne0100000000-01241 1 20.7622 across controlLa Cygne0100000000-01241 1 30.7942 across controlAverage emission modification factor0.7785Emission control device type Bin 23Nelson Dewey0208560000-04054 1 10.9805 across controlNelson Dewey0208560000-04054 1 21.0560 across controlNelson Dewey0208560000-04054 1 31.2327 across controlAverage emission modification factor1.0897Emission control device type Bin 24Leland Olds Station0013070000-02817 2 11.2353 across controlLeland Olds Station0013070000-02817 2 20.6674 across controlAverage emission modification factor0.9513Emission control device type Bin 25Stockton Cogen Company10640 GEN1 10.0565 across control12AB C DE FPlant IDEIA Plant Code &ORIS Plant Code orjust ORIS PlantCodeUnit No. Run NumberEmission ModificationFactor(fractional Hgretention acrosstesting locations)Testing locations290291292293294295296297298299300301302303304305306307308309310311312313314315316317318319320321322323324325326327328329330331332333334335Stockton Cogen Company10640 GEN1 20.1105 across controlStockton Cogen Company10640 GEN1 30.0784 across controlAverage emission modification factor0.0818Emission control device type Bin 26 - Not Used inModelEmission control device type Bin 27Scrubgrass Generating Company L. P. 50974 GEN1 10.0008 across controlScrubgrass Generating Company L. P. 50974 GEN1 20.0010 across controlScrubgrass Generating Company L. P. 50974 GEN1 30.0015 across controlAverage emission modification factor0.0011Emission control device type Bin 28R.M. Heskett Station0128190000-02790 B2 10.4462 across controlR.M. Heskett Station0128190000-02790 B2 20.8891 across controlR.M. Heskett Station0128190000-02790 B2 30.4538 across controlAverage emission modification factor0.5964Emission control device type Bin 29TNP-One0400510000-07030 U2 10.4489 across controlTNP-One0400510000-07030 U2 20.4604 across controlTNP-One0400510000-07030 U2 30.3812 across controlAverage emission modification factor0.4302Emission control device type Bin 30Kline Township Cogen Facility50039 GEN1 10.0025 across controlKline Township Cogen Facility50039 GEN1 20.0026 across controlKline Township Cogen Facility50039 GEN1 30.0026 across controlAverage emission modification factor0.0026Emission control device type Bin 31Dwayne Collier Battle Cogeneration Facility 10384 2B 10.0707 across controlDwayne Collier Battle Cogeneration Facility 10384 2B 20.0565 across controlDwayne Collier Battle Cogeneration Facility 10384 2B 30.0629 across controlAverage emission modification factor0.0634Emission control device type Bin 32 - Not Used inModelEmission control device type Bin 33Big Brown0443720000-03497 1 10.9928 last control12AB C DE FPlant IDEIA Plant Code &ORIS Plant Code orjust ORIS PlantCodeUnit No. Run NumberEmission ModificationFactor(fractional Hgretention acrosstesting locations)Testing locations336337338339340341342343344345346347348349350351352353354355356357358359360361362363364365366367368369370371372373374375376377378379380381382383Big Brown0443720000-03497 1 21.1296 last controlBig Brown0443720000-03497 1 31.1199 last controlMonticello0443720000-06147 1 10.7131 last controlMonticello0443720000-06147 1 21.5152 last controlMonticello0443720000-06147 1 31.4095 last controlSecond unit average emission modification factor 1.1467First unit average emission modification correctionfactor 1.0346Combined emission modification factor1.1864Emission control device type Bin 34Antelope Valley Station0013070000-06469 B1 10.0545 across controlAntelope Valley Station0013070000-06469 B1 21.0527 across controlAntelope Valley Station0013070000-06469 B1 30.8930 across controlStanton Station0195140000-02824 10 10.9397 across controlStanton Station0195140000-02824 10 21.0030 across controlStanton Station0195140000-02824 10 31.0131 across controlAverage emission modification factor0.8260Emission control device type Bin 35Lewis & Clark0128190000-06089 B1 10.4925 across controlLewis & Clark0128190000-06089 B1 20.6126 across controlLewis & Clark0128190000-06089 B1 30.9119 across controlAverage emission modification factor0.6723Emission control device type Bin 36Monticello0443720000-06147 3 10.7869 last controlMonticello0443720000-06147 3 20.5443 last controlMonticello0443720000-06147 3 30.5756 last controlLimestone0089010000-00298 LIM1 10.5060 last controlLimestone0089010000-00298 LIM1 20.5241 last controlLimestone0089010000-00298 LIM1 30.4393 last controlSecond unit average emission modification factor 0.5627First unit average emission modification correctionfactor 1.0346Combined emission modification factor0.5822Emission control device type Bin 37Bay Front Plant Generating0137810000-03982 5 10.9966 across controlBay Front Plant Generating0137810000-03982 5 21.4654 across controlBay Front Plant Generating0137810000-03982 5 32.2500 across controlAverage emission modification factor1.5707Emission control device type Bin 38Bailly0137560000-00995 7 and 8 10.5117 last control12AB C DE FPlant IDEIA Plant Code &ORIS Plant Code orjust ORIS PlantCodeUnit No. Run NumberEmission ModificationFactor(fractional Hgretention acrosstesting locations)Testing locations384385386387388389390391392393394395396397398399400401402403404405406407408409410411412413414415416417418419420421422423424425426427428429430Bailly0137560000-00995 7 and 8 20.5361 last controlBailly0137560000-00995 7 and 8 30.5138 last controlSecond unit average emission modification factor 0.5205First unit average emission modification correctionfactor 0.9513Combined emission modification factor0.4952Emission control device type Bin 39Coyote0128190000-08222 1 10.8801 across controlCoyote0128190000-08222 1 20.0275 across controlCoyote0128190000-08222 1 30.9453 across controlAverage emission modification factor0.6176Emission control device type Bin 40AES Hawaii, Inc.10673 AB 10.4330 across controlAES Hawaii, Inc.10673 AB 20.4626 across controlAES Hawaii, Inc.10673 AB 30.5288 across controlAverage emission modification factor0.4748Emission control device type Bin 41Meramec0194360000-02104 4 10.1873 across controlMeramec0194360000-02104 4 20.3003 across controlMeramec0194360000-02104 4 30.2804 across controlSt Clair Power Plant0051090000-01743 4 10.6605 across controlSt Clair Power Plant0051090000-01743 4 20.8093 across controlSt Clair Power Plant0051090000-01743 4 30.9235 across controlAverage emission modification factor0.5269Emission control device type Bin 42Clifty Creek0092690000-00983 6 10.6442 across controlClifty Creek0092690000-00983 6 20.7049 across controlClifty Creek0092690000-00983 6 30.6301 across controlAverage emission modification factor0.6597Emission control device type Bin 43Valley0208470000-04042 2 10.9433 across controlValley0208470000-04042 2 21.0070 across controlValley0208470000-04042 2 31.2521 across controlAverage emission modification factor1.0675Emission control device type Bin 44Shawnee Fossil Plant0186420000-01379 3 10.3459 across control12AB C DE FPlant IDEIA Plant Code &ORIS Plant Code orjust ORIS PlantCodeUnit No. Run NumberEmission ModificationFactor(fractional Hgretention acrosstesting locations)Testing locations431432433434435436437438439440441442443444Shawnee Fossil Plant0186420000-01379 3 20.3190 across controlShawnee Fossil Plant0186420000-01379 3 30.2884 across controlAverage emission modification factor0.31781Although combustion NOxcontrols and furnace bottom type are listedin this column, they have no effect on the bin intowhich the unit wasclassified.2This column addresses external NOxcontrols only.3Speciation was accomplished by analyzing the data in the test reportsand computing the total mercury leaving the last control device for eachrun. Then, within the run, we computed the percentage that each Hgspecies composed of the total. Then, within the bin, we took theaverage of each species column. These average percentages werethen applied to the units that used the specific bin. A “0" in the dataoccurred when any speciated Hg outlet number was not provided or wasunacceptable (according to the test method). The sum of the fractionalsplits is 1 except where slight rounding errors exist.4All test runs are listed as 1, 2, and 3. This doesnot mean that duringthe stack testing that these were the actual 1st, 2nd, or 3rd test runs.However, these were the runs presented in the testreports and dateorder was maintained.5Coal gasification units burn synthetic gas (derivedfrom coal) in acomplex process that requires no PM or SO2control following theprocess.6A different method was used to average fuel type/boiler type/emissioncontrol system(s) from all dual-controlled units (units having both a PMand an SO2control device) than was used for single-controlled units.Since stack test flue-gas speciated Hg was analyzedat the inlet andoutlet of the last control device, the effect of the PM control on Hgremoval on these dual-controlled units was not clear. Thus: EPAdecided that it would be more realistic to add thePM control deviceremoval of Hg to the SO2control device removal of Hg for dualcontrolled units. The PM control device average EMF was taken fromthe bin of a unit with a similar fuel type/boiler type/PM emission controlsystem to the dual-controlled bin it was modifying.The average EMF ofa tested unit with a single PM control device was multiplied by eachindividual run EMF from a similarly configured dual-controlled unit.These modified EMFs were averaged. This average was used tocompute the Hg removal of a dual-controlled unit inthe nationalemissions model.7All fluidized bed combustor units tested had limestone injection in theirfurnaces to reduce SO2.12345678910111213141516171819202122232425262728293031323334353637383940414243444546474849G H I J K L M NSpeciated Hg split instack (fraction)3Primary Fuel/ SecondaryFuel Boiler/furnace type1PM Control SO2 Control External NOXControl2Particle-bound Hg Oxidized Hg Elemental HgBituminous/None COAL GASCOAL GAS5COAL GAS5NONE 0.00127 0.09886 0.89987Bituminous/None COAL GASCOAL GAS5COAL GAS5NONE 0.00129 0.08021 0.91850Bituminous/None COAL GASCOAL GAS5COAL GAS5NONE 0.00136 0.03528 0.96337Bituminous/None COAL GASCOAL GAS5COAL GAS5NONE 0.00826 0.13884 0.85289Bituminous/None COAL GASCOAL GAS5COAL GAS5NONE 0.00937 0.01667 0.97397Bituminous/None COAL GASCOAL GAS5COAL GAS5NONE 0.00923 0.13846 0.85231Average speciated Hg fraction0.005130.084720.91015Bituminous/None CONV/PC/NOX/DRY ESP- CS COMP COAL NONE 0.15600 0.77737 0.06663Bituminous/None CONV/PC/NOX/DRY ESP- CS COMP COAL NONE 0.17475 0.74119 0.08406Bituminous/None CONV/PC/NOX/DRY ESP- CS COMP COAL NONE 0.18584 0.73054 0.08363Bituminous/None CONV/PC/NOX/DRY ESP- CS COMP COAL NONE 0.16677 0.67634 0.15689Bituminous/None CONV/PC/NOX/DRY ESP- CS COMP COAL NONE 0.23975 0.61485 0.14540Bituminous/None CONV/PC/NOX/DRY ESP- CS COMP COAL NONE 0.00000 0.51134 0.48866Bituminous/None CONV/PC/NOX/DRY ESP- CS NONE NONE 0.00023 0.80969 0.19008Bituminous/None CONV/PC/NOX/DRY ESP- CS NONE NONE 0.00027 0.84721 0.15252Bituminous/None CONV/PC/NOX/DRY ESP- CS NONE NONE 0.00021 0.91121 0.08858Bituminous/None CONV/PC/NOX/DRY ESP- CS NONE NONE 0.00212 0.53814 0.45975Bituminous/None CONV/PC/NOX/DRY ESP- CS NONE NONE 0.00351 0.61599 0.38049Bituminous/None CONV/PC/NOX/DRY ESP- CS NONE NONE 0.00150 0.69738 0.30112Bituminous/None CONV/PC/NOX/DRY ESP- CS NONE NONE 0.00548 0.57534 0.41918Bituminous/None CONV/PC/NOX/DRY ESP- CS NONE NONE 0.01316 0.75987 0.22697Bituminous/None CONV/PC/NOX/DRY ESP- CS NONE NONE 0.00818 0.75941 0.23241Bituminous/None CONV/PC/NONOX/DRY ESP- CS COMP COAL NONE 0.05797 0.60870 0.33333Bituminous/None CONV/PC/NONOX/DRY ESP- CS COMP COAL NONE 0.02597 0.63636 0.33766Bituminous/None CONV/PC/NONOX/DRY ESP- CS COMP COAL NONE 0.05742 0.46411 0.47847Average speciated Hg fraction0.061060.681950.25699Bituminous/Pet Coke CONV/PC/NONOX/WET ESP- CS COMP COAL NONE 0.00599 0.40120 0.59281Bituminous/Pet Coke CONV/PC/NONOX/WET ESP- CS COMP COAL NONE 0.00228 0.44470 0.55302Bituminous/Pet Coke CONV/PC/NONOX/WET ESP- CS COMP COAL NONE 0.01035 0.43338 0.55627Bituminous/Pet Coke CONV/PC/NONOX/WET ESP- CS COMP COAL NONE 0.03657 0.52743 0.43601Bituminous/Pet Coke CONV/PC/NONOX/WET ESP- CS COMP COAL NONE 0.01353 0.51297 0.47351Bituminous/Pet Coke CONV/PC/NONOX/WET ESP- CS COMP COAL NONE 0.00154 0.47409 0.52437Average speciated Hg fraction0.011710.465630.52267Bituminous/None CONV/PC/NOX/DRY ESP- CS COMP COAL SNCR 0.09158 0.38383 0.52459Bituminous/None CONV/PC/NOX/DRY ESP- CS COMP COAL SNCR 0.30311 0.21507 0.48182Bituminous/None CONV/PC/NOX/DRY ESP- CS COMP COAL SNCR 0.21475 0.21475 0.5705012G H I J K L M NSpeciated Hg split instack (fraction)3Primary Fuel/ SecondaryFuel Boiler/furnace type1PM Control SO2 Control External NOXControl2Particle-bound Hg Oxidized Hg Elemental Hg505152535455565758596061626364656667686970717273747576777879808182838485868788899091929394959697Average speciated Hg fraction0.203150.271210.52564Bituminous/None CONV/PC/NONOX/DRY ESP- HS NONE NONE 0.05699 0.39033 0.55268Bituminous/None CONV/PC/NONOX/DRY ESP- HS NONE NONE 0.02273 0.52557 0.45170Bituminous/None CONV/PC/NONOX/DRY ESP- HS NONE NONE 0.01463 0.60146 0.38391Bituminous/None CONV/PC/NOX/DRY ESP- HS COMP COAL NONE 0.03800 0.62758 0.33442Bituminous/None CONV/PC/NOX/DRY ESP- HS COMP COAL NONE 0.02142 0.63591 0.34267Bituminous/None CONV/PC/NOX/DRY ESP- HS COMP COAL NONE 0.00573 0.62385 0.37041Bituminous/None CONV/PC/NOX/DRY ESP- HS NONE NONE 0.09484 0.60399 0.30116Bituminous/None CONV/PC/NOX/DRY ESP- HS NONE NONE 0.04095 0.59974 0.35931Bituminous/None CONV/PC/NOX/DRY ESP- HS NONE NONE 0.14577 0.59718 0.25705Average speciated Hg fraction0.049010.578400.37259Bituminous/None CONV/PC/NOX/DRY PARTSCRUB NONE NONE 0.02038 0.20815 0.77147Bituminous/None CONV/PC/NOX/DRY PARTSCRUB NONE NONE 0.01667 0.25119 0.73214Bituminous/None CONV/PC/NOX/DRY PARTSCRUB NONE NONE 0.01704 0.12582 0.85714Average speciated Hg fraction0.018030.195050.78692Bituminous/None CONV/PC/NONOX/DRY ESP- CS DRY SORBENT NONE 0.00042 0.67652 0.32306Bituminous/None CONV/PC/NONOX/DRY ESP- CS DRY SORBENT NONE 0.00044 0.65693 0.34263Bituminous/None CONV/PC/NONOX/DRY ESP- CS DRY SORBENT NONE 0.00397 0.67945 0.31658Average speciated Hg fraction0.001610.670970.32742Bituminous/None CONV/PC/NONOX/DRY BAGHOUSE NONE NONE 0.03429 0.43429 0.53143Bituminous/None CONV/PC/NONOX/DRY BAGHOUSE NONE NONE 0.05263 0.48947 0.45789Bituminous/None CONV/PC/NONOX/DRY BAGHOUSE NONE NONE 0.04571 0.45143 0.50286Bituminous/None CONV/PC/NOX/DRY BAGHOUSE COMP COAL NONE0.03521 0.73944 0.22535Bituminous/None CONV/PC/NOX/DRY BAGHOUSE COMP COAL NONE0.04717 0.79245 0.16038Bituminous/None CONV/PC/NOX/DRY BAGHOUSE COMP COAL NONE0.02381 0.84762 0.12857Average speciated Hg fraction0.039800.625780.33441Bituminous/None CONV/PC/NOX/DRY BAGHOUSE SDA NONE 0.09122 0.44595 0.46284Bituminous/None CONV/PC/NOX/DRY BAGHOUSE SDA NONE 0.08966 0.44828 0.46207Bituminous/None CONV/PC/NOX/DRY BAGHOUSE SDA NONE 0.12273 0.25000 0.62727Average speciated Hg fraction0.101200.381410.5173912G H I J K L M NSpeciated Hg split instack (fraction)3Primary Fuel/ SecondaryFuel Boiler/furnace type1PM Control SO2 Control External NOXControl2Particle-bound Hg Oxidized Hg Elemental Hg9899100101102103104105106107108109110111112113114115116117118119120121122123124125126127128129130131132133134135136137138139140141142143144145Bituminous/None CONV/PC/NOX/DRY BAGHOUSE SDA SCR 0.018790.60543 0.37578Bituminous/None CONV/PC/NOX/DRY BAGHOUSE SDA SCR 0.055560.38889 0.55556Bituminous/None CONV/PC/NOX/DRY BAGHOUSE SDA SCR 0.077380.38690 0.53571Bituminous/None CONV/PC/NOX/DRY BAGHOUSE SDA SCR 0.119620.21505 0.66532Bituminous/None CONV/PC/NOX/DRY BAGHOUSE SDA SCR 0.109310.35088 0.53981Bituminous/None CONV/PC/NOX/DRY BAGHOUSE SDA SCR 0.017720.02165 0.96063Average speciated Hg fraction0.066400.328130.60547Bituminous/None CONV/PC/TURBO/NOX/DRY ESP- CS WETSCRUBNONE 0.00000 0.08791 0.91209Bituminous/None CONV/PC/TURBO/NOX/DRY ESP- CS WETSCRUBNONE 0.00000 0.06294 0.93706Bituminous/None CONV/PC/TURBO/NOX/DRY ESP- CS WETSCRUBNONE 0.00000 0.10227 0.89773Bituminous/None CONV/PC/NOX/DRY ESP- CS WETSCRUB NONE 0.00000 0.10484 0.89516Bituminous/None CONV/PC/NOX/DRY ESP- CS WETSCRUB NONE 0.00555 0.05975 0.93470Bituminous/None CONV/PC/NOX/DRY ESP- CS WETSCRUB NONE 0.00755 0.04906 0.94340Average speciated Hg fraction0.002180.077790.92002Bituminous/None CONV/PC/NONOX/DRY ESP- HS WETSCRUB NONE0.00735 0.32843 0.66422Bituminous/None CONV/PC/NONOX/DRY ESP- HS WETSCRUB NONE0.01136 0.34318 0.64545Bituminous/None CONV/PC/NONOX/DRY ESP- HS WETSCRUB NONE0.00467 0.39019 0.60514Bituminous/None CONV/PC/NOX/DRY ESP- HS WETSCRUB NONE 0.00389 0.29030 0.70582Bituminous/None CONV/PC/NOX/DRY ESP- HS WETSCRUB NONE 0.00248 0.28353 0.71399Bituminous/None CONV/PC/NOX/DRY ESP- HS WETSCRUB NONE 0.00298 0.19711 0.79991Bituminous/None CONV/PC/NONOX/DRY ESP- HS WETSCRUB NONE0.01431 0.00954 0.97615Bituminous/None CONV/PC/NONOX/DRY ESP- HS WETSCRUB NONE0.00585 0.00923 0.98492Bituminous/None CONV/PC/NONOX/DRY ESP- HS WETSCRUB NONE0.00343 0.00934 0.98723Average speciated Hg fraction0.006260.206760.78698Bituminous/None CONV/PC/NOX/DRY BAGHOUSE WETSCRUB NONE 0.06452 0.53226 0.40323Bituminous/None CONV/PC/NOX/DRY BAGHOUSE WETSCRUB NONE 0.02500 0.67500 0.30000Bituminous/None CONV/PC/NOX/DRY BAGHOUSE WETSCRUB NONE 0.18750 0.25000 0.56250Bituminous/None CONV/PC/NOX/DRY BAGHOUSE WETSCRUB NONE 0.06997 0.11953 0.81050Bituminous/None CONV/PC/NOX/DRY BAGHOUSE WETSCRUB NONE 0.01591 0.18849 0.79559Bituminous/None CONV/PC/NOX/DRY BAGHOUSE WETSCRUB NONE 0.02597 0.21457 0.75946Average speciated Hg fraction0.064810.329980.6052112G H I J K L M NSpeciated Hg split instack (fraction)3Primary Fuel/ SecondaryFuel Boiler/furnace type1PM Control SO2 Control External NOXControl2Particle-bound Hg Oxidized Hg Elemental Hg146147148149150151152153154155156157158159160161162163164165166167168169170171172173174175176177178179180181182183184185186187188189190191192193Subbituminous/None CONV/PC/NOX/DRY ESP- CS COMP COAL NONE 0.00082 0.32094 0.67824Subbituminous/None CONV/PC/NOX/DRY ESP- CS COMP COAL NONE 0.00037 0.30577 0.69386Subbituminous/None CONV/PC/NOX/DRY ESP- CS COMP COAL NONE 0.00023 0.28996 0.70981Subbituminous/None CONV/PC/NOX/DRY ESP- CS COMP COAL NONE 0.00318 0.42494 0.57188Subbituminous/None CONV/PC/NOX/DRY ESP- CS COMP COAL NONE 0.00535 0.39920 0.59545Subbituminous/None CONV/PC/NOX/DRY ESP- CS COMP COAL NONE 0.00299 0.42431 0.57269Subbituminous/None CONV/PC/NOX/DRY ESP- CS COMP COAL NONE 0.00040 0.21830 0.78129Subbituminous/None CONV/PC/NOX/DRY ESP- CS COMP COAL NONE 0.00034 0.18913 0.81054Subbituminous/None CONV/PC/NOX/DRY ESP- CS COMP COAL NONE 0.00028 0.20219 0.79753Average speciated Hg fraction0.001550.308300.69014Subbituminous/None CONV/PC/NONOX/DRY ESP- HS NONE NONE 0.00000 0.21429 0.78571Subbituminous/None CONV/PC/NONOX/DRY ESP- HS NONE NONE 0.00000 0.00000 1.00000Subbituminous/None CONV/PC/NONOX/DRY ESP- HS NONE NONE 0.00000 0.23404 0.76596Subbituminous/None CONV/PC/NOX/DRY ESP- HS COMP COAL NONE 0.00033 0.18931 0.81036Subbituminous/None CONV/PC/NOX/DRY ESP- HS COMP COAL NONE 0.00034 0.15419 0.84548Subbituminous/None CONV/PC/NOX/DRY ESP- HS COMP COAL NONE 0.00033 0.18109 0.81858Subbituminous/None CONV/PC/NOX/WET ESP- HS COMP COAL NONE 0.00256 0.14199 0.85545Subbituminous/None CONV/PC/NOX/WET ESP- HS COMP COAL NONE 0.00153 0.04396 0.95451Subbituminous/None CONV/PC/NOX/WET ESP- HS COMP COAL NONE 0.00138 0.09210 0.90652Subbituminous/None CONV/PC/NOX/WET ESP- HS COMP COAL NONE 0.00043 0.08318 0.91639Subbituminous/None CONV/PC/NOX/WET ESP- HS COMP COAL NONE 0.00035 0.09076 0.90889Subbituminous/None CONV/PC/NOX/WET ESP- HS COMP COAL NONE 0.00030 0.07797 0.92173Average speciated Hg fraction0.000630.125240.87413Subbituminous/None CONV/PC/NOX/DRY BAGHOUSE COMP COAL NONE 0.05004 0.85666 0.09330Subbituminous/None CONV/PC/NOX/DRY BAGHOUSE COMP COAL NONE 0.00662 0.59603 0.39735Subbituminous/None CONV/PC/NOX/DRY BAGHOUSE COMP COAL NONE 0.00917 0.82569 0.16514Subbituminous/None CONV/PC/NOX/DRY BAGHOUSE COMP COAL NONE 0.01398 0.91057 0.07545Subbituminous/None CONV/PC/NOX/DRY BAGHOUSE COMP COAL NONE 0.00318 0.86016 0.13666Subbituminous/None CONV/PC/NOX/DRY BAGHOUSE COMP COAL NONE 0.00648 0.92056 0.07296Average speciated Hg fraction0.014910.828280.15681Subbituminous/None CONV/PC/NOX/DRY PARTSCRUB COMP COALNONE 0.00041 0.00818 0.99141Subbituminous/None CONV/PC/NOX/DRY PARTSCRUB COMP COALNONE 0.00011 0.01131 0.98858Subbituminous/None CONV/PC/NOX/DRY PARTSCRUB COMP COALNONE 0.00045 0.01128 0.98827Subbituminous/None CONV/PC/NOX/DRY PARTSCRUB NONE NONE 0.00403 0.01815 0.97782Subbituminous/None CONV/PC/NOX/DRY PARTSCRUB NONE NONE 0.03041 0.06798 0.90161Subbituminous/None CONV/PC/NOX/DRY PARTSCRUB NONE NONE 0.04291 0.09142 0.86567Subbituminous/None CONV/PC/NONOX/DRY MECH/PARTSCRUB NONE NONE 0.00000 0.05114 0.9488612G H I J K L M NSpeciated Hg split instack (fraction)3Primary Fuel/ SecondaryFuel Boiler/furnace type1PM Control SO2 Control External NOXControl2Particle-bound Hg Oxidized Hg Elemental Hg194195196197198199200201202203204205206207208209210211212213214215216217218219220221222223224225226227228229230231232233234235236237238239240241Subbituminous/None CONV/PC/NONOX/DRY MECH/PARTSCRUB NONE NONE 0.00000 0.02970 0.97030Subbituminous/None CONV/PC/NONOX/DRY MECH/PARTSCRUB NONE NONE 0.00000 0.03117 0.96883Subbituminous/None CONV/PC/NOX/DRY PARTSCRUB NONE NONE 0.01431 0.04329 0.94240Subbituminous/None CONV/PC/NOX/DRY PARTSCRUB NONE NONE 0.01172 0.03924 0.94904Subbituminous/None CONV/PC/NOX/DRY PARTSCRUB NONE NONE 0.03451 0.14925 0.81623Subbituminous/None CONV/PC/NONOX/DRY PARTSCRUB NONE NONE 0.01684 0.07016 0.91300Subbituminous/None CONV/PC/NONOX/DRY PARTSCRUB NONE NONE 0.03105 0.07032 0.89863Subbituminous/None CONV/PC/NONOX/DRY PARTSCRUB NONE NONE 0.03125 0.07422 0.89453Average speciated Hg fraction0.014530.051120.93435Subbituminous/Bituminous CONV/PC/NOX/DRY ESP- CS SDA NONE 0.00095 0.12155 0.87750Subbituminous/Bituminous CONV/PC/NOX/DRY ESP- CS SDA NONE 0.00198 0.10317 0.89484Subbituminous/Bituminous CONV/PC/NOX/DRY ESP- CS SDA NONE 0.00110 0.03072 0.96818Subbituminous/None CONV/PC/NOX/DRY ESP- CS SDA NONE 0.00647 0.02423 0.96930Subbituminous/None CONV/PC/NOX/DRY ESP- CS SDA NONE 0.00618 0.00821 0.98561Subbituminous/None CONV/PC/NOX/DRY ESP- CS SDA NONE 0.00619 0.00722 0.98659Subbituminous/None CONV/PC/NOX/DRY ESP- CS SDA NONE 0.00176 0.00677 0.99147Subbituminous/None CONV/PC/NOX/DRY ESP- CS SDA NONE 0.00204 0.01687 0.98110Subbituminous/None CONV/PC/NOX/DRY ESP- CS SDA NONE 0.00196 0.02520 0.97284Average speciated Hg fraction0.003180.038210.95860Subbituminous/None CONV/PC/NOX/DRY BAGHOUSE SDA NONE 0.00344 0.03436 0.96220Subbituminous/None CONV/PC/NOX/DRY BAGHOUSE SDA NONE 0.00344 0.03436 0.96220Subbituminous/None CONV/PC/NOX/DRY BAGHOUSE SDA NONE 0.00364 0.03636 0.96000Subbituminous/None CONV/PC/NOX/DRY BAGHOUSE SDA NONE 0.02035 0.06409 0.91556Subbituminous/None CONV/PC/NOX/DRY BAGHOUSE SDA NONE 0.00055 0.06466 0.93479Subbituminous/None CONV/PC/NOX/DRY BAGHOUSE SDA NONE 0.00597 0.09797 0.89606Subbituminous/None CONV/PC/NOX/DRY BAGHOUSE SDA NONE 0.01401 0.02241 0.96359Subbituminous/None CONV/PC/NOX/DRY BAGHOUSE SDA NONE 0.01109 0.01411 0.97480Subbituminous/None CONV/PC/NOX/DRY BAGHOUSE SDA NONE 0.02638 0.02278 0.95084Average speciated Hg fraction0.009870.043460.94667Subbituminous/None CONV/PC/NOX/DRY ESP- CS WETSCRUB NONE 0.00904 0.03615 0.95482Subbituminous/None CONV/PC/NOX/DRY ESP- CS WETSCRUB NONE 0.00688 0.04376 0.94936Subbituminous/None CONV/PC/NOX/DRY ESP- CS WETSCRUB NONE 0.00553 0.03316 0.96131Subbituminous/None CONV/PC/NOX/DRY ESP- CS WETSCRUB NONE 0.00000 0.05689 0.94311Subbituminous/None CONV/PC/NOX/DRY ESP- CS WETSCRUB NONE 0.00000 0.02015 0.97985Subbituminous/None CONV/PC/NOX/DRY ESP- CS WETSCRUB NONE 0.00000 0.00635 0.99365Subbituminous/None CONV/PC/NONOX/DRY ESP- CS WETSCRUB NONE 0.00473 0.01893 0.97633Subbituminous/None CONV/PC/NONOX/DRY ESP- CS WETSCRUB NONE 0.00758 0.02165 0.97078Subbituminous/None CONV/PC/NONOX/DRY ESP- CS WETSCRUB NONE 0.00480 0.02758 0.9676312G H I J K L M NSpeciated Hg split instack (fraction)3Primary Fuel/ SecondaryFuel Boiler/furnace type1PM Control SO2 Control External NOXControl2Particle-bound Hg Oxidized Hg Elemental Hg242243244245246247248249250251252253254255256257258259260261262263264265266267268269270271272273274275276277278279280281282283284285286287288289Average speciated Hg fraction0.004280.029400.96631Subbituminous/None CONV/PC/NOX/WET ESP- HS WETSCRUB NONE 0.00423 0.01205 0.98371Subbituminous/None CONV/PC/NOX/WET ESP- HS WETSCRUB NONE 0.02567 0.01073 0.96360Subbituminous/None CONV/PC/NOX/WET ESP- HS WETSCRUB NONE 0.03366 0.03990 0.92644Subbituminous/None CONV/PC/NOX/DRY ESP- HS WETSCRUB NONE 0.00168 0.05419 0.94413Subbituminous/None CONV/PC/NOX/DRY ESP- HS WETSCRUB NONE 0.00147 0.04895 0.94957Subbituminous/None CONV/PC/NOX/DRY ESP- HS WETSCRUB NONE 0.00548 0.04388 0.95064Subbituminous/None CONV/PC/NONOX/DRY ESP- HS WETSCRUB NONE 0.00636 0.05891 0.93474Subbituminous/None CONV/PC/NONOX/DRY ESP- HS WETSCRUB NONE 0.01592 0.07173 0.91235Subbituminous/None CONV/PC/NONOX/DRY ESP- HS WETSCRUB NONE 0.01086 0.06111 0.92802Average speciated Hg fraction0.011700.044610.94369Lignite/None CONV/PC/NOX/DRY ESP- CS NONE NONE 0.00170 0.03663 0.96166Lignite/None CONV/PC/NOX/DRY ESP- CS NONE NONE 0.00094 0.03626 0.96280Lignite/None CONV/PC/NOX/DRY ESP- CS NONE NONE 0.00019 0.03571 0.96410Average speciated Hg fraction0.000940.036200.96286Subbituminous/None CYCLONE/NOX/WET PARTSCRUB NONE NONE 0.01840 0.04742 0.93418Subbituminous/None CYCLONE/NOX/WET PARTSCRUB NONE NONE 0.01637 0.05401 0.92962Subbituminous/None CYCLONE/NOX/WET PARTSCRUB NONE NONE 0.03556 0.07111 0.89333Average speciated Hg fraction0.023440.057510.91905Subbituminous/Pet Coke CYCLONE/NOX/WET ESP- HS COMP COAL NONE 0.01355 0.07067 0.91578Subbituminous/Pet Coke CYCLONE/NOX/WET ESP- HS COMP COAL NONE 0.00748 0.06229 0.93023Subbituminous/Pet Coke CYCLONE/NOX/WET ESP- HS COMP COAL NONE 0.00676 0.09275 0.90048Average speciated Hg fraction0.009260.075240.91550Lignite/None CYCLONE/NOX/WET ESP- CS NONE NONE 0.00049 0.16821 0.83130Lignite/None CYCLONE/NOX/WET ESP- CS NONE NONE 0.00037 0.17158 0.82805Average speciated Hg fraction0.000430.169890.82968Bituminous/Pet CokeFBC7BAGHOUSE NONE SNCR 0.43144 0.28094 0.2876312G H I J K L M NSpeciated Hg split instack (fraction)3Primary Fuel/ SecondaryFuel Boiler/furnace type1PM Control SO2 Control External NOXControl2Particle-bound Hg Oxidized Hg Elemental Hg290291292293294295296297298299300301302303304305306307308309310311312313314315316317318319320321322323324325326327328329330331332333334335Bituminous/Pet CokeFBC7BAGHOUSE NONE SNCR 0.42319 0.28116 0.29565Bituminous/Pet CokeFBC7BAGHOUSE NONE SNCR 0.41846 0.27385 0.30769Average speciated Hg fraction0.424360.278650.29699Waste Bituminous/NoneFBC7BAGHOUSE NONE NONE 0.01921 0.44236 0.53843Waste Bituminous/NoneFBC7BAGHOUSE NONE NONE 0.02166 0.37582 0.60252Waste Bituminous/NoneFBC7BAGHOUSE NONE NONE 0.02268 0.34624 0.63108Average speciated Hg fraction0.021180.388140.59068Lignite/NoneFBC7ESP- CS NONE NONE 0.01768 0.24082 0.74151Lignite/NoneFBC7ESP- CS NONE NONE 0.01221 0.07016 0.91762Lignite/NoneFBC7ESP- CS NONE NONE 0.01106 0.03814 0.95080Average speciated Hg fraction0.013650.116370.86998Lignite/NoneFBC7BAGHOUSE NONE NONE 0.00425 0.71601 0.27975Lignite/NoneFBC7BAGHOUSE NONE NONE 0.00590 0.69340 0.30071Lignite/NoneFBC7BAGHOUSE NONE NONE 0.00238 0.72603 0.27159Average speciated Hg fraction0.004180.711810.28401Waste Anthracite/NoneFBC7BAGHOUSE NONE NONE 0.03061 0.25510 0.71429Waste Anthracite/NoneFBC7BAGHOUSE NONE NONE 0.03061 0.25510 0.71429Waste Anthracite/NoneFBC7BAGHOUSE NONE NONE 0.02899 0.60870 0.36232Average speciated Hg fraction0.030070.372970.59696Bituminous/None STOKER/NOX/DRY BAGHOUSE SDA NONE 0.344830.13793 0.51724Bituminous/None STOKER/NOX/DRY BAGHOUSE SDA NONE 0.194030.18657 0.61940Bituminous/None STOKER/NOX/DRY BAGHOUSE SDA NONE 0.059830.21368 0.72650Average speciated Hg fraction0.199560.179390.62105Lignite/None CONV/PC/NONOX/DRY ESP- CS/BAGHOUSE COMP COAL NONE 0.00229 0.39599 0.6017212G H I J K L M NSpeciated Hg split instack (fraction)3Primary Fuel/ SecondaryFuel Boiler/furnace type1PM Control SO2 Control External NOXControl2Particle-bound Hg Oxidized Hg Elemental Hg336337338339340341342343344345346347348349350351352353354355356357358359360361362363364365366367368369370371372373374375376377378379380381382383Lignite/None CONV/PC/NONOX/DRY ESP- CS/BAGHOUSE COMP COAL NONE 0.00088 0.40910 0.59001Lignite/None CONV/PC/NONOX/DRY ESP- CS/BAGHOUSE COMP COAL NONE 0.00091 0.45496 0.54413Lignite/None CONV/PC/NONOX/DRY ESP- CS/BAGHOUSE COMP COAL NONE 0.00503 0.94819 0.04678Lignite/None CONV/PC/NONOX/DRY ESP- CS/BAGHOUSE COMP COAL NONE 0.00121 0.83816 0.16063Lignite/None CONV/PC/NONOX/DRY ESP- CS/BAGHOUSE COMP COAL NONE 0.00078 0.82310 0.17613Average speciated Hg fraction0.001850.644920.35323Lignite/None CONV/PC/NOX/DRY BAGHOUSE SDA NONE 0.01333 0.56000 0.42667Lignite/None CONV/PC/NOX/DRY BAGHOUSE SDA NONE 0.00267 0.08824 0.90909Lignite/None CONV/PC/NOX/DRY BAGHOUSE SDA NONE 0.00320 0.04320 0.95360Lignite/None CONV/PC/NOX/DRY BAGHOUSE SDA NONE 0.00073 0.03658 0.96269Lignite/None CONV/PC/NOX/DRY BAGHOUSE SDA NONE 0.00071 0.01555 0.98375Lignite/None CONV/PC/NOX/DRY BAGHOUSE SDA NONE 0.00069 0.01384 0.98547Average speciated Hg fraction0.003560.126230.87021Lignite/None CONV/PC/NOX/DRY PARTSCRUB NONE NONE 0.004160.03468 0.96115Lignite/None CONV/PC/NOX/DRY PARTSCRUB NONE NONE 0.000300.02429 0.97541Lignite/None CONV/PC/NOX/DRY PARTSCRUB NONE NONE 0.000270.03046 0.96927Average speciated Hg fraction0.001580.029810.96861Lignite/None CONV/PC/NONOX/DRY ESP- CS WETSCRUB NONE 0.00843 0.17939 0.81218Lignite/None CONV/PC/NONOX/DRY ESP- CS WETSCRUB NONE 0.00689 0.01695 0.97617Lignite/None CONV/PC/NONOX/DRY ESP- CS WETSCRUB NONE 0.00781 0.23713 0.75506Lignite/None CONV/PC/NOX/WET ESP- CS WETSCRUB NONE 0.00222 0.14370 0.85407Lignite/None CONV/PC/NOX/WET ESP- CS WETSCRUB NONE 0.01683 0.16129 0.82188Lignite/None CONV/PC/NOX/WET ESP- CS WETSCRUB NONE 0.00671 0.06855 0.92474Average speciated Hg fraction0.008150.134500.85735Bituminous/None CYCLONE/NONOX/WET MECH NONE NONE 0.321140.16260 0.51626Bituminous/None CYCLONE/NONOX/WET MECH NONE NONE 0.158330.50833 0.33333Bituminous/None CYCLONE/NONOX/WET MECH NONE NONE 0.082900.61140 0.30570Average speciated Hg fraction0.187460.427440.38510Bituminous/Pet Coke CYCLONE/NONOX/WET ESP- CS WETSCRUBNONE 0.00040 0.11196 0.8876512G H I J K L M NSpeciated Hg split instack (fraction)3Primary Fuel/ SecondaryFuel Boiler/furnace type1PM Control SO2 Control External NOXControl2Particle-bound Hg Oxidized Hg Elemental Hg384385386387388389390391392393394395396397398399400401402403404405406407408409410411412413414415416417418419420421422423424425426427428429430Bituminous/Pet Coke CYCLONE/NONOX/WET ESP- CS WETSCRUBNONE 0.00044 0.10522 0.89434Bituminous/Pet Coke CYCLONE/NONOX/WET ESP- CS WETSCRUBNONE 0.00122 0.12180 0.87698Average speciated Hg fraction0.000690.112990.88632Lignite/None CYCLONE/NONOX/WET BAGHOUSE SDA NONE 0.005940.00097 0.99309Lignite/None CYCLONE/NONOX/WET BAGHOUSE SDA NONE 0.288460.48718 0.22436Lignite/None CYCLONE/NONOX/WET BAGHOUSE SDA NONE 0.004200.02392 0.97188Average speciated Hg fraction0.099530.170690.72978Subbituminous/NoneFBC7BAGHOUSE NONE SNCR 0.00344 0.03436 0.96220Subbituminous/NoneFBC7BAGHOUSE NONE SNCR 0.00165 0.02475 0.97360Subbituminous/NoneFBC7BAGHOUSE NONE SNCR 0.00289 0.04335 0.95376Average speciated Hg fraction0.002660.034160.96318Subbituminous/Bituminous CONV/PC/NOX/DRY ESP- CS NONE NONE 0.00168 0.48658 0.51175Subbituminous/Bituminous CONV/PC/NOX/DRY ESP- CS NONE NONE 0.00234 0.65861 0.33905Subbituminous/Bituminous CONV/PC/NOX/DRY ESP- CS NONE NONE 0.00106 0.65539 0.34355Subbituminous/Bituminous CONV/PC/NONOX/DRY ESP- CS COMP COAL NONE 0.02691 0.30105 0.67204Subbituminous/Bituminous CONV/PC/NONOX/DRY ESP- CS COMP COAL NONE 0.00842 0.26792 0.72366Subbituminous/Bituminous CONV/PC/NONOX/DRY ESP- CS COMP COAL NONE 0.01254 0.19971 0.78775Average speciated Hg fraction0.008820.428210.56297Subbituminous/Bituminous CONV/PC/NOX/WET ESP- HS COMPCOAL NONE 0.07764 0.40161 0.52075Subbituminous/Bituminous CONV/PC/NOX/WET ESP- HS COMPCOAL NONE 0.00058 0.48527 0.51415Subbituminous/Bituminous CONV/PC/NOX/WET ESP- HS COMPCOAL NONE 0.00768 0.58643 0.40589Average speciated Hg fraction0.028630.491100.48026Bituminous/Pet Coke CONV/PC/NOX/DRY BAGHOUSE NONE NONE 0.04500 0.79500 0.16000Bituminous/Pet Coke CONV/PC/NOX/DRY BAGHOUSE NONE NONE 0.01887 0.77358 0.20755Bituminous/Pet Coke CONV/PC/NOX/DRY BAGHOUSE NONE NONE 0.00209 0.78370 0.21421Average speciated Hg fraction0.021990.784090.19392Bituminous/Subbituminous CONV/PC/NOX/DRY BAGHOUSE COMPCOAL NONE 0.04762 0.40952 0.5428612G H I J K L M NSpeciated Hg split instack (fraction)3Primary Fuel/ SecondaryFuel Boiler/furnace type1PM Control SO2 Control External NOXControl2Particle-bound Hg Oxidized Hg Elemental Hg431432433434435436437438439440441442443444Bituminous/Subbituminous CONV/PC/NOX/DRY BAGHOUSE COMPCOAL NONE 0.08081 0.40909 0.51010Bituminous/Subbituminous CONV/PC/NOX/DRY BAGHOUSE COMPCOAL NONE 0.05000 0.44444 0.50556Average speciated Hg fraction0.059480.421020.51950

# 15 

# ATTACHMENT 4

Hg_speciation_data_CAMR.xls

(Tab: 04_Hg_Speciation_Profiles)

# A LISTING OF TEST BINS WITH HG REMOVALS AND PERCENT SPECIATION

Bin Type Fuel, Boiler, Emission control device(s) Hg Removal PERCENT SPECIATION

Particulate Hg Oxidized Hg Elemental Hg

0 Bituminous Coal, Coal Gasification 0.26% 0.51% 8.47% 91.02%

1 Bituminous Coal, PC Boiler with ESP-CS 29.13% 6.11% 68.20% 25.70%

2 Bituminous Coal and Pet. Coke, PC Boiler with ESP- CS 60.36% 1.17% 46.56% 52.27%

3 Bituminous Coal, PC Boiler with SNCR and ESP-CS 89.88% 20.32% 27.12% 52.56%

4 Bituminous Coal, PC Boiler with ESP-HS 10.65% 4.90% 57.84% 37.26%

5 Bituminous Coal, PC Boiler with PM Scrubber 12.07% 1.80% 19.51% 78.69%

6 Bituminous Coal, PC Boiler with Dry Sorbent Inject ion and ESP-CS 44.89% 0.16% 67.10% 32.74%

7 Bituminous Coal, PC Boiler with FF Baghouse 89.37% 3.98% 62.58% 33.44%

8 Bituminous Coal, PC Boiler with SDA/FF Baghouse 98.17% 9.17% 28.86% 61.97%

9 Bituminous Coal, PC Boiler with SCR and SDA/FF Bag house 97.36% 5.06% 46.04% 48.90%

10 Bituminous Coal, PC Boiler with ESP-CS and Wet FG D 77.73% 0.22% 7.78% 92.00%

11 Bituminous Coal, PC Boiler with ESP-HS and Wet FG D 39.19% 0.63% 20.68% 78.70%

12 Bituminous Coal, PC Boiler with FF Baghouse and W et FGD 97.39% 6.48% 33.00% 60.52%

13 Subbituminous Coal, PC Boiler with ESP-CS 2.65% 0.16% 30.83% 69.01%

14 Subbituminous Coal, PC Boiler with ESP-HS 0.00% 0.06% 12.52% 87.41%

15 Subbituminous Coal, PC Boiler with FF Baghouse 72.58% 1.49% 82.83% 15.68%

16 Subbituminous Coal, PC Boiler with PM Scrubber 0.00% 1.45% 5.11% 93.44%

17 Subbituminous Coal, PC Boiler with SDA/ESP 0.00% 0.32% 3.82% 95.86%

18 Subbituminous Coal, PC Boiler with SDA/FF Baghous e 23.30% 0.99% 4.35% 94.67%

19 Subbituminous Coal, PC Boiler with ESP-CS and Wet FGD 15.93% 0.43% 2.94% 96.63%

20 Subbituminous Coal, PC Boiler with ESP-HS and Wet FGD 8.03% 1.17% 4.46% 94.37%

21 Lignite Coal, PC Boiler with ESP-CS 0.00% 0.09% 3.62% 96.29%

22 Subbituminous Coal, Cyclone Boiler with PM Scrubb er 22.15% 2.34% 5.75% 91.91%

23 Subbituminous Coal/Pet. Coke, Cyclone Boiler with ESP-HS 0.00% 0.93% 7.52% 91.55%

24 Lignite Coal Coal, Cyclone Boiler with ESP-CS 4.87% 0.04% 16.99% 82.97%

25 Bituminous Coal/Pet.Coke, Fludized Bed Combustor with SNCR and FF Baghouse 91.82% 42.44% 27.87% 29.70%

26 Not Used

27 Bituminous Waste, Fludized Bed Combustor with FF Baghouse 99.89% 2.12% 38.81% 59.07%

28 Lignite Coal, Fludized Bed Combustor with ESP-CS 40.36% 1.37% 11.64% 87.00%

29 Lignite Coal, Fludized Bed Combustor with FF Bagh ouse 56.98% 0.42% 71.18% 28.40%

30 Antracite Waste, Fludized Bed Combustor with FF B aghouse 99.75% 3.01% 37.30% 59.70%

31 Bituminous Coal, Stoker Boiler with SDA/FF Baghou se 93.66% 19.96% 17.94% 62.11%

32 Not Used

33 Lignite Coal, PC Boiler with ESP-CS and FF Baghou se 0.00% 0.19% 64.49% 35.32%

34 Lignite Coal, PC Boiler with SDA/FF Baghouse 17.40% 0.36% 12.62% 87.02%

35 Lignite Coal, PC Boiler with PM Scrubber 32.77% 0.16% 2.98% 96.86%

36 Lignite Coal, PC Boiler with ESP-CS and Wet FGD 41.78% 0.82% 13.45% 85.74%

37 Bituminous Coal, Cyclone Boiler with Mechanical C ollector 0.00% 18.75% 42.74% 38.51%

38 Bituminous Coal/Pet. Coke, Cyclone with ESP-CS an d Wet FGD 50.48% 0.07% 11.30% 88.63%

39 Lignite Coal, Cyclone Boiler with SDA/FF Baghouse 38.24% 9.95% 17.07% 72.98%

40 Subbituminous Coal, Fludized Bed Combustor with S NCR and FF Baghouse 52.52% 0.27% 3.42% 96.32%

41 Subbituminous Coal/Bituminous Coal, PC Boiler wit h ESP-CS 47.31% 0.88% 42.82% 56.30%

42 Subbituminous Coal/Bituminous Coal, PC Boiler wit h ESP-HS 34.03% 2.86% 49.11% 48.03%

43 Bituminous Coal/Pet. Coke, PC Boiler with FF Bagh ouse 0.00% 2.20% 78.41% 19.39%

44 Bituminous Coal/Subbituminous Coal, PC Boiler wit h FF Baghouse 68.22% 5.95% 42.10% 51.95%Publication No. EPA-454/R-11-010November, 2011Office of Air Quality Planning and StandardsAir Quality Assessment DivisionResearch Triangle Park, NCUnited StatesEnvironmental ProtectionAgency