Electric Generating Utility Mercury Speciation 

Profiles for the Clean Air Mercury Rule 
 
EPA-454/R-11-010 

November 2011 

Electric Generating Utility Mercury Speciation Profiles 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 Mercury 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 preparing for finalizing the National 

Emission Standards for Hazardous Air Pollutants from 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 Standards [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 were developed from the 1999 information 

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

(CAMR). 

This memorandum describes the general process followed 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 during 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 measurements (μg/dscm) for particle-bound 
2 

(Hgp), oxidized (Hg2+), and elemental (Hg0) mercury. All emissions tests were conducted 

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

(measurements after the last control device) were used 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), moisture content (%), and oxygen content (%) 

were reported. 

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

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

percent sulfur (%), percent moisture (%), percent ash (%), chlorine content (ppm), and 

mercury content (ppm). 

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

one-half of the MDL was substituted. These 1⁄2-MDL values 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 blank caused the emissions sampling data to 

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

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

suspect or missing values (i.e., zero is used as the 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 for 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 (including 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 mercury emissions data collection effort was 

geared toward characterizing the mercury emission reduction potentials of existing EGU 

emission control schemes and developing mercury “emission 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 nationwide mercury emissions from coal-fired 

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

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

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

emission reduction bins. 

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

control scenarios with differing mercury emission reduction potentials. These same bins 

were used to create average mercury speciation profiles. 

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 “conventional pulverized coal, turbo-fired.” 

This boiler was included with conventional pulverized 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 includes a cross-section of particulate matter 

(PM), sulfur dioxide (SO2), and nitrogen oxides (NOx) emission control technologies. At the 

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

emission control technology designed specifically for 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) 

SO2 control technologies represented in the data set include: 

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 SO2 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 set include: 

Selective non-catalytic reduction (SNCR) 

Selective catalytic reduction (SCR) 

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

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

mercury emission reduction bins. 

Data Grouping

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

secondary fuel type, boiler type, PM control, SO2 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 were developed for only 43 bins. 
5 

Attachment 3 provides a summary of the individual runs 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: 

Hgp fraction = Hgp conc / (Hgp conc + Hg2+ conc + Hg0 conc) 

where: Hgp fraction = unitless fraction of mercury in the particle-bound form 

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

 Hg2+ conc = oxidized mercury concentration (μg/dscm) 

 Hg0 conc = elemental mercury concentration (μg/dscm)

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

each speciation fraction (Hgp, Hg2+, and Hg0) 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 were developed from the eighty mercury 

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

Of the 43 bins for which EMFs and mercury speciation 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. Only 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 and the final mercury speciation profiles 

is provided as Attachment 4. 

III. Conclusion 

Forty-three mercury emission reduction bins and their associated mercury speciation profiles 

were developed from the eighty mercury emissions tests collected to support the 

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

total mercury emissions from electric utility boilers (taking into account boiler type, fuel 
6 

type, and emission control schemes) to estimate the speciation of mercury (Hgp, Hg2+, and 

Hg0

) where no speciated mercury sampling data are available. 

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

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

collecting additional data to develop mercury speciation profiles for units equipped with 

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

might be conducted specifically with the goal of developing 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 fraction obtained from the 

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

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

fraction. For example, a total EMF of 0.68 is equal 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 Information 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 originally 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 identification 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 decay and mineral deposition. The properties 

of coal vary depending on the type of vegetative matter 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 decay and mineral deposition. The properties 

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

ASTM D 388-82). Bituminous coal has a higher heating 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 vegetative decay and mineral deposition. The 

properties of coal vary depending on the type of vegetative 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 composed of organic and mineral materials that 

has formed over time by vegetative decay and mineral 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 heating content (Btu/lb) of the four major coal 

rankings. 

PET COKE = Petroleum coke is a by-product of the petroleum 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 furnace. In pulverized-coal-fired boiler 

systems, coal is pulverized in a mill to the consistency 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, combustion 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 distributed below the combustor floor. "Fluidized" 

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

through the bed. 

COAL GAS = Integrated Coal Gasification Combined Cycle 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 combustible 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 pattern. The burner design and placement cause 

the ash to become a molten slag that is collected below 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 (slag 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 NOX controls. A variety of combustion control practices can be used 

including low NOx burners, overfire air, off-stoichiometric firing, selective or biased burner 

firing, reburning, and burners-out-of-service. Control of NOX can also be achieved through 

staged combustion (also called air staging). 

NONOX = No combustion NOX controls on furnace. 

SCR = Selective Catalytic Reduction (a post combustion, add-on, NOX control device). The 

selective catalytic reduction (SCR) process uses a catalyst with ammonia gas (NH3) to reduce the 

NO and NO2 in the flue gas to molecular nitrogen and water. 

SNCR = Selective Noncatalytic Reduction (a post combustion, add-on, NOX control device). 

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

reducing the NO and NO2 in the flue gas to molecular nitrogen and water as the SCR but does 

not require the use of a catalyst to prompt these reactions. 

Sulfur Dioxide control technology

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

flue gas containing SO2 is brought into contact with a limestone-water slurry. The SO2 is 

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

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

emissions into compliance with SO2 regulations. Compliance coal may be obtained through the 

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

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

with fine spray droplets of hydrated lime slurry in a spray dryer vessel. The SO2 is absorbed in 

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

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

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

FBC = In an SO2 control context, FBC refers to the use of a sorbent such as limestone in the 

furnace’s fluidized bed for SO2 control. 

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

directly injected into the ductwork upstream of a PM control device. 
12 

Particulate matter control technology

ESP- CS = Electrostatic precipitator, cold-side (meaning 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 oppositely charged plates for collection. The collected 

particles are periodically dislodged in sheets or agglomerates by rapping or otherwise vibrating 

the plates. 

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

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

removal. 

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

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

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

particles are periodically dislodged in sheets or agglomerates by rapping or otherwise vibrating 

the plates. 

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

MECH = Mechanical collector (assumed to be a cyclone 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 forced toward the wall by centrifugal force, then 

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

PARTSCRUB = Particulate scrubber. Particulate scrubbers operate by shattering streams of 

water into small droplets that collide with and trap 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 bottom 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) 
1

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101112131415161718192021222324252627282930313233343536373839404142434445464748495051525354555657585960

A B C D E F G 

Plant Name EIA Plant Code Unit No. RunNumber CoalFlowRate HHV pctSulphur 

& ORIS Code (kg/hr), dry Btu/lb % 

AES Cayuga (NY) (formerly NYSEG Milliken) 0135110000-02535 2 1 50040.96 13731 2.51 AES Cayuga (NY) (formerly NYSEG Milliken) 0135110000-02535 2 2 51915.19 13791 2.55 AES Cayuga (NY) (formerly NYSEG Milliken) 0135110000-02535 2 3 52215.01 13661 2.33 AES Hawaii, Inc. 10673 AB 1 32884 12742 0.67 AES Hawaii, Inc. 10673 AB 2 33360 12743 0.65 AES Hawaii, Inc. 10673 AB 3 33485 12625 0.66 Antelope Valley Station 0013070000-06469 B1 1 433349 10180 1.09 Antelope Valley Station 0013070000-06469 B1 2 419526 10280 1.24 Antelope Valley Station 0013070000-06469 B1 3 413661 10400 1.05 Bailly 0137560000-00995 7 and 8 1 177627 12725 3.16 Bailly 0137560000-00995 7 and 8 2 179853 12735 3.12 Bailly 0137560000-00995 7 and 8 3 175369 12813 2.5 Bay Front Plant Generating 0137810000-03982 5 1 3911 12790 0.65 Bay Front Plant Generating 0137810000-03982 5 2 3913 12635 0.65 Bay Front Plant Generating 0137810000-03982 5 3 3934 12597 0.66 Big Bend 0184540000-00645 BB03 1 133914 12730 3.15 Big Bend 0184540000-00645 BB03 2 132229 12790 3.22 Big Bend 0184540000-00645 BB03 3 132805 12980 3.08 Big Brown 0443720000-03497 1 1 310664 8690 1.01 Big Brown 0443720000-03497 1 2 312513 8720 1.03 Big Brown 0443720000-03497 1 3 298538 9050 1 Brayton Point 0134330000-01619 1 1 76292 13684 0.83 Brayton Point 0134330000-01619 1 2 75446 13756 0.73 Brayton Point 0134330000-01619 1 3 76493 13754 0.76 Brayton Point 0134330000-01619 3 1 163357 13521 0.82 Brayton Point 0134330000-01619 3 2 157296 13583 0.76 Brayton Point 0134330000-01619 3 3 178153 13875 0.77 Bruce Mansfield 0147160000-06094 1 1 277790 13163 4.29 Bruce Mansfield 0147160000-06094 1 2 279761 13678 4.54 Bruce Mansfield 0147160000-06094 1 3 270273 13237 4.6 Charles R. Lowman 0001890000-00056 2 1 77844 13352 0.53 Charles R. Lowman 0001890000-00056 2 2 76370 13356 0.52 Charles R. Lowman 0001890000-00056 2 3 77844 13352 0.53 Cholla 0008030000-00113 2 1 125445.6 11222 0.495 Cholla 0008030000-00113 2 2 123908.4 10955 0.51 Cholla 0008030000-00113 2 3 127224 11134 0.525 Cholla 0008030000-00113 3 1 116562.6 11863 0.43 Cholla 0008030000-00113 3 2 120860.6 12172 0.42 Cholla 0008030000-00113 3 3 121240.5 12135 0.42 Clay Boswell 0126470000-01893 2 1 21481 12158 0.62 Clay Boswell 0126470000-01893 2 2 21590 12087 0.62 Clay Boswell 0126470000-01893 2 3 21620 12100 0.68 Clay Boswell 0126470000-01893 3 1 125453 12072 0.61 Clay Boswell 0126470000-01893 3 2 119812 12052 0.75 Clay Boswell 0126470000-01893 3 3 120910 11972 0.68 Clay Boswell 0126470000-01893 4 1 195911 12075 0.54 Clay Boswell 0126470000-01893 4 2 197038 12197 0.57 Clay Boswell 0126470000-01893 4 3 200509 11888 0.6 Cliffside 0054160000-02721 1 1 15852 13803 0.85 Cliffside 0054160000-02721 1 2 15818 13181 0.77 Cliffside 0054160000-02721 1 3 15838 13804 0.85 Clifty Creek 0092690000-00983 6 1 71060 12494 0.86 Clifty Creek 0092690000-00983 6 2 69626 12578 0.86 Clifty Creek 0092690000-00983 6 3 74180 12632 0.99 Clover Power Station 0198760000-07213 2 1 143480 13089.39 NA Clover Power Station 0198760000-07213 2 2 143553 13605.30 NA Clover Power Station 0198760000-07213 2 3 142146 13568.31 NA Colstrip 0128250000-06076 3 1 370938 10779 0.72 
1

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A B C D E F G 

Plant Name EIA Plant Code Unit No. RunNumber CoalFlowRate HHV pctSulphur 

& ORIS Code (kg/hr), dry Btu/lb % 

616263646566676869707172737475767778798081828384858687888990919293949596979899

100101102103104105106107108109110111112113114115116117118

Colstrip 0128250000-06076 3 2 373615 10568 0.74 Colstrip 0128250000-06076 3 3 366517 10688 0.76 Columbia 0208560000-08023 1 1 205968 12261 0.43 Columbia 0208560000-08023 1 2 210060 12120 0.43 Columbia 0208560000-08023 1 3 208610 12182 0.42 Comanche 0154660000-00470 2 1 133163 11891.63 0.43 Comanche 0154660000-00470 2 2 130385 11891.63 0.43 Comanche 0154660000-00470 2 3 135158 11891.63 0.43 Coronado 0615720000-06177 U1B 1 159600 11187 0.53 Coronado 0615720000-06177 U1B 2 158800 11439 0.49 

Coronado 0615720000-06177 U1B 3 162900 11262 0.51 Coyote 0128190000-08222 1 1 180563 11080 1.33 Coyote 0128190000-08222 1 2 184283 106.73 2.07 Coyote 0128190000-08222 1 3 179437 10904 1.76 Craig 0301510000-06021 C1 1 155754 12322 0.52 Craig 0301510000-06021 C1 2 159979 12447 0.52 Craig 0301510000-06021 C1 3 155324 12451 0.58 Craig 0301510000-06021 C3 1 157201 12549 0.47 Craig 0301510000-06021 C3 2 156035 12624 0.44 Craig 0301510000-06021 C3 3 153356 12562 0.49 Dunkirk 0135730000-02554 2 1 32714 13907 2.31 Dunkirk 0135730000-02554 2 2 32650 14022 2.23 Dunkirk 0135730000-02554 2 3 31910 13819 2.25 Dwayne Collier Battle Cogeneration Facility 10384 2B 1 12432 13820 0.73 Dwayne Collier Battle Cogeneration Facility 10384 2B 2 12391 13900 0.76 Dwayne Collier Battle Cogeneration Facility 10384 2B 3 11888 13930 0.77 Gaston 0001950000-00026 1 1 82264 13560 0.8 Gaston 0001950000-00026 1 2 78015 13300 1.03 Gaston 0001950000-00026 1 3 72147 13640 0.83 George Neal south 0123410000-07343 4 1 312422 12003 0.42 George Neal south 0123410000-07343 4 2 305364 12014 0.44 George Neal south 0123410000-07343 4 3 312314 11901 0.44 Gibson Generating Station (10/99 testing) 0154700000-06113 3 1 209510 12530 1.71 Gibson Generating Station (10/99 testing) 0154700000-06113 3 2 216693 12570 1.74 Gibson Generating Station (10/99 testing) 0154700000-06113 3 3 215173 12570 1.71 Gibson Generating Station (03/00 testing) 0154700000-06113 3 1 248127 11640 1.45 Gibson Generating Station (03/00 testing) 0154700000-06113 3 2 240702 11630 1.45 Gibson Generating Station (03/00 testing) 0154700000-06113 3 3 230739 11550 1.57 GRDA 0074900000-00165 2 1 192022 12091 0.71 GRDA 0074900000-00165 2 2 184341 12186 0.73 GRDA 0074900000-00165 2 3 211706 12096 0.88 Intermountain 0112080000-06481 2SGA 1 281058 12986 0.68 Intermountain 0112080000-06481 2SGA 2 279461 13022 0.67 Intermountain 0112080000-06481 2SGA 3 284219 12949 0.63 Jack Watson 0126860000-02049 4 1 80122 13080 1.02 Jack Watson 0126860000-02049 4 2 80893 13080 1.06 Jack Watson 0126860000-02049 4 3 81111 13070 1.03 Jim Bridger 0143540000-08066 BW 74 1 NA 11821 0.71 Jim Bridger 0143540000-08066 BW 74 2 NA 11963 0.64 Jim Bridger 0143540000-08066 BW 74 3 NA 11973 0.69 Kline Township Cogen Facility 50039 GEN1 1 165225.69 5110 0.43 Kline Township Cogen Facility 50039 GEN1 2 171535.06 5050 0.44 Kline Township Cogen Facility 50039 GEN1 3 176051.86 4930 0.38 La Cygne 0100000000-01241 1 1 290481 11800 1.22 La Cygne 0100000000-01241 1 2 277548 11740 1.31 La Cygne 0100000000-01241 1 3 284632 11800 1.2 Laramie River Station 0013070000-06204 1 1 207045 11860 0.52 Laramie River Station 0013070000-06204 1 2 197203 11940 0.52 
1

2

A B C D E F G 

Plant Name EIA Plant Code Unit No. RunNumber CoalFlowRate HHV pctSulphur 

& ORIS Code (kg/hr), dry Btu/lb % 

119120121122123124125126127128129130131132133134135136137138139140141142143144145146147148149150151152153154155156157158159160161162163164165166167168169170171172173174175176

Laramie River Station 0013070000-06204 1 3 195728 11890 0.54 Laramie River Station 0013070000-06204 3 1 208000 11820 0.49 Laramie River Station 0013070000-06204 3 2 213000 11990 0.49 Laramie River Station 0013070000-06204 3 3 210000 12070 0.47 Lawrence 0002250000-01250 4 1 36186 12280 0.58 Lawrence 0002250000-01250 4 2 38541 12260 0.45 Lawrence 0002250000-01250 4 3 38095 12340 0.44 Leland Olds Station 0013070000-02817 2 1 229813 10500 0.8 Leland Olds Station 0013070000-02817 2 2 187931 10700 1.07 Leland Olds Station 0013070000-02817 2 3 315756 10890 0.91 Lewis & Clark 0128190000-06089 B1 1 28727 10427 0.89 Lewis & Clark 0128190000-06089 B1 2 27281 10435 0.7 Lewis & Clark 0128190000-06089 B1 3 25593 10391 0.87 Limestone 0089010000-00298 LIM1 1 332740.50 10422 1.37 Limestone 0089010000-00298 LIM1 2 336256.88 10700 1.52 Limestone 0089010000-00298 LIM1 3 344827.24 10574 1.54 Logan Generating Plant 10043 Gen 1 1 75400 13758 1.13 Logan Generating Plant 10043 Gen 1 2 75526 13767 1.08 Logan Generating Plant 10043 Gen 1 3 75351 13757 1.08 Mecklenburg Cogeneration Facility 52007 GEN 1 1 25138 14042 1.25 Mecklenburg Cogeneration Facility 52007 GEN 1 2 26151 13877 1.55 Mecklenburg Cogeneration Facility 52007 GEN 1 3 25488 13867 1.38 Meramec 0194360000-02104 4 1 126826 13254 0.89 Meramec 0194360000-02104 4 2 112566 13499 1.29 Meramec 0194360000-02104 4 3 105878 13415 1.27 Monticello 0443720000-06147 1 1 314734 8220 0.58 Monticello 0443720000-06147 1 2 319432 8340 0.64 Monticello 0443720000-06147 1 3 315757 7740 1.55 Monticello 0443720000-06147 3 1 430100 8680 0.66 Monticello 0443720000-06147 3 2 447000 8250 0.57 Monticello 0443720000-06147 3 3 434600 8740 0.63 Montrose 0100000000-02080 1 1 69976 10440 0.2 Montrose 0100000000-02080 1 2 70645 10300 0.2 Montrose 0100000000-02080 1 3 68841 10500 0.21 Navajo 0165720000-04941 3 1 277000 12771 0.53 Navajo 0165720000-04941 3 2 277300 12700 0.57 Navajo 0165720000-04941 3 3 278500 12850 0.56 Nelson Dewey 0208560000-04054 1 1 39446 13006 1.48 Nelson Dewey 0208560000-04054 1 2 37930 13052 1.37 Nelson Dewey 0208560000-04054 1 3 37886 12984 1.35 Newton 0032530000-06017 2 1 206681 11025 0.44 Newton 0032530000-06017 2 2 204152.16 11105 0.4 Newton 0032530000-06017 2 3 202528.83 11019 0.38 Northern States Power - Sherburne County Generating Plant 0137810000-06090 #3 1 331255 11770 0.81 

Northern States Power - Sherburne County Generating Plant 0137810000-06090 #3 2 336080 11670 0.68 Northern States Power - Sherburne County Generating Plant 0137810000-06090 #3 3 341562 11541 0.78 

Platte 0406060000-00059 1 1 35418 12230 0.45 Platte 0406060000-00059 1 2 37782 12211 0.43 Platte 0406060000-00059 1 3 33011 12284 0.42 Polk Power 0184540000-07242 1 1 91456 11965 3.11 Polk Power 0184540000-07242 1 2 88709 12934 3.12 Polk Power 0184540000-07242 1 3 71375 12958 3.36 Port Washington 0208470000-04040 4 1 29740 14025 1.49 Port Washington 0208470000-04040 4 2 30173 13947 1.55 Port Washington 0208470000-04040 4 3 29648 13982 1.5 Presque Isle 0208470000-01769 5 1 31232 12771.62 1.01 Presque Isle 0208470000-01769 5 2 30874 12798.90 1.02 Presque Isle 0208470000-01769 5 3 31922 12765.62 1.04 
1

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A B C D E F G 

Plant Name EIA Plant Code Unit No. RunNumber CoalFlowRate HHV pctSulphur 

& ORIS Code (kg/hr), dry Btu/lb % 

177178179180181182183184185186187188189190191192193194195196197198199200201202203204205206207208209210211212213214215216217218219220221222223224225226227228229230231232233234

Presque Isle 0208470000-01769 6 1 36121 12765.62 0.41 Presque Isle 0208470000-01769 6 2 36399 12026.46 0.42 Presque Isle 0208470000-01769 6 3 36525 12066.71 0.42 Presque Isle 0208470000-01769 9 1 27400 12051.83 1.02 Presque Isle 0208470000-01769 9 2 27636 12694.30 1.04 Presque Isle 0208470000-01769 9 3 27550 12772.39 1.04 R. D. Morrow Sr. Generating plant 0175680000-06061 2 1 71013 13145 1.11 R. D. Morrow Sr. Generating plant 0175680000-06061 2 2 73853 12982 1.11 R. D. Morrow Sr. Generating plant 0175680000-06061 2 3 68743 12876 1.05 R.M. Heskett Station 0128190000-02790 B2 1 36399 10828 1.63 R.M. Heskett Station 0128190000-02790 B2 2 35751 10887 1.14 R.M. Heskett Station 0128190000-02790 B2 3 36658 10666 1.19 Rawhide 0151430000-06761 101 1 111122 11867 0.31 Rawhide 0151430000-06761 101 2 103104 12003 0.3 Rawhide 0151430000-06761 101 3 105518 11932 0.3 Salem Harbor 0134330000-01626 3 1 49538 13889 0.7 Salem Harbor 0134330000-01626 3 2 48150 13850 0.69 Salem Harbor 0134330000-01626 3 3 48689 13707 0.74 Sam Seymour 0112690000-06179 3 1 136862 11773.31 0.54 Sam Seymour 0112690000-06179 3 2 136755 11897.54 0.47 Sam Seymour 0112690000-06179 3 3 138096 11964.54 0.47 San Juan 0154730000-02451 2 1 157925 9976 0.67 San Juan 0154730000-02451 2 2 142879 10946 0.73 San Juan 0154730000-02451 2 3 148399 10354 0.82 Scrubgrass Generating Company L. P. 50974 GEN1 1 59438 8509 1.49 Scrubgrass Generating Company L. P. 50974 GEN1 2 59438 8520 1.52 Scrubgrass Generating Company L. P. 50974 GEN1 3 61826 7996 1.4 SEI - Birchwood Power Facility 54304 1 1 76807 12650 0.77 SEI - Birchwood Power Facility 54304 1 2 75641 12570 0.79 SEI - Birchwood Power Facility 54304 1 3 76065 12440 0.83 Shawnee Fossil Plant 0186420000-01379 3 1 46649 12882 0.48 Shawnee Fossil Plant 0186420000-01379 3 2 48001 12714 0.5 Shawnee Fossil Plant 0186420000-01379 3 3 47095 12777 0.49 St Clair Power Plant 0051090000-01743 4 1 65723 12430 0.94 St Clair Power Plant 0051090000-01743 4 2 65129 12670 0.96 St Clair Power Plant 0051090000-01743 4 3 64469 12580 0.96 Stanton Station 0195140000-02824 1 1 91172 10674 1.21 Stanton Station 0195140000-02824 1 2 91172 10749 1.68 Stanton Station 0195140000-02824 1 3 91625 10703 1.01 Stanton Station 0195140000-02824 10 1 22582 10621 1.33 Stanton Station 0195140000-02824 10 2 22877 10448 1.26 Stanton Station 0195140000-02824 10 3 22762 10529 1.31 Stockton Cogen Company 10640 GEN1 1 17000 12334 0.64 Stockton Cogen Company 10640 GEN1 2 13746 12935 0.59 Stockton Cogen Company 10640 GEN1 3 14990 12254 0.56 TNP-One 0400510000-07030 U2 1 75449 9520 1.27 TNP-One 0400510000-07030 U2 2 72195 9810 1.26 TNP-One 0400510000-07030 U2 3 78013 9000 1.43 Valley 0208470000-04042 2 1 27746 13318 0.85 Valley 0208470000-04042 2 2 27687 13269 0.85 Valley 0208470000-04042 2 3 27022 13456 0.92 Valmont 0154660000-00477 5 1 59355 12299 0.29 Valmont 0154660000-00477 5 2 58814 12243 0.3 Valmont 0154660000-00477 5 3 55471 11607 0.49 W. H. Sammis 0139980000-02866 1 1 50494 12202 0.91 W. H. Sammis 0139980000-02866 1 2 48308 13594 1.51 W. H. Sammis 0139980000-02866 1 3 48049 13531 1.43 Wabash River Generating Station 0154700000-01010 1 + 1A 1 90663 12350 2.72 
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A B C D E F G 

Plant Name EIA Plant Code Unit No. RunNumber CoalFlowRate HHV pctSulphur 

& ORIS Code (kg/hr), dry Btu/lb % 

235236237238239240241242243244245246247248

Wabash River Generating Station 0154700000-01010 1 + 1A 2 89629 12530 2.75 Wabash River Generating Station 0154700000-01010 1 + 1A 3 89493 12540 2.89 Widows Creek Fossil Plant 0186420000-00050 6 1 41312 12633 0.59 Widows Creek Fossil Plant 0186420000-00050 6 2 41520 12744 0.51 Widows Creek Fossil Plant 0186420000-00050 6 3 40552 12769 0.53 Wyodak 0143540000-06101 BW 91 1 145472 11550 0.87 

Wyodak 0143540000-06101 BW 91 2 145265 11677 0.84 Wyodak 0143540000-06101 BW 91 3 147351 11640 0.81 XB = Excessive reagent blank caused the data to be unreliableNA = Data was not included in reportLS = Test sample was broken, damaged, or lost during testing or in transport
1

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101112131415161718192021222324252627282930313233343536373839404142434445464748495051525354555657585960

A

Plant 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 StationColstrip

K L M N 

Hg CoalAnalysisMethod FuelType Inlet Flo

mg/kg or ppm dscm

0.11 EPA 7471 Bituminous 50.11 EPA 7471 Bituminous 50.10 EPA 7471 Bituminous 50.03 D3684-94 - FICVAA Subbituminous 0.03 D3684-94 - FICVAA Subbituminous 0.02 D3684-94 - FICVAA Subbituminous 0.06 EPA 7471 Lignite 

0.071 EPA 7471 Lignite 0.055 EPA 7471 Lignite 

0.07 ASTM 3684 Bituminous/Petroleum Coke 0.08 ASTM 3684 Bituminous/Petroleum Coke 0.06 ASTM 3684 Bituminous/Petroleum Coke 0.06 ASTM 3684 Bituminous 0.06 ASTM 3684 Bituminous 0.06 ASTM 3684 Bituminous 

0.177 EPA 7471 Bituminous 0.113 EPA 7471 Bituminous 0.125 EPA 7471 Bituminous 0.287 ASTM 6414 Lignite 

0.29 ASTM 6414 Lignite 

0.287 ASTM 6414 Lignite 

0.08 ASTM 3684 Bituminous 0.05 ASTM 3684 Bituminous 0.06 ASTM 3684 Bituminous 

0.1 ASTM 3684 Bituminous 

0.07 ASTM 3684 Bituminous 0.07 ASTM 3684 Bituminous 

0.096 ASTM 6414 Bituminous 0.079 ASTM 6414 Bituminous 0.103 ASTM 6414 Bituminous 0.084 ASTM 6414 Bituminous 0.077 ASTM 6414 Bituminous 

0.08 ASTM 6414 Bituminous 

0.045 EPA 7471 Subbituminous 

0.04 EPA 7471 Subbituminous 

0.035 EPA 7471 Subbituminous 

0.04 ASTM 3684 Subbituminous 0.04 ASTM 3684 Subbituminous 0.03 ASTM 3684 Subbituminous 

0.078 ASTM 6414 Subbituminous 0.043 ASTM 6414 Subbituminous 0.049 ASTM 6414 Subbituminous 0.054 ASTM 6414 Subbituminous 0.072 ASTM 6414 Subbituminous 0.063 ASTM 6414 Subbituminous 0.065 ASTM 6414 Subbituminous 0.063 ASTM 6414 Subbituminous 

0.07 ASTM 6414 Subbituminous 0.07 ASTM 3684 Bituminous 0.05 ASTM 3684 Bituminous 0.06 ASTM 3684 Bituminous 0.08 ASTM 3684 Subbituminous/Bituminous 0.08 ASTM 3684 Subbituminous/Bituminous 0.08 ASTM 3684 Subbituminous/Bituminous 0.12 EPA 7471 Bituminous 0.17 EPA 7471 Bituminous 0.20 EPA 7471 Bituminous 

0.063 ASTM 6414 Subbituminous 
1

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A

Plant Name

616263646566676869707172737475767778798081828384858687888990919293949596979899

100101102103104105106107108109110111112113114115116117118

ColstripColstripColumbiaColumbiaColumbiaComancheComancheComancheCoronadoCoronadoCoronadoCoyoteCoyoteCoyoteCraigCraigCraigCraigCraigCraigDunkirkDunkirkDunkirkDwayne 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 Cygne La Cygne La Cygne Laramie River StationLaramie River Station

K L M N 

Hg CoalAnalysisMethod FuelType Inlet Flo

mg/kg or ppm dscm

0.066 ASTM 6414 Subbituminous 0.067 ASTM 6414 Subbituminous 

0.1 ASTM 3684 Subbituminous 0.1 ASTM 3684 Subbituminous 0.1 ASTM 3684 Subbituminous 

0.09 EPA 1631 Subbituminous 0.10 EPA 1631 Subbituminous 0.09 EPA 1631 Subbituminous 

0.035 EPA 7371/1631 Subbituminous 0.039 EPA 7371/1631 Subbituminous 0.031 EPA 7371/1631 Subbituminous 0.088 EPA 3050/7471 Lignite 

0.15 EPA 3050/7471 Lignite 

0.094 EPA 3050/7471 Lignite 0.022 EPA 1631/7371 Subbituminous 0.025 EPA 1631/7371 Subbituminous 0.021 EPA 1631/7371 Subbituminous 0.011 EPA 1631/7371 Subbituminous 

0.01 EPA 1631/7371 Subbituminous 

0.009 EPA 1631/7371 Subbituminous 

0.13 ASTM 3684 Bituminous 0.13 ASTM 3684 Bituminous 0.13 ASTM 3684 Bituminous 

ND(0.06) EPA 7471 Bituminous ND(0.06) EPA 7471 Bituminous ND(0.06) EPA 7471 Bituminous 

0.054 EPA 7471 Bituminous 0.067 EPA 7471 Bituminous 0.057 EPA 7471 Bituminous 

0.09 ASTM 3684 Subbituminous 0.08 ASTM 3684 Subbituminous 

0.1 ASTM 3684 Subbituminous 

0.134 ASTM 6414 Bituminous 0.142 ASTM 6414 Bituminous 0.141 ASTM 6414 Bituminous 0.117 ASTM 6414 Bituminous 0.115 ASTM 6414 Bituminous 0.123 ASTM 6414 Bituminous 

0.1 ASTM 3684 Subbituminous/Bituminous 0.1 ASTM 3684 Subbituminous/Bituminous 0.1 ASTM 3684 Subbituminous/Bituminous 

0.02 ASTM 3684 Bituminous 0.02 ASTM 3684 Bituminous 0.03 ASTM 3684 Bituminous 0.05 EPA 7471 Bituminous 

0.052 EPA 7471 Bituminous 0.059 EPA 7471 Bituminous 

0.08 Other Subbituminous 0.08 Other Subbituminous 0.06 Other Subbituminous 

0.3 EPA 7471 Waste Anthracite 0.4 EPA 7471 Waste Anthracite 0.3 EPA 7471 Waste Anthracite 

0.11 ASTM 6414 Subbituminous NA 

0.102 ASTM 6414 Subbituminous NA 0.098 ASTM 6414 Subbituminous NA 0.103 EPA 3051/3052/7471 Subbituminous 0.111 EPA 3051/3052/7471 Subbituminous 
1

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Plant Name

119120121122123124125126127128129130131132133134135136137138139140141142143144145146147148149150151152153154155156157158159160161162163164165166167168169170171172173174175176

Laramie 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 Generating PlantNorthern States Power - Sherburne County Generating PlantNorthern States Power - Sherburne County Generating PlantPlattePlattePlattePolk PowerPolk PowerPolk PowerPort WashingtonPort WashingtonPort WashingtonPresque IslePresque IslePresque Isle

K L M N 

Hg CoalAnalysisMethod FuelType Inlet Flo

mg/kg or ppm dscm

0.144 EPA 3051/3052/7471 Subbituminous 0.118 EPA 3051/3052/7471 Subbituminous 0.142 EPA 3051/3052/7471 Subbituminous 0.114 EPA 3051/3052/7471 Subbituminous 0.052 ASTM 6414 Subbituminous 0.044 ASTM 6414 Subbituminous 0.047 ASTM 6414 Subbituminous 

ND(0.05) EPA 7471 Lignite 

0.056 EPA 7471 Lignite 

ND(0.05) EPA 7471 Lignite 

0.107 7471A Lignite 0.121 7471A Lignite 

0.13 7471A Lignite 

0.121 ASTM 3684 Lignite 0.171 ASTM 3684 Lignite 0.125 ASTM 3684 Lignite 

0.19 ASTM 3684 Bituminous 0.18 ASTM 3684 Bituminous 0.17 ASTM 3684 Bituminous 0.09 ASTM 3684 Bituminous 0.11 ASTM 3684 Bituminous 0.09 ASTM 3684 Bituminous 

0.085 ASTM 3684 Subbituminous/Bituminous 

0.12 ASTM 3684 Subbituminous/Bituminous 

0.068 ASTM 3684 Subbituminous/Bituminous 0.318 ASTM 6414 Lignite 0.325 ASTM 6414 Lignite 0.472 ASTM 6414 Lignite 0.388 ASTM 6414 Lignite 0.375 ASTM 6414 Lignite 0.482 ASTM 6414 Lignite 0.089 ASTM 6414 Subbituminous 0.107 ASTM 6414 Subbituminous 0.103 ASTM 6414 Subbituminous 0.040 EPA 7371/1631 Bituminous 0.024 EPA 7371/1631 Bituminous 0.027 EPA 7371/1631 Bituminous 

0.06 ASTM 3684 Subbituminous/Petroleum Coke 0.06 ASTM 3684 Subbituminous/Petroleum Coke 0.06 ASTM 3684 Subbituminous/Petroleum Coke 

0.074 EPA 7473 Subbituminous 0.068 EPA 7473 Subbituminous 0.070 EPA 7473 Subbituminous 

0.08 ASTM 3684 Subbituminous 0.08 ASTM 3684 Subbituminous 0.07 ASTM 3684 Subbituminous 0.11 ASTM 3684 Subbituminous 0.09 ASTM 3684 Subbituminous 0.07 ASTM 3684 Subbituminous 

ND(0.1) EPA 7471 BituminousND(0.1) EPA 7471 BituminousND(0.1) EPA 7471 Bituminous

0.09 ASTM 3684 EPA 7473 and 7471A Bituminous 0.09 ASTM 3684 EPA 7473 and 7471A Bituminous 0.09 ASTM 3684 EPA 7473 and 7471A Bituminous 0.05 Proposed ASTM Method Bituminous/Petroleum Coke 40.04 Proposed ASTM Method Bituminous/Petroleum Coke 40.04 Proposed ASTM Method Bituminous/Petroleum Coke 4
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Plant Name

177178179180181182183184185186187188189190191192193194195196197198199200201202203204205206207208209210211212213214215216217218219220221222223224225226227228229230231232233234

Presque 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 Harbor Salem Harbor Salem Harbor Sam 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 Station

K L M N 

Hg CoalAnalysisMethod FuelType Inlet Flo

mg/kg or ppm dscm

0.07 Proposed ASTM Method Bituminous/Petroleum Coke 30.07 Proposed ASTM Method Bituminous/Petroleum Coke 30.07 Proposed ASTM Method Bituminous/Petroleum Coke 30.03 Proposed ASTM Method Subbituminous 30.05 Proposed ASTM Method Subbituminous 30.04 Proposed ASTM Method Subbituminous 3

ND(0.1) EPA 7471 Bituminous ND(0.1) EPA 7471 Bituminous ND(0.1) EPA 7471 Bituminous 

0.098 EPA 7471A Lignite 0.088 EPA 7471A Lignite 0.073 EPA 7471A Lignite 

0.07 ASTM 3684 Subbituminous 0.07 ASTM 3684 Subbituminous 0.08 ASTM 3684 Subbituminous 0.03 ASTM 3684 Bituminous 0.02 ASTM 3684 Bituminous 0.03 ASTM 3684 Bituminous 

0.139 EPA 7471A Subbituminous 0.115 EPA 7471A Subbituminous 0.114 EPA 7471A Subbituminous 0.045 EPA 7371/1631 Subbituminous 0.051 EPA 7371/1631 Subbituminous 0.065 EPA 7371/1631 Subbituminous 

0.55 ASTM 3684 Waste Bituminous 0.52 ASTM 3684 Waste Bituminous 0.51 ASTM 3684 Waste Bituminous 0.11 EPA 7471 Bituminous 0.11 EPA 7471 Bituminous 0.11 EPA 7471 Bituminous 

0.022 ASTM 6414 Bituminous/Subbituminous 0.039 ASTM 6414 Bituminous/Subbituminous 0.024 ASTM 6414 Bituminous/Subbituminous 

0.06 ASTM 6414 Subbituminous/Bituminous 

0.055 ASTM 6414 Subbituminous/Bituminous 0.069 ASTM 6414 Subbituminous/Bituminous 0.086 EPA 3051/7471 Lignite 0.105 EPA 3051/7471 Lignite 0.056 EPA 3051/7471 Lignite 

0.0865 EPA 3051/7471 Lignite 

0.101 EPA 3051/7471 Lignite 0.063 EPA 3051/7471 Lignite 0.026 ASTM 3684 Bituminous/Petroleum Coke 0.026 ASTM 3684 Bituminous/Petroleum Coke 0.029 ASTM 3684 Bituminous/Petroleum Coke 0.222 ASTM 6414 Lignite 

0.18 ASTM 6414 Lignite 

0.362 ASTM 6414 Lignite 

0.0092 ASTM 3684 EPA 7473 and 7471 Bituminous/Petroleum Coke 

0.013 ASTM 3684 EPA 7473 and 7471 Bituminous/Petroleum Coke 0.015 ASTM 3684 EPA 7473 and 7471 Bituminous/Petroleum Coke 

0.01 MODIFIED EPA 3051/7471A Bituminous 

0.0055 MODIFIED EPA 3051/7471A Bituminous 0.0083 MODIFIED EPA 3051/7471A Bituminous 

0.081 ASTM 6414 Bituminous 

0.12 ASTM 6414 Bituminous 

0.117 ASTM 6414 Bituminous 0.064 ASTM 6414 Bituminous
1

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Plant Name

235236237238239240241242243244245246247248

Wabash River Generating StationWabash River Generating StationWidows Creek Fossil PlantWidows Creek Fossil PlantWidows Creek Fossil PlantWyodakWyodakWyodakXB = Excessive reagent blank caused the data to be unreliableNA = Data was not included in reportLS = Test sample was broken, damaged, or lost during testing or in transport

K L M N 

Hg CoalAnalysisMethod FuelType Inlet Flo

mg/kg or ppm dscm

0.068 ASTM 6414 Bituminous

0.07 ASTM 6414 Bituminous

0.029 ASTM 6414 Bituminous 0.024 ASTM 6414 Bituminous 0.021 ASTM 6414 Bituminous 

0.03 ASTM 3684 Subbituminous 0.04 ASTM 3684 Subbituminous 0.05 ASTM 3684 Subbituminous 
1

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101112131415161718192021222324252627282930313233343536373839404142434445464748495051525354555657585960

A

Plant 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 StationColstrip

P Q R S 

pct_StackGasMoistureIn pct_StackGasO2In Hg_ParticleBoundIn Hg_OxidizedIn 

% % ug/dscm ug/dscm 

8 4.9 NA 5.25 8.1 5.28 0.72 5.59 8.1 5.16 1.62 4.88 8.7 8.0 0.19 ND(0.056) 8.1 8.0 0.25 0.12 9.4 XB 0.26 0.077 15.4 5.4 ND(0.13) 0.33 15 5.4 ND(0.18) 0.36 14.8 5.4 0.14 0.14 8.63 5.63 0.036 2.92 8.22 5.7 0.05 1.95 8.19 6.28 0.06 2.76 9.82 8.7 0.52 0.53 7.18 8.3 0.76 0.47 7.12 9.0 0.06 0.51 9.1 4.1 XB 4.56 9 4.4 XB 4.54 9 3.5 XB 4.14 14.67 5.6 2.22 7.14 13.53 5.2 0.47 9.1 13.79 5.2 0.2 12.41 7.55 6.68 1.6 2.66 7.7 6.8 2.06 2.88 8.05 7.0 1.65 2.71 8.9 8.1 2.11 2.75 9.3 7.25 1.46 2.41 7.45 6.85 1.05 2.55 7.3 7.1 0.33 6.68 6.69 7 0.57 7.65 6.66 6.3 0.34 6.81 7.02 6.2 XB 2.74 6.45 6.7 1.23 3.16 7.48 6.8 2.72 2.8 8.8 4.7 XB 0.61 9.2 3.8 0.95 NA 8.7 3.8 XB 1.21 9.7 3.8 XB ND(0.08) 9.5 3.9 XB 0.3 9.3 3.7 XB 0.41 10.5 6.0 2.29 1.51 10.4 6.7 1.58 1 11.4 6.4 0.67 0.93 10.8 5.4 0.01 0.22 12.5 5.4 ND(0.02) 0.27 11.4 5.5 0.05 0.53 10.4 5.6 0.09 0.28 11.5 5.2 2.62 0.94 10.7 5.2 2.41 0.48 8.71 4.3 0.16 3.45 8.61 4.3 0.08 3.28 9.01 4.4 0.07 3.83 12.01 3.9 0.38 2.23 11.62 3.8 0.02 3.42 11.42 3.7 ND(0.01) 3.28 6 4.5 0.05 0.86 6.15 4.7 0.03 0.94 6.15 4.75 0.07 1.02 9.58 4.6 1.62 2.09 
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A

Plant Name

616263646566676869707172737475767778798081828384858687888990919293949596979899

100101102103104105106107108109110111112113114115116117118

ColstripColstripColumbiaColumbiaColumbiaComancheComancheComancheCoronadoCoronadoCoronadoCoyoteCoyoteCoyoteCraigCraigCraigCraigCraigCraigDunkirkDunkirkDunkirkDwayne 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 Cygne La Cygne La Cygne Laramie River StationLaramie River Station

P Q R S 

pct_StackGasMoistureIn pct_StackGasO2In Hg_ParticleBoundIn Hg_OxidizedIn 

% % ug/dscm ug/dscm 

9.54 4.6 1.77 2.16 10.71 4.8 1.47 2.57 13.48 3.8 0.02 0.89 13.91 4 0.03 5.5 11.85 4.2 0.04 0.43 10 5.4 1.70 2.95 9.4 6.5 2.15 0.87 10.6 5.2 4.69 0.69 10.05 4.94 ND(0.05) 0.88 9.58 4.27 ND(0.05) 0.76 10.27 3.97 ND(0.05) 1.03 13.8 8.2 0.49 1.15 13.7 8.3 0.83 2.1 14 8.2 1.2 2.18 8.43 7.32 ND(0.06) 0.25 8.33 7.24 ND(0.06) 0.22 7.98 7.69 ND(0.06) 0.12 9.74 6.57 0.46 0.52 9.13 6.36 0.75 0.41 8.66 6.36 0.73 0.19 8.0 5.1 0.16 7.56 8.83 4.9 .25 7.97 8.47 4.4 .32 8.43 7.4 4.3 2.03 ND(0.05) 8 4.3 1.93 0.17 7.8 4.3 1.85 ND(0.06) 7.9 4.2 3.99 0.8 8.7 4.2 2.4 0.66 7.5 4.1 0.4 3.7 12.94 5.5 0.147 4.11 13.04 6.2 0.058 3.57 12.7 6.8 ND(0.03) 2.79 7.92 5.6 4.77 8.84 4.63 5.4 23.92 3.28 8.20 5.2 4.09 9.67 7.21 6.0 1.62 26.45 7.92 6.2 1.03 31.29 7.48 6.2 1.44 36.54 12.59 5.4 0.22 3.83 11.67 5.6 0.45 2.54 12.53 5.2 1.0 7.71 7.2 4.5 ND(0.018) 0.94 6.7 4.4 ND(0.016) 1.05 6.6 5.1 ND(0.017) 1.21 9.1 6.7 2.86 0.97 8.4 6.7 3.9 0.92 7.9 6.8 3.66 0.47 9.6 5.8 0.04 2.1 9.0 6.0 0.37 1.7 9.1 5.8 0.06 1.5 6.4 2.4 46.02 ND(0.12) 7.4 2.4 44.56 ND(0.06) 6.4 2.1 47.22 ND(0.06) 10.74 5.4 5.81 3.46 10.78 5.3 5.69 2.91 10.93 5.6 5.12 ND(1.01) 12.8 10 0.154 1.921 11.9 10.1 0.023 1.3058 
1

2

A

Plant Name

119120121122123124125126127128129130131132133134135136137138139140141142143144145146147148149150151152153154155156157158159160161162163164165166167168169170171172173174175176

Laramie 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 Generating PlantNorthern States Power - Sherburne County Generating PlantNorthern States Power - Sherburne County Generating PlantPlattePlattePlattePolk PowerPolk PowerPolk PowerPort WashingtonPort WashingtonPort WashingtonPresque IslePresque IslePresque Isle

P Q R S 

pct_StackGasMoistureIn pct_StackGasO2In Hg_ParticleBoundIn Hg_OxidizedIn 

% % ug/dscm ug/dscm 

11.6 10.1 ND(0.02) 1.866 10.4 9.9 ND(0.032) 0.1368 10.6 9.9 1.0417 0.3235 10.6 10.1 2.7544 0.2642 8.82 6.6 0.18 1.32 9.43 6.4 0.43 ND(1.03) 9.19 7 0.19 ND(1.13) 12.1 5.3 0.49 0.2 14.4 5.6 0.22 0.39 14.8 5.6 LS LS 14.6 4.5 1.05 15.1 14.5 4.4 1.55 12.58 14.5 4.4 1.3 5.79 13.2 6.5 0.01 18.97 13.6 6.5 0.01 19.78 13.6 6.5 0.02 22.68 9.6 3.7 12.3 4.85 9.4 3.5 12.39 3.58 10 3.8 11.9 1.92 9.08 4.4 10.46 3.14 9.54 4.0 5.35 3.98 9.81 4.0 6.52 2.87 10.92 6.61 6.08 0.39 10.29 6.82 7.36 1.07 10.84 6.43 4.57 1.56 14.78 3.6 15.44 21.79 14.55 5.4 0.32 12.84 14.50 7.4 6.02 17.18 10.17 9.4 0.12 10.63 11.90 9.4 0.07 12.74 11.49 9.6 0.08 16.36 11.05 5.2 1.69 1.62 11.29 4.6 0.82 2.3 11.37 4.2 1.51 2.66 8.89 6.23 ND(0.05) 2.39 8.53 5.88 ND(0.05) 0.38 8.76 6.00 ND(0.045) 0.52 10.75 4.4 0.0224 0.45 10.34 4.3 0.0167 0.22 10.29 3.8 0.0191 0.11 14.98 4.0 ND(0.08) 0.55 14.15 4.05 ND(0.07) 0.59 13.82 3.96 ND(0.16) 1.56 11.67 3.8 ND(0.01) 0.51 12.02 3.6 ND(0.01) 0.22 12.03 4.2 ND(0.01) 0.18 12.38 4.5 0.03 3.8 13.61 4.2 0.03 1.79 15.08 2.9 0.03 4.41 7.38 4.3 ND(0.008) 4.02 8.2 4.3 ND(0.02) 7.19 7.41 4.5 ND(0.009) 5.87 9.5 5.5 3.92 0.41 9.4 5 3.20 0.59 9.4 4.9 4.53 0.40 
1

2

A

Plant Name

177178179180181182183184185186187188189190191192193194195196197198199200201202203204205206207208209210211212213214215216217218219220221222223224225226227228229230231232233234

Presque 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 Harbor Salem Harbor Salem Harbor Sam 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 Station

P Q R S 

pct_StackGasMoistureIn pct_StackGasO2In Hg_ParticleBoundIn Hg_OxidizedIn 

% % ug/dscm ug/dscm 

14.8 2.1 0.05 0.01 14.1 2 ND(0.02) 0.15 13.8 2.1 ND(0.03) 0.10 10.1 4.9 2.44 0.56 9.7 4.9 2.66 0.64 9.8 5.2 2.60 0.54 7.9 7.3 0.044 8.22 7.5 6.9 ND(0.013) 6.51 7.2 6.8 ND(0.015) 5.51 14 8.6 3.26 3.71 14.7 8.6 2.02 0.66 15 8.2 5.28 0.31 12.65 5.1 0.22 1.22 12.86 4.2 1.79 0.77 12.27 5.6 3.22 0.39 8.2 8.8 2.81 0.22 8.3 8.5 2.83 0.034 8.8 8.0 2.85 0.042 9.9 4.5 0.02 2.02 13.3 4.7 ND(0.01) 3.07 7 4.75 ND(0.01) 3.9 8.96 5.61 ND(0.03) 5.34 8.37 5.32 0.07 2.88 9.41 4.63 ND(0.05) 4.61 8.7 7.2 141.1 0.52 8.8 6.7 98.6 0.33 8.6 6.3 62.62 0.18 8.7 5.9 11.31 0.25 8.9 5.8 8 0.21 9.4 5.7 10.21 0.21 6.97 8.2 2.26 ND(0.82) 6.74 8.2 2.14 0.7 6.68 8.6 2.37 ND(0.79) 8.23 7.4 1.91 1.73 8.57 7.2 2.2 1.63 7.70 8.0 0.71 1.4 12.89 6.9 ND(0.21) 0.099 12.22 6.7 ND(0.083) 0.08 13.35 6.5 0.054 0.039 14.29 5.5 ND(0.01) 0.18 14.94 5.7 ND(0.004) 0.26 14.98 5.4 NC(0.004) 0.52 5.9 3.7 2.737 ND(0.136) 6 4.36 ND(3.012) ND(0.141) 6 3.87 2.1 ND(0.131) 15.31 5.2 19 7.62 13.16 5.4 9.23 3.91 15.08 4.4 25.93 12.71 7.63 6.6 0.03 1.15 7.35 6.6 0.04 1.19 7.52 6.5 0.03 0.98 11.7 5.4 0.8 0.1 8.57 5.3 0.8 0.06 7.37 5.5 1.06 0.09 6.13 6 9.814 ND(0.80) 6.7 6 12.788 ND(0.83) 6.95 6 12.186 ND(0.85) 
1

2

A

Plant Name

235236237238239240241242243244245246247248

Wabash River Generating StationWabash River Generating StationWidows Creek Fossil PlantWidows Creek Fossil PlantWidows Creek Fossil PlantWyodakWyodakWyodakXB = Excessive reagent blank caused the data to be unreliableNA = Data was not included in reportLS = Test sample was broken, damaged, or lost during testing or in transport

P Q R S 

pct_StackGasMoistureIn pct_StackGasO2In Hg_ParticleBoundIn Hg_OxidizedIn 

% % ug/dscm ug/dscm 

7.73 5.2 2.95 ND(0.78) 7.29 5.6 2.55 ND(0.77) 7.6 5 2.55 ND(0.83) 9.3 8 1.8 2.8 9.9 8 2.2 3.4 9.8 7.4 1.7 2.7 
1

23456789

101112131415161718192021222324252627282930313233343536373839404142434445464748495051525354555657585960

A

Plant 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 StationColstrip

V W X Y 

temp_GasOut pct_StackGasMoistureOut pct_StackGasO2Out Hg_ParticleBound

Deg C % % ug/dscm 

49.89 14.2 5.61 NA 50.44 14.4 5.31 0.013 49.94 14 5.32 0.02 133.7 7.7 8.0 ND(0.003) 133.2 7.5 8.0 ND(0.002) 133.7 8.2 8.0 ND(0.002) 86 18.9 6 ND(0.01) 82 18.4 6 0.02 84 18.4 5.6 0.02 54.5 15.5 7.0 ND(0.002) 53.9 14.5 7.0 ND(0.002) 54.2 15.06 7.0 0.003 135 8.10 9.0 0.79 132 7.15 9.0 0.57 134 7.17 9.1 0.32 52 13 7.3 XB 52 9.9 7.2 XB 52 12.4 7.1 XB 167 12.4 6 0.08 171 12.78 6.8 0.03 164 13.47 6.4 0.03 144 6.7 7.2 0.59 144 7.4 7.1 0.58 141 7.4 7.4 0.58 127 8.3 8.6 0.54 126 7.6 9.4 0.62 121 7.0 8.0 XB 52 15.37 7.4 0.14 53 14.75 7.1 0.14 52 12.76 6.8 0.13 122 8.46 6.6 0.03 121 7.41 6.4 0.05 123 8.43 6.4 0.02 86.7 13.4 5.7 XB 86.7 13.5 5.9 XB 86.6 13.6 5.1 XB 159 8.5 6.2 XB 155 8.7 5.5 XB 159 8.6 5.7 XB 169 10.4 6.6 0.059 166 10.5 7.2 0.003 168 11.3 7.1 ND(0.01) 51 13.3 6.0 0.002 51 13.8 6.4 ND(0.001) 51 13.6 6.7 0.002 67 13.8 5.2 0.02 68 14.0 5.6 0.17 69 14.3 6.0 0.23 195.1 8.05 6.4 0.33 196.6 8.46 6.3 0.08 191.7 7.95 6.1 0.08 170 9.91 6.0 0.58 166 8.64 6.0 ND(0.01) 166 8.02 6.0 0.06 50.6 11.9 6.7 0.04 50 12.3 6.5 ND(0.02) 50 12.1 6.4 0.03 89 15.6 6.2 0.114 
1

2

A

Plant Name

616263646566676869707172737475767778798081828384858687888990919293949596979899

100101102103104105106107108109110111112113114115116117118

ColstripColstripColumbiaColumbiaColumbiaComancheComancheComancheCoronadoCoronadoCoronadoCoyoteCoyoteCoyoteCraigCraigCraigCraigCraigCraigDunkirkDunkirkDunkirkDwayne 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 Cygne La Cygne La Cygne Laramie River StationLaramie River Station

V W X Y 

temp_GasOut pct_StackGasMoistureOut pct_StackGasO2Out Hg_ParticleBound

Deg C % % ug/dscm 

89 15.91 6.2 0.112 89 15.61 6.2 0.074 149 11.7 6 0.004 156 11.85 5.8 0.004 157 11.88 6 0.004 149.44 10.8 4.5 0.043 157.78 11.1 4.5 ND(0.025) 147.22 11.6 4.5 ND(0.038) 48 13.7 5.71 ND(0.026) 47 12.9 5.42 0.073 49 13.8 5.39 0.097 109 15.2 9.8 0.052 96 16.8 9.7 0.09 102 16.7 9.7 0.049 64 10.91 7.16 ND(0.006) 64 13.04 7.11 ND(0.005) 58 11.48 7.18 0.009 80.6 10.38 8.43 ND(0.005) 85.6 10.3 8.27 ND(0.005) 79.4 10.36 8.03 ND(0.005) 293.4 7.50 5.9 0.35 295.2 8.11 5.8 .13 295.8 7.74 5.7 0.05 85 11.6 5 0.05 86 11.6 5.1 0.026 86 12.1 5.3 ND(0.014) 128 6.3 7.1 0.57 124 7.0 6.9 0.31 128 6.1 6.5 0.93 138 11.07 6.8 0.024 142 11.65 7 0.048 144 10.88 8.6 0.023 171 6.60 5.9 ND(0.04) 171 5.69 6.0 ND(0.08) 173 7.26 5.8 ND(0.04) 154 6.30 9.2 0.006 154 7.11 8.8 0.007 157 5.90 9.1 0.006 84.0 15.81 6.1 0.01 84.2 15.77 6.4 0.02 84.2 15.68 6.3 0.01 49 11.5 4.5 0.012 49 11.5 4.4 0.0065 48 11.5 5.1 0.0092 157 8.9 6.3 0.02 150 8.3 7.1 0.04 150 8.0 6.7 ND(0.05) 54 12.8 5.8 0.053 53 14.1 5.8 0.039 54 13.4 5.8 0.028 173 6.9 5.2 ND(0.006) 174 6.9 5.2 ND(0.006) 174 6.1 5.2 ND(0.006) 72 13.98 7.4 0.13 72 14.65 7.2 0.1 74 13.6 6.8 0.16 64.4 15.2 10.5 XB 63.3 14.9 10.0 XB 
1

2

A

Plant Name

119120121122123124125126127128129130131132133134135136137138139140141142143144145146147148149150151152153154155156157158159160161162163164165166167168169170171172173174175176

Laramie 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 Generating PlantNorthern States Power - Sherburne County Generating PlantNorthern States Power - Sherburne County Generating PlantPlattePlattePlattePolk PowerPolk PowerPolk PowerPort WashingtonPort WashingtonPort WashingtonPresque IslePresque IslePresque Isle

V W X Y 

temp_GasOut pct_StackGasMoistureOut pct_StackGasO2Out Hg_ParticleBound

Deg C % % ug/dscm 

63.3 15.7 7.8 XB 77.7 15.3 10.0 0.0158 78.9 14.8 10 0.0173 78.9 14.9 9.8 0.0206 68 16.94 7.2 0.09 66 15.09 7.8 0.17 68 15.23 7.7 0.16 182 12.9 5.8 ND(0.004) 182 13.1 5.8 ND(0.004) 185 14 5.8 LS 60 20.4 4.8 0.054 60 20.9 4.7 ND(0.008) 60 21.0 4.7 ND(0.008) 59 18.5 8 0.03 61 19.5 8 0.24 59 18.7 8 0.09 86.7 12.9 5.3 0.0178 87 12.6 5.2 0.0162 87.2 13.4 5 0.0131 75.5 13.15 4.8 ND(0.027) 74.4 13.59 4.4 ND(0.026) 73.9 14.09 4.8 ND(0.027) 162 9.02 7.27 ND(0.004) 163 8.91 7.20 0.006 150 9.25 6.17 ND(0.004) 166 12.73 10.4 0.1 166 13.01 11.4 0.06 164 13.59 12.2 0.04 90 19.91 10.4 0.18 89 17.3 8.0 0.13 89 17.17 8.2 0.17 166.1 10.41 6.8 0.0052 167.8 10.74 6.6 ND(0.005) 167.8 11.17 6.0 ND(0.003) 49 13.8 5.96 0.045 49 13.8 5.82 0.019 49 14.1 5.85 0.011 258 11.1 4.2 ND(0.092) 258 10.78 4.2 ND(0.036) 264 10.91 3.8 ND(0.035) 169 13.51 5.84 ND(0.007) 163 11.7 5.86 ND(0.005) 170 14.94 5.08 ND(0.005) 80 11.49 6.3 0.1 80 17.86 6.6 0.11 81 15.02 6.5 0.22 153.4 12.15 5.9 0.022 158.0 14.24 5.7 0.023 152.9 13.42 5.9 0.019 171 7.1 12.2 ND(0.01) 172 6.9 11.6 ND(0.01) 171 6.9 11.9 ND(0.01) 204.5 6.9 6.0 ND(0.0066) 206.3 6.89 6.0 ND(0.0065) 206.8 7.04 6.0 ND(0.0635) 171.11 9.2 5.4 0.01 172.78 9.2 5 0.004 171.67 9.3 5.2 0.04 
1

2

A

Plant Name

177178179180181182183184185186187188189190191192193194195196197198199200201202203204205206207208209210211212213214215216217218219220221222223224225226227228229230231232233234

Presque 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 Harbor Salem Harbor Salem Harbor Sam 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 Station

V W X Y 

temp_GasOut pct_StackGasMoistureOut pct_StackGasO2Out Hg_ParticleBound

Deg C % % ug/dscm 

195 14.4 4 0.00 195.56 13.7 3.8 ND(0.005) 196.67 13.7 3.6 ND(0.004) 151.67 9.5 6.1 0.05 151.11 9.5 5.8 0.02 152.22 9.4 5.9 ND(0.004) 83 12.8 7.6 ND(0.041) 88 11.8 7.2 ND(0.024) 88 12.8 7.2 ND(0.026) 159 14.7 7.9 0.077 153 14.6 8 0.051 161 14.6 8.2 0.038 103.8 12.78 6.0 0.20 104.9 16.27 5.5 ND(0.01) 103.3 16.19 6.0 0.05 128 8.0 9.6 0.0419 128 8.2 8.3 0.0692 130 7.9 8.4 0.0527 57.1 17.6 8 0.04 53.9 20.1 8 0.07 56.1 18.1 8 0.04 47.7 14.42 5.8 0.041 47.7 13.73 5.7 0.071 48.3 14.54 5.16 0.048 156 8.4 7.3 ND(0.0043) 157 8.5 7.0 ND(0.0043) 158 8.3 7 ND(0.0041) 90 12.6 6 0.009 90 13 6.2 0.01 90 12.7 5.9 0.013 152 6.28 8.8 0.05 149 7.39 9 0.08 153 6.75 9 ND(0.09) 137 7.43 7.8 ND(0.177) 142 8.25 8.4 ND(0.061) 141 7.47 8.8 ND(0.113) 191.1 13.36 6.4 ND(0.026) 150.0 13.77 6.9 ND(0.014) 158.3 14.03 6.7 ND(0.003) 91.1 20.44 6.5 ND(0.01) 95.0 19.17 6.4 ND(0.01) 93.9 19.75 6.4 ND(0.01) 147 5.7 5.07 ND(0.129) 146 5.5 5.22 ND(0.146) 145 5.7 5.15 ND(0.136) 177 13.33 6 0.06 178 11.99 5.4 0.05 171 13.54 4.8 0.04 157.8 7.02 6.8 0.09 158.7 7.00 6.7 0.03 158.8 7.11 6.7 ND(0.008) 134 8.27 5.4 ND(0.01) 138 8.51 5.4 ND(0.01) 148 7.57 5.5 ND(0.01) 153 6.64 7.1 0.03 149 7.54 6.8 0.05 150 8.25 7 0.04 181.7 14.47 13.6 ND(0.05) 
1

2

A

Plant Name

235236237238239240241242243244245246247248

Wabash River Generating StationWabash River Generating StationWidows Creek Fossil PlantWidows Creek Fossil PlantWidows Creek Fossil PlantWyodakWyodakWyodakXB = Excessive reagent blank caused the data to be unreliableNA = Data was not included in reportLS = Test sample was broken, damaged, or lost during testing or in transport

V W X Y 

temp_GasOut pct_StackGasMoistureOut pct_StackGasO2Out Hg_ParticleBound

Deg C % % ug/dscm 

168.3 14.46 14.0 ND(0.05) 178.3 13.79 13.6 0.03 162 6.95 8.2 0.1 158 6.53 7.2 0.04 151 6.79 7.6 0.06 82 13.7 8 ND(0.025) 82 13.7 8 ND(0.029) 81 13.2 8 ND(0.028) 
14 

ATTACHMENT 3 

Hg_speciation_data_CAMR.xls 

(Tab: 03_Data_Bin_Table) 
1

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10111213141516171819202122232425262728293031323334353637383940414243444546474849

A B C D 

Plant ID

EIA Plant Code & 

ORIS Plant Code or 

just ORIS Plant 

Code Unit No. Run Number

Emission control device type Bin 0Polk Power 0184540000-07242 1 1 (4) 

Polk Power 0184540000-07242 1 2 (4) Polk Power 0184540000-07242 1 3 (4) Wabash River Generating Station 0154700000-01010 1 + 1A 1 

Wabash River Generating Station 0154700000-01010 1 + 1A 2 

Wabash River Generating Station 0154700000-01010 1 + 1A 3 

Average emission modificatio

Emission control device type Bin 1Brayton Point 0134330000-01619 1 1 

Brayton Point 0134330000-01619 1 2 

Brayton Point 0134330000-01619 1 3 

Brayton Point 0134330000-01619 3 1 

Brayton Point 0134330000-01619 3 2 

Brayton Point 0134330000-01619 3 3 

Gibson Generating Station (03/00 testing) 0154700000-06113 3 1 Gibson Generating Station (03/00 testing) 0154700000-06113 3 2 Gibson Generating Station (03/00 testing) 0154700000-06113 3 3 Gibson Generating Station (10/99 testing) 0154700000-06113 3 1 Gibson Generating Station (10/99 testing) 0154700000-06113 3 2 Gibson Generating Station (10/99 testing) 0154700000-06113 3 3 Jack Watson 0126860000-02049 4 1 

Jack Watson 0126860000-02049 4 2 

Jack Watson 0126860000-02049 4 3 

Widows Creek Fossil Plant 0186420000-00050 6 1 

Widows Creek Fossil Plant 0186420000-00050 6 2 

Widows Creek Fossil Plant 0186420000-00050 6 3 

Average emission modificatio

Emission control device type Bin 2Presque Isle 0208470000-01769 5 1 

Presque Isle 0208470000-01769 5 2 

Presque Isle 0208470000-01769 5 3 

Presque Isle 0208470000-01769 6 1 

Presque Isle 0208470000-01769 6 2 

Presque Isle 0208470000-01769 6 3 

Average emission modificatio

Emission control device type Bin 3Salem Harbor 0134330000-01626 3 1 

Salem Harbor 0134330000-01626 3 2 

Salem Harbor 0134330000-01626 3 3 
1

2

A B C D 

Plant ID

EIA Plant Code & 

ORIS Plant Code or 

just ORIS Plant 

Code Unit No. Run Number

505152535455565758596061626364656667686970717273747576777879808182838485868788899091929394959697

Average emission modificatio

Emission control device type Bin 4Cliffside 0054160000-02721 1 1 

Cliffside 0054160000-02721 1 2 

Cliffside 0054160000-02721 1 3 

Dunkirk 0135730000-02554 2 1 

Dunkirk 0135730000-02554 2 2 

Dunkirk 0135730000-02554 2 3 

Gaston 0001950000-00026 1 1 

Gaston 0001950000-00026 1 2 

Gaston 0001950000-00026 1 3 

Average emission modificatio

Emission control device type Bin 5Bruce Mansfield 0147160000-06094 1 1 

Bruce Mansfield 0147160000-06094 1 2 

Bruce Mansfield 0147160000-06094 1 3 

Average emission modificatio

Emission control device type Bin 6Port Washington 0208470000-04040 4 1 

Port Washington 0208470000-04040 4 2 

Port Washington 0208470000-04040 4 3 

Average emission modificatio

Emission control device type Bin 7W. H. Sammis 0139980000-02866 1 1 

W. H. Sammis 0139980000-02866 1 2 

W. H. Sammis 0139980000-02866 1 3 

Valmont 0154660000-00477 5 1 

Valmont 0154660000-00477 5 2 

Valmont 0154660000-00477 5 3 

Average emission modificatio

Emission control device type Bin 8Mecklenburg Cogeneration Facility 52007 GEN 1 1 Mecklenburg Cogeneration Facility 52007 GEN 1 2 Mecklenburg Cogeneration Facility 52007 GEN 1 3 

Average emission modificatio

Emission control device type Bin 9
1

2

A B C D 

Plant ID

EIA Plant Code & 

ORIS Plant Code or 

just ORIS Plant 

Code Unit No. Run Number

9899

100101102103104105106107108109110111112113114115116117118119120121122123124125126127128129130131132133134135136137138139140141142143144145

SEI - Birchwood Power Facility 54304 1 1 

SEI - Birchwood Power Facility 54304 1 2 SEI - Birchwood Power Facility 54304 1 3 Logan Generating Plant 10043 Gen 1 1 Logan Generating Plant 10043 Gen 1 2 Logan Generating Plant 10043 Gen 1 3 

Average emission modificatio

Emission control device type Bin 10Big Bend 0184540000-00645 BB03 1 

Big Bend 0184540000-00645 BB03 2 

Big Bend 0184540000-00645 BB03 3 

AES Cayuga (NY) (formerly NYSEG Milliken) 0135110000-02535 2 1 

AES Cayuga (NY) (formerly NYSEG Milliken) 0135110000-02535 2 2 AES Cayuga (NY) (formerly NYSEG Milliken) 0135110000-02535 2 3 

Second unit average emission modificati

First unit average emission modification correcti

Combined emission modification 

Emission control device type Bin 11Charles R. Lowman 0001890000-00056 2 1 

Charles R. Lowman 0001890000-00056 2 2 

Charles R. Lowman 0001890000-00056 2 3 

R. D. Morrow Sr. Generating plant 0175680000-06061 2 1 R. D. Morrow Sr. Generating plant 0175680000-06061 2 2 R. D. Morrow Sr. Generating plant 0175680000-06061 2 3 Navajo 0165720000-04941 3 1 

Navajo 0165720000-04941 3 2 

Navajo 0165720000-04941 3 3 

Second unit average emission modificati

First unit average emission modification correcti

Combined emission modificatio

Emission control device type Bin 12Clover Power Station 0198760000-07213 2 1 

Clover Power Station 0198760000-07213 2 2 

Clover Power Station 0198760000-07213 2 3 

Intermountain 0112080000-06481 2SGA 1 

Intermountain 0112080000-06481 2SGA 2 

Intermountain 0112080000-06481 2SGA 3 

Second unit average emission modificati

First unit average emission modification correcti

Combined emission modificatio
1

2

A B C D 

Plant ID

EIA Plant Code & 

ORIS Plant Code or 

just ORIS Plant 

Code Unit No. Run Number

146147148149150151152153154155156157158159160161162163164165166167168169170171172173174175176177178179180181182183184185186187188189190191192193

Emission control device type Bin 13Montrose 0100000000-02080 1 1 

Montrose 0100000000-02080 1 2 

Montrose 0100000000-02080 1 3 

George Neal South 0123410000-07343 4 1 

George Neal South 0123410000-07343 4 2 

George Neal South 0123410000-07343 4 3 

Newton 0032530000-06017 2 1 

Newton 0032530000-06017 2 2 

Newton 0032530000-06017 2 3 

Average emission modificatio

Emission control device type Bin 14Cholla 0008030000-00113 3 1 

Cholla 0008030000-00113 3 2 

Cholla 0008030000-00113 3 3 

Columbia 0208560000-08023 1 1 

Columbia 0208560000-08023 1 2 

Columbia 0208560000-08023 1 3 

Platte 0406060000-00059 1 1 

Platte 0406060000-00059 1 2 

Platte 0406060000-00059 1 3 

Presque Isle 0208470000-01769 9 1 

Presque Isle 0208470000-01769 9 2 

Presque Isle 0208470000-01769 9 3 

Average emission modificatio

Emission control device type Bin 15Clay Boswell 0126470000-01893 2 1 

Clay Boswell 0126470000-01893 2 2 

Clay Boswell 0126470000-01893 2 3 

Comanche 0154660000-00470 2 1 

Comanche 0154660000-00470 2 2 

Comanche 0154660000-00470 2 3 

Average emission modificatio

Emission control device type Bin 16Clay Boswell 0126470000-01893 3 1 

Clay Boswell 0126470000-01893 3 2 

Clay Boswell 0126470000-01893 3 3 

Clay Boswell 0126470000-01893 4 1 

Clay Boswell 0126470000-01893 4 2 

Clay Boswell 0126470000-01893 4 3 

Cholla 0008030000-00113 2 1 
1

2

A B C D 

Plant ID

EIA Plant Code & 

ORIS Plant Code or 

just ORIS Plant 

Code Unit No. Run Number

194195196197198199200201202203204205206207208209210211212213214215216217218219220221222223224225226227228229230231232233234235236237238239240241

Cholla 0008030000-00113 2 2 

Cholla 0008030000-00113 2 3 

Colstrip 0128250000-06076 3 1 

Colstrip 0128250000-06076 3 2 

Colstrip 0128250000-06076 3 3 

Lawrence 0002250000-01250 4 1 

Lawrence 0002250000-01250 4 2 

Lawrence 0002250000-01250 4 3 

Average emission modificatio

Emission control device type Bin 17GRDA 0074900000-00165 2 1 

GRDA 0074900000-00165 2 2 

GRDA 0074900000-00165 2 3 

Laramie River Station 0013070000-06204 3 1 

Laramie River Station 0013070000-06204 3 2 

Laramie River Station 0013070000-06204 3 3 

Wyodak 0143540000-06101 BW 91 1 

Wyodak 0143540000-06101 BW 91 2 

Wyodak 0143540000-06101 BW 91 3 

Average emission modificatio

Emission control device type Bin 18Craig 0301510000-06021 C3 1 

Craig 0301510000-06021 C3 2 

Craig 0301510000-06021 C3 3 

Rawhide 0151430000-06761 101 1 

Rawhide 0151430000-06761 101 2 

Rawhide 0151430000-06761 101 3 

Northern States Power - Sherburne County Generating Plant 0137810000-06090 #3 1 

Northern States Power - Sherburne County Generating Plant 0137810000-06090 #3 2 

Northern States Power - Sherburne County Generating Plant 0137810000-06090 #3 3 

Average emission modificatio

Emission control device type Bin 19Jim Bridger 0143540000-08066 BW 74 1 

Jim Bridger 0143540000-08066 BW 74 2 

Jim Bridger 0143540000-08066 BW 74 3 

Laramie River Station 0013070000-06204 1 1 

Laramie River Station 0013070000-06204 1 2 

Laramie River Station 0013070000-06204 1 3 

Sam Seymour 0112690000-06179 3 1 

Sam Seymour 0112690000-06179 3 2 

Sam Seymour 0112690000-06179 3 3 
1

2

A B C D 

Plant ID

EIA Plant Code & 

ORIS Plant Code or 

just ORIS Plant 

Code Unit No. Run Number

242243244245246247248249250251252253254255256257258259260261262263264265266267268269270271272273274275276277278279280281282283284285286287288289

Second unit average emission modificati

First unit average emission modification correcti

Combined emission modificatio

Emission control device type Bin 20Coronado 0615720000-06177 U1B 1 

Coronado 0615720000-06177 U1B 2 

Coronado 0615720000-06177 U1B 3 

Craig 0301510000-06021 C1 1 

Craig 0301510000-06021 C1 2 

Craig 0301510000-06021 C1 3 

San Juan 0154730000-02451 2 1 

San Juan 0154730000-02451 2 2 

San Juan 0154730000-02451 2 3 

Second unit average emission modificati

First unit average emission modification correcti

Combined emission modificatio

Emission control device type Bin 21Stanton Station 0195140000-02824 1 1 

Stanton Station 0195140000-02824 1 2 

Stanton Station 0195140000-02824 1 3 

Average emission modificatio

Emission control device type Bin 22La Cygne 0100000000-01241 1 1 

La Cygne 0100000000-01241 1 2 

La Cygne 0100000000-01241 1 3 

Average emission modificatio

Emission control device type Bin 23Nelson Dewey 0208560000-04054 1 1 

Nelson Dewey 0208560000-04054 1 2 

Nelson Dewey 0208560000-04054 1 3 

Average emission modificatio

Emission control device type Bin 24Leland Olds Station 0013070000-02817 2 1 

Leland Olds Station 0013070000-02817 2 2 

Average emission modificatio

Emission control device type Bin 25Stockton Cogen Company 10640 GEN1 1 
1

2

A B C D 

Plant ID

EIA Plant Code & 

ORIS Plant Code or 

just ORIS Plant 

Code Unit No. Run Number

290291292293294295296297298299300301302303304305306307308309310311312313314315316317318319320321322323324325326327328329330331332333334335

Stockton Cogen Company 10640 GEN1 2 

Stockton Cogen Company 10640 GEN1 3 

Average emission modificatio

Emission control device type Bin 26 - Not Used in ModelEmission control device type Bin 27Scrubgrass Generating Company L. P. 50974 GEN1 1 Scrubgrass Generating Company L. P. 50974 GEN1 2 Scrubgrass Generating Company L. P. 50974 GEN1 3 

Average emission modificatio

Emission control device type Bin 28R.M. Heskett Station 0128190000-02790 B2 1 

R.M. Heskett Station 0128190000-02790 B2 2 

R.M. Heskett Station 0128190000-02790 B2 3 

Average emission modificatio

Emission control device type Bin 29TNP-One 0400510000-07030 U2 1 

TNP-One 0400510000-07030 U2 2 

TNP-One 0400510000-07030 U2 3 

Average emission modificatio

Emission control device type Bin 30Kline Township Cogen Facility 50039 GEN1 1 Kline Township Cogen Facility 50039 GEN1 2 Kline Township Cogen Facility 50039 GEN1 3 

Average emission modificatio

Emission control device type Bin 31Dwayne Collier Battle Cogeneration Facility 10384 2B 1 Dwayne Collier Battle Cogeneration Facility 10384 2B 2 Dwayne Collier Battle Cogeneration Facility 10384 2B 3 

Average emission modificatio

Emission control device type Bin 32 - Not Used in ModelEmission control device type Bin 33Big Brown 0443720000-03497 1 1 
1

2

A B C D 

Plant ID

EIA Plant Code & 

ORIS Plant Code or 

just ORIS Plant 

Code Unit No. Run Number

336337338339340341342343344345346347348349350351352353354355356357358359360361362363364365366367368369370371372373374375376377378379380381382383

Big Brown 0443720000-03497 1 2 

Big Brown 0443720000-03497 1 3 

Monticello 0443720000-06147 1 1 

Monticello 0443720000-06147 1 2 

Monticello 0443720000-06147 1 3 

Second unit average emission modificati

First unit average emission modification correcti

Combined emission modificatio

Emission control device type Bin 34Antelope Valley Station 0013070000-06469 B1 1 

Antelope Valley Station 0013070000-06469 B1 2 

Antelope Valley Station 0013070000-06469 B1 3 

Stanton Station 0195140000-02824 10 1 

Stanton Station 0195140000-02824 10 2 

Stanton Station 0195140000-02824 10 3 

Average emission modificatio

Emission control device type Bin 35Lewis & Clark 0128190000-06089 B1 1 

Lewis & Clark 0128190000-06089 B1 2 

Lewis & Clark 0128190000-06089 B1 3 

Average emission modificatio

Emission control device type Bin 36Monticello 0443720000-06147 3 1 

Monticello 0443720000-06147 3 2 

Monticello 0443720000-06147 3 3 

Limestone 0089010000-00298 LIM1 1 

Limestone 0089010000-00298 LIM1 2 

Limestone 0089010000-00298 LIM1 3 

Second unit average emission modificati

First unit average emission modification correcti

Combined emission modificatio

Emission control device type Bin 37Bay Front Plant Generating 0137810000-03982 5 1 

Bay Front Plant Generating 0137810000-03982 5 2 

Bay Front Plant Generating 0137810000-03982 5 3 

Average emission modificatio

Emission control device type Bin 38Bailly 0137560000-00995 7 and 8 1 
1

2

A B C D 

Plant ID

EIA Plant Code & 

ORIS Plant Code or 

just ORIS Plant 

Code Unit No. Run Number

384385386387388389390391392393394395396397398399400401402403404405406407408409410411412413414415416417418419420421422423424425426427428429430

Bailly 0137560000-00995 7 and 8 2 

Bailly 0137560000-00995 7 and 8 3 

Second unit average emission modificati

First unit average emission modification correcti

Combined emission modificatio

Emission control device type Bin 39Coyote 0128190000-08222 1 1 

Coyote 0128190000-08222 1 2 

Coyote 0128190000-08222 1 3 

Average emission modificatio

Emission control device type Bin 40AES Hawaii, Inc. 10673 AB 1 AES Hawaii, Inc. 10673 AB 2 AES Hawaii, Inc. 10673 AB 3 

Average emission modificatio

Emission control device type Bin 41Meramec 0194360000-02104 4 1 

Meramec 0194360000-02104 4 2 

Meramec 0194360000-02104 4 3 

St Clair Power Plant 0051090000-01743 4 1 

St Clair Power Plant 0051090000-01743 4 2 

St Clair Power Plant 0051090000-01743 4 3 

Average emission modificatio

Emission control device type Bin 42Clifty Creek 0092690000-00983 6 1 

Clifty Creek 0092690000-00983 6 2 

Clifty Creek 0092690000-00983 6 3 

Average emission modificatio

Emission control device type Bin 43Valley 0208470000-04042 2 1 

Valley 0208470000-04042 2 2 

Valley 0208470000-04042 2 3 

Average emission modificatio

Emission control device type Bin 44Shawnee Fossil Plant 0186420000-01379 3 1 
1

2

A B C D 

Plant ID

EIA Plant Code & 

ORIS Plant Code or 

just ORIS Plant 

Code Unit No. Run Number

431432433434435436437438439440441442443444

Shawnee Fossil Plant 0186420000-01379 3 2 

Shawnee Fossil Plant 0186420000-01379 3 3 

Average emission modificatio

1 Although combustion NOx controls and furnace bottom type are listed 

in this column, they have no effect on the bin into which the unit was classified.

2 This column addresses external NOx controls only.3 Speciation was accomplished by analyzing the data in the test reports 

and computing the total mercury leaving the last control device for each run. Then, within the run, we computed the percentage that each Hg species composed of the total. Then, within the bin, we took the average of each species column. These average percentages were then applied to the units that used the specific bin. A “0" in the data 

occurred when any speciated Hg outlet number was not provided or was unacceptable (according to the test method). The sum of the fractional splits is 1 except where slight rounding errors exist.4 All test runs are listed as 1, 2, and 3. This does not mean that during 

the stack testing that these were the actual 1st, 2nd, or 3rd test runs. However, these were the runs presented in the test reports and date order was maintained.

5 Coal gasification units burn synthetic gas (derived from coal) in a 

complex process that requires no PM or SO2 control following the 

process. 

6 A different method was used to average fuel type/boiler type/emission 

control system(s) from all dual-controlled units (units having both a PM and an SO2 control device) than was used for single-controlled units. 

Since stack test flue-gas speciated Hg was analyzed at the inlet and outlet of the last control device, the effect of the PM control on Hg removal on these dual-controlled units was not clear. Thus: EPA decided that it would be more realistic to add the PM control device removal of Hg to the SO2 control device removal of Hg for dualcontrolled units. The PM control device average EMF was taken from 

the bin of a unit with a similar fuel type/boiler type/PM emission control system to the dual-controlled bin it was modifying. The average EMF of a tested unit with a single PM control device was multiplied by each individual run EMF from a similarly configured dual-controlled unit. These modified EMFs were averaged. This average was used to compute the Hg removal of a dual-controlled unit in the national emissions model.

7 All fluidized bed combustor units tested had limestone injection in their 

furnaces to reduce SO2.
1

23456789

10111213141516171819202122232425262728293031323334353637383940414243444546474849

G H I J K 

Primary Fuel/ Secondary 

Fuel Boiler/furnace type 1 PM Control SO2 Control External NOX Control 2 Particle-

Bituminous/None COAL GAS COAL GAS 5 COAL GAS 5 NONE 

Bituminous/None COAL GAS COAL GAS 5 COAL GAS 5 NONE Bituminous/None COAL GAS COAL GAS 5 COAL GAS 5 NONE Bituminous/None COAL GAS COAL GAS 5 COAL GAS 5 NONE Bituminous/None COAL GAS COAL GAS 5 COAL GAS 5 NONE Bituminous/None COAL GAS COAL GAS 5 COAL GAS 5 NONE 

Average speciated Hg fraction 

Bituminous/None CONV/PC/NOX/DRY ESP- CS COMP COAL NONE Bituminous/None CONV/PC/NOX/DRY ESP- CS COMP COAL NONE Bituminous/None CONV/PC/NOX/DRY ESP- CS COMP COAL NONE Bituminous/None CONV/PC/NOX/DRY ESP- CS COMP COAL NONE Bituminous/None CONV/PC/NOX/DRY ESP- CS COMP COAL NONE Bituminous/None CONV/PC/NOX/DRY ESP- CS COMP COAL NONE Bituminous/None CONV/PC/NOX/DRY ESP- CS NONE NONE Bituminous/None CONV/PC/NOX/DRY ESP- CS NONE NONE Bituminous/None CONV/PC/NOX/DRY ESP- CS NONE NONE Bituminous/None CONV/PC/NOX/DRY ESP- CS NONE NONE Bituminous/None CONV/PC/NOX/DRY ESP- CS NONE NONE Bituminous/None CONV/PC/NOX/DRY ESP- CS NONE NONE Bituminous/None CONV/PC/NOX/DRY ESP- CS NONE NONE Bituminous/None CONV/PC/NOX/DRY ESP- CS NONE NONE Bituminous/None CONV/PC/NOX/DRY ESP- CS NONE NONE Bituminous/None CONV/PC/NONOX/DRY ESP- CS COMP COAL NONE Bituminous/None CONV/PC/NONOX/DRY ESP- CS COMP COAL NONE Bituminous/None CONV/PC/NONOX/DRY ESP- CS COMP COAL NONE 

Average speciated Hg fraction 

Bituminous/Pet Coke CONV/PC/NONOX/WET ESP- CS COMP COAL NONE Bituminous/Pet Coke CONV/PC/NONOX/WET ESP- CS COMP COAL NONE Bituminous/Pet Coke CONV/PC/NONOX/WET ESP- CS COMP COAL NONE Bituminous/Pet Coke CONV/PC/NONOX/WET ESP- CS COMP COAL NONE Bituminous/Pet Coke CONV/PC/NONOX/WET ESP- CS COMP COAL NONE Bituminous/Pet Coke CONV/PC/NONOX/WET ESP- CS COMP COAL NONE 

Average speciated Hg fraction 

Bituminous/None CONV/PC/NOX/DRY ESP- CS COMP COAL SNCR Bituminous/None CONV/PC/NOX/DRY ESP- CS COMP COAL SNCR Bituminous/None CONV/PC/NOX/DRY ESP- CS COMP COAL SNCR 
1

2

G H I J K 

Primary Fuel/ Secondary 

Fuel Boiler/furnace type 1 PM Control SO2 Control External NOX Control 2 Particle-

505152535455565758596061626364656667686970717273747576777879808182838485868788899091929394959697

Average speciated Hg fraction 

Bituminous/None CONV/PC/NONOX/DRY ESP- HS NONE NONE Bituminous/None CONV/PC/NONOX/DRY ESP- HS NONE NONE Bituminous/None CONV/PC/NONOX/DRY ESP- HS NONE NONE Bituminous/None CONV/PC/NOX/DRY ESP- HS COMP COAL NONE Bituminous/None CONV/PC/NOX/DRY ESP- HS COMP COAL NONE Bituminous/None CONV/PC/NOX/DRY ESP- HS COMP COAL NONE Bituminous/None CONV/PC/NOX/DRY ESP- HS NONE NONE Bituminous/None CONV/PC/NOX/DRY ESP- HS NONE NONE Bituminous/None CONV/PC/NOX/DRY ESP- HS NONE NONE 

Average speciated Hg fraction 

Bituminous/None CONV/PC/NOX/DRY PARTSCRUB NONE NONE Bituminous/None CONV/PC/NOX/DRY PARTSCRUB NONE NONE Bituminous/None CONV/PC/NOX/DRY PARTSCRUB NONE NONE 

Average speciated Hg fraction 

Bituminous/None CONV/PC/NONOX/DRY ESP- CS DRY SORBENT NONE Bituminous/None CONV/PC/NONOX/DRY ESP- CS DRY SORBENT NONE Bituminous/None CONV/PC/NONOX/DRY ESP- CS DRY SORBENT NONE 

Average speciated Hg fraction 

Bituminous/None CONV/PC/NONOX/DRY BAGHOUSE NONE NONE Bituminous/None CONV/PC/NONOX/DRY BAGHOUSE NONE NONE Bituminous/None CONV/PC/NONOX/DRY BAGHOUSE NONE NONE Bituminous/None CONV/PC/NOX/DRY BAGHOUSE COMP COAL NONE Bituminous/None CONV/PC/NOX/DRY BAGHOUSE COMP COAL NONE Bituminous/None CONV/PC/NOX/DRY BAGHOUSE COMP COAL NONE 

Average speciated Hg fraction 

Bituminous/None CONV/PC/NOX/DRY BAGHOUSE SDA NONE Bituminous/None CONV/PC/NOX/DRY BAGHOUSE SDA NONE Bituminous/None CONV/PC/NOX/DRY BAGHOUSE SDA NONE 

Average speciated Hg fraction 
1

2

G H I J K 

Primary Fuel/ Secondary 

Fuel Boiler/furnace type 1 PM Control SO2 Control External NOX Control 2 Particle-

9899

100101102103104105106107108109110111112113114115116117118119120121122123124125126127128129130131132133134135136137138139140141142143144145

Bituminous/None CONV/PC/NOX/DRY BAGHOUSE SDA SCR 

Bituminous/None CONV/PC/NOX/DRY BAGHOUSE SDA SCR Bituminous/None CONV/PC/NOX/DRY BAGHOUSE SDA SCR Bituminous/None CONV/PC/NOX/DRY BAGHOUSE SDA SCR Bituminous/None CONV/PC/NOX/DRY BAGHOUSE SDA SCR Bituminous/None CONV/PC/NOX/DRY BAGHOUSE SDA SCR 

Average speciated Hg fraction 

Bituminous/None CONV/PC/TURBO/NOX/DRY ESP- CS WETSCRUB NONE Bituminous/None CONV/PC/TURBO/NOX/DRY ESP- CS WETSCRUB NONE Bituminous/None CONV/PC/TURBO/NOX/DRY ESP- CS WETSCRUB NONE Bituminous/None CONV/PC/NOX/DRY ESP- CS WETSCRUB NONE Bituminous/None CONV/PC/NOX/DRY ESP- CS WETSCRUB NONE Bituminous/None CONV/PC/NOX/DRY ESP- CS WETSCRUB NONE 

Average speciated Hg fraction 

Bituminous/None CONV/PC/NONOX/DRY ESP- HS WETSCRUB NONE Bituminous/None CONV/PC/NONOX/DRY ESP- HS WETSCRUB NONE Bituminous/None CONV/PC/NONOX/DRY ESP- HS WETSCRUB NONE Bituminous/None CONV/PC/NOX/DRY ESP- HS WETSCRUB NONE Bituminous/None CONV/PC/NOX/DRY ESP- HS WETSCRUB NONE Bituminous/None CONV/PC/NOX/DRY ESP- HS WETSCRUB NONE Bituminous/None CONV/PC/NONOX/DRY ESP- HS WETSCRUB NONE Bituminous/None CONV/PC/NONOX/DRY ESP- HS WETSCRUB NONE Bituminous/None CONV/PC/NONOX/DRY ESP- HS WETSCRUB NONE 

Average speciated Hg fraction 

Bituminous/None CONV/PC/NOX/DRY BAGHOUSE WETSCRUB NONE Bituminous/None CONV/PC/NOX/DRY BAGHOUSE WETSCRUB NONE Bituminous/None CONV/PC/NOX/DRY BAGHOUSE WETSCRUB NONE Bituminous/None CONV/PC/NOX/DRY BAGHOUSE WETSCRUB NONE Bituminous/None CONV/PC/NOX/DRY BAGHOUSE WETSCRUB NONE Bituminous/None CONV/PC/NOX/DRY BAGHOUSE WETSCRUB NONE 

Average speciated Hg fraction 
1

2

G H I J K 

Primary Fuel/ Secondary 

Fuel Boiler/furnace type 1 PM Control SO2 Control External NOX Control 2 Particle-

146147148149150151152153154155156157158159160161162163164165166167168169170171172173174175176177178179180181182183184185186187188189190191192193

Subbituminous/None CONV/PC/NOX/DRY ESP- CS COMP COAL NONE 

Subbituminous/None CONV/PC/NOX/DRY ESP- CS COMP COAL NONE Subbituminous/None CONV/PC/NOX/DRY ESP- CS COMP COAL NONE Subbituminous/None CONV/PC/NOX/DRY ESP- CS COMP COAL NONE Subbituminous/None CONV/PC/NOX/DRY ESP- CS COMP COAL NONE Subbituminous/None CONV/PC/NOX/DRY ESP- CS COMP COAL NONE Subbituminous/None CONV/PC/NOX/DRY ESP- CS COMP COAL NONE Subbituminous/None CONV/PC/NOX/DRY ESP- CS COMP COAL NONE Subbituminous/None CONV/PC/NOX/DRY ESP- CS COMP COAL NONE 

Average speciated Hg fraction 

Subbituminous/None CONV/PC/NONOX/DRY ESP- HS NONE NONE Subbituminous/None CONV/PC/NONOX/DRY ESP- HS NONE NONE Subbituminous/None CONV/PC/NONOX/DRY ESP- HS NONE NONE Subbituminous/None CONV/PC/NOX/DRY ESP- HS COMP COAL NONE Subbituminous/None CONV/PC/NOX/DRY ESP- HS COMP COAL NONE Subbituminous/None CONV/PC/NOX/DRY ESP- HS COMP COAL NONE Subbituminous/None CONV/PC/NOX/WET ESP- HS COMP COAL NONE Subbituminous/None CONV/PC/NOX/WET ESP- HS COMP COAL NONE Subbituminous/None CONV/PC/NOX/WET ESP- HS COMP COAL NONE Subbituminous/None CONV/PC/NOX/WET ESP- HS COMP COAL NONE Subbituminous/None CONV/PC/NOX/WET ESP- HS COMP COAL NONE Subbituminous/None CONV/PC/NOX/WET ESP- HS COMP COAL NONE 

Average speciated Hg fraction 

Subbituminous/None CONV/PC/NOX/DRY BAGHOUSE COMP COAL NONE Subbituminous/None CONV/PC/NOX/DRY BAGHOUSE COMP COAL NONE Subbituminous/None CONV/PC/NOX/DRY BAGHOUSE COMP COAL NONE Subbituminous/None CONV/PC/NOX/DRY BAGHOUSE COMP COAL NONE Subbituminous/None CONV/PC/NOX/DRY BAGHOUSE COMP COAL NONE Subbituminous/None CONV/PC/NOX/DRY BAGHOUSE COMP COAL NONE 

Average speciated Hg fraction 

Subbituminous/None CONV/PC/NOX/DRY PARTSCRUB COMP COAL NONE Subbituminous/None CONV/PC/NOX/DRY PARTSCRUB COMP COAL NONE Subbituminous/None CONV/PC/NOX/DRY PARTSCRUB COMP COAL NONE Subbituminous/None CONV/PC/NOX/DRY PARTSCRUB NONE NONE Subbituminous/None CONV/PC/NOX/DRY PARTSCRUB NONE NONE Subbituminous/None CONV/PC/NOX/DRY PARTSCRUB NONE NONE Subbituminous/None CONV/PC/NONOX/DRY MECH/PARTSCRUB NONE NONE 
1

2

G H I J K 

Primary Fuel/ Secondary 

Fuel Boiler/furnace type 1 PM Control SO2 Control External NOX Control 2 Particle-

194195196197198199200201202203204205206207208209210211212213214215216217218219220221222223224225226227228229230231232233234235236237238239240241

Subbituminous/None CONV/PC/NONOX/DRY MECH/PARTSCRUB NONE NONE 

Subbituminous/None CONV/PC/NONOX/DRY MECH/PARTSCRUB NONE NONE Subbituminous/None CONV/PC/NOX/DRY PARTSCRUB NONE NONE Subbituminous/None CONV/PC/NOX/DRY PARTSCRUB NONE NONE Subbituminous/None CONV/PC/NOX/DRY PARTSCRUB NONE NONE Subbituminous/None CONV/PC/NONOX/DRY PARTSCRUB NONE NONE Subbituminous/None CONV/PC/NONOX/DRY PARTSCRUB NONE NONE Subbituminous/None CONV/PC/NONOX/DRY PARTSCRUB NONE NONE 

Average speciated Hg fraction 

Subbituminous/Bituminous CONV/PC/NOX/DRY ESP- CS SDA NONE Subbituminous/Bituminous CONV/PC/NOX/DRY ESP- CS SDA NONE Subbituminous/Bituminous CONV/PC/NOX/DRY ESP- CS SDA NONE 

Subbituminous/None CONV/PC/NOX/DRY ESP- CS SDA NONE 

Subbituminous/None CONV/PC/NOX/DRY ESP- CS SDA NONE Subbituminous/None CONV/PC/NOX/DRY ESP- CS SDA NONE Subbituminous/None CONV/PC/NOX/DRY ESP- CS SDA NONE Subbituminous/None CONV/PC/NOX/DRY ESP- CS SDA NONE Subbituminous/None CONV/PC/NOX/DRY ESP- CS SDA NONE 

Average speciated Hg fraction 

Subbituminous/None CONV/PC/NOX/DRY BAGHOUSE SDA NONE Subbituminous/None CONV/PC/NOX/DRY BAGHOUSE SDA NONE Subbituminous/None CONV/PC/NOX/DRY BAGHOUSE SDA NONE Subbituminous/None CONV/PC/NOX/DRY BAGHOUSE SDA NONE Subbituminous/None CONV/PC/NOX/DRY BAGHOUSE SDA NONE Subbituminous/None CONV/PC/NOX/DRY BAGHOUSE SDA NONE Subbituminous/None CONV/PC/NOX/DRY BAGHOUSE SDA NONE Subbituminous/None CONV/PC/NOX/DRY BAGHOUSE SDA NONE Subbituminous/None CONV/PC/NOX/DRY BAGHOUSE SDA NONE 

Average speciated Hg fraction 

Subbituminous/None CONV/PC/NOX/DRY ESP- CS WETSCRUB NONE Subbituminous/None CONV/PC/NOX/DRY ESP- CS WETSCRUB NONE Subbituminous/None CONV/PC/NOX/DRY ESP- CS WETSCRUB NONE Subbituminous/None CONV/PC/NOX/DRY ESP- CS WETSCRUB NONE Subbituminous/None CONV/PC/NOX/DRY ESP- CS WETSCRUB NONE Subbituminous/None CONV/PC/NOX/DRY ESP- CS WETSCRUB NONE Subbituminous/None CONV/PC/NONOX/DRY ESP- CS WETSCRUB NONE Subbituminous/None CONV/PC/NONOX/DRY ESP- CS WETSCRUB NONE Subbituminous/None CONV/PC/NONOX/DRY ESP- CS WETSCRUB NONE 
1

2

G H I J K 

Primary Fuel/ Secondary 

Fuel Boiler/furnace type 1 PM Control SO2 Control External NOX Control 2 Particle-

242243244245246247248249250251252253254255256257258259260261262263264265266267268269270271272273274275276277278279280281282283284285286287288289

Average speciated Hg fraction 

Subbituminous/None CONV/PC/NOX/WET ESP- HS WETSCRUB NONE Subbituminous/None CONV/PC/NOX/WET ESP- HS WETSCRUB NONE Subbituminous/None CONV/PC/NOX/WET ESP- HS WETSCRUB NONE Subbituminous/None CONV/PC/NOX/DRY ESP- HS WETSCRUB NONE Subbituminous/None CONV/PC/NOX/DRY ESP- HS WETSCRUB NONE Subbituminous/None CONV/PC/NOX/DRY ESP- HS WETSCRUB NONE Subbituminous/None CONV/PC/NONOX/DRY ESP- HS WETSCRUB NONE Subbituminous/None CONV/PC/NONOX/DRY ESP- HS WETSCRUB NONE Subbituminous/None CONV/PC/NONOX/DRY ESP- HS WETSCRUB NONE 

Average speciated Hg fraction 

Lignite/None CONV/PC/NOX/DRY ESP- CS NONE NONE Lignite/None CONV/PC/NOX/DRY ESP- CS NONE NONE Lignite/None CONV/PC/NOX/DRY ESP- CS NONE NONE 

Average speciated Hg fraction 

Subbituminous/None CYCLONE/NOX/WET PARTSCRUB NONE NONE Subbituminous/None CYCLONE/NOX/WET PARTSCRUB NONE NONE Subbituminous/None CYCLONE/NOX/WET PARTSCRUB NONE NONE 

Average speciated Hg fraction 

Subbituminous/Pet Coke CYCLONE/NOX/WET ESP- HS COMP COAL NONE Subbituminous/Pet Coke CYCLONE/NOX/WET ESP- HS COMP COAL NONE Subbituminous/Pet Coke CYCLONE/NOX/WET ESP- HS COMP COAL NONE 

Average speciated Hg fraction 

Lignite/None CYCLONE/NOX/WET ESP- CS NONE NONE Lignite/None CYCLONE/NOX/WET ESP- CS NONE NONE 

Average speciated Hg fraction 

Bituminous/Pet Coke FBC 7 BAGHOUSE NONE SNCR 
1

2

G H I J K 

Primary Fuel/ Secondary 

Fuel Boiler/furnace type 1 PM Control SO2 Control External NOX Control 2 Particle-

290291292293294295296297298299300301302303304305306307308309310311312313314315316317318319320321322323324325326327328329330331332333334335

Bituminous/Pet Coke FBC 7 BAGHOUSE NONE SNCR 

Bituminous/Pet Coke FBC 7 BAGHOUSE NONE SNCR 

Average speciated Hg fraction 

Waste Bituminous/None FBC 7 BAGHOUSE NONE NONE 

Waste Bituminous/None FBC 7 BAGHOUSE NONE NONE Waste Bituminous/None FBC 7 BAGHOUSE NONE NONE 

Average speciated Hg fraction 

Lignite/None FBC 7 ESP- CS NONE NONE 

Lignite/None FBC 7 ESP- CS NONE NONE Lignite/None FBC 7 ESP- CS NONE NONE 

Average speciated Hg fraction 

Lignite/None FBC 7 BAGHOUSE NONE NONE 

Lignite/None FBC 7 BAGHOUSE NONE NONE Lignite/None FBC 7 BAGHOUSE NONE NONE 

Average speciated Hg fraction 

Waste Anthracite/None FBC 7 BAGHOUSE NONE NONE 

Waste Anthracite/None FBC 7 BAGHOUSE NONE NONE Waste Anthracite/None FBC 7 BAGHOUSE NONE NONE 

Average speciated Hg fraction 

Bituminous/None STOKER/NOX/DRY BAGHOUSE SDA NONE Bituminous/None STOKER/NOX/DRY BAGHOUSE SDA NONE Bituminous/None STOKER/NOX/DRY BAGHOUSE SDA NONE 

Average speciated Hg fraction 

Lignite/None CONV/PC/NONOX/DRY ESP- CS/BAGHOUSE COMP COAL NONE 
1

2

G H I J K 

Primary Fuel/ Secondary 

Fuel Boiler/furnace type 1 PM Control SO2 Control External NOX Control 2 Particle-

336337338339340341342343344345346347348349350351352353354355356357358359360361362363364365366367368369370371372373374375376377378379380381382383

Lignite/None CONV/PC/NONOX/DRY ESP- CS/BAGHOUSE COMP COAL NONE Lignite/None CONV/PC/NONOX/DRY ESP- CS/BAGHOUSE COMP COAL NONE Lignite/None CONV/PC/NONOX/DRY ESP- CS/BAGHOUSE COMP COAL NONE Lignite/None CONV/PC/NONOX/DRY ESP- CS/BAGHOUSE COMP COAL NONE Lignite/None CONV/PC/NONOX/DRY ESP- CS/BAGHOUSE COMP COAL NONE 

Average speciated Hg fraction 

Lignite/None CONV/PC/NOX/DRY BAGHOUSE SDA NONE Lignite/None CONV/PC/NOX/DRY BAGHOUSE SDA NONE Lignite/None CONV/PC/NOX/DRY BAGHOUSE SDA NONE Lignite/None CONV/PC/NOX/DRY BAGHOUSE SDA NONE Lignite/None CONV/PC/NOX/DRY BAGHOUSE SDA NONE Lignite/None CONV/PC/NOX/DRY BAGHOUSE SDA NONE 

Average speciated Hg fraction 

Lignite/None CONV/PC/NOX/DRY PARTSCRUB NONE NONE Lignite/None CONV/PC/NOX/DRY PARTSCRUB NONE NONE Lignite/None CONV/PC/NOX/DRY PARTSCRUB NONE NONE 

Average speciated Hg fraction 

Lignite/None CONV/PC/NONOX/DRY ESP- CS WETSCRUB NONE Lignite/None CONV/PC/NONOX/DRY ESP- CS WETSCRUB NONE Lignite/None CONV/PC/NONOX/DRY ESP- CS WETSCRUB NONE Lignite/None CONV/PC/NOX/WET ESP- CS WETSCRUB NONE Lignite/None CONV/PC/NOX/WET ESP- CS WETSCRUB NONE Lignite/None CONV/PC/NOX/WET ESP- CS WETSCRUB NONE 

Average speciated Hg fraction 

Bituminous/None CYCLONE/NONOX/WET MECH NONE NONE Bituminous/None CYCLONE/NONOX/WET MECH NONE NONE Bituminous/None CYCLONE/NONOX/WET MECH NONE NONE 

Average speciated Hg fraction 

Bituminous/Pet Coke CYCLONE/NONOX/WET ESP- CS WETSCRUB NONE 
1

2

G H I J K 

Primary Fuel/ Secondary 

Fuel Boiler/furnace type 1 PM Control SO2 Control External NOX Control 2 Particle-

384385386387388389390391392393394395396397398399400401402403404405406407408409410411412413414415416417418419420421422423424425426427428429430

Bituminous/Pet Coke CYCLONE/NONOX/WET ESP- CS WETSCRUB NONE 

Bituminous/Pet Coke CYCLONE/NONOX/WET ESP- CS WETSCRUB NONE 

Average speciated Hg fraction 

Lignite/None CYCLONE/NONOX/WET BAGHOUSE SDA NONE Lignite/None CYCLONE/NONOX/WET BAGHOUSE SDA NONE Lignite/None CYCLONE/NONOX/WET BAGHOUSE SDA NONE 

Average speciated Hg fraction 

Subbituminous/None FBC 7 BAGHOUSE NONE SNCR 

Subbituminous/None FBC 7 BAGHOUSE NONE SNCR Subbituminous/None FBC 7 BAGHOUSE NONE SNCR 

Average speciated Hg fraction 

Subbituminous/Bituminous CONV/PC/NOX/DRY ESP- CS NONE NONE Subbituminous/Bituminous CONV/PC/NOX/DRY ESP- CS NONE NONE Subbituminous/Bituminous CONV/PC/NOX/DRY ESP- CS NONE NONE Subbituminous/Bituminous CONV/PC/NONOX/DRY ESP- CS COMP COAL NONE Subbituminous/Bituminous CONV/PC/NONOX/DRY ESP- CS COMP COAL NONE Subbituminous/Bituminous CONV/PC/NONOX/DRY ESP- CS COMP COAL NONE 

Average speciated Hg fraction 

Subbituminous/Bituminous CONV/PC/NOX/WET ESP- HS COMP COAL NONE Subbituminous/Bituminous CONV/PC/NOX/WET ESP- HS COMP COAL NONE Subbituminous/Bituminous CONV/PC/NOX/WET ESP- HS COMP COAL NONE 

Average speciated Hg fraction 

Bituminous/Pet Coke CONV/PC/NOX/DRY BAGHOUSE NONE NONE Bituminous/Pet Coke CONV/PC/NOX/DRY BAGHOUSE NONE NONE Bituminous/Pet Coke CONV/PC/NOX/DRY BAGHOUSE NONE NONE 

Average speciated Hg fraction 

Bituminous/Subbituminous CONV/PC/NOX/DRY BAGHOUSE COMP COAL NONE 
1

2

G H I J K 

Primary Fuel/ Secondary 

Fuel Boiler/furnace type 1 PM Control SO2 Control External NOX Control 2 Particle-

431432433434435436437438439440441442443444

Bituminous/Subbituminous CONV/PC/NOX/DRY BAGHOUSE COMP COAL NONE 

Bituminous/Subbituminous CONV/PC/NOX/DRY BAGHOUSE COMP COAL NONE 

Average speciated Hg fraction 
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 Injection 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 Baghouse 97.36% 5.06% 46.04% 48.90%

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

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

12 Bituminous Coal, PC Boiler with FF Baghouse and Wet 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 Baghouse 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 Scrubber 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 Baghouse 56.98% 0.42% 71.18% 28.40%

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

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

32 Not Used

33 Lignite Coal, PC Boiler with ESP-CS and FF Baghouse 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 Collector 0.00% 18.75% 42.74% 38.51%

38 Bituminous Coal/Pet. Coke, Cyclone with ESP-CS and 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 SNCR and FF Baghouse 52.52% 0.27% 3.42% 96.32%

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

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

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

44 Bituminous Coal/Subbituminous Coal, PC Boiler with FF Baghouse 68.22% 5.95% 42.10% 51.95%
 
Publication No. EPA-454/R-11-010 

November, 2011

Office of Air Quality Planning and Standards 

Air Quality Assessment Division 

Research Triangle Park, NC 

United States Environmental Protection Agency