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
-------
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 ((ig/dscm) for particle-bound
-------
94- 0
(Hgp), oxidized (Hg ), and elemental (Hg ) 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 Vi-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
------- 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
-------
Emission Controls
The data set used to develop the speciation data includes a cross-section of particulate matter
(PM), sulfur dioxide (862), 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 862 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.
-------
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 cone / (Hgp cone + Hg2+ cone + Hg° cone)
where: Hgp fraction = unitless fraction of mercury in the particle-bound form
Hgp cone = particle-bound mercury concentration ((ig/dscm)
Hg2+ cone = oxidized mercury concentration ((ig/dscm)
Hg° cone = elemental mercury concentration ((ig/dscm)
To determine the average speciation profile for each bin, all of the individual run values for
each speciation fraction (Hgp, Hg2+, and Hg°) 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
-------
9-1-
type, and emission control schemes) to estimate the speciation of mercury (Hgp, Hg , and
Hg°) 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.
------- ATTACHMENTS ------- ATTACHMENT 1 Glossary of Terms ------- 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.
-------
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 high-
temperature 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.
10
-------
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 (NHa) 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.
11
-------
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.
12
-------
ATTACHMENT 2
Hg_speciation_data_CAMR.xls
(Tab: 02_Raw_Data_Table)
13
------- 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 21 22 23 24 25 OR 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 45 46 47 48 49 51 52 53 54 55 56 57 58 59 60 A Plant Name AES Cayuga (NY) (formerly NYSEG Milliken) AES Cayuga (NY) (formerly NYSEG Milliken) AES Cayuga (NY) (formerly NYSEG Milliken) AES Hawaii, Inc. AES Hawaii, Inc. Antelope Valley Station Antelope Valley Station Antelope Valley Station Bailly Bailly Bay Front Plant Generating Bay Front Plant Generating Bay Front Plant Generating Big Bend Big Bend Big Brown Big Brown Big Brown Brayton Point Brayton Point Brayton Point Brayton Point Brayton Point Bruce Mansfield Bruce Mansfield Charles R. Lowman Charles R. Lowman Charles R. Lowman Cholla Cholla Cholla Cholla Cholla Clay Boswell Clay Boswell Clay Boswell Clay Boswell Clay Boswell Clay Boswell Clay Boswell Cliffside Cliffside Cliffside Cliffy Creek Clifty Creek Clover Power Station Clover Power Station Clover Power Station Colstrip B EIA Plant Code & ORIS Code 0135110000-02535 0135110000-02535 0135110000-02535 10673 10673 10673 0013070000-06469 0013070000-06469 0013070000-06469 0137560000-00995 0137560000-00995 0137560000-00995 0137810000-03982 0137810000-03982 0137810000-03982 0184540000-00645 0184540000-00645 0443720000-03497 0443720000-03497 0443720000-03497 0134330000-01619 0134330000-01619 0134330000-01619 0134330000-01619 0134330000-01619 0134330000-01619 0147160000-06094 0147160000-06094 0147160000-06094 0001890000-00056 0001890000-00056 0001890000-00056 0008030000-00113 0008030000-00113 0008030000-00113 0008030000-00113 0008030000-00113 0008030000-00113 0126470000-01893 0126470000-01893 0126470000-01893 0126470000-01893 0126470000-01893 0126470000-01893 0126470000-01893 0126470000-01893 0126470000-01893 0054160000-02721 0054160000-02721 0054160000-02721 0092690000-00983 0092690000-00983 0092690000-00983 0198760000-07213 0198760000-07213 0198760000-07213 0128250000-06076 C Unit No. 2 2 2 AB AB AB B1 B1 B1 7 and 8 7 and 8 7 and 8 5 5 5 BB03 BB03 BB03 1 1 1 1 1 1 3 3 3 1 1 1 2 2 2 2 2 2 3 3 3 D RunNumber 1 2 3 1 2 3 1 2 3 1 2 3 1 2 3 1 2 3 1 2 3 1 2 3 1 2 3 1 2 3 1 2 3 1 2 ; 2 3 2 1 2 2 2 3 3 1 3 2 3 | 3 4 4 4 1 1 1 6 6 6 2 2 2 1 2 3 2 3 1 2 ; 2 3 E CoalFlowRate (kg/hr), dry 50040.96 51915.19 52215.01 32884 33360 33485 433349 419526 413661 1 77627 1 79853 175369 3911 3913 3934 133914 132229 310664 312513 298538 76292 75446 JCACfZ 163357 157296 178153 277790 279761 270273 77844 76370 77844 125445.6 123908.4 127224 116562.6 120860.6 121240.5 21481 21590 125453 119812 120910 195911 197038 15852 15818 15838 71060 69626 74180 143480 143553 142146 3 1 370938 F HHV Btu/lb 13731 13791 13661 12742 12743 12625 10180 10280 10400 12725 12735 12813 12790 12635 12597 12730 12790 8690 8720 9050 13684 13756 -t-ayc^ 13521 13583 13875 13163 13678 13237 13352 13356 13352 11222 10955 1 1 134 11863 12172 12135 12158 12087 12072 12052 11972 12075 12197 13803 13181 13804 12494 12578 12632 13089.39 13605.30 13568.31 G pctSulphur % 2.51 2.55 2.33 0.67 0.65 0.66 1.09 1.24 1.05 3.16 3.12 2.5 0.65 0.65 0.66 3.15 3.22 1.01 1.03 1 0.83 0.73 n 7fi 0.82 0.76 0.77 4.29 4.54 4.6 0.53 0.52 0.53 0.495 0.51 0 525 0.43 0.42 0.42 0.62 0.62 0.61 0.75 0.68 0.54 0.57 0.85 0.77 0.85 0.86 0.86 0.99 NA NA NA 10779 1 0.72 H pctMoisture % 4.81 5.77 5.93 12.72 12.79 13 37.64 35.95 36.67 14.25 14.78 15.0 13.77 13.73 13.26 9.55 9.58 25 25.5 26.1 6.56 6.03 5.97 6.48 6.04 5.49 5.98 5.42 12 12.1 12 5.68 6.13 5 76 7.49 7.74 7.46 26.6 26.5 26.1 28.3 27.8 26.7 26.3 7.34 7.83 7.26 22.69 22.74 21.52 4.35 3.42 3.82 11.4 I pctAsh % 9.41 9.01 9.69 8.17 8.04 8.85 15.3 15.93 14.39 8.87 8.88 9.86 7.57 7.51 7.56 11 10.6 23.7 23 21 7.6 7.6 7 A^ 10.56 10 8.14 12.1 8.57 11.2 4.65 5.29 4.93 18.8 20.49 19 44 11.94 9.06 9.91 7.31 7.97 7.67 7.13 8.54 7.27 7.44 9.16 8.31 8.44 8.08 8.66 8.98 NA NA NA 16.8 J Chlorine mg/kg or ppm 840 955 850 60 ND(50) 52 140 84 97 713 459 766 110 119 152 1800 1800 100 100 200 300 700 ynn 900 1100 900 800 700 800 400 400 300 ND(100) ND(100) ND(100) ND(100) ND(100) ND(100) ND(100) ND(100) ND(100) ND(100) ND(100) ND(100) ND(100) 1400 1400 1400 430 374 519 418.19 517.71 623.83 ND(100)
-------
Plant Name
B
EIA Plant Code
Unit No.
RunNumber
CoalFlowRate
HHV
pctSulphur
H
pctMoisture
I
pctAsh
Chlorine
& ORIS Code
(kg/hr), dry
Btu/lb
mg/kg or ppm
Colstrip
Colstrip
Columbia
0128250000-06076
0128250000-06076
0208560000-08023
373615
366517
205968
10568
0.74
12
10688
0.76
11.4
12261
0.43
30.43
18
17.3
6.49
ND(100)
100
292
64
Columbia
0208560000-08023
210060
12120
0.43
29.09
6.2
347
0208560000-
0154660000-
0154660000-
0154660000-
0615720000-
08023
•00470
•00470
•00470
•06177
208610
12182
0.42
29.77
133163
11891.63
0.43
27.1
130385
11891.63
0.43
27.1
135158
11891.63
0.43
27.1
159600
11187
0.53
13.26
5.38
6.45
6.45
6.45
17.76
303
ND(100)
ND(100)
ND(100)
100
70
Coronado
0615720000-06177
158800
11439
0.49
13.62
17.08
ND(100)
Coronado
Coyote
Coyote
Coyote
Craig
0615720000-
0128190000-
0128190000-
0128190000-
0301510000-
•06177
08222
08222
08222
06021
162900
11262
0.51
13.53
180563
11080
1.33
35.23
184283
106.73
2.07
35.12
179437
10904
1.76
35.11
155754
12322
0.52
15.84
18.25
11.1
13.26
12.68
8.02
200
ND(200)
ND(200)
ND(200)
400
76
Craig
0301510000-06021
159979
12447
0.52
14.81
8.17
200
81
Craig
Craig
Craig
Craig
Dunkirk
0301510000-
0301510000-
0301510000-
0301510000-
0135730000-
06021
06021
06021
06021
02554
155324
12451
0.58
18.08
157201
12549
0.47
17.09
156035
12624
0.44
17.11
153356
12562
0.49
17.94
13907
2.31
5.76
6.37
6.63
5.96
6.4
7.4
200
100
ND(100)
200
811
82
Dunkirk
0135730000-02554
14022
2.23
5.1
7.8
925
Dunkirk
Dwayne Collier Battle Cogeneration Facility
Dwayne Collier Battle Cogeneration Facility
Dwayne Collier Battle Cogeneration Facility
Gaston
0135730000-02554
10384
10384
10384
0001950000-00026
13819
2.25
6.6
13820
0.73
4.5
13900
0.76
4.37
13930
0.77
4.43
13560
0.8
6.97
8.92
7.16
6.94
6.42
13.2
880
1500
1800
1800
300
Gaston
0001950000-00026
13300
1.03
6.58
13.8
300
Gaston
George Neal south
George Neal south
George Neal south
Gibson Generating Station (10/99 testing)
0001950000-
0123410000-
0123410000-
0123410000-
0154700000-
00026
07343
07343
07343
06113
13640
0.83
7.33
12003
0.42
27.89
12014
0.44
28.31
11901
0.44
30.03
12530
1.71
13.6
12.1
7.6
7.61
8.64
13.1
400
200
100
273
1900
94
Gibson Generating Station (10/99 testing)
0154700000-06113
12570
1.74
12.6
12.9
2200
95
Gibson Generating Station (10/99 testing)
0154700000-06113
12570
1.71
12.8
13.1
2200
96
Gibson Generating Station (03/00 testing)
0154700000-06113
11640
1.45
7.38
12.2
1700
97
Gibson Generating Station (03/00 testing)
0154700000-06113
11630
1.45
7.81
12.9
1700
Gibson Generating Station (03/00 testing)
GRDA
100 GRDA
101
102
GRDA
Intermountain
0154700000-
0074900000-
0074900000-
0074900000-
0112080000-
06113
00165
00165
00165
06481
11550
1.57
8.19
12091
0.71
24.16
12186
0.73
24.9
12096
0.88
24.25
12986
0.68
7.52
13.9
8.11
8.04
8.46
9.16
2200
379
386
431
300
103
Intermountain
0112080000-06481
13022
0.67
7.77
9.36
200
104 Intermountain
losl Jack Watson
lo§ Jack Watson
107 Jack Watson
108 Jim Bridger
109 Jim Bridger
110 Jim Bridger
111 Kline Township Cogen Facility
112 Kline Township Cogen Facility
113 Kline Township Cogen Facility
114| La Cygne
0112080000-
0126860000-
0126860000-
0126860000-
0143540000-
06481
02049
02049
02049
08066
12949
0.63
7.31
13080
1.02
13080
1.06
3.4
13070
1.03
3.34
11821
0.71
19.03
0143540000-08066
11963
0.64
19.51
0143540000-08066
50039
50039
50039
0100000000-01241
11973
0.69
19.55
5110
5050
4930
0.43
9.51
0.44
8.54
0.38
7.94
11800
1.22
25.5
9.36
6.84
6.97
7.12
11.83
11.45
10.85
58.3
58.7
61
11.4
100
833
725
724
ND(100)
ND(100)
ND(100)
300
200
300
300
115
116
117
118
La Cygne
0100000000-01241
11740
1.31
24.7
11.7
300
La Cygne
Laramie River Station
Laramie River Station
0100000000-01241
0013070000-06204
0013070000-06204
11800
1.2
23.4
11860
0.52
31.05
197203
11940
0.52
31.21
10.8
7.84
7.63
300
87
78
-------
Laramie River Station
Laramie River Station
0013070000-06204
0013070000-06204
Laramie River Station
Laramie River Station
Lawrence
Lawrence
Lawrence
Leland Olds Station
0013070000
0002250000
0002250000
0002250000
0013070000
06204
01250
01250
01250
02817
Leland Olds Station
Leland Olds Station
Lewis & Clark
Lewis & Clark
Lewis & Clark
Limestone
0013070000
0128190000
0128190000
0128190000
0089010000
Limestone
Logan Generating Plant
Logan Generating Plant
Logan Generating Plant
Mecklenburg Cogeneration Facility
0089010000-
10043
10043
10043
52007
LIM1
Gen 1
Gen 1
Gen 1
GEN1
Mecklenburg Cogeneration Facility
Mecklenburg Cogeneration Facility
ramec
Meramec
Me ramec
Monticello
02104
02104
02104
06147
Monticello
nticello
nticello
nticello
Montrose
0443720000
0443720000
0443720000
0443720000
0100000000
06147
06147
06147
06147
02080
0100000000
0165720000
0165720000
0165720000
0208560000
02080
04941
04941
04941
04054
Nelson Dewey
ewton
0208560000
0032530000
0032530000
0032530000
0137810000
04054
06017
06017
06017
06090
Northern States Power - Sherburne County Generating Plant
Northern States Power - Sherburne County Generating Plant
Northern States Power - Sherburne County Generating Plant
latte
0137810000
0406060000
0406060000
0406060000
0184540000
Polk Power
Port Washington
Port Washington
Port Washington
Presque Isle
0184540000
0208470000
0208470000
0208470000
0208470000
07242
04040
04040
04040
01769
-------
Presque Isle
Presque Isle
Presque Isle
Presque Isle
0208470000-01769
0208470000-01769
0208470000-01769
0208470000-01769
182 Presque Isle
1831R. D. Morrow Sr. Generating plant
184 R. D. Morrow Sr. Generating plant
185 R. D. Morrow Sr. Generating plant
1861R.M. Heskett Station
0208470000
0175680000
0175680000
0175680000
0128190000
01769
06061
06061
06061
02790
187 R.M. Heskett Station
188JR.M. Heskett Station
189] Rawhide
190] Rawhide
191] Rawhide
192lsalem Harbor
0128190000
0151430000
0151430000
0151430000
0134330000
02790
06761
06761
06761
01626
36658
111122
103104
193 Salem Harbor
194 Salem Harbor
1951 Sam Seymour
196 Sam Seymour
197 Sam Seymour
198 San Juan
0134330000
0112690000
0112690000
0112690000
0154730000
01626
06179
06179
06179
02451
200JSan Juan
201 Scrubgrass Generating Company L. P
202|Scrubgrass Generating Company L. P
203] Scrubgrass Generating Company L. P
2041SEI - Birchwood Power Facility
0154730000-
50974
50974
50974
54304
205 SEI - Birchwood Power Facility
206ISEI - Birchwood Power Facility
207 Shawnee Fossil Plant
208^Shawnee Fossil Plant
20§Shawnee Fossil Plant
210 St Clair Power Plant
01379
01379
01379
01743
211 StCair Power Pant
212 St Clair Power Plant
213^Stanton Station
2T4] Stanton Station
215 Stanton Station
216 Stanton Station
0051090000
0195140000
0195140000
0195140000
0195140000
217 Stanton Station
218ptanton Station
219| Stockton Cogen Company
220|Stockton Cogen Company
221 Stockton Cogen Company
222llNP-One
10
GEN1
GEN1
GEN1
U2
07030
04042
04042
04042
00477
0154660000
0139980000
0139980000
0139980000
0154700000
00477
02866
02866
02866
01010
V. H. Sammis
V. H. Sammis
Vabash River Generating Station
-------
Plant Name
B
EIA Plant Code
Unit No.
RunNumber
CoalFlowRate
HHV
pctSulphur
H
pctMoisture
I
pctAsh
Chlorine
& ORIS Code
(kg/hr), dry
Btu/lb
mg/kg or ppm
235|Wabash River Generating Station
0154700000-01010
89629
12530
2.75
15.7
12.7
600
§ abash River Generating Station
idows Creek Fossil Pla
idows Creek Fossil Plant
idows Creek Fossil Plant
240|Wyodak
0154700000-
0186420000-
0186420000-
0186420000-
0143540000-
•01010
00050
00050
00050
06101
89493
12540
2.89
15.9
41312
12633
0.59
8.89
41520
12744
0.51
9.45
40552
12769
0.53
9.23
145472
11550
0.87
29.67
13.1
11.4
10.4
10.2
10.04
600
400
300
300
ND(50)
241
Wyodak
0143540000-06101
BW91
145265
11677
0.84
29.77
9.4
ND(50)
242
243
Wyodak
0143540000-06101
BW91
147351
11640
0.81
30.29
9.7
ND(50)
244 XB = Excessive reagent blank caused the data to be unreliable
245
246
247
NA = Data was not included in report
LS = Test sample was broken, damaged, or lost during testing
248|or in transport
-------
Plant Name
Hg
CoalAnalysisMethod
M
FuelType
N
Inlet Flow Rate
temp_Gasln
mg/kg or ppm
dscm/hr
DegC
AES Cayuga (NY) (formerly NYSEG Milliken)
0.11
EPA 7471
Bituminous
549382.00
134.78
AES Cayuga (NY) (formerly NYSEG Milliken)
0.11
EPA 7471
Bituminous
563471.90
137
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49
50
51
52
53
54
55
56
57
58
59
60
AES Cayuga (NY) (formerly NYSEG Milliken)
AES Hawaii, Inc.
AES Hawaii, Inc.
AES Hawaii, Inc.
Antelope Valley Station
0.10
EPA 7471
Bituminous
0.03
D3684-94 - FICVAA
Subbituminous
0.03
D3684-94 - FICVAA
Subbituminous
0.02
D3684-94 - FICVAA
Subbituminous
0.06
EPA 7471
Lignite
560811.25
140.33
415320
137.2
427620
135.2
423900
137.2
2166565
154
Antelope Valley Station
0.071
EPA 7471
Lignite
2143628
151
Antelope Valley Station
Bailly
Bailly
Bailly
Bay Front Plant Generating
0.055
EPA 7471
0.07
ASTM 3684
0.08
ASTM 3684
0.06
ASTM 3684
0.06
ASTM 3684
Lignite
Bituminous/Petroleum Coke
Bituminous/Petroleum Coke
Bituminous/Petroleum Coke
Bituminous
2100474
154
2404954
176.3
2433488
167.3
2396825
175.1
232291
136
Bay Front Plant Generating
0.06
ASTM 3684
Bituminous
195145
132
Bay Front Plant Generating
Big Bend
Big Bend
Big Bend
Big Brown
0.06
ASTM 3684
0.177
EPA 7471
0.113
EPA 7471
0.125
EPA 7471
0.287
ASTM 6414
Bituminous
Bituminous
Bituminous
Bituminous
Lignite
191081
134
1440752
155
1440242
155
1421383
156
2049164
183
Big Brown
0.29
ASTM 6414
Lignite
2067102
186
Big Brown
Brayton Point
Brayton Point
Brayton Point
Brayton Point
0.287
ASTM 6414
0.08
ASTM 3684
0.05
ASTM 3684
0.06
ASTM 3684
0.1
ASTM 3684
Lignite
Bituminous
Bituminous
Bituminous
Bituminous
2108492
185
1219061
155
1228778
153
1237069
153
2836137
123
Brayton Point
0.07
ASTM 3684
Bituminous
2907989
123
Brayton Point
Bruce Mansfield
Bruce Mansfield
Bruce Mansfield
Charles R. Lowman
0.07
ASTM 3684
0.096
ASTM 6414
0.079
ASTM 6414
0.103
ASTM 6414
0.084
ASTM 6414
Bituminous
Bituminous
Bituminous
Bituminous
Bituminous
3025158
119
3160872
137
3183792
144
2883648
141
338513
146
Charles R. Lowman
0.077
ASTM 6414
Bituminous
344092
146
Charles R. Lowman
Cholla
Cholla
Cholla
Cholla
0.08
ASTM 6414
0.045
EPA 7471
0.04
EPA 7471
0.035
EPA 7471
0.04
ASTM 3684
Bituminous
Subbituminous
Subbituminous
Subbituminous
Subbituminous
329689
147
943921
136
814490
137
915890
137
938720
362
Cholla
0.04
ASTM 3684
Subbituminous
962341
358
Cholla
Clay Boswell
Clay Boswell
Clay Boswell
Clay Boswell
0.03
ASTM 3684
0.078
ASTM 6414
0.043
ASTM 6414
0.049
ASTM 6414
0.054
ASTM 6414
Subbituminous
Subbituminous
Subbituminous
Subbituminous
Subbituminous
934887
357
240607
179
268405
173
251138
175
1564633
139
Clay Boswell
0.072
ASTM 6414
Subbituminous
1560844
148
Clay Boswell
Clay Boswell
Clay Boswell
Clay Boswell
Cliffside
0.063
ASTM 6414
0.065
ASTM 6414
0.063
ASTM 6414
0.07
ASTM 6414
0.07
ASTM 3684
Subbituminous
Subbituminous
Subbituminous
Subbituminous
Bituminous
1528607
144
2133642
154
2104866
141
2015790
136
220456
343.9
Cliffside
0.05
ASTM 3684
Bituminous
221841
342.6
Cliffside
Cliffy Creek
Clifty Creek
Clifty Creek
Clover Power Station
0.06
ASTM 3684
0.08
ASTM 3684
0.08
ASTM 3684
0.08
ASTM 3684
0.12
EPA 7471
Bituminous
Subbitumino us/Bituminous
Subbitumino us/Bituminous
Subbitumino us/Bituminous
Bituminous
214583
340.8
746218
382
760863
385
760318
382
694552
139
Clover Power Station
0.17
EPA 7471
Bituminous
705133
139
Clover Power Station
Colstrip
0.20
EPA 7471
0.063
ASTM 6414
Bituminous
Subbituminous
696696
139
3362880
140
-------
Plant Name
Hg
CoalAnalysisMethod
M
FuelType
N
Inlet Flow Rate
temp_Gasln
mg/kg or ppm
dscm/hr
DegC
Colstrip
Colstrip
Columbia
0.066
ASTM6414
0.067
ASTM6414
0.1
ASTM 3684
Subbituminous
Subbituminous
Subbituminous
3391696
142
3441304
136
2188995
406
64
Columbia
0.1
ASTM 3684
Subbituminous
2159390
403
0.1
ASTM 3684
0.09
EPA 1631
0.10
EPA 1631
0.09
EPA 1631
0.035
EPA 7371/1631
Subbituminous
Subbituminous
Subbituminous
Subbituminous
Subbituminous
2158955
409
1246033
142.78
1252037
150
1270674
141.67
1405808
136
70
Coronado
0.039
EPA 7371/1631
Subbituminous
1398779
135
Coronado
Coyote
Coyote
Coyote
Craig
0.031
EPA 7371/1631
0.088
EPA 3050/7471
0.15
EPA 3050/7471
0.094
EPA 3050/7471
0.022
EPA 1631/7371
Subbituminous
Lignite
Lignite
Lignite
Subbituminous
1392035
143
2126971
163
2111511
176
2083307
177
1842363
121
76
Craig
0.025
EPA 1631/7371
Subbituminous
1875084
124
81
Craig
Craig
Craig
Craig
Dunkirk
0.021
EPA 1631/7371
0.011
EPA 1631/7371
0.01
EPA 1631/7371
0.009
EPA 1631/7371
0.13
ASTM 3684
Subbituminous
Subbituminous
Subbituminous
Subbituminous
Bituminous
1919707
118
1650793
138
1651990
146
1654007
133
478725
303.4
82
Dunkirk
0.13
ASTM 3684
Bituminous
460709
304.5
Dunkirk
Dwayne Collier Battle Cogeneration Facility
Dwayne Collier Battle Cogeneration Facility
Dwayne Collier Battle Cogeneration Facility
Gaston
0.13
ASTM 3684
ND(0.06)
EPA 7471
ND(0.06)
EPA 7471
ND(0.06)
EPA 7471
0.054
EPA 7471
Bituminous
Bituminous
Bituminous
Bituminous
Bituminous
466192
306.4
124965
167
120578
167
122308
169
914665
336
Gaston
0.067
EPA 7471
Bituminous
893577
334
Gaston
George Neal south
George Neal south
George Neal south
Gibson Generating Station (10/99 testing)
0.057
EPA 7471
0.09
ASTM 3684
0.08
ASTM 3684
0.1
ASTM 3684
0.134
ASTM 6414
Bituminous
Subbituminous
Subbituminous
Subbituminous
Bituminous
931343
339
2633333
149
2709436
153
2688240
154
2343261
158
94
Gibson Generating Station (10/99 testing)
0.142
ASTM 6414
Bituminous
2353191
162
95
Gibson Generating Station (10/99 testing)
0.141
ASTM 6414
Bituminous
2371609
163
96
Gibson Generating Station (03/00 testing)
0.117
ASTM 6414
Bituminous
2544538
156
97
Gibson Generating Station (03/00 testing)
0.115
ASTM 6414
Bituminous
2525292
157
Gibson Generating Station (03/00 testing)
GRDA
100 GRDA
101
102
GRDA
Intermountain
0.123
ASTM 6414
0.1
ASTM 3684
0.1
ASTM 3684
0.1
ASTM 3684
0.02
ASTM 3684
Bituminous
Subbitumino us/Bituminous
Subbitumino us/Bituminous
Subbitumino us/Bituminous
Bituminous
2551178
155
1795109
154.8
1814982
156.6
1808161
155.8
3312000
152
103
Intermountain
0.02
ASTM 3684
Bituminous
3336000
152
104 Intermountain
losl Jack Watson
lo§ Jack Watson
107 Jack Watson
108 Jim Bridger
0.03
ASTM 3684
0.05
EPA 7471
0.052
EPA 7471
0.059
EPA 7471
0.08
Other
Bituminous
Bituminous
Bituminous
Bituminous
Subbituminous
3372000
149
1072801
155
934375
148
978658
146
2833202
147
109 Jim Bridger
0.08
Other
Subbituminous
2701314
146
110 Jim Bridger
Kline Township Cogen Facility
Kline Township Cogen Facility
Kline Township Cogen Facility
La Cygne
111
112
113
114
115
116
117
118
La Cygne
La Cygne
Laramie River Station
Laramie River Station
0.06
Other
0.3
EPA 7471
EPA 7471
EPA 7471
0.11
ASTM 6414
0.102
ASTM 6414
0.098
ASTM 6414
Subbituminous
Waste Anthracite
Waste Anthracite
Waste Anthracite
2729912
145
322630
188
311820
186
327118
Subbituminous NA
Subbituminous NA
Subbituminous NA
189
144
144
144
0.103
EPA 3051/3052/7471
Subbituminous
0.111
EPA 3051/3052/7471
Subbituminous
2330443
2278573
141.1
138.3
-------
Laramie River Station
Laramie River Station
Laramie River Station
Laramie River Station
Lawrence
Lawrence
Lawrence
Leland Olds Station
Leland Olds Station
Leland Olds Station
Lewis & Clark
Lewis & Clark
Lewis & Clark
Limestone
Limestone
Logan Generating Plant
Logan Generating Plant
Logan Generating Plant
Mecklenburg Cogeneration Facility
Mecklenburg Cogeneration Facility
Mecklenburg Cogeneration Facility
ramec
Meramec
Me ramec
Monticello
Monticello
nticello
nticello
nticello
Montrose
Nelson Dewey
ewton
Northern States Power - Sherburne County Generating Plant
Northern States Power - Sherburne County Generating Plant
Northern States Power - Sherburne County Generating Plant
latte
Polk Power
Port Washington
Port Washington
Port Washington
Presque Isle
Hg
CoalAnalysisMethod
M
FuelType
N
Inlet Flow Rate
temp_Gasln
mg/kg or ppm
dscm/hr
DegC
0.144
EPA 3051/3052/7471
Subbituminous
0.118
EPA 3051/3052/7471
Subbituminous
2298553
136.1
2648783
137.7
0.142
EPA 3051/3052/7471
Subbituminous
2776514
140.6
0.114
EPA 3051/3052/7471
Subbituminous
0.052
ASTM6414
0.044
ASTM6414
0.047
ASTM6414
ND(0.05)
EPA 7471
Subbituminous
Subbituminous
Subbituminous
Lignite
2645760
136.1
376788
172
382234
157
381990
169
1830157
199
0.056
EPA 7471
Lignite
1895399
201
ND(0.05)
EPA 7471
0.107
7471A
0.121
7471A
0.13
7471A
0.121
ASTM 3684
Lignite
Lignite
Lignite
Lignite
Lignite
1826759
205
207448
195
214924
198
214924
203
4920304
156
0.171
ASTM 3684
Lignite
4845548
162
0.125
ASTM 3684
0.19
ASTM 3684
0.18
ASTM 3684
0.17
ASTM 3684
0.09
ASTM 3684
Lignite
Bituminous
Bituminous
Bituminous
Bituminous
4818364
167
769254
145
759560
149
763218
148
225117
149.4
0.11
ASTM 3684
Bituminous
243126
147.2
0.09
ASTM 3684
0.085
ASTM 3684
0.12
ASTM 3684
0.068
ASTM 3684
0.318
ASTM 6414
Bituminous
Subbitumino us/Bituminous
Subbitumino us/Bituminous
Subbitumino us/Bituminous
Lignite
227410
147.2
1610937
169
1405042
172
1278496
168
1925000
178
0.325
ASTM 6414
Lignite
2214400
183
0.472
ASTM 6414
0.388
ASTM 6414
0.375
ASTM 6414
0.482
ASTM 6414
0.089
ASTM 6414
Lignite
Lignite
Lignite
Lignite
Subbituminous
2330200
182
4179262
179
4120503
175
4322378
175
158080
155.5
0.107
ASTM 6414
Subbituminous
159491
157.8
0.103
ASTM 6414
0.040
EPA 7371/1631
0.024
EPA 7371/1631
0.027
EPA 7371/1631
0.06
ASTM 3684
Subbituminous
Bituminous
Bituminous
Bituminous
Subbituminous/Petroleum Coke
158977
161.7
3055474
157
3004856
152
3077836
156.
387802
254
0.06
ASTM 3684
Subbituminous/Petroleum Coke
379100
257
0.06
ASTM 3684
0.074
EPA 7473
0.068
EPA 7473
0.070
EPA 7473
0.08
ASTM 3684
Subbituminous/Petroleum Coke
Subbituminous
Subbituminous
Subbituminous
Subbituminous
390626
260
1882980
169
1830477
150
1901994
164
3344159
145
0.08
ASTM 3684
Subbituminous
3362593
147
0.07
ASTM 3684
0.11
ASTM 3684
0.09
ASTM 3684
0.07
ASTM 3684
ND(0.1)
EPA 7471
Subbituminous
Subbituminous
Subbituminous
Subbituminous
Bituminous
3315734
150
382795
411.8
377498
413.2
379912
415.9
ND(0.1)
EPA 7471
Bituminous
ND(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
344842
403.8
340791
406.7
339646
406.4
407436.43
170
0.04
Proposed ASTM Method
Bituminous/Petroleum Coke
421072.69
172.22
0.04
Proposed ASTM Method
Bituminous/Petroleum Coke
416619.58
174.44
-------
Presque Isle
Presque Isle
Presque Isle
Presque Isle
182 Presque Isle
1831R. D. Morrow Sr. Generating plant
184 R. D. Morrow Sr. Generating plant
185 R. D. Morrow Sr. Generating plant
1861R.M. Heskett Station
187 R.M. Heskett Station
188JR.M. Heskett Station
189] Rawhide
190] Rawhide
191] Rawhide
192lsalem Harbor
193 Salem Harbor
194 Salem Harbor
1951 Sam Seymour
196 Sam Seymour
197 Sam Seymour
198 San Juan
200JSan Juan
201 Scrubgrass Generating Company L. P
202|Scrubgrass Generating Company L. P
203] Scrubgrass Generating Company L. P
2041SEI - Birchwood Power Facility
205 SEI - Birchwood Power Facility
206ISEI - Birchwood Power Facility
207 Shawnee Fossil Plant
208^Shawnee Fossil Plant
20§Shawnee Fossil Plant
210 St Clair Power Plant
211 StCair Power Pant
212 St Clair Power Plant
213^Stanton Station
2T4] Stanton Station
215 Stanton Station
216 Stanton Station
217 Stanton Station
218ptanton Station
219| Stockton Cogen Company
220|Stockton Cogen Company
221 Stockton Cogen Company
222llNP-One
V. H. Sammis
V. H. Sammis
Vabash River Generating Station
Hg
CoalAnalysisMethod
M
FuelType
N
Inlet Flow Rate
temp_Gasln
mg/kg or ppm
dscm/hr
DegC
0.07
Proposed ASTM Method
Bituminous/Petroleum Coke
0.07
Proposed ASTM Method
Bituminous/Petroleum Coke
0.07
Proposed ASTM Method
Bituminous/Petroleum Coke
0.03
Proposed ASTM Method
Subbituminous
304913.01
375.56
318501.70
381.67
311204.45
387.78
371896.52
153.89
0.05
Proposed ASTM Method
Subbituminous
363848.30
152.78
0.04
Proposed ASTM Method
Subbituminous
ND(0.1)
EPA 7471
ND(0.1)
EPA 7471
ND(0.1)
EPA 7471
0.098
EPA 7471A
Bituminous
Bituminous
Bituminous
Lignite
370661.34
153.33
850873
166
869922
166
808602
167
381222
164
0.088
EPA 7471A
Lignite
360188
157
0.073
EPA 7471A
0.07
ASTM 3684
0.07
ASTM 3684
0.08
ASTM 3684
0.03
ASTM 3684
Lignite
Subbituminous
Subbituminous
Subbituminous
Bituminous
338645
166
1088760
171.2
1055239
170.5
1068097
171.1
705491
124
0.02
ASTM 3684
Bituminous
672460
126
0.03
ASTM 3684
0.139
EPA 7471A
0.115
EPA 7471A
0.114
EPA 7471A
0.045
EPA 7371/1631
Bituminous
Subbituminous
Subbituminous
Subbituminous
Subbituminous
677049
127
742598
152
771746
150
664148
147
1046292
145.5
0.051
EPA 7371/1631
Subbituminous
962604
136.6
0.065
EPA 7371/1631
0.55
ASTM 3684
0.52
ASTM 3684
0.51
ASTM 3684
0.11
EPA 7471
Subbituminous
Waste Bituminous
Waste Bituminous
Waste Bituminous
Bituminous
964490
146.6
217768
159
222024
161
213797
163
776654
134
0.11
EPA 7471
Bituminous
763255
132
0.11
EPA 7471
0.022
ASTM 6414
0.039
ASTM 6414
0.024
ASTM 6414
0.06
ASTM 6414
Bituminous
Bituminous/Subbituminous
Bituminous/Subbituminous
Bituminous/Subbituminous
Subbitumino us/Bituminous
747652
136
603793
159
613149
157
616736
157
707478
138
0.055
ASTM 6414
Subbitumino us/Bituminous
717298
140
0.069
ASTM 6414
0.086
EPA 3051/7471
0.105
EPA 3051/7471
0.056
EPA 3051/7471
0.0865
EPA 3051/7471
Subbitumino us/Bituminous
Lignite
Lignite
Lignite
Lignite
778622
141
317712
173.3
292227
157.2
319411
164.4
280334
169.1
0.101
EPA 3051/7471
Lignite
275237
172.2
0.063
EPA 3051/7471
0.026
ASTM 3684
0.026
ASTM 3684
0.029
ASTM 3684
0.222
ASTM 6414
Lignite
Bituminous/Petroleum Coke
Bituminous/Petroleum Coke
Bituminous/Petroleum Coke
Lignite
275237
186.7
274312
150
268688
148
275359
147
555305
184
0.18
ASTM 6414
Lignite
584340
181
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
573407
177
334586
157.0
339094
156.6
331724
156.4
858556
142
0.0055
MODIFIED EPA 3051/7471A
Bituminous
844486
143
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
849780
156
739403
161
729449
157
706103
156
------- 1 2 235 A Plant Name Wabash River Generating Station § abash River Generating Station idows Creek Fossil Plant idows Creek Fossil Plant idows Creek Fossil Plant 240 Wyodak 241 242 243 244 245 246 247 248 Wyodak Wyodak XB = Excessive reagent blank caused the data to be unreliable NA = Data was not included in report LS = Test sample was broken, damaged, or lost during testing or in transport K Hg mg/kg or ppm 0.068 0.07 0.029 0.024 0.021 0.03 0.04 0.05 L CoalAnalysisMethod ASTM6414 ASTM6414 ASTM6414 ASTM6414 ASTM6414 ASTM 3684 ASTM 3684 ASTM 3684 M FuelType Bituminous Bituminous Bituminous Bituminous Bituminous Subbituminous Subbituminous Subbituminous N Inlet Flow Rate dscm/hr 438532 436101 445789 1928365 1 789047 1712592 0 temp Gasln DegC 160 162 159 162 158 160 ------- 1 2 3 4 5 6 7 9 10 11 12 13 14 15 16 17 18 19 21 22 23 24 25 OR 27 28 29 30 31 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 51 52 53 54 55 56 57 58 59 60 A Plant Name AES Cayuga (NY) (formerly NYSEG Milliken) AES Cayuga (NY) (formerly NYSEG Milliken) AES Cayuga (NY) (formerly NYSEG Milliken) AES Hawaii, Inc. AES Hawaii, Inc. Antelope Valley Station Antelope Valley Station Antelope Valley Station Bailly Bailly Bay Front Plant Generating Bay Front Plant Generating Bay Front Plant Generating Big Bend Big Bend Big Brown Big Brown Big Brown Brayton Point Brayton Point Brayton Point Brayton Point Brayton Point Bruce Mansfield Bruce Mansfield Charles R. Lowman Charles R. Lowman Charles R. Lowman Cholla Cholla Cholla Cholla Cholla Clay Boswell Clay Boswell Clay Boswell Clay Boswell Clay Boswell Clay Boswell Clay Boswell Clay Boswell Cliffside Cliffside Cliffside Cliffy Creek Clifty Creek Clifty Creek Clover Power Station Clover Power Station Clover Power Station P pet StackGasMoistureln % 8 8.1 8.1 8.7 8.1 15.4 15 14.8 8.63 8.22 8.19 9.82 7.18 7.12 9.1 9 14.67 13.53 13.79 7.55 7.7 Q (\C, 8.9 9.3 7.45 7.3 6.69 7.02 6.45 7.48 8.8 9.2 8 7 9.7 9.5 9.3 10.5 10.4 11.4 10.8 12.5 11.4 10.4 11.5 8.71 8.61 9.01 12.01 11.62 11.42 6 6.15 6.15 Colstrip 9.58 Q pet StackGasO2ln % 4.9 5.28 5.16 8.0 8.0 5.4 5.4 5.4 5.63 5.7 6.28 8.7 8.3 9.0 4.1 4.4 5.6 5.2 5.2 6.68 6.8 7 n 8.1 7.25 6.85 7.1 7 6.2 6.7 6.8 4.7 3.8 3 8 3.8 3.9 3.7 6.0 6.7 6.4 5.4 5.4 5.5 5.6 5.2 4.3 4.3 4.4 3.9 3.8 3.7 4.5 4.7 4.75 4.6 R Hg ParticleBoundln ug/dscm NA 0.72 1.62 0.19 0.25 ND(0.13) ND(0.18) 0.14 0.036 0.05 0.06 0.52 0.76 0.06 XB XB XB 2.22 0.47 0.2 1.6 2.06 1 R^ 2.11 1.46 1.05 0.33 0.57 XB 1.23 2.72 XB 0.95 XB XB XB XB 2.29 1.58 0.67 0.01 ND(0.02) 0.05 0.09 2.62 0.16 0.08 0.07 0.38 0.02 ND(0.01) 0.05 0.03 0.07 1.62 S Hg Oxidizedln ug/dscm 5.25 5.59 4.88 ND(0.056) 0.12 0.33 0.36 0.14 2.92 1.95 2.76 0.53 0.47 0.51 4.56 4.54 7.14 9.1 12.41 2.66 2.88 0 71 2.75 2.41 2.55 6.68 7.65 2.74 3.16 2.8 0.61 NA 1 21 ND(0.08) 0.3 0.41 1.51 1 0.93 0.22 0.27 0.53 0.28 0.94 3.45 3.28 3.83 2.23 3.42 3.28 0.86 0.94 1.02 2.09 T Hg Elementalln ug/dscm 1.91 2.10 2.42 0.79 0.94 6.76 6.94 6.81 2.41 2.65 2.22 1.48 1.37 1.16 2.25 2.13 26.73 23.97 19.25 0.401 0.318 n ^n^ 0.39 0.379 2.39 1.22 1.62 1.72 1.72 1.59 4.24 2.5 2 86 1.84 0.44 0.59 1.33 1.16 2.02 5.25 5.2 4.49 4.32 1.29 3.07 4.31 6.7 10.61 10.64 11.01 0.96 1.09 0.54 0.98 U Outlet Flow Rate dscm/hr 609379.18 609569.47 616217.70 399840 411360 1915792 1932952 1873657 2083127 2107800 2086775 95812 110435 105389 1904069 1907467 2351953 2345298 2332550 1031980 1028595 1 nc>fiRQ9 2547085 2520381 2493881 3050116 3041448 961444 955671 963479 986504 978703 99051 7 1101701 1085343 1077618 252527 243054 238502 1627639 1668489 1657786 2191238 2182773 220456 221841 214583 989499 880430 947181 1636723 1651090 1659892 3143106
-------
Plant Name
pct_StackGasMoistureln
Q
pct_StackGasO2l n
Hg_ParticleBoundln
Hg_Oxidizedln
Hg_Elementalln
y
Outlet Flow Rate
Colstrip
Colstrip
Columbia
9.54
10.71
13.48
4.6
1.77
ug/dscm
ug/dscm
ug/dscm
dscm/hr
2.16
5.8
4.8
1.47
2.57
4.85
3.8
0.02
0.89
13.64
3124774
3157213
2188995
64
Columbia
13.91
0.03
5.5
12.66
2159390
11.85
4.2
0.04
0.43
13.67
2158955
10
9.4
10.6
10.05
5.4
1.70
2.95
4.61
6.5
2.15
0.87
4.27
5.2
4.69
0.69
3.01
4.94
ND(0.05)
0.88
1.95
1262340
1253400
1290710
1385518
70
Coronado
9.58
4.27
ND(0.05)
0.76
1.73
1380391
Coronado
Coyote
Coyote
Coyote
Craig
10.27
13.8
13.7
14
8.43
3.97
ND(0.05)
1.03
1.77
8.2
0.49
1.15
9.73
8.3
0.83
2.1
9.81
8.2
1.2
2.18
10.6
7.32
ND(0.06)
0.25
2.74
1363637
2126971
2111511
2083307
1741594
76
Craig
8.33
7.24
ND(0.06)
0.22
1.93
1711326
Craig
Craig
Craig
Craig
Dunkirk
7.98
7.69
ND(0.06)
0.12
1.47
1767065
81
9.74
9.13
8.66
8.0
6.57
0.46
0.52
0.24
6.36
0.75
0.41
0.23
6.36
0.73
0.19
0.18
5.1
0.16
7.56
2.49
1897089
1902028
1868838
481326
82
Dunkirk
8.83
4.9
.25
7.97
1.28
464347
Dunkirk
Dwayne Collier Battle Cogeneration Facility
Dwayne Collier Battle Cogeneration Facility
Dwayne Collier Battle Cogeneration Facility
Gaston
8.47
7.4
7.8
7.9
4.4
.32
8.43
2.91
4.3
2.03
ND(0.05)
ND(0.17)
4.3
1.93
0.17
0.39
4.3
1.85
ND(0.06)
ND(0.20)
4.2
3.99
0.8
2.46
469910
135128
132796
132687
938079
Gaston
8.7
4.2
2.4
0.66
3.32
973011
Gaston
George Neal south
George Neal south
George Neal south
Gibson Generating Station (10/99 testing)
7.5
12.94
13.04
12.7
7.92
4.1
0.4
3.7
2.66
5.5
0.147
4.11
5.4
6.2
0.058
3.57
6.78
6.8
ND(0.03)
2.79
2.97
5.6
4.77
8.84
2.15
980478
2630138
2671453
2660146
2587937
94
Gibson Generating Station (10/99 testing)
4.63
5.4
23.92
3.28
1.31
2952993
95
Gibson Generating Station (10/99 testing)
8.20
5.2
4.09
9.67
1.62
3508960
96
Gibson Generating Station (03/00 testing)
7.21
6.0
1.62
26.45
3.66
3195060
97
Gibson Generating Station (03/00 testing)
7.92
6.2
1.03
31.29
2.4
3152365
Gibson Generating Station (03/00 testing)
GRDA
100 GRDA
101
102
GRDA
Intermountain
7.48
12.59
6.2
1.44
36.54
1.36
5.4
0.22
3.83
6.73
5.6
0.45
2.54
5.56
5.2
1.0
7.71
3.26
4.5
ND(0.018)
0.94
0.125
3189981
1974682
2007962
1970052
3312000
103
Intermountain
4.4
ND(0.016)
1.05
0.127
3336000
104 Intermountain
losl Jack Watson
lo§ Jack Watson
107 Jack Watson
108 Jim Bridger
5.1
ND(0.017)
1.21
0.145
6.7
2.86
0.97
0.73
6.7
3.9
0.92
0.2
6.8
3.66
0.47
ND(0.15)
5.8
0.04
2.1
4.4
3372000
1043609
961264
971814
2187085
109 Jim Bridger
6.0
0.37
1.7
4.55
2133973
110 Jim Bridger
111 Kline Township Cogen Facility
112 Kline Township Cogen Facility
113 Kline Township Cogen Facility
114| La Cygne
5.8
0.06
1.5
3.66
2.4
46.02
ND(0.12)
0.47
2.4
44.56
ND(0.06)
0.41
2.1
47.22
ND(0.06)
0.36
5.4
5.81
3.46
1.13
2159407
285771
278346
276877
2871424
115
116
117
118
La Cygne
5.3
5.69
2.91
ND(1.04)
2856858
La Cygne
Laramie River Station
Laramie River Station
10.93
12.8
11.9
5.6
5.12
ND(1.01)
ND(1.04)
10
0.154
1.921
4.593
10.1
0.023
1.3058
5.055
2897940
2376027
2295053
-------
pet StackGasMoistureln
pet StackGasO2ln
Hg ParticleBoundln
Outlet Flow Rate
ug/dscm
ND(0.02)
Laramie River Station
Laramie River Station
Laramie River Station
Laramie River Station
Lawrence
Lawrence
Lawrence
Leland Olds Station
Leland Olds Station
Leland Olds Station
Lewis & Clark
Lewis & Clark
Lewis & Clark
Limestone
Limestone
Logan Generating Plant
Logan Generating Plant
Logan Generating Plant
Mecklenburg Cogeneration Facility
Mecklenburg Cogeneration Facility
Mecklenburg Cogeneration Facility
ramec
Meramec
Me ramec
Monticello
Monticello
nticello
nticello
nticello
Montrose
Nelson Dewey
ewton
Northern States Power - Sherburne County Generating Plant
Northern States Power - Sherburne County Generating Plant
Northern States Power - Sherburne County Generating Plant
latte
Polk Power
Port Washington
Port Washington
Port Washington
Presque Isle
-------
pet StackGasMoistureln
pet StackGasO2ln
Hg ParticleBoundln
Outlet Flow Rate
Presque Isle
Presque Isle
Presque Isle
Presque Isle
182 Presque Isle
1831R. D. Morrow Sr. Generating plant
184 R. D. Morrow Sr. Generating plant
185 R. D. Morrow Sr. Generating plant
1861R.M. Heskett Station
187 R.M. Heskett Station
188JR.M. Heskett Station
189] Rawhide
190] Rawhide
191] Rawhide
192lsalem Harbor
193 Salem Harbor
194 Salem Harbor
1951 Sam Seymour
196 Sam Seymour
197 Sam Seymour
198 San Juan
200JSan Juan
201 Scrubgrass Generating Company L. P
202|Scrubgrass Generating Company L. P
203] Scrubgrass Generating Company L. P
2041SEI - Birchwood Power Facility
205 SEI - Birchwood Power Facility
206ISEI - Birchwood Power Facility
207 Shawnee Fossil Plant
208^Shawnee Fossil Plant
20§Shawnee Fossil Plant
210 St Clair Power Plant
211 StCair Power Pant
212 St Clair Power Plant
213^Stanton Station
2T4lStanton Station
215 Stanton Station
216 Stanton Station
217 Stanton Station
2j[8JStanton Station
219| Stockton Cogen Company
220|Stockton Cogen Company
221 Stockton Cogen Company
222llNP-One
V. H. Sammis
V. H. Sammis
Vabash River Generating Station
------- 1 2 235 A Plant Name Wabash River Generating Station 236|Wabash River Generating Station 240 Wyodak 241 242 243 244 245 246 247 248 Wyodak Wyodak XB = Excessive reagent blank caused the data to be unreliable NA = Data was not included in report LS = Test sample was broken, damaged, or lost during testing or in transport P pet StackGasMoistureln % 7.73 7.29 7.6 9.3 9.9 9.8 Q pet StackGasO2ln % 5.2 5.6 5 8 8 7.4 R Hg ParticleBoundln ug/dscm 2.95 2.55 2.55 1.8 2.2 1.7 S Hg Oxidizedln ug/dscm ND(0.78) ND(0.77) ND(0.83) 2.8 3.4 2.7 T Hg Elementalln ug/dscm ND(0.94) ND(0.87) ND(0.88) 8.2 6.8 8.7 U Outlet Flow Rate dscm/hr 1385884 1352458 496976 500143 500532 1906278 1913074 1952151 ------- 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 39 40 41 42 43 45 46 47 48 49 50 51 52 53 54 55 57 58 59 60 A Plant Name AES 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 Station Antelope Valley Station Antelope Valley Station Bailly Bailly Bailly Bay Front Plant Generating Bay Front Plant Generating Bay Front Plant Generating Big Bend Big Bend Big Brown Big Brown Big Brown Brayton Point Brayton Point Brayton Point Brayton Point Brayton Point Brayton Point Bruce Mansfield Bruce Mansfield Bruce Mansfield Charles R. Lowman Charles R. Lowman Charles R. Lowman Cholla Cholla Cholla Cholla Cholla Clay Boswell Clay Boswell Clay Boswell Clay Boswell Clay Boswell Clay Boswell Clay Boswell Clay Boswell Cliffside Cliffside Cliffside Cliffy Creek Clifty Creek Clover Power Station Clover Power Station Clover Power Station Colstrip V temp GasOut DegC 49.89 50.44 49.94 133.7 133.2 133.7 86 82 84 54.5 53.9 54.2 135 132 134 52 52 167 171 164 144 144 141 127 126 121 52 53 52 122 121 123 86.7 86.7 159 155 159 169 166 51 51 51 67 68 69 195.1 196.6 191.7 170 166 50.6 50 50 89 W pet StackGasMoistureOut % 14.2 14.4 14 7.7 7.5 8.2 18.9 18.4 18.4 15.5 14.5 15.06 8.10 7.15 7.17 13 9.9 12.4 12.78 13.47 6.7 7.4 7.4 8.3 7.6 7.0 15.37 14.75 12.76 8.46 7.41 8.43 13.4 13.5 8.5 8.7 8.6 10.4 10.5 13.3 13.8 13.6 13.8 14.0 14.3 8.05 8.46 7.95 9.91 8.64 11.9 12.3 12.1 15.6 X pet StackGasO2Out % 5.61 5.31 5.32 8.0 8.0 8.0 6 6 5.6 7.0 7.0 7.0 9.0 9.0 9.1 7.3 7.2 6 6.8 6.4 7.2 7.1 7.4 8.6 9.4 8.0 7.4 7.1 6.8 6.6 6.4 6.4 5.7 5.9 6.2 5.5 5.7 6.6 7.2 6.0 6.4 6.7 5.2 5.6 6.0 6.4 6.3 6.1 6.0 6.0 6.7 6.5 6.4 6.2 Y Hg ParticleBoundOut ug/dscm NA 0.013 0.02 ND(O.OOS) ND(0.002) ND(0.002) ND(0.01) 0.02 0.02 ND(0.002) ND(0.002) 0.003 0.79 0.57 0.32 XB XB 0.08 0.03 0.03 0.59 0.58 0.58 0.54 0.62 XB 0.14 0.14 0.13 0.03 0.05 0.02 XB XB XB XB XB 0.059 0.003 0.002 ND(0.001) 0.002 0.02 0.17 0.23 0.33 0.08 0.08 0.58 ND(0.01) 0.04 ND(0.02) 0.03 0.114 Z Hg OxidizedOut ug/dscm 0.26 0.14 0.13 ND(0.03) ND(0.03) ND(0.03) 0.21 0.66 0.27 0.28 0.24 0.3 0.4 1.83 2.36 0.16 0.09 13.82 13.93 15 2.94 2.46 2.28 2.19 1.59 2.48 1.43 2.11 0.96 1.34 1.51 1.67 0.18 0.12 0.42 NA 0.33 1.01 0.27 0.04 0.05 0.05 0.09 0.38 0.49 2.26 1.85 3.29 3 4.2 0.33 0.27 ND(0.08) ND(0.69) AA Hg ElementalOut ug/dscm 2.22 2.19 2.50 0.42 0.59 0.33 0.16 6.8 5.96 2.22 2.04 2.16 1.27 1.2 1.18 1.66 1.34 21 20.09 17.94 0.252 0.279 0.261 0.508 0.376 2.37 5.3 6.15 6.54 2.71 2.84 2.59 3.34 3.92 1.54 0.86 1.08 0.11 0.18 4.85 4.37 4.38 4.85 5.04 4.64 3.2 1.59 2.1 3.89 4.45 0.25 0.12 0.09 7.51 ------- 1 2 61 63 64 65 66 67 CQ "69" 70 71 72 73 75 76 77 78 79 Q(-l 81 82 83 84 85 86 87 88 89 90 91 92 93 94 95 96 97 98 99 100 101 102 103 A Plant Name V temp GasOut DegC Colstrip 89 Columbia Columbia Columbia Comanche Comanche Coronado Coronado Coronado Coyote Coyote Craig Craig Craig Craig Craig Dunkirk Dunkirk Dunkirk Dwayne Collier Battle Cogeneration Facility Dwayne Collier Battle Cogeneration Facility Dwayne Collier Battle Cogeneration Facility Gaston Gaston Gaston George Neal south George Neal south Gibson 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) Intermountain Intermountain 104 Intermountain 108 Jim Bridger 109 110 111 112 113 114 115 116 117 118 Jim Bridger Jim Bridger La Cygne La Cygne La Cygne Laramie River Station Laramie River Station 149 156 157 149.44 157.78 147 99 48 47 49 109 96 64 64 58 80.6 85.6 7Q A 293.4 295.2 295.8 85 86 86 128 124 128 138 142 144 171 171 173 154 154 157 84.0 84.2 84.2 49 49 48 157 150 150 54 53 54 173 174 174 72 72 74 64.4 63.3 W pet StackGasMoistureOut % 15.91 11.7 11.85 11.88 10.8 11.1 1 1 fi 13.7 12.9 13.8 15.2 16.8 10.91 13.04 11.48 10.38 10.3 -in ^R 7.50 8.11 7.74 11.6 11.6 12.1 6.3 7.0 6.1 11.07 11.65 10.88 6.60 5.69 7.26 6.30 7.11 5.90 15.81 15.77 15.68 11.5 11.5 11.5 8.9 8.3 8.0 12.8 14.1 13.4 6.9 6.9 6.1 13.98 14.65 13.6 15.2 14.9 X pet StackGasO2Out % 6.2 6 5.8 6 4.5 4.5 A C, 5.71 5.42 5.39 9.8 9.7 7.16 7.11 7.18 8.43 8.27 Q n^ 5.9 5.8 5.7 5 5.1 5.3 7.1 6.9 6.5 6.8 7 8.6 5.9 6.0 5.8 9.2 8.8 9.1 6.1 6.4 6.3 4.5 4.4 5.1 6.3 7.1 6.7 5.8 5.8 5.8 5.2 5.2 5.2 7.4 7.2 6.8 10.5 10.0 Y Hg ParticleBoundOut ug/dscm 0.112 0.004 0.004 0.004 0.043 ND(0.025) Mrvn nrw\ ND(0.026) 0.073 0.097 0.052 0.09 ND(0.006) ND(O.OOS) 0.009 ND(O.OOS) ND(O.OOS) Mrvn nrvn 0.35 .13 0.05 0.05 0.026 ND(0.014) 0.57 0.31 0.93 0.024 0.048 0.023 ND(0.04) ND(0.08) ND(0.04) 0.006 0.007 0.006 0.01 0.02 0.01 0.012 0.0065 0.0092 0.02 0.04 ND(0.05) 0.053 0.039 0.028 ND(0.006) ND(0.006) ND(0.006) 0.13 0.1 0.16 XB XB Z Hg OxidizedOut ug/dscm ND(0.75) 2.28 1.82 2.21 2.80 3.38 9 ?n 0.037 ND(0.061) 0.115 ND(0.017) 0.152 0.097 0.083 0.072 ND(0.05) ND(0.05) Mrvn n^ 5.78 3.86 5.44 ND(0.04) ND(0.05) ND(0.05) 3.63 4.54 3.81 3.21 3.58 3.26 5.08 7.01 9.31 21 21.83 26.23 1.28 1.04 0.28 ND(0.041) 0.077 0.076 2.1 2.31 2.32 0.212 0.248 0.168 ND(0.05) ND(0.05) 0.063 ND(0.67) ND(0.66) ND(0.64) 0.171 0.072 AA Hg ElementalOut ug/dscm 9.07 9.76 9.98 9.99 0.232 0.537 n 914 3.02 2.74 2.67 8.695 ND(0.14) 1.69 1.61 1.56 0.7 0.7 n fifi 3.08 2.08 3.23 ND(0.15) ND(0.166) ND(0.17) 1.81 2.72 1.64 4.32 5.34 4.40 4.34 4.33 4.02 4.93 3.93 2.55 9.241 9.02 8.825 0.139 0.325 0.269 1.53 0.69 0.71 5.6 5.38 4.87 0.07 0.07 ND(0.075) 6.6 5.68 4.02 2.835 3.501
-------
pet StackGasMoistureOut
pet StackGasO2Out
Hg ParticleBoundOut
Hg OxidizedOut
Hg ElementalOut
Laramie River Station
Laramie River Station
Laramie River Station
Laramie River Station
Lawrence
Lawrence
Lawrence
Leland Olds Station
Leland Olds Station
ND(0.004)
LS
0.054
Leland Olds Station
Lewis & Clark
Lewis & Clark
Lewis & Clark
Limestone
Limestone
Logan Generating Plant
Logan Generating Plant
Logan Generating Plant
Mecklenburg Cogeneration Facility
Mecklenburg Cogeneration Facility
Mecklenburg Cogeneration Facility
ramec
Meramec
Me ramec
Monticello
Monticello
nticello
nticello
nticello
Montrose
Nelson Dewey
ewton
Northern States Power - Sherburne County Generating Plant
Northern States Power - Sherburne County Generating Plant
Northern States Power - Sherburne County Generating Plant
latte
Polk Power
Port Washington
Port Washington
Port Washington
Presque Isle
-------
pet StackGasMoistureOut
pet StackGasO2Out
Hg ParticleBoundOut
Hg OxidizedOut
Hg ElementalOut
Presque Isle
Presque Isle
Presque Isle
Presque Isle
182 Presque Isle
1831R. D. Morrow Sr. Generating plant
184 R. D. Morrow Sr. Generating plant
185 R. D. Morrow Sr. Generating plant
1861R.M. Heskett Station
187 R.M. Heskett Station
188JR.M. Heskett Station
189] Rawhide
190] Rawhide
191] Rawhide
192lsalem Harbor
193 Salem Harbor
194 Salem Harbor
1951 Sam Seymour
196 Sam Seymour
197 Sam Seymour
198 San Juan
200JSan Juan
201 Scrubgrass Generating Company L. P
202|Scrubgrass Generating Company L. P
203] Scrubgrass Generating Company L. P
2041SEI - Birchwood Power Facility
205 SEI - Birchwood Power Facility
206ISEI - Birchwood Power Facility
207 Shawnee Fossil Plant
208^Shawnee Fossil Plant
20§Shawnee Fossil Plant
210 St Clair Power Plant
211 StCair Power Pant
212 St Clair Power Plant
213^Stanton Station
2T4lStanton Station
215 Stanton Station
216 Stanton Station
217 Stanton Station
2j[8JStanton Station
219| Stockton Cogen Company
220|Stockton Cogen Company
221 Stockton Cogen Company
222llNP-One
V. H. Sammis
V. H. Sammis
Vabash River Generating Station
------- 1 2 235 A Plant Name Wabash River Generating Station § abash River Generating Station idows Creek Fossil Plant idows Creek Fossil Plant idows Creek Fossil Plant 240 Wyodak 241 242 243 244 245 246 247 248 Wyodak Wyodak XB = Excessive reagent blank caused the data to be unreliable NA = Data was not included in report LS = Test sample was broken, damaged, or lost during testing or in transport V temp GasOut DegC 168.3 178.3 162 158 151 82 82 81 W pet StackGasMoistureOut % 14.46 13.79 6.95 6.53 6.79 13.7 13.7 13.2 X pet StackGasO2Out % 14.0 13.6 8.2 7.2 7.6 8 8 8 Y Hg ParticleBoundOut ug/dscm ND(0.05) 0.03 0.1 0.04 0.06 ND(0.025) ND(0.029) ND(0.028) Z Hg OxidizedOut ug/dscm ND(0.089) ND(0.90) 1.05 0.98 ND(0.97) 0.048 0.12 0.18 AA Hg ElementalOut ug/dscm 2.6 2.77 ND(1.15) ND(1 .04) ND(1 .00) 7.03 6.98 6.95
-------
ATTACHMENT 3
Hg_speciation_data_CAMR.xls
(Tab: 03_Data_Bm_Table)
14
------- 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 A Plant ID Emission control device type Bin 0 Polk Power Polk Power Polk Power Wabash River Generating Station Wabash River Generating Station Wabash River Generating Station Emission control device type Bin 1 Brayton Point Brayton Point Brayton Point Brayton Point Brayton Point Brayton Point Gibson Generating Station (03/00 testing) Gibson Generating Station (03/00 testing) Gibson Generating Station (03/00 testing) Gibson Generating Station (10/99 testing) Gibson Generating Station (10/99 testing) Gibson Generating Station (10/99 testing) Jack Watson Jack Watson Jack Watson Widows Creek Fossil Plant Widows Creek Fossil Plant Widows Creek Fossil Plant Emission control device type Bin 2 Presque Isle Presque Isle Presque Isle Presque Isle Presque Isle Presque Isle Emission control device type Bin 3 Salem Harbor Salem Harbor Salem Harbor B EIA Plant Code & ORIS Plant Code or just ORIS Plant Code 0184540000-07242 0184540000-07242 0184540000-07242 0154700000-01010 0154700000-01010 0154700000-01010 0134330000-01619 0134330000-01619 0134330000-01619 0134330000-01619 0134330000-01619 0134330000-01619 0154700000-06113 0154700000-06113 0154700000-06113 0154700000-06113 0154700000-06113 0154700000-06113 0126860000-02049 0126860000-02049 0126860000-02049 0186420000-00050 0186420000-00050 0186420000-00050 0208470000-01769 0208470000-01769 0208470000-01769 0208470000-01769 0208470000-01769 0208470000-01769 0134330000-01626 0134330000-01626 0134330000-01626 C Unit No. 1 1 1 1 +1A 1 +1A 1 +1A 1 1 1 3 3 3 3 3 3 3 3 3 4 4 4 6 6 6 5 5 5 6 6 6 3 3 3 D Run Number 1(4) 2 (4) 3 (4) 1 2 3 Average emission modification factor 1 2 3 1 2 3 1 2 3 1 2 3 1 2 3 1 2 3 Average emission modification factor 1 2 3 1 2 3 Average emission modification factor 1 2 3 E Emission Modification Factor (fractional Hg retention across testing locations) 1 .2338 1 .2667 1.4601 0.7153 0.6070 0.7017 0.9974 0.8420 0.6449 0.6887 0.6416 0.7214 0.8813 1.0391 0.9003 0.9100 0.6109 0.4151 0.9023 0.7787 0.6230 0.7214 0.5589 0.5100 0.3665 0.7087 0.3471 0.3813 0.2856 0.4546 0.4971 0.4127 0.3964 0.1453 0.0748 0.0835 F Testing locations coal to stack coal to stack coal to stack coal to stack coal to stack coal to stack across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control ------- 1 2 50 51 52 53 54 55 56 57 58 59 60 61 62 63 64 65 66 67 68 69 70 71 72 73 74 75 76 77 78 79 80 81 82 83 84 85 86 87 88 89 90 91 92 93 94 95 96 97 A Plant ID Emission control device type Bin 4 Cliffside Cliffside Cliffside Dunkirk Dunkirk Dunkirk Gaston Gaston Gaston Emission control device type Bin 5 Bruce Mansfield Bruce Mansfield Bruce Mansfield Emission control device type Bin 6 Port Washington Port Washington Port Washington Emission control device type Bin 7 W. H. Sammis W. H. Sammis W. H. Sammis Valmont Valmont Valmont Emission control device type Bin 8 Mecklenburg Cogeneration Facility Mecklenburg Cogeneration Facility Mecklenburg Cogeneration Facility Emission control device type Bin 9 B EIA Plant Code & ORIS Plant Code or just ORIS Plant Code 00541 60000-02721 00541 60000-02721 00541 60000-02721 0135730000-02554 0135730000-02554 0135730000-02554 0001950000-00026 0001950000-00026 0001950000-00026 0147160000-06094 0147160000-06094 0147160000-06094 0208470000-04040 0208470000-04040 0208470000-04040 0139980000-02866 0139980000-02866 0139980000-02866 0154660000-00477 0154660000-00477 0154660000-00477 52007 52007 52007 C Unit No. 1 1 1 2 2 2 1 1 1 1 1 1 4 4 4 1 1 1 5 5 5 GEN 1 GEN 1 GEN 1 D Run Number Average emission modification factor 1 2 3 1 2 3 1 2 3 Average emission modification factor 1 2 3 Average emission modification factor 1 2 3 Average emission modification factor 1 2 3 1 2 3 Average emission modification factor 1 2 3 Average emission modification factor E Emission Modification Factor (fractional Hg retention across testing locations) 0.1012 0.9914 0.5214 0.5749 0.9499 0.6768 0.8114 1.0019 1.4137 1.1000 0.8935 0.8532 0.8598 0.9249 0.8793 0.5932 0.4738 0.5863 0.5511 0.0882 0.0735 0.0719 0.1340 0.1089 0.1615 0.1063 0.0076 0.0158 0.0122 0.0119 F Testing locations across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control ------- 1 2 98 99 100 101 102 103 104 105 106 107 108 109 110 111 112 113 114 115 116 117 118 119 120 121 122 123 124 125 126 127 128 129 130 131 132 133 134 135 136 137 138 139 140 141 142 143 144 145 A Plant ID SEI - Birchwood Power Facility SEI - Birchwood Power Facility SEI - Birchwood Power Facility Logan Generating Plant Logan Generating Plant Logan Generating Plant Emission control device type Bin 10 Big Bend Big Bend Big Bend AES Cayuga (NY) (formerly NYSEG Milliken) AES Cayuga (NY) (formerly NYSEG Milliken) AES Cayuga (NY) (formerly NYSEG Milliken) Emission control device type Bin 11 Charles R. Lowman Charles R. Lowman Charles R. Lowman R. D. Morrow Sr. Generating plant R. D. Morrow Sr. Generating plant R. D. Morrow Sr. Generating plant Navajo Navajo Navajo Emission control device type Bin 12 Clover Power Station Clover Power Station Clover Power Station Intermountain Intermountain Intermountain B EIA Plant Code & ORIS Plant Code or just ORIS Plant Code 54304 54304 54304 10043 10043 10043 0184540000-00645 0184540000-00645 0184540000-00645 0135110000-02535 0135110000-02535 0135110000-02535 0001890000-00056 0001890000-00056 0001890000-00056 0175680000-06061 0175680000-06061 0175680000-06061 0165720000-04941 0165720000-04941 0165720000-04941 0198760000-07213 0198760000-07213 0198760000-07213 0112080000-06481 0112080000-06481 0112080000-06481 C Unit No. 1 1 1 Gen1 Gen 1 Gen 1 BB03 BB03 BB03 2 2 2 2 2 2 2 2 2 3 3 3 2 2 2 2SGA 2SGA 2SGA D Run Number 1 2 3 1 2 3 Average emission modification factor 1 2 3 1 2 3 Second unit average emission modification factor First unit average emission modification correction factor Combined emission modification factor 6 1 2 3 1 2 3 1 2 3 Second unit average emission modification factor First unit average emission modification correction factor Combined emission modification factor 1 2 3 1 2 3 Second unit average emission modification factor First unit average emission modification correction factor Combined emission modification factor E Emission Modification Factor (fractional Hg retention across testing locations) 0.0410 0.0221 0.0161 0.0091 0.0101 0.0553 0.0256 0.3297 0.2579 0.3568 0.3624 0.2791 0.3001 0.3143 0.7087 0.2228 0.9402 0.7053 0.5855 0.4636 0.5076 0.5517 0.5800 0.8735 0.9182 0.6806 0.8935 0.6081 0.3826 0.2183 0.1093 0.1597 0.3447 0.2598 0.2457 0.1063 0.0261 F Testing locations across control across control across control across control across control across control last control last control last control last control last control last control last control last control last control last control last control last control last control last control last control last control last control last control last control last control last control ------- 1 2 146 147 148 149 150 151 152 153 154 155 156 157 158 159 160 161 162 163 164 165 166 167 168 169 170 171 172 173 174 175 176 177 178 179 180 181 182 183 184 185 186 187 188 189 190 191 192 193 A Plant ID Emission control device type Bin 13 Montrose Montrose Montrose George Neal South George Neal South George Neal South Newton Newton Newton Emission control device type Bin 14 Cholla Cholla Cholla Columbia Columbia Columbia Platte Platte Platte Presque Isle Presque Isle Presque Isle Emission control device type Bin 15 Clay Boswell Clay Boswell Clay Boswell Comanche Comanche Comanche Emission control device type Bin 16 Clay Boswell Clay Boswell Clay Boswell Clay Boswell Clay Boswell Clay Boswell Cholla B EIA Plant Code & ORIS Plant Code or just ORIS Plant Code 0100000000-02080 0100000000-02080 0100000000-02080 0123410000-07343 0123410000-07343 0123410000-07343 0032530000-06017 0032530000-06017 0032530000-06017 0008030000-00113 0008030000-00113 0008030000-00113 0208560000-08023 0208560000-08023 0208560000-08023 0406060000-00059 0406060000-00059 0406060000-00059 0208470000-01769 0208470000-01769 0208470000-01769 0126470000-01893 0126470000-01893 0126470000-01893 0154660000-00470 0154660000-00470 0154660000-00470 0126470000-01893 0126470000-01893 0126470000-01893 0126470000-01893 0126470000-01893 0126470000-01893 0008030000-00113 C Unit No. 1 1 1 4 4 4 2 2 2 3 3 3 1 1 1 1 1 1 9 9 9 2 2 2 2 2 2 3 3 3 4 4 4 2 D Run Number 1 2 3 1 2 3 1 2 3 Average emission modification factor 1 2 3 1 2 3 1 2 3 1 2 3 Average emission modification factor 1 2 3 1 2 3 Average emission modification factor 1 2 3 1 2 3 1 E Emission Modification Factor (fractional Hg retention across testing locations) 0.8241 1 .0234 0.8725 0.8538 0.9109 1 .5235 1.0010 0.8367 0.9154 0.9735 1.2116 1.2821 1 .5943 0.9492 0.7258 0.9667 0.7318 1.3316 1 .0247 0.9990 1 .0523 1 .0577 1.0772 0.2394 0.1255 0.1581 0.3140 0.4737 0.3348 0.2742 0.9284 0.8619 0.9475 1 .0308 1.1825 1 .4440 0.7732 F Testing locations across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control ------- 1 2 194 195 196 197 198 199 200 201 202 203 204 205 206 207 208 209 210 211 212 213 214 215 216 217 218 219 220 221 222 223 224 225 226 227 228 229 230 231 232 233 234 235 236 237 238 239 240 241 A Plant ID Cholla Cholla Colstrip Colstrip Colstrip Lawrence Lawrence Lawrence Emission control device type Bin 17 GRDA GRDA GRDA Laramie River Station Laramie River Station Laramie River Station Wyodak Wyodak Wyodak Emission control device type Bin 18 Craig Craig Craig Rawhide Rawhide Rawhide Northern States Power - Sherburne County Generating Plant Northern States Power - Sherburne County Generating Plant Northern States Power - Sherburne County Generating Plant Emission control device type Bin 19 Jim Bridger Jim Bridger Jim Bridger Laramie River Station Laramie River Station Laramie River Station Sam Seymour Sam Seymour Sam Seymour B EIA Plant Code & ORIS Plant Code or just ORIS Plant Code 0008030000-00113 0008030000-00113 0128250000-06076 0128250000-06076 0128250000-06076 0002250000-01250 0002250000-01250 0002250000-01250 0074900000-001 65 0074900000-001 65 0074900000-001 65 001 3070000-06204 001 3070000-06204 001 3070000-06204 0143540000-06101 0143540000-06101 0143540000-06101 0301510000-06021 0301510000-06021 0301510000-06021 0151430000-06761 0151430000-06761 0151430000-06761 0137810000-06090 0137810000-06090 0137810000-06090 0143540000-08066 0143540000-08066 0143540000-08066 001 3070000-06204 001 3070000-06204 001 3070000-06204 0112690000-06179 0112690000-06179 0112690000-06179 C Unit No. 2 2 3 3 3 4 4 4 2 2 2 3 3 3 BW91 BW91 BW91 C3 C3 C3 101 101 101 #3 #3 #3 BW74 BW74 BW74 1 1 1 3 3 3 D Run Number 2 3 1 2 3 1 2 3 Average emission modification factor 1 2 3 1 2 3 1 2 3 Average emission modification factor 1 2 3 1 2 3 1 2 3 Average emission modification factor 1 2 3 1 2 3 1 2 3 E Emission Modification Factor (fractional Hg retention across testing locations) 1 .3339 1 .0233 1 .8828 1 .0884 0.2640 1.0159 1 .3383 1.1678 1.0855 1 .0228 1 .2436 0.8185 4.5534 0.4265 0.3746 0.5540 0.5738 0.5705 1.1264 0.6846 0.6019 0.7055 0.8369 0.6798 0.5285 0.7633 1.1114 0.9916 0.7670 0.8968 0.8448 0.9705 0.4723 0.5546 0.4242 1.3143 1 .4656 0.8297 F Testing locations across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control last control last control last control last control last control last control last control last control last control ------- 1 2 242 243 244 245 246 247 248 249 250 251 252 253 254 255 256 257 258 259 260 261 262 263 264 265 266 267 268 269 270 271 272 273 274 275 276 277 278 279 280 281 282 283 284 285 286 287 288 289 A Plant ID Emission control device type Bin 20 Coronado Coronado Coronado Craig Craig Craig San Juan San Juan San Juan Emission control device type Bin 21 Stanton Station Stanton Station Stanton Station Emission control device type Bin 22 La Cygne La Cygne La Cygne Emission control device type Bin 23 Nelson Dewey Nelson Dewey Nelson Dewey Emission control device type Bin 24 Leland Olds Station Leland Olds Station Emission control device type Bin 25 Stockton Cogen Company B EIA Plant Code & ORIS Plant Code or just ORIS Plant Code 061 5720000-061 77 061 5720000-061 77 061 5720000-061 77 0301510000-06021 0301510000-06021 0301510000-06021 0154730000-02451 0154730000-02451 0154730000-02451 0195140000-02824 0195140000-02824 0195140000-02824 0100000000-01241 0100000000-01241 0100000000-01241 0208560000-04054 0208560000-04054 0208560000-04054 0013070000-02817 0013070000-02817 10640 C Unit No. U1B U1B U1B C1 C1 C1 2 2 2 1 1 1 1 1 1 1 1 1 2 2 GEN1 D Run Number Second unit average emission modification factor First unit average emission modification correction factor Combined emission modification factor 1 2 3 1 2 3 1 2 3 Second unit average emission modification factor First unit average emission modification correction factor Combined emission modification factor 1 2 3 Average emission modification factor 1 2 3 Average emission modification factor 1 2 3 Average emission modification factor 1 2 Average emission modification factor 1 E Emission Modification Factor (fractional Hg retention across testing locations) 0.8636 0.9735 0.8407 1.1295 1.2141 1.1130 0.5859 0.7705 0.9756 0.6326 0.6865 0.5761 0.8537 1 .0772 0.9197 0.9784 1 .0865 1 .0390 1.0346 0.7792 0.7622 0.7942 0.7785 0.9805 1 .0560 1 .2327 1.0897 1 .2353 0.6674 0.9513 0.0565 F Testing locations last control last control last control last control last control last control last control last control last control across control across control across control across control across control across control across control across control across control across control across control across control ------- 1 2 290 291 292 293 294 295 296 297 298 299 300 301 302 303 304 305 306 307 308 309 310 311 312 313 314 315 316 317 318 319 320 321 322 323 324 325 326 327 328 329 330 331 332 333 334 335 A Plant ID Stockton Cogen Company Stockton Cogen Company Emission control device type Bin 26 - Not Used in Model Emission control device type Bin 27 Scrubgrass Generating Company L. P. Scrubgrass Generating Company L. P. Scrubgrass Generating Company L. P. Emission control device type Bin 28 R.M. Heskett Station R.M. Heskett Station R.M. Heskett Station Emission control device type Bin 29 TNP-One TNP-One TNP-One Emission control device type Bin 30 Kline Township Cogen Facility Kline Township Cogen Facility Kline Township Cogen Facility Emission control device type Bin 31 Dwayne Collier Battle Cogeneration Facility Dwayne Collier Battle Cogeneration Facility Dwayne Collier Battle Cogeneration Facility Emission control device type Bin 32 - Not Used in Model Emission control device type Bin 33 Big Brown B EIA Plant Code & ORIS Plant Code or just ORIS Plant Code 10640 10640 50974 50974 50974 0128190000-02790 0128190000-02790 0128190000-02790 0400510000-07030 0400510000-07030 0400510000-07030 50039 50039 50039 10384 10384 10384 0443720000-03497 C Unit No. GEN1 GEN1 GEN1 GEN1 GEN1 B2 B2 B2 U2 U2 U2 GEN1 GEN1 GEN1 2B 2B 2B 1 D Run Number 2 3 Average emission modification factor 1 2 3 Average emission modification factor 1 2 3 Average emission modification factor 1 2 3 Average emission modification factor 1 2 3 Average emission modification factor 1 2 3 Average emission modification factor 1 E Emission Modification Factor (fractional Hg retention across testing locations) 0.1105 0.0784 0.0818 0.0008 0.0010 0.0015 0.0011 0.4462 0.8891 0.4538 0.5964 0.4489 0.4604 0.3812 0.4302 0.0025 0.0026 0.0026 0.0026 0.0707 0.0565 0.0629 0.0634 0.9928 F Testing locations across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control last control ------- 1 2 336 337 338 339 340 341 342 343 344 345 346 347 348 349 350 351 352 353 354 355 356 357 358 359 360 361 362 363 364 365 366 367 368 369 370 371 372 373 374 375 376 377 378 379 380 381 382 383 A Plant ID Big Brown Big Brown Monticello Monticello Monticello Emission control device type Bin 34 Antelope Valley Station Antelope Valley Station Antelope Valley Station Stanton Station Stanton Station Stanton Station Emission control device type Bin 35 Lewis & Clark Lewis & Clark Lewis & Clark Emission control device type Bin 36 Monticello Monticello Monticello Limestone Limestone Limestone Emission control device type Bin 37 Bay Front Plant Generating Bay Front Plant Generating Bay Front Plant Generating Emission control device type Bin 38 Bailly B EIA Plant Code & ORIS Plant Code or just ORIS Plant Code 0443720000-03497 0443720000-03497 0443720000-061 47 0443720000-061 47 0443720000-061 47 001 3070000-06469 001 3070000-06469 001 3070000-06469 0195140000-02824 0195140000-02824 0195140000-02824 0128190000-06089 0128190000-06089 0128190000-06089 0443720000-061 47 0443720000-061 47 0443720000-061 47 0089010000-00298 0089010000-00298 0089010000-00298 0137810000-03982 0137810000-03982 0137810000-03982 0137560000-00995 C Unit No. 1 1 1 1 1 B1 B1 B1 10 10 10 B1 B1 B1 3 3 3 LIM1 LIM1 LIM1 5 5 5 7 and 8 D Run Number 2 3 1 2 3 Second unit average emission modification factor First unit average emission modification correction factor Combined emission modification factor 1 2 3 1 2 3 Average emission modification factor 1 2 3 Average emission modification factor 1 2 3 1 2 3 Second unit average emission modification factor First unit average emission modification correction factor Combined emission modification factor 1 2 3 Average emission modification factor 1 E Emission Modification Factor (fractional Hg retention across testing locations) 1.1296 1.1199 0.7131 1.5152 1 .4095 1.1467 1 .0346 1.1864 0.0545 1 .0527 0.8930 0.9397 1 .0030 1.0131 0.8260 0.4925 0.6126 0.9119 0.6723 0.7869 0.5443 0.5756 0.5060 0.5241 0.4393 0.5627 1 .0346 0.5822 0.9966 1 .4654 2.2500 1.5707 0.5117 F Testing locations last control last control last control last control last control across control across control across control across control across control across control across control across control across control last control last control last control last control last control last control across control across control across control last control ------- 1 2 384 385 386 387 388 389 390 391 392 393 394 395 396 397 398 399 400 401 402 403 404 405 406 407 408 409 410 411 412 413 414 415 416 417 418 419 420 421 422 423 424 425 426 427 428 429 430 A Plant ID Bailly Bailly Emission control device type Bin 39 Coyote Coyote Coyote Emission control device type Bin 40 AES Hawaii, Inc. AES Hawaii, Inc. AES Hawaii, Inc. Emission control device type Bin 41 Meramec Meramec Meramec St Clair Power Plant St Clair Power Plant St Clair Power Plant Emission control device type Bin 42 Clifty Creek Clifty Creek Clifty Creek Emission control device type Bin 43 Valley Valley Valley Emission control device type Bin 44 Shawnee Fossil Plant B EIA Plant Code & ORIS Plant Code or just ORIS Plant Code 0137560000-00995 0137560000-00995 0128190000-08222 0128190000-08222 0128190000-08222 10673 10673 10673 0194360000-02104 0194360000-02104 0194360000-02104 0051090000-01743 0051090000-01743 0051090000-01743 0092690000-00983 0092690000-00983 0092690000-00983 0208470000-04042 0208470000-04042 0208470000-04042 0186420000-01379 C Unit No. 7 and 8 7 and 8 1 1 1 AB AB AB 4 4 4 4 4 4 6 6 6 2 2 2 3 D Run Number 2 3 Second unit average emission modification factor First unit average emission modification correction factor Combined emission modification factor 1 2 3 Average emission modification factor 1 2 3 Average emission modification factor 1 2 3 1 2 3 Average emission modification factor 1 2 3 Average emission modification factor 1 2 3 Average emission modification factor 1 E Emission Modification Factor (fractional Hg retention across testing locations) 0.5361 0.5138 0.5205 0.9513 0.4952 0.8801 0.0275 0.9453 0.6176 0.4330 0.4626 0.5288 0.4748 0.1873 0.3003 0.2804 0.6605 0.8093 0.9235 0.5269 0.6442 0.7049 0.6301 0.6597 0.9433 1 .0070 1.2521 1.0675 0.3459 F Testing locations last control last control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control across control ------- 1 2 431 432 433 434 435 436 437 438 439 440 441 442 443 444 A Plant ID Shawnee Fossil Plant Shawnee Fossil Plant 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. 3Speciation 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 dual- controlled 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. B EIA Plant Code & ORIS Plant Code or just ORIS Plant Code 0186420000-01379 0186420000-01379 C Unit No. 3 3 D Run Number 2 3 Average emission modification factor E Emission Modification Factor (fractional Hg retention across testing locations) 0.3190 0.2884 0.3178 F Testing locations across control across control ------- 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 G Primary Fuel/ Secondary Fuel Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/Pet Coke Bituminous/Pet Coke Bituminous/Pet Coke Bituminous/Pet Coke Bituminous/Pet Coke Bituminous/Pet Coke Bituminous/None Bituminous/None Bituminous/None H Boiler/furnace type 1 COAL GAS COAL GAS COAL GAS COAL GAS COAL GAS COAL GAS CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NONOX/DRY CONV/PC/NONOX/DRY CONV/PC/NONOX/DRY CONV/PC/NONOX/WET CONV/PC/NONOX/WET CONV/PC/NONOX/WET CONV/PC/NONOX/WET CONV/PC/NONOX/WET CONV/PC/NONOX/WET CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY I PM Control COAL GAS 5 COAL GAS 5 COAL GAS 5 COAL GAS 5 COAL GAS 5 COAL GAS 5 ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS J SO2 Control COAL GAS 5 COAL GAS 5 COAL GAS 5 COAL GAS 5 COAL GAS 5 COAL GAS 5 COMP COAL COMP COAL COMP COAL COMP COAL COMP COAL COMP COAL NONE NONE NONE NONE NONE NONE NONE NONE NONE COMP COAL COMP COAL COMP COAL COMP COAL COMP COAL COMP COAL COMP COAL COMP COAL COMP COAL COMP COAL COMP COAL COMP COAL K External NOX Control 2 NONE NONE NONE NONE NONE NONE Average speciated Hg fraction NONE NONE NONE NONE NONE NONE NONE NONE NONE NONE NONE NONE NONE NONE NONE NONE NONE NONE Average speciated Hg fraction NONE NONE NONE NONE NONE NONE Average speciated Hg fraction SNCR SNCR SNCR L Particle-bound Hg 0.00127 0.00129 0.00136 0.00826 0.00937 0.00923 0.00513 0.15600 0.17475 0.18584 0.16677 0.23975 0.00000 0.00023 0.00027 0.00021 0.00212 0.00351 0.00150 0.00548 0.01316 0.00818 0.05797 0.02597 0.05742 0.06106 0.00599 0.00228 0.01035 0.03657 0.01353 0.00154 0.01171 0.09158 0.30311 0.21475 M Speciated Hg split in stack (fraction) 3 Oxidized Hg 0.09886 0.08021 0.03528 0.13884 0.01667 0.13846 0.08472 0.77737 0.74119 0.73054 0.67634 0.61485 0.51134 0.80969 0.84721 0.91121 0.53814 0.61599 0.69738 0.57534 0.75987 0.75941 0.60870 0.63636 0.4641 1 0.68195 0.40120 0.44470 0.43338 0.52743 0.51297 0.47409 0.46563 0.38383 0.21507 0.21475 N Elemental Hg 0.89987 0.91850 0.96337 0.85289 0.97397 0.85231 0.91015 0.06663 0.08406 0.08363 0.15689 0.14540 0.48866 0.19008 0.15252 0.08858 0.45975 0.38049 0.30112 0.41918 0.22697 0.23241 0.33333 0.33766 0.47847 0.25699 0.59281 0.55302 0.55627 0.43601 0.47351 0.52437 0.52267 0.52459 0.48182 0.57050 ------- 1 2 50 51 52 53 54 55 56 57 58 59 60 61 62 63 64 65 66 67 68 69 70 71 72 73 74 75 76 77 78 79 80 81 82 83 84 85 86 87 88 89 90 91 92 93 94 95 96 97 G Primary Fuel/ Secondary Fuel Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None H Boiler/furnace type 1 CONV/PC/NONOX/DRY CONV/PC/NONOX/DRY CONV/PC/NONOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NONOX/DRY CONV/PC/NONOX/DRY CONV/PC/NONOX/DRY CONV/PC/NONOX/DRY CONV/PC/NONOX/DRY CONV/PC/NONOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY I PM Control ESP-HS ESP-HS ESP-HS ESP-HS ESP-HS ESP-HS ESP-HS ESP-HS ESP-HS PARTSCRUB PARTSCRUB PARTSCRUB ESP-CS ESP-CS ESP-CS BAGHOUSE BAGHOUSE BAGHOUSE BAGHOUSE BAGHOUSE BAGHOUSE BAGHOUSE BAGHOUSE BAGHOUSE J SO2 Control NONE NONE NONE COMP COAL COMP COAL COMP COAL NONE NONE NONE NONE NONE NONE DRYSORBENT DRYSORBENT DRYSORBENT NONE NONE NONE COMP COAL COMP COAL COMP COAL SDA SDA SDA K External NOX Control 2 Average speciated Hg fraction NONE NONE NONE NONE NONE NONE NONE NONE NONE Average speciated Hg fraction NONE NONE NONE Average speciated Hg fraction NONE NONE NONE Average speciated Hg fraction NONE NONE NONE NONE NONE NONE Average speciated Hg fraction NONE NONE NONE Average speciated Hg fraction L Particle-bound Hg 0.20315 0.05699 0.02273 0.01463 0.03800 0.02142 0.00573 0.09484 0.04095 0.14577 0.04901 0.02038 0.01667 0.01704 0.01803 0.00042 0.00044 0.00397 0.00161 0.03429 0.05263 0.04571 0.03521 0.04717 0.02381 0.03980 0.09122 0.08966 0.12273 0.10120 M Speciated Hg split in stack (fraction) 3 Oxidized Hg 0.27121 0.39033 0.52557 0.60146 0.62758 0.63591 0.62385 0.60399 0.59974 0.59718 0.57840 0.20815 0.25119 0.12582 0.19505 0.67652 0.65693 0.67945 0.67097 0.43429 0.48947 0.45143 0.73944 0.79245 0.84762 0.62578 0.44595 0.44828 0.25000 0.38141 N Elemental Hg 0.52564 0.55268 0.45170 0.38391 0.33442 0.34267 0.37041 0.30116 0.35931 0.25705 0.37259 0.77147 0.73214 0.85714 0.78692 0.32306 0.34263 0.31658 0.32742 0.53143 0.45789 0.50286 0.22535 0.16038 0.12857 0.33441 0.46284 0.46207 0.62727 0.51739 ------- 1 2 98 99 100 101 102 103 104 105 106 107 108 109 110 111 112 113 114 115 116 117 118 119 120 121 122 123 124 125 126 127 128 129 130 131 132 133 134 135 136 137 138 139 140 141 142 143 144 145 G Primary Fuel/ Secondary Fuel Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None Bituminous/None H Boiler/furnace type 1 CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/TURBO/NOX/DRY CONV/PC/TURBO/NOX/DRY CONV/PC/TURBO/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NONOX/DRY CONV/PC/NONOX/DRY CONV/PC/NONOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NONOX/DRY CONV/PC/NONOX/DRY CONV/PC/NONOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY I PM Control BAGHOUSE BAGHOUSE BAGHOUSE BAGHOUSE BAGHOUSE BAGHOUSE ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS ESP-HS ESP-HS ESP-HS ESP-HS ESP-HS ESP-HS ESP-HS ESP-HS ESP-HS BAGHOUSE BAGHOUSE BAGHOUSE BAGHOUSE BAGHOUSE BAGHOUSE J SO2 Control SDA SDA SDA SDA SDA SDA WETSCRUB WETSCRUB WETSCRUB WETSCRUB WETSCRUB WETSCRUB WETSCRUB WETSCRUB WETSCRUB WETSCRUB WETSCRUB WETSCRUB WETSCRUB WETSCRUB WETSCRUB WETSCRUB WETSCRUB WETSCRUB WETSCRUB WETSCRUB WETSCRUB K External NOX Control 2 SCR SCR SCR SCR SCR SCR Average speciated Hg fraction NONE NONE NONE NONE NONE NONE Average speciated Hg fraction NONE NONE NONE NONE NONE NONE NONE NONE NONE Average speciated Hg fraction NONE NONE NONE NONE NONE NONE Average speciated Hg fraction L Particle-bound Hg 0.01879 0.05556 0.07738 0.11962 0.10931 0.01772 0.06640 0.00000 0.00000 0.00000 0.00000 0.00555 0.00755 0.00218 0.00735 0.01136 0.00467 0.00389 0.00248 0.00298 0.01431 0.00585 0.00343 0.00626 0.06452 0.02500 0.18750 0.06997 0.01591 0.02597 0.06481 M Speciated Hg split in stack (fraction) 3 Oxidized Hg 0.60543 0.38889 0.38690 0.21505 0.35088 0.02165 0.32813 0.08791 0.06294 0.10227 0.10484 0.05975 0.04906 0.07779 0.32843 0.34318 0.39019 0.29030 0.28353 0.19711 0.00954 0.00923 0.00934 0.20676 0.53226 0.67500 0.25000 0.11953 0.18849 0.21457 0.32998 N Elemental Hg 0.37578 0.55556 0.53571 0.66532 0.53981 0.96063 0.60547 0.91209 0.93706 0.89773 0.89516 0.93470 0.94340 0.92002 0.66422 0.64545 0.60514 0.70582 0.71399 0.79991 0.97615 0.98492 0.98723 0.78698 0.40323 0.30000 0.56250 0.81050 0.79559 0.75946 0.60521 ------- 1 2 146 147 148 149 150 151 152 153 154 155 156 157 158 159 160 161 162 163 164 165 166 167 168 169 170 171 172 173 174 175 176 177 178 179 180 181 182 183 184 185 186 187 188 189 190 191 192 193 G Primary Fuel/ Secondary Fuel Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None H Boiler/furnace type 1 CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NONOX/DRY CONV/PC/NONOX/DRY CONV/PC/NONOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/WET CONV/PC/NOX/WET CONV/PC/NOX/WET CONV/PC/NOX/WET CONV/PC/NOX/WET CONV/PC/NOX/WET CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NONOX/DRY I PM Control ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS ESP-HS ESP-HS ESP-HS ESP-HS ESP-HS ESP-HS ESP-HS ESP-HS ESP-HS ESP-HS ESP-HS ESP-HS BAGHOUSE BAGHOUSE BAGHOUSE BAGHOUSE BAGHOUSE BAGHOUSE PARTSCRUB PARTSCRUB PARTSCRUB PARTSCRUB PARTSCRUB PARTSCRUB MECH/PARTSCRUB J SO2 Control COMP COAL COMP COAL COMP COAL COMP COAL COMP COAL COMP COAL COMP COAL COMP COAL COMP COAL NONE NONE NONE COMP COAL COMP COAL COMP COAL COMP COAL COMP COAL COMP COAL COMP COAL COMP COAL COMP COAL COMP COAL COMP COAL COMP COAL COMP COAL COMP COAL COMP COAL COMP COAL COMP COAL COMP COAL NONE NONE NONE NONE K External NOX Control 2 NONE NONE NONE NONE NONE NONE NONE NONE NONE Average speciated Hg fraction NONE NONE NONE NONE NONE NONE NONE NONE NONE NONE NONE NONE Average speciated Hg fraction NONE NONE NONE NONE NONE NONE Average speciated Hg fraction NONE NONE NONE NONE NONE NONE NONE L Particle-bound Hg 0.00082 0.00037 0.00023 0.00318 0.00535 0.00299 0.00040 0.00034 0.00028 0.00155 0.00000 0.00000 0.00000 0.00033 0.00034 0.00033 0.00256 0.00153 0.00138 0.00043 0.00035 0.00030 0.00063 0.05004 0.00662 0.00917 0.01398 0.00318 0.00648 0.01491 0.00041 0.00011 0.00045 0.00403 0.03041 0.04291 0.00000 M Speciated Hg split in stack (fraction) 3 Oxidized Hg 0.32094 0.30577 0.28996 0.42494 0.39920 0.42431 0.21830 0.18913 0.20219 0.30830 0.21429 0.00000 0.23404 0.18931 0.15419 0.18109 0.14199 0.04396 0.09210 0.08318 0.09076 0.07797 0.12524 0.85666 0.59603 0.82569 0.91057 0.86016 0.92056 0.82828 0.00818 0.01131 0.01128 0.01815 0.06798 0.09142 0.05114 N Elemental Hg 0.67824 0.69386 0.70981 0.57188 0.59545 0.57269 0.78129 0.81054 0.79753 0.69014 0.78571 1 .00000 0.76596 0.81036 0.84548 0.81858 0.85545 0.95451 0.90652 0.91639 0.90889 0.92173 0.87413 0.09330 0.39735 0.16514 0.07545 0.13666 0.07296 0.15681 0.99141 0.98858 0.98827 0.97782 0.90161 0.86567 0.94886 ------- 1 2 194 195 196 197 198 199 200 201 202 203 204 205 206 207 208 209 210 211 212 213 214 215 216 217 218 219 220 221 222 223 224 225 226 227 228 229 230 231 232 233 234 235 236 237 238 239 240 241 G Primary Fuel/ Secondary Fuel Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/Bituminous Subbituminous/Bituminous Subbituminous/Bituminous Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None H Boiler/furnace type 1 CONV/PC/NONOX/DRY CONV/PC/NONOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NONOX/DRY CONV/PC/NONOX/DRY CONV/PC/NONOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NONOX/DRY CONV/PC/NONOX/DRY CONV/PC/NONOX/DRY I PM Control MECH/PARTSCRUB MECH/PARTSCRUB PARTSCRUB PARTSCRUB PARTSCRUB PARTSCRUB PARTSCRUB PARTSCRUB ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS BAGHOUSE BAGHOUSE BAGHOUSE BAGHOUSE BAGHOUSE BAGHOUSE BAGHOUSE BAGHOUSE BAGHOUSE ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS J SO2 Control NONE NONE NONE NONE NONE NONE NONE NONE SDA SDA SDA SDA SDA SDA SDA SDA SDA SDA SDA SDA SDA SDA SDA SDA SDA SDA WETSCRUB WETSCRUB WETSCRUB WETSCRUB WETSCRUB WETSCRUB WETSCRUB WETSCRUB WETSCRUB K External NOX Control 2 NONE NONE NONE NONE NONE NONE NONE NONE Average speciated Hg fraction NONE NONE NONE NONE NONE NONE NONE NONE NONE Average speciated Hg fraction NONE NONE NONE NONE NONE NONE NONE NONE NONE Average speciated Hg fraction NONE NONE NONE NONE NONE NONE NONE NONE NONE L Particle-bound Hg 0.00000 0.00000 0.01431 0.01172 0.03451 0.01684 0.03105 0.03125 0.01453 0.00095 0.00198 0.00110 0.00647 0.00618 0.00619 0.00176 0.00204 0.00196 0.00318 0.00344 0.00344 0.00364 0.02035 0.00055 0.00597 0.01401 0.01109 0.02638 0.00987 0.00904 0.00688 0.00553 0.00000 0.00000 0.00000 0.00473 0.00758 0.00480 M Speciated Hg split in stack (fraction) 3 Oxidized Hg 0.02970 0.03117 0.04329 0.03924 0.14925 0.07016 0.07032 0.07422 0.05112 0.12155 0.10317 0.03072 0.02423 0.00821 0.00722 0.00677 0.01687 0.02520 0.03821 0.03436 0.03436 0.03636 0.06409 0.06466 0.09797 0.02241 0.01411 0.02278 0.04346 0.03615 0.04376 0.03316 0.05689 0.02015 0.00635 0.01893 0.02165 0.02758 N Elemental Hg 0.97030 0.96883 0.94240 0.94904 0.81623 0.91300 0.89863 0.89453 0.93435 0.87750 0.89484 0.96818 0.96930 0.98561 0.98659 0.99147 0.98110 0.97284 0.95860 0.96220 0.96220 0.96000 0.91556 0.93479 0.89606 0.96359 0.97480 0.95084 0.94667 0.95482 0.94936 0.96131 0.94311 0.97985 0.99365 0.97633 0.97078 0.96763 ------- 1 2 242 243 244 245 246 247 248 249 250 251 252 253 254 255 256 257 258 259 260 261 262 263 264 265 266 267 268 269 270 271 272 273 274 275 276 277 278 279 280 281 282 283 284 285 286 287 288 289 G Primary Fuel/ Secondary Fuel Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/None Lignite/None Lignite/None Lignite/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/Pet Coke Subbituminous/Pet Coke Subbituminous/Pet Coke Lignite/None Lignite/None Bituminous/Pet Coke H Boiler/furnace type 1 CONV/PC/NOX/WET CONV/PC/NOX/WET CONV/PC/NOX/WET CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NONOX/DRY CONV/PC/NONOX/DRY CONV/PC/NONOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CYCLONE/NOX/WET CYCLONE/NOX/WET CYCLONE/NOX/WET CYCLONE/NOX/WET CYCLONE/NOX/WET CYCLONE/NOX/WET CYCLONE/NOX/WET CYCLONE/NOX/WET FBC7 I PM Control ESP-HS ESP-HS ESP-HS ESP-HS ESP-HS ESP-HS ESP-HS ESP-HS ESP-HS ESP-CS ESP-CS ESP-CS PARTSCRUB PARTSCRUB PARTSCRUB ESP-HS ESP-HS ESP-HS ESP-CS ESP-CS BAGHOUSE J SO2 Control WETSCRUB WETSCRUB WETSCRUB WETSCRUB WETSCRUB WETSCRUB WETSCRUB WETSCRUB WETSCRUB NONE NONE NONE NONE NONE NONE COMP COAL COMP COAL COMP COAL NONE NONE NONE K External NOX Control 2 Average speciated Hg fraction NONE NONE NONE NONE NONE NONE NONE NONE NONE Average speciated Hg fraction NONE NONE NONE Average speciated Hg fraction NONE NONE NONE Average speciated Hg fraction NONE NONE NONE Average speciated Hg fraction NONE NONE Average speciated Hg fraction SNCR L Particle-bound Hg 0.00428 0.00423 0.02567 0.03366 0.00168 0.00147 0.00548 0.00636 0.01592 0.01086 0.01170 0.00170 0.00094 0.00019 0.00094 0.01840 0.01637 0.03556 0.02344 0.01355 0.00748 0.00676 0.00926 0.00049 0.00037 0.00043 0.43144 M Speciated Hg split in stack (fraction) 3 Oxidized Hg 0.02940 0.01205 0.01073 0.03990 0.05419 0.04895 0.04388 0.05891 0.07173 0.06111 0.04461 0.03663 0.03626 0.03571 0.03620 0.04742 0.05401 0.07111 0.05751 0.07067 0.06229 0.09275 0.07524 0.16821 0.17158 0.16989 0.28094 N Elemental Hg 0.96631 0.98371 0.96360 0.92644 0.94413 0.94957 0.95064 0.93474 0.91235 0.92802 0.94369 0.96166 0.96280 0.96410 0.96286 0.93418 0.92962 0.89333 0.91905 0.91578 0.93023 0.90048 0.91550 0.83130 0.82805 0.82968 0.28763 ------- 1 2 290 291 292 293 294 295 296 297 298 299 300 301 302 303 304 305 306 307 308 309 310 311 312 313 314 315 316 317 318 319 320 321 322 323 324 325 326 327 328 329 330 331 332 333 334 335 G Primary Fuel/ Secondary Fuel Bituminous/Pet Coke Bituminous/Pet Coke Waste Bituminous/None Waste Bituminous/None Waste Bituminous/None Lignite/None Lignite/None Lignite/None Lignite/None Lignite/None Lignite/None Waste Anthracite/None Waste Anthracite/None Waste Anthracite/None Bituminous/None Bituminous/None Bituminous/None Lignite/None H Boiler/furnace type 1 FBC7 FBC7 FBC7 FBC7 FBC7 FBC7 FBC7 FBC7 FBC7 FBC7 FBC7 FBC7 FBC7 FBC7 STOKE R/N OX/DRY STOKE R/N OX/DRY STOKE R/N OX/DRY CONV/PC/NONOX/DRY I PM Control BAGHOUSE BAGHOUSE BAGHOUSE BAGHOUSE BAGHOUSE ESP-CS ESP-CS ESP-CS BAGHOUSE BAGHOUSE BAGHOUSE BAGHOUSE BAGHOUSE BAGHOUSE BAGHOUSE BAGHOUSE BAGHOUSE ESP- CS/BAGHOUSE J SO2 Control NONE NONE NONE NONE NONE NONE NONE NONE NONE NONE NONE NONE NONE NONE SDA SDA SDA COMP COAL K External NOX Control 2 SNCR SNCR Average speciated Hg fraction NONE NONE NONE Average speciated Hg fraction NONE NONE NONE Average speciated Hg fraction NONE NONE NONE Average speciated Hg fraction NONE NONE NONE Average speciated Hg fraction NONE NONE NONE Average speciated Hg fraction NONE L Particle-bound Hg 0.42319 0.41846 0.42436 0.01921 0.02166 0.02268 0.02118 0.01768 0.01221 0.01106 0.01365 0.00425 0.00590 0.00238 0.00418 0.03061 0.03061 0.02899 0.03007 0.34483 0.19403 0.05983 0.19956 0.00229 M Speciated Hg split in stack (fraction) 3 Oxidized Hg 0.28116 0.27385 0.27865 0.44236 0.37582 0.34624 0.38814 0.24082 0.07016 0.03814 0.11637 0.71601 0.69340 0.72603 0.71181 0.25510 0.25510 0.60870 0.37297 0.13793 0.18657 0.21368 0.17939 0.39599 N Elemental Hg 0.29565 0.30769 0.29699 0.53843 0.60252 0.63108 0.59068 0.74151 0.91762 0.95080 0.86998 0.27975 0.30071 0.27159 0.28401 0.71429 0.71429 0.36232 0.59696 0.51724 0.61940 0.72650 0.62105 0.60172 ------- 1 2 336 337 338 339 340 341 342 343 344 345 346 347 348 349 350 351 352 353 354 355 356 357 358 359 360 361 362 363 364 365 366 367 368 369 370 371 372 373 374 375 376 377 378 379 380 381 382 383 G Primary Fuel/ Secondary Fuel Lignite/None Lignite/None Lignite/None Lignite/None Lignite/None Lignite/None Lignite/None Lignite/None Lignite/None Lignite/None Lignite/None Lignite/None Lignite/None Lignite/None Lignite/None Lignite/None Lignite/None Lignite/None Lignite/None Lignite/None Bituminous/None Bituminous/None Bituminous/None Bituminous/Pet Coke H Boiler/furnace type 1 CONV/PC/NONOX/DRY CONV/PC/NONOX/DRY CONV/PC/NONOX/DRY CONV/PC/NONOX/DRY CONV/PC/NONOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NONOX/DRY CONV/PC/NONOX/DRY CONV/PC/NONOX/DRY CONV/PC/NOX/WET CONV/PC/NOX/WET CONV/PC/NOX/WET CYCLONE/NONOX/WET CYCLONE/NONOX/WET CYCLONE/NONOX/WET CYCLONE/NONOX/WET I PM Control ESP- CS/BAGHOUSE ESP- CS/BAGHOUSE ESP- CS/BAGHOUSE ESP- CS/BAGHOUSE ESP- CS/BAGHOUSE BAGHOUSE BAGHOUSE BAGHOUSE BAGHOUSE BAGHOUSE BAGHOUSE PARTSCRUB PARTSCRUB PARTSCRUB ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS MECH MECH MECH ESP-CS J SO2 Control COMP COAL COMP COAL COMP COAL COMP COAL COMP COAL SDA SDA SDA SDA SDA SDA NONE NONE NONE WETSCRUB WETSCRUB WETSCRUB WETSCRUB WETSCRUB WETSCRUB NONE NONE NONE WETSCRUB K External NOX Control 2 NONE NONE NONE NONE NONE Average speciated Hg fraction NONE NONE NONE NONE NONE NONE Average speciated Hg fraction NONE NONE NONE Average speciated Hg fraction NONE NONE NONE NONE NONE NONE Average speciated Hg fraction NONE NONE NONE Average speciated Hg fraction NONE L Particle-bound Hg 0.00088 0.00091 0.00503 0.00121 0.00078 0.00185 0.01333 0.00267 0.00320 0.00073 0.00071 0.00069 0.00356 0.00416 0.00030 0.00027 0.00158 0.00843 0.00689 0.00781 0.00222 0.01683 0.00671 0.00815 0.32114 0.15833 0.08290 0.18746 0.00040 M Speciated Hg split in stack (fraction) 3 Oxidized Hg 0.40910 0.45496 0.94819 0.83816 0.82310 0.64492 0.56000 0.08824 0.04320 0.03658 0.01555 0.01384 0.12623 0.03468 0.02429 0.03046 0.02981 0.17939 0.01695 0.23713 0.14370 0.16129 0.06855 0.13450 0.16260 0.50833 0.61140 0.42744 0.11196 N Elemental Hg 0.59001 0.54413 0.04678 0.16063 0.17613 0.35323 0.42667 0.90909 0.95360 0.96269 0.98375 0.98547 0.87021 0.96115 0.97541 0.96927 0.96861 0.81218 0.97617 0.75506 0.85407 0.82188 0.92474 0.85735 0.51626 0.33333 0.30570 0.38510 0.88765 ------- 1 2 384 385 386 387 388 389 390 391 392 393 394 395 396 397 398 399 400 401 402 403 404 405 406 407 408 409 410 411 412 413 414 415 416 417 418 419 420 421 422 423 424 425 426 427 428 429 430 G Primary Fuel/ Secondary Fuel Bituminous/Pet Coke Bituminous/Pet Coke Lignite/None Lignite/None Lignite/None Subbituminous/None Subbituminous/None Subbituminous/None Subbituminous/Bituminous Subbituminous/Bituminous Subbituminous/Bituminous Subbituminous/Bituminous Subbituminous/Bituminous Subbituminous/Bituminous Subbituminous/Bituminous Subbituminous/Bituminous Subbituminous/Bituminous Bituminous/Pet Coke Bituminous/Pet Coke Bituminous/Pet Coke Bituminous/Subbituminous H Boiler/furnace type 1 CYCLONE/NONOX/WET CYCLONE/NONOX/WET CYCLONE/NONOX/WET CYCLONE/NONOX/WET CYCLONE/NONOX/WET FBC7 FBC7 FBC7 CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NONOX/DRY CONV/PC/NONOX/DRY CONV/PC/NONOX/DRY CONV/PC/NOX/WET CONV/PC/NOX/WET CONV/PC/NOX/WET CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY CONV/PC/NOX/DRY I PM Control ESP-CS ESP-CS BAGHOUSE BAGHOUSE BAGHOUSE BAGHOUSE BAGHOUSE BAGHOUSE ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS ESP-CS ESP-HS ESP-HS ESP-HS BAGHOUSE BAGHOUSE BAGHOUSE BAGHOUSE J SO2 Control WETSCRUB WETSCRUB SDA SDA SDA NONE NONE NONE NONE NONE NONE COMP COAL COMP COAL COMP COAL COMP COAL COMP COAL COMP COAL NONE NONE NONE COMP COAL K External NOX Control 2 NONE NONE Average speciated Hg fraction NONE NONE NONE Average speciated Hg fraction SNCR SNCR SNCR Average speciated Hg fraction NONE NONE NONE NONE NONE NONE Average speciated Hg fraction NONE NONE NONE Average speciated Hg fraction NONE NONE NONE Average speciated Hg fraction NONE L Particle-bound Hg 0.00044 0.00122 0.00069 0.00594 0.28846 0.00420 0.09953 0.00344 0.00165 0.00289 0.00266 0.00168 0.00234 0.00106 0.02691 0.00842 0.01254 0.00882 0.07764 0.00058 0.00768 0.02863 0.04500 0.01887 0.00209 0.02199 0.04762 M Speciated Hg split in stack (fraction) 3 Oxidized Hg 0.10522 0.12180 0.11299 0.00097 0.48718 0.02392 0.17069 0.03436 0.02475 0.04335 0.03416 0.48658 0.65861 0.65539 0.30105 0.26792 0.19971 0.42821 0.40161 0.48527 0.58643 0.49110 0.79500 0.77358 0.78370 0.78409 0.40952 N Elemental Hg 0.89434 0.87698 0.88632 0.99309 0.22436 0.97188 0.72978 0.96220 0.97360 0.95376 0.96318 0.51175 0.33905 0.34355 0.67204 0.72366 0.78775 0.56297 0.52075 0.51415 0.40589 0.48026 0.16000 0.20755 0.21421 0.19392 0.54286 ------- 1 2 431 432 433 434 435 436 437 438 439 440 441 442 443 444 G Primary Fuel/ Secondary Fuel Bituminous/Subbituminous Bituminous/Subbituminous H Boiler/furnace type 1 CONV/PC/NOX/DRY CONV/PC/NOX/DRY I PM Control BAGHOUSE BAGHOUSE J SO2 Control COMP COAL COMP COAL K External NOX Control 2 NONE NONE Average speciated Hg fraction L Particle-bound Hg 0.08081 0.05000 0.05948 M Speciated Hg split in stack (fraction) 3 Oxidized Hg 0.40909 0.44444 0.42102 N Elemental Hg 0.51010 0.50556 0.51950
-------
ATTACHMENT 4
Hg_speciation_data_CAMR.xls
(Tab: 04_Hg_Speciation_Profiles)
15
-------
A LISTING OF TEST BINS WITH HG REMOVALS AND PERCENT SPECIATION
Bin Type Fuel, Boiler, Emission control device(s)
Hg Removal
PERCENT SPECIATION
Paniculate Hg Oxidized Hg Elemental Hg
0 Bituminous Coa , Coal Gasification
1 Bituminous Coa , PC Boiler with ESP-CS
2 Bituminous Coa and Pet. Coke, PC Boiler with ESP-CS
3 Bituminous Coa , PC Boiler with SNCR and ESP-CS
4 Bituminous Coa , PC Boiler with ESP-HS
5 Bituminous Coa , PC Boiler with PM Scrubber
6 Bituminous Coa , PC Boiler with Dry Sorbent Injection and ESP-CS
7 Bituminous Coa , PC Boiler with FF Baghouse
8 Bituminous Coa , PC Boiler with SDA/FF Baghouse
9 Bituminous Coa , PC Boiler with SCR and SDA/FF Baghouse
10 Bituminous Coa , PC Boiler with ESP-CS and Wet FGD
1 1 Bituminous Coa , PC Boiler with ESP-HS and Wet FGD
12 Bituminous Coa , PC Boiler with FF Baghouse and Wet FGD
13 Subbituminous Coal, PC Boiler with ESP-CS
14 Subbituminous Coal, PC Boiler with ESP-HS
15 Subbituminous Coal, PC Boiler with FF Baghouse
16 Subbituminous Coal, PC Boiler with PM Scrubber
17 Subbituminous Coal, PC Boiler with SDA/ESP
18 Subbituminous Coal, PC Boiler with SDA/FF Baghouse
19 Subbituminous Coal, PC Boiler with ESP-CS and Wet FGD
20 Subbituminous Coal, PC Boiler with ESP-HS and Wet FGD
21 Lignite Coal, PC Boiler with ESP-CS
22 Subbituminous Coal, Cyclone Boiler with PM Scrubber
23 Subbituminous Coal/Pet. Coke, Cyclone Boiler with ESP-HS
24 Lignite Coal Coal, Cyclone Boiler with ESP-CS
25 Bituminous Coal/Pet. Coke, Fludized Bed Combustorwith SNCR and FF Baghouse
26 Not Used
27 Bituminous Waste, Fludized Bed Combustorwith FF Baghouse
28 Lignite Coal, Fludized Bed Combustorwith ESP-CS
29 Lignite Coal, Fludized Bed Combustorwith FF Baghouse
30 Antracite Waste, Fludized Bed Combustorwith FF Baghouse
31 Bituminous Coal, Stoker Boiler with SDA/FF Baghouse
32 Not Used
33 Lignite Coal, PC Boiler with ESP-CS and FF Baghouse
34 Lignite Coal, PC Boiler with SDA/FF Baghouse
35 Lignite Coal, PC Boiler with PM Scrubber
36 Lignite Coal, PC Boiler with ESP-CS and Wet FGD
37 Bituminous Coal, Cyclone Boiler with Mechanical Collector
38 Bituminous Coal/Pet. Coke, Cyclone with ESP-CS and Wet FGD
39 Lignite Coal, Cyclone Boiler with SDA/FF Baghouse
40 Subbituminous Coal, Fludized Bed Combustor with SNCR and FF Baghouse
41 Subbituminous Coal/Bituminous Coal, PC Boiler with ESP-CS
42 Subbituminous Coal/Bituminous Coal, PC Boiler with ESP-HS
43 Bituminous Coal/Pet. Coke, PC Boiler with FF Baghouse
44 Bituminous Coal/Subbituminous Coal, PC Boiler with FF Baghouse
0.26%
29.13%
60.36%
89.88%
10.65%
12.07%
44.89%
89.37%
98.17%
97.36%
77.73%
39.19%
97.39%
2.65%
0.00%
72.58%
0.00%
0.00%
23.30%
15.93%
8.03%
0.00%
22.15%
0.00%
4.87%
91.82%
99.89%
40.36%
56.98%
99.75%
93.66%
0.00%
17.40%
32.77%
41.78%
0.00%
50.48%
38.24%
52.52%
47.31%
34.03%
0.00%
68.22%
0.51%
6.11%
1.17%
20.32%
4.90%
1.80%
0.16%
3.98%
9.17%
5.06%
0.22%
0.63%
6.48%
0.16%
0.06%
1.49%
1.45%
0.32%
0.99%
0.43%
1.17%
0.09%
2.34%
0.93%
0.04%
42.44%
2.12%
1.37%
0.42%
3.01%
19.96%
0.19%
0.36%
0.16%
0.82%
18.75%
0.07%
9.95%
0.27%
0.88%
2.86%
2.20%
5.95%
8.47%
68.20%
46.56%
27.12%
57.84%
19.51%
67.10%
62.58%
28.86%
46.04%
7.78%
20.68%
33.00%
30.83%
12.52%
82.83%
5.11%
3.82%
4.35%
2.94%
4.46%
3.62%
5.75%
7.52%
16.99%
27.87%
38.81%
11.64%
71.18%
37.30%
17.94%
64.49%
12.62%
2.98%
13.45%
42.74%
11.30%
17.07%
3.42%
42.82%
49.11%
78.41%
42.10%
91.02%
25.70%
52.27%
52.56%
37.26%
78.69%
32.74%
33.44%
61.97%
48.90%
92.00%
78.70%
60.52%
69.01%
87.41%
15.68%
93.44%
95.86%
94.67%
96.63%
94.37%
96.29%
91.91%
91.55%
82.97%
29.70%
59.07%
87.00%
28.40%
59.70%
62.11%
35.32%
87.02%
96.86%
85.74%
38.51%
88.63%
72.98%
96.32%
56.30%
48.03%
19.39%
51.95%
-------
-------
O ^H
o o
<
PH
fi
o
•
o
>
a §
vi ;s? O
Is .£ „
oo -M h
r^ H 03
IIS
o3 w 00
o? fi
(D
M .3
03
o
s
O
03
o
o
(D
-
3 oo
w •<
------- |