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? 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