# APPENDIX A

Air Quality System (AQS) and Indiana Department of Environmental Management (IDEM) Monitor Data Values for Central Indiana Area (2000-2008)

### This page left intentionally blank.

## Monitoring Data for the Central Indiana Area

SITE ID COUNTY SITE NAME YEAR Annual Average μg/m 3 2006-2008 Average μg/m 3
18-095-0009 Madison Anderson 2006 12.06
18-095-0009 Madison Anderson 2007 13.57
18-095-0009 Madison Anderson 2008 12.13 12.6
18-097-0078 Marion Washington Park 2006 14.14
18-097-0078 Marion Washington Park 2007 15.66
18-097-0078 Marion Washington Park 2008 13.02 14.3
18-097-0081 Marion W 18 th Street 2006 14.12
18-097-0081 Marion W 18 th Street 2007 16.07
18-097-0081 Marion W 18 th Street 2008 13.75 14.6

18-097-0083 Marion E. Michigan Street 2006 14.15
18-097-0083 Marion E. Michigan Street 2007 15.93
18-097-0083 Marion E. Michigan Street 2008 13.17 14.4

Site ID County Site Name Yearly Annual Means 2000 2001 2002 2003 2004 2005 2006 2007 2008
180950009 Madison Anderson 15.55 14.61 14.91 14.35 12.83 16.06 12.06 13.57 12.13

180970042 Marion Mann Road 15.19 14.78 15.22 14.53 12.92 16.10 12.49 14.57 Site Discontinued 180970043 Marion West Street 18.44 17.69 17.02 17.23 15.68 19.10 15.50 17.29 15.06
180970066 Marion English Ave 18.90 18.63 18.35 17.46 16.68 19.35 15.22 17.08 13.23
180970078 Marion Washington Park 17.75 16.58 16.55 15.45 14.31 16.39 14.14 15.66 13.02

180970079 Marion E. 75 th Street 16.36 16.25 15.68 14.67 13.44 16.88 12.75 14.76 Site Discontinued 180970081 Marion W. 18 th Street 16.78 17.14 14.24 16.21 14.96 18.06 14.12 16.07 13.75
180970083 Marion E. Michigan Street 17.00 17.09 16.72 16.32 14.97 17.54 14.15 15.93 13.17

Value Above the Annual PM 2.5 Standard Source Oriented Monitor NOT used for comparison to the Annual PM 2.5 Standard Note: The Mann Road and E. 75 th Street monitors were discontinued December 31, 2007

Site ID County Site Name Three Year Design Values 00-02 01-03 02-04 03-05 04-06 05-07 06-08
180950009 Madison Anderson 15.0 14.6 14.0 14.4 13.6 13.9 12.6

180970042 Marion Mann Road 15.1 14.8 14.2 14.5 13.8 14.4 Site Discontinued 180970043 Marion West Street 17.7 17.3 16.6 17.3 16.8 17.3 16.0
180970066 Marion English Ave 18.6 18.1 17.5 17.8 17.1 17.2 15.2
180970078 Marion Washington Park 17.0 16.2 15.4 15.4 15.0 15.4 14.3

180970079 Marion E. 75 th Street 16.1 15.5 14.6 15.0 14.4 14.8 Site Discontinued 180970081 Marion W. 18 th Street 16.1 15.9 15.1 16.4 15.7 16.1 14.6
180970083 Marion E. Michigan Street 16.9 16.7 16.0 16.3 15.6 15.9 14.4

Value Above the Annual PM 2.5 Standard Source Oriented Monitor NOT used for comparison to the Annual PM 2.5 Standard Note: The Mann Road and E. 75 th Street monitors were discontinued December 31, 2007



### A - 1

### Design Values for the Central Indiana Area for Fine Particles, 2004 through 2008

10.5 11.5 12.5 13.5 14.5 15.5 16.5AndersonMann RoadWashingtonParkE. 75thStreetW. 18thStreetE. MichiganStreetug/m3



### 2004-2006 2005-2007 2006-2008 Annual PM 2.5 Standard

Note: The Mann Road and E. 75 th Street monitors were discontinued December 31, 2007



### Central Indiana Annual Fine Particles Trends, 2004 through 2008

11.00 12.00 13.00 14.00 15.00 16.00 17.00 18.00 19.0020042005200620072008



### Yearug/m3



### Anderson Mann Road Washington Park E. 75th Street W. 18th Street E. Michigan Street Annual PM 2.5 Standard

Note: The Mann Road and E. 75 th Street monitors were discontinued December 31, 2007



### A - 2

# APPENDIX B

Nitrogen Oxides (NO x 

# ), Sulfur Dioxides (SO 2 

# ) and Direct Fine Particulate Matter (PM 2.5 

# ) Point Source Emissions (2002, 2005/2006) for Central Indiana Area

### This page left intentionally blank.Point Source Totals (Tons per Year) Year NO x SO 2 Direct PM 2.5 2002 20,433.95 72,984.10 764.22
2005 14,062.68 71,834.98 1,005.98 2006 14,334.95 65,150.91 1,024.45

2002-Point Source Emissions (Tons per Year) County NOx SO 2 Direct PM 2.5 Hamilton 1,209.82 3,751.30 21.55 Hendricks 3.23 0.40 57.15 Johnson 10.88 0.05 0.60 Marion 14,342.02 51,088.72 558.42 Morgan 4,868.00 18,143.63 126.50 Total 20433.95 72984.10 764.22

2005-Point Source Emissions (Tons per Year)

County EGU-NOx NON-EGUNOx EGU-SO 2 NON-EGUSO 2 EGUDirect PM 2.5 NON-EGUDirect PM 2.5 Hamilton 28.10 6.39 1.10 0.80 12.88 7.47 Hendricks 97.28 86.89 31.67 Johnson 6.48 0.04 0.52

Marion 4,574.40 5,605.45 49, 351.00 3,694.99 117.63 749.80 Morgan 3,536.10 208.49 17,811.30 888.86 31.86 54.15 Sub-Total 8,138.60 5,924.09 67,163.40 4,671.58 162.37 843.61

NOx SO2 Direct PM 2.5 Grand Total 14,062.68 71,834.98 1,005.98

2006-Point Source Emissions (Tons per Year)

County EGU-NOx NON-EGUNOx EGU-SO 2 NON-EGUSO 2 EGUDirect PM 2.5 NON-EGUDirect PM 2.5 Hamilton 30.56 6.36 0.40 0.62 9.63 7.98 Hendricks 98.44 88.33 31.21 Johnson 5.35 0.03 0.43

Marion 4,343.90 6,727.24 46, 346.40 3,040.45 267.31 602.32 Morgan 2,897.80 225.31 14,829.30 845.38 47.20 58.37 Sub-Total 7,272.26 7,062.70 61,176.10 3,974.81 324.14 700.31

NOx SO2 Direct PM 2.5 Grand Total 14,334.95 65,150.91 1,024.45



### B-12002 Hamilton County Point Source Inventory (Tons per Year) Facility Name NOX PM 2.5 SO2 INDIANA DUCTILE LLC 0.03 4.10 0.03 FIRESTONE INDUSTRIAL PRODUCTS 52.36 6.02 89.54 IRVING MATERIALS, INC./STO NY CREEK STONE 2.82 INDUSTRIAL DIELECTRICS, INC. 0.03 MAR-ZANE PLANT #18 4.73 0.00 0.54 PRAIRIE GROUP - PLANT 79 0.00 Total 57.12 12.97 90.10

2002 Hamilton County EGU Inventory (Tons per Year) Facility Name NOX PM 2.5 SO2 PSI ENERGY-NOBLESVILLE 1,152.70 8.59 3,661.20 Total 1,152.70 8.59 3,661.20

2002 Hendricks County Point Source Inventory (Tons per Year) Facility Name NOX PM 2.5 SO2 TWIN BRIDGES RECYCLING & DISPOSAL FACIL 3.23 52.81 0.40 PHOENIX FABRICATOR AND ERECTORS 4.34 Total 3.23 57.15 0.40

2002 Johnson County Point Source Inventory (Tons per Year) Facility Name NOX PM 2.5 SO2 SONOCO FLEXIBLE PACKAGING 10.88 0.58 0.05 LEAR CORPORATION EEDS & INTERIORS 0.02 Total 10.88 0.60 0.05

2002 Marion County Point Source Inventory (Tons per Year) Facility Name NOX PM 2.5 SO2 HUBBARD FEEDS INC. FORMERLY CONTI GROUP 0.25 0.08 0.00 AMERICAN ART CLAY CO. INC. 1.12 1.52 0.71 BRIDGEPORT BRASS D/B/A OL IN BRASS 24.61 1.90 0.11 CENTRAL STATE HOSPITAL 0.07 0.00 0.00 GM MFD INDIANAPOLIS METAL CENTER 4.13 0.22 0.02 DAIMLER CHRYSLER CORPORAT ION FOUNDRY 42.04 28.04 0.18 ELI LILLY AND COMPANY (LCC) 0.28 0.28 0.16 CARGILL DRY CORN INGREDIENTS 7.22 9.66 0.03 VISTEON CORPORATION - INDIANAPOLIS PLANT 23.44 2.43 0.19 ADM GRAIN COMPANY 0.55 0.61 0.00 ZIMMER PAPER PRODUCTS INC 1.37 0.06 0.00 INDIANA VENEERS CORP 8.95 0.19 0.31 INDIANAPOLIS BELMONT WWTP 221.14 2.07 3.66 C.C. PERRY K STEAM PLANT 2,002.18 21.40 3,123.66 CAPITOL CITY CONTAINER CORP. 0.17



### B-22002 Marion County Point Source Inventory (Tons per Year)--continued Facility Name NOX PM 2.5 SO2 INTERNATIONAL TRUCK AND ENGINE CORP. 46.30 58.19 6.94 VALSPAR COATINGS 2.01 0.14 0.01 WISHARD MEMORIAL HOSPITAL 23.90 3.11 2.24 NATIONAL STARCH & CHEMICAL CORPORATION 86.87 82.31 8.15 IR VON DUPRIN 0.99 0.00 PRAXAIR SURFACE TECHNOLOGIES, INC. 0.01 CITIZENS GAS & COKE 551.63 99.59 186.85 INTERSTATE CASTINGS 0.03 11.31 0.04 INDPLS.JUVENILE CORRECTIONAL FACILITY 0.18 0.01 0.00 QUEMETCO, INC. 362.14 8.48 146.68 DORSEY PAVING INC 0.00 0.03 0.00 F.E. HARDING ASPHALT COMPANY 7.69 2.62 4.62 MILESTONE CONTRACTORS, L.P. 24.38 16.59 36.09 RIETH-RILEY88 ASPHALT PL ANT #325 8.11 10.96 16.30 RIETH-RILEY89 ASPHALT PL ANT #326 9.35 12.36 18.68 CRYOVAC RIGID PACKAGING CRYOVAC, INC. 0.02 PANHANDLE EASTERN PIPELIN E CO 2,197.80 3.14 0.20 ASPHALT MATERIALS, INC. 11.22 0.55 0.04 RAYTHEON TECH. SERVICES CO. 5.41 0.30 0.02 BMG MUSIC 1.40 0.09 0.01 HANSON AGGREGATES MIDWEST, INC-STONE 21.90 CAPITOL CITY METALS, L.L.C--S HREDDING YD 2.08 BEST ACCESS SYSTEMS 0.09 SENSIENT FLAVORS, INC. 1.22 0.91 0.01 COVANTA INDIANAPOLIS, INC. 1143.58 8.04 54.01 SUPERIOR METAL TECHNOLOGIES 0.93 0.05 0.00 ST VINCENT HOSPITAL 3.38 0.19 0.02 E & B PAVING INC. 7.59 0.35 9.63 GEIGER & PETERS, INC. 0.23 METALWORKING LUBRICANTS COMPANY 7.67 1.59 2.28 FIRESTONE BUILDING PROD UCTS CO. 1.38 CITIZENS GAS & COKE UTILITY - LNG NORTH 8.56 0.30 0.01 MILLER VENEERS,INC. 0.00 0.02 0.00 BUTLER UNIVERSITY 5.50 0.33 0.03 INLAND PAPERBOARD - GRAPHIC RESOURCE CEN 0.53 0.05 0.00 UNITED AIRLINES INDPLS MAINTENANCE CENTR 17.34 1.31 0.24 SAINT CLAIR PRESS 0.10 0.01 0.00 KROGER COMPANY - INDIANAPO LIS BAKERY 16.32 0.87 0.07 ST. FRANCIS HOSPITAL - BEE CH GROVE 8.11 0.45 1.62 MAR-ZANE, INC. PT. 16 1.26 0.36 INTERSTATE BRANDS CORP. 7.14 0.39 0.03 COMMERCIAL FINISHING 0.64 0.03 0.00



### B-32002 Marion County Point Source Inventory (Tons per Year)--continued Facility Name NOX PM 2.5 SO2 COMMERCIAL FINISHING CORP 26TH ST. 0.06 0.00 0.00 CONAGRA FOODS 7.35 0.41 0.03 ASHLAND DISTRIBUTION CO. – INDIANAPOLIS 0.13 0.01 0.00 KERR-MCGEE CHEMICAL CORPORATION – FPD 2.09 0.16 0.01 COMMUNITY HOSPITAL EAST 24.64 0.47 0.04 DELUXE FINANCIAL SERVICES 0.18 0.01 0.00 GENERAL DEVICES CO., INC 1.61 0.08 0.01 HOLCOMB & HOKE MFG CO,. INC. 0.45 0.03 0.00 NATIONAL BY-PRODUCTS, INC. 15.00 1.01 0.06 INLAND PAPERBOARD – ROOSEVELT 0.45 0.02 0.00 FEDERAL EXPRESS 7.77 0.15 0.62 DOW AGROSCIENCES 12.70 0.74 0.08 INDY RAILWAY SERVICE CORP. 2.85 INDUSTRIAL COATINGS SERVICES 2.37 0.13 0.01 MAJOR TOOL & MACHINE, INC. 0.02 INDPLS AIR ROUTE TRAFFIC CONTROL CENTER 8.74 0.40 0.34 CITIZENS GAS & COKE UTILITY - LNG SOUTH 56.91 0.11 0.01 WINONA MEMORIAL HOSPITAL 2.31 0.13 0.02 CMW, INC. 0.18 0.01 0.00 IVC INDUSTRIAL COATING 2.40 ST. FRANCIS HOSPITAL AND HEAL TH CENTER 5.77 0.30 0.10 ALLISON TRANSMISSION GENERAL MOTORS CORP 280.35 9.58 99.23 ROLLS-ROYCE CORPORATION. PLANT 5 & 8 122.30 15.37 58.83 CENTRAL CORRUGATED, INCORPORATED 2.41 1.19 0.01 INLAND PAPERBOARD - STOUT FIELD 3.08 0.42 0.01 REILLY INDUSTRIES, INC. 109.18 11.55 16.38 RTP COMPANY 0.02 SCHERER INDUSTRIAL GROUP, INC. 0.35 0.15 0.00 ROCHE DIAGNOSTICS CORPORATION 0.43 0.00 0.00 SUBURBAN STEEL SUPPLY COMPANY 0.72 3.70 0.02 DESIGN INDUSTRIES 7.62 QUAKER OATS CO-MAYFLOWER MIDWEST FACILIT 13.53 0.70 0.06 SOUTH SIDE LANDFILL, INC. 12.28 3.48 17.52 PARTS CLEANING TECHNOLOGIES, LLC 0.64 0.02 0.00 AT OF GM - PARK FLETCHER BUILDING 38 1.46 0.06 0.06 ROYAL SPA MFG. 0.35 QWEST - T1 0.25 0.01 0.01 QWEST – POP 0.08 0.00 0.00 Total 7,601.19 483.95 3,817.70



### B-42002 Marion County EGU Inventory (Tons per Year) Facility Name NOX PM 2.5 SO2 IPL HARDING STREET STATION 6,633.70 65.90 47,267.90 GEORGETOWN SUBSTATION GENERATING PLANT 17.75 5.52 0.10 IPL THOMPSON SUBSTATION 24.92 0.85 0.84 IPL SUNNYSIDE SUBSTATION 10.47 0.36 0.35 IPL ROCKVILLE SUBSTATION 8.16 0.28 0.28 IPL PROSPECT SUBSTATION 7.13 0.24 0.24 IPL GERMAN CHURCH SUBSTATION 12.11 0.41 0.41 IPL-GLENS VALLEY SUBSTATION 9.09 0.31 0.31 IPL-GUION SUBSTATION 9.88 0.34 0.33 IPL CUMBERLAND SUBSTATION 7.63 0.26 0.26 Total 6,740.82 74.47 47,271.03

2002 Morgan County Point Source Inventory (Tons per Year) Facility Name NOX PM 2.5 SO2 GENERAL SHALE PRODUCTS 70.40 27.30 366.66 HYDRAULIC PRESS BRICK CO. 303.10 70.98 560.67 WAVERLY PLANT 0.62 Total 373.50 98.90 927.33

2002 Morgan County EGU Inventory (Tons per Year) Facility Name NOX PM 2.5 SO2 IPALCO-PRITCHARD STATION 4,494.50 27.60 17,216.30 Total 4,494.50 27.60 17,216.30



### B-52005 Hamilton County Point Source Inventory (Tons per Year) Facility Name NOX PM 2.5 SO2 INDIANA DUCTILE LLC 6.39 7.47 0.80 Total 6.39 7.47 0.80

2005 Hamilton County EGU Inventory (Tons per Year) Facility Name NOX PM 2.5 SO2 PSI ENERGY-NOBLESVILLE 28.10 12.88 1.10 Total 28.10 12.88 1.10

2005 Hendricks County Point Source Inventory (Tons per Year) Facility Name NOX PM 2.5 SO2 TWIN BRIDGES RECYCLING 7 DISPOSAL 22.90 13.2 4.8 STEEL DYNAMICS, INC (SDI) BAR PROD 74.38 15.1 82.09 PHOENIX FABRICATOR AND ERECTORS 3.37 Total 97.28 31.67 86.89

2005 Johnson County Point Source Inventory (Tons per Year) Facility Name NOX PM 2.5 SO2 SONOCO FLEXIBLE PACKAGING 6.48 0.52 0.04 Total 6.48 0.52 0.04

2005 Marion County Point Source Inventory (Tons per Year) Facility Name NOX PM 2.5 SO2 DAIMLER CHRYSLER CORPORATION FOUNDRY 24.15 23.37 16.60 CARGILL DRY CORN INGREDIENTS 3.83 9.76 0.02 INDIANAPOLIS BELMONT WWTP 141.24 3.08 12.70 C.C. PERRY K STEAM PLANT 1481.51 18.12 3,195.78 INTERNATIONAL TRUCK AND ENGINE CORP. 15.58 204.10 4.99 NATIONAL STARCH & CHEMICAL CORPORATION 66.41 107.59 8.82 CITIZENS GAS & COKE 780.58 307.18 193.09 CRYOVAC RIGID PACKAGING CRYOVAC, INC

. 0.02 PEPL - ZIONSVILLE COMPRESSOR STATION 2,527.63 21.44 0.32 ST VINCENT HOSPITAL 1.64 0.54 0.02 WEYERHAEUSER 2.01 0.15 0.01 ALLISON TRANSMISSION GENERAL MOTORS CORP 276.17 15.04 13.38 ROLLS-ROYCE CORPORATION. PLANT 5 & 8 142.28 26.85 211.39 VERTELLUS SPECIALTIES 142.42 12.50 37.80 Total 5,605.45 749.80 3,694.99

2005 Marion County EGU Inventory (Tons per Year) Facility Name NOX PM 2.5 SO2 IPL GEORGETOWN SUBSTATION 16.50 0.30 IPL HARDING STREET STATION 4,557.90 117.63 49,350.70 Total 4,574.40 117.63 49,351.00



### B-62005 Morgan County Point Source Inventory (Tons per Year) Facility Name NOX PM 2.5 SO2 GENERAL SHALE BRICK, INC. 42.40 2.80 76.90 HYDRAULIC PRESS BRICK CO. 166.09 51.35 811.96 Total 208.49 54.15 888.86

2005 Morgan County EGU Inventory (Tons per Year) Facility Name NOX PM 2.5 SO2 IPL EAGLE VALLEY STATION 3,536.10 31.86 17,811.30 Total 3,536.10 31.86 17,811.30



### *NOTE: Indiana does not have a Point Source Inventory for individual companies for the year 2006

B-7

### Central Indiana Area NO x 

### Point Source Emission Trends, 2002, 2005 and 2006

- 5,000 10,000 15,000 20,000 25,000

2002 2005 2006 

### YearTons per Year



### NOX



### Central Indiana Area SO 2 

### Point Source Emission Trends, 2002, 2005 and 2006

50,000 52,500 55,000 57,500 60,000 62,500 65,000 67,500 70,000 72,500 75,000

2002 2005 2006 

### YearTons per Year



### SO2



### B-8

### Central Indiana Area Direct PM 2.5 

### Point Source Emission Trends, 2002, 2005 and 2006

- 200 400 600 800 1,000 1,200

2002 2005 2006 

### YearTons per Year



### PM 2.5



### B-9

# APPENDIX C

Nitrogen Oxides (NO x 

# ), Sulfur Dioxides (SO 2 

# ) and Direct Fine Particulate Matter (PM 2.5 

# ) (2002, 2005/2006) Emission Trends, All Sources, Central Indiana Area

### This page left intentionally blank.2002 COUNTY Sector NOX PM 2.5 SO2 HAMILTON AREA 582.45 264.52 674.38 HAMILTON NONROAD 1,804.71 162.39 192.22 HAMILTON POINT 1,209.82 21.55 3,751.30 HENDRICKS AREA 277.30 123.46 275.82 HENDRICKS NONROAD 1,666.03 112.96 167.19 HENDRICKS POINT 3.23 57.15 0.40

JOHNSON AREA 462.93 279.53 754.15 JOHNSON NONROAD 733.62 69.60 70.88 JOHNSON POINT 10.88 0.60 0.05

MARION AREA 4,000.66 2,092.57 6,672.71 MARION NONROAD 7,292.64 453.80 642.68 MARION POINT 14,342.02 558.42 51,088.72 MORGAN AREA 194.78 174.85 299.29 MORGAN NONROAD 476.65 48.98 48.03 MORGAN POINT 4,868.00 126.50 18,143.63 5 COUNTY TOTAL (Hamilton,

Hendricks, Johnson, Marion, Morgan Counties) ONROAD 38,059.50 670.50 1,219.50

2002 TOTALS AREA NONROAD ONROAD POINT GRAND TOTAL
NOX 5,518.12 11,973.65 38, 059.50 20,433.95 75,985.22 Direct PM 2.5 2,934.95 847.73 670.50 764.22 5,217.40 SO2 8,676.35 1,121.00 1, 219.50 72,984.10 84,000.95



### C – 12005 COUNTY Sector NOX PM 2.5 SO2 HAMILTON AREA 565.88 7.29 214.12 HAMILTON NONROAD 2,774.02 238.21 350.75 HAMILTON ONROAD 5,130.33 121.55 100.98 HAMILTON EGU 28.10 12.88 1.10 HAMILTON POINT 6.39 7.47 0.80 HENDRICKS AREA 278.64 4.96 114.24 HENDRICKS NONROAD 1,798.51 139.70 228.87 HENDRICKS ONROAD 2,996.01 65.05 53.59 HENDRICKS POINT 97.28 31.67 86.89

JOHNSON AREA 402.01 4.53 137.47 JOHNSON NONROAD 989.89 82.50 111.85 JOHNSON ONROAD 3,247.76 71.42 58.84 JOHNSON POINT 6.48 0.52 0.04

MARION AREA 3,381.47 62.10 1,263.07 MARION NONROAD 6,886.63 444.59 690.56 MARION ONROAD 23,104.27 631.45 442.28 MARION EGU 4,574.40 117.63 49,351.00 MARION POINT 5,605.45 749.80 3,694.99 MORGAN AREA 190.56 6.98 87.27 MORGAN NONROAD 466.97 44.65 50.24 MORGAN ONROAD 2,269.21 50.71 41.89 MORGAN EGU 3,536.10 31.86 17,811.30 MORGAN POINT 208.49 54.15 888.86

2005 TOTALS

AREA NONROAD ONROAD EGU POINT GRAND TOTAL
NOX 4,818.55 12,916.03 36,747.59 8,138.60 5,924.09 68,544.85
Direct PM 2.5 85.87 949.66 940.18 162.37 843.61 2,981.69 SO2 1,816.17 1,432.28 697.59 67, 163.40 4,671.58 75,781.02



### C - 22006 COUNTY Sector NOX PM 2.5 SO2 HAMILTON AREA 569.48 7.29 215.31 HAMILTON NONROAD 2,658.44 226.37 276.55 HAMILTON ONROAD 4,866.81 119.51 83.10 HAMILTON EGU 30.56 9.63 0.40 HAMILTON POINT 6.36 7.98 0.62 HENDRICKS AREA 280.51 4.98 114.69 HENDRICKS NONROAD 1,709.74 131.58 183.49 HENDRICKS ONROAD 2,848.97 63.80 44.01 HENDRICKS POINT 98.44 31.21 88.33

JOHNSON AREA 404.04 4.53 138.10 JOHNSON NONROAD 945.49 78.31 88.52 JOHNSON ONROAD 3,031.07 69.22 48.11 JOHNSON POINT 5.35 0.43 0.03

MARION AREA 3,394.86 61.91 1,264.82 MARION NONROAD 6,498.64 422.61 558.55 MARION ONROAD 21,694.14 590.06 362.01 MARION EGU 4,343.90 267.31 46,346.40 MARION POINT 6,727.24 602.32 3,040.45 MORGAN AREA 192.10 6.99 87.87 MORGAN NONROAD 449.60 42.71 39.79 MORGAN ONROAD 2,153.21 49.32 34.28 MORGAN EGU 2,897.80 47.20 14,829.30 MORGAN POINT 225.31 58.37 845.38

2006 TOTALS

AREA NONROAD ONROAD EGU POINT GRAND TOTAL
NOX 4,841.00 12,261.91 34,594.20 7,272.26 7,062.70 66,032.06
Direct PM 2.5 85.70 901.58 891.91 324.14 700.31 2,903.64 SO2 1,820.79 1,146.90 571.50 61, 176.10 3,974.81 68,690.10



### C – 3

### NO x 

### Emission Trends, All Sources in th e Central Indiana Area, 2002, 2005 and 2006

60,000 62,000 64,000 66,000 68,000 70,000 72,000 74,000 76,000 78,000

2002 2005 2006 

### YearTons per Year



### NOX



### SO 2 

### Emission Trends, All Sources in th e Central Indiana Area, 2002, 2005 and 2006

- 10,000 20,000 30,000 40,000 50,000 60,000 70,000 80,000 90,000

2002 2005 2006 YearTons per Year



### SO2



### C – 4

### Direct PM 2.5 

### Emission Trends, All Sources in Central Indiana Area, 2002,2005 and 2006

- 1,000 2,000 3,000 4,000 5,000 6,000

2002 2005 2006 YearTons per Year



### PM 2.5



### C – 5

# APPENDIX D

Nitrogen Oxides (NO x 

# ) and Sulfur Dioxides (SO 2 

# ) Emissions from Electric Generating Units, Central Indiana Area

### This page left intentionally blank.

### Statewide Indiana NO x 

### Emissions from EGUs

Year NO x 

### Emissions, tons / year 1999 347,216.5 2000 334,522.1 2001 315,419.7 2002 281,146.1 2003 260,980.0 2004 224,311.3 2005 207,981.6 2006 202,728.0 2007 196,553.1 2008 196,134.5 Budget 2009-2014 108,935 Budget 2015 and later 90,779

Indiana Statewide NO x 

### Emissions from Electric Generating Units, 1999 to 2008

0 50,000 100,000 150,000 200,000 250,000 300,000 350,000 400,0001999200020012002200320042005200620072008



### YearTons per Year



### NOx



### D-1

### Central Indiana NO x 

### Emissions from EGUs Facility NO x 

### Emissions, tons / year

1999 13,841.9 2000 13,036.2 2001 12,796.3 2002 12,295.7 2003 11,627.0 2004 10,021.6 2005 8,140.5 2006 7,254.4 2007 7,190.4 2008 6,932.0

NO x 

### Emissions from Electric Generating Units, Central Indiana Area, 1999 to 2008

0 2,000 4,000 6,000 8,000 10,000 12,000 14,000 16,0001999200020012002200320042005200620072008



### YearTons per Year



### NOx



### D-2

### Central Indiana NOx Emissions from EGUs 1999 Facility NO x 

### Emissions, tons / year Noblesville 2,157.1

Anderson 0.0 IPL Harding Street Station (EW Stout) 7,899.7

IPL Eagle Valley Generating Station 3,785.1 Total 13,841.9

Central Indiana NOx Emissions from EGUs 2000 Facility NO x 

### Emissions, tons / year Noblesville 2,145.1

Anderson 9.3 IPL Georgetown Substation 3.0 IPL Harding Street Station (EW Stout) 6,434.3

IPL Eagle Valley Generating Station 4,444.5 Total 13,036.2

Central Indiana NOx Emissions from EGUs 2001 Facility NO x 

### Emissions, tons / year Noblesville 1,578.4

Anderson 5.4 IPL Georgetown Substation 8.5 IPL Harding Street Station (EW Stout) 6,723.7

IPL Eagle Valley Generating Station 4,480.3 Total 12,796.3

Central Indiana NOx Emissions from EGUs 2002 Facility NO x 

### Emissions, tons / year Noblesville 1,152.7

Anderson 5.2 IPL Georgetown Substation 9.6 IPL Harding Street Station (EW Stout) 6,633.7

IPL Eagle Valley Generating Station 4,494.5 Total 12,295.7

D-3

### Central Indiana NOx Emissions from EGUs 2003 Facility NO x 

### Emissions, tons / year Noblesville 842.6

Anderson 3.5 IPL Georgetown Substation 1.0 IPL Harding Street Station (EW Stout) 6,352.3

IPL Eagle Valley Generating Station 4,427.6 Total 11,627.0

Central Indiana NOx Emissions from EGUs 2004 Facility NO x 

### Emissions, tons / year Noblesville 22.2

Anderson 1.9 IPL Georgetown Substation 2.6 IPL Harding Street Station (EW Stout) 6,238.0

IPL Eagle Valley Generating Station 3,756.9 Total 10,021.6

Central Indiana NOx Emissions from EGUs 2005 Facility NO x 

### Emissions, tons / year Noblesville 28.1

Anderson 1.9 IPL Georgetown Substation 16.5 IPL Harding Street Station (EW Stout) 4,557.9

IPL Eagle Valley Generating Station 3,536.1 Total 8,140.5

Central Indiana NOx Emissions from EGUs 2006 Facility NO x 

### Emissions, tons / year Noblesville 10.0

Anderson 2.7 IPL Georgetown Substation 7.5 IPL Harding Street Station (EW Stout) 4,336.4

IPL Eagle Valley Generating Station 2,897.8 Total 7,254.4

D-4

### Central Indiana NOx Emissions from EGUs 2007 Facility NO x 

### Emissions, tons / year Noblesville 27.9

Anderson 3.1 IPL Georgetown Substation 9.5 IPL Harding Street Station (EW Stout) 4,270.5

IPL Eagle Valley Generating Station 2,879.4 Total 7,190.4

Central Indiana NOx Emissions from EGUs 2008 Facility NO x 

### Emissions, tons / year Noblesville 31.1

Anderson 2.9 IPL Georgetown Substation 1.7 IPL Harding Street Station (EW Stout) 4,548.0

IPL Eagle Valley Generating Station 2,348.3 Total 6,932.0

D-5

### This page left intentionally blank

.

D-6

### Statewide Indiana SO 2 

### Emissions from EGUs

Year SO 2 

### Emissions, tons / year 1999 941,852.4 2000 874,617.2 2001 795,505.6 2002 778,868.0 2003 804,828.6 2004 862,876.4 2005 870,811.8 2006 820,993.4 2007 714,529.2 2008 593,154.0 Budget 2009-2014 254,599.0 Budget 2015 and later 178,219.0

Indiana Statewide SO 2 

### Emissions from Electric Generating Units, 1999 to 2008

0 100,000 200,000 300,000 400,000 500,000 600,000 700,000 800,000 900,000 1,000,0001999200020012002200320042005200620072008



### YearTons per Year



### SO2



### D-7

### Central Indiana SO 2 

### Emissions from EGUs Facility SO 2 

### Emissions, tons / year

1999 69,678.6 2000 64,849.9 2001 64,173.2 2002 68,096.0 2003 69,178.4 2004 61,543.5 2005 67,163.8 2006 61,176.2 2007 52,303.5 2008 32,660.2

SO 2 

### Emissions from Electric Generating Units, Central Indiana Area, 1999 to 2008

0 10,000 20,000 30,000 40,000 50,000 60,000 70,000 80,0001999200020012002200320042005200620072008



### YearTons per Year



### SO2



### D-8

### Central Indiana SO 2 

### Emissions from EGUs 1999 Facility NO x 

### Emissions, tons / year Noblesville 9,613.3

Anderson 0.0 IPL Harding Street Station (EW Stout) 44,589.6

IPL Eagle Valley Generating Station 15,475.7 Total 69,678.6

Central Indiana SO 2 

### Emissions from EGUs 2000 Facility NO x 

### Emissions, tons / year Noblesville 6,874.1

Anderson 3.3 IPL Georgetown Substation 0.1 IPL Harding Street Station (EW Stout) 40,309.8

IPL Eagle Valley Generating Station 17,662.6 Total 64,849.9

Central Indiana SO 2 

### Emissions from EGUs 2001 Facility NO x 

### Emissions, tons / year Noblesville 4,688.1

Anderson 0.7 IPL Georgetown Substation IPL Harding Street Station (EW Stout) 43,052.7

IPL Eagle Valley Generating Station 16,431.5 Total 64,173.2

Central Indiana SO 2 

### Emissions from EGUs 2002 Facility NO x 

### Emissions, tons / year Noblesville 3,611.2

Anderson 0.4 IPL Georgetown Substation 0.2 IPL Harding Street Station (EW Stout) 47,267.9

IPL Eagle Valley Generating Station 17,216.3 Total 68,096.0

D-9

### Central Indiana SO 2 

### Emissions from EGUs 2003 Facility NO x 

### Emissions, tons / year Noblesville 1,224.6

Anderson 1.4 IPL Georgetown Substation 0.0 IPL Harding Street Station (EW Stout) 51,016.9

IPL Eagle Valley Generating Station 16,935.5 Total 69,178.4

Central Indiana SO 2 

### Emissions from EGUs 2004 Facility NO x 

### Emissions, tons / year Noblesville 0.7

Anderson 0.1 IPL Georgetown Substation 0.1 IPL Harding Street Station (EW Stout) 44,782.9

IPL Eagle Valley Generating Station 16,759.7 Total 61,543.5

Central Indiana SO 2 

### Emissions from EGUs 2005 Facility NO x 

### Emissions, tons / year Noblesville 1.1

Anderson 0.4 IPL Georgetown Substation 0.3 Harding Street St ation (EW Stout) 49,350.7 IPL Eagle Valley Generating Station 17,811.3 Total 67,163.8

Central Indiana SO 2 

### Emissions from EGUs 2006 Facility NO x 

### Emissions, tons / year Noblesville 0.4

Anderson 0.1 IPL Georgetown Substation 0.2 IPL Harding Street Station (EW Stout) 46,346.2

IPL Eagle Valley Generating Station 14,829.3 Total 61,176.2

D-10

### D-11 Central Indiana SO 2 

### Emissions from EGUs 2007 Facility NO x 

### Emissions, tons / year Noblesville 1.0

Anderson 0.0 IPL Georgetown Substation 0.2 IPL Harding Street Station (EW Stout) 36,201.4

IPL Eagle Valley Generating Station 16,100.9 Total 52,303.5

Central Indiana SO 2 

### Emissions from EGUs 2008 Facility NO x 

### Emissions, tons / year Noblesville 1.0

Anderson 0.0 IPL Georgetown Substation 0.0 IPL Harding Street Station (EW Stout) 19,573.0

IPL Eagle Valley Generating Station 13,086.2 Total 32,660.2

# APPENDIX E

2006 Base Year Emissions Inventory and 2015 and 2020 Projected Emissions Inventory Nitrogen Oxides (NO x 

# ), Sulfur Dioxides (SO 2 

# ) and Direct Fine Particulate Matter (PM 2.5 

# ) in Central Indiana Area

### This page left intentionally blank.2005 (Tons per Year)
Area Category NO x Direct PM 2.5 SO 2 Central Indiana Area Area 4,818.55 85.87 1,816.17 Central Indiana Area EGU 8,138.60 162.37 67,163.40 Central Indiana Area Nonroad 12,916.03 949.66 1,432.28 Central Indiana Area Point 5,924.08 843.61 4,671.58 Central Indiana Area Onroad 36,747.59 940.18 697.59
Total 68,544.85 2,981.69 75,781.01

2006 (Tons per Year)
Area Category NO x Direct PM 2.5 SO 2 Central Indiana Area Area 4,841.00 85.70 1,820.79 Central Indiana Area EGU 7,272.26 324.14 61,176.10 Central Indiana Area Nonroad 12,261.91 901.58 1,146.90 Central Indiana Area Point 7,062.69 700.31 3,974.81 Central Indiana Area Onroad 34,594.20 891.91 571.50
Total 66,032.06 2,903.64 68,690.10

2015 (Tons per Year)
Area Category NO x Direct PM 2.5 SO 2 Central Indiana Area Area 4,808.82 81.77 1,778.03 Central Indiana Area EGU 6,864.90 263.84 28,314.66 Central Indiana Area Nonroad 7,146.72 537.76 165.60 Central Indiana Area Point 6,267.99 722.74 1,631.65
Central Indiana Area Onroad 17,890.21 666.04 184.49
Total 42,978.64 2,272.14 32.074.43

2020 (Tons per Year)
Area Category NO x Direct PM 2.5 SO 2 Central Indiana Area Area 4,759.05 80.05 1,749.73 Central Indiana Area EGU 6,864.47 263.83 28,314.53 Central Indiana Area Nonroad 5,570.32 427.96 103.03
Central Indiana Area Point 6,216.37 712.68 1,615.44 Central Indiana Area Onroad 8,929.80 251.63 180.11 Total 32,340.01 1,736.16 31,962.83

2006 2020 Change % Change NO x 66,032.06 32,340.01 -33,69 2.05 51.02% decrease SO 2 68,690.10 31,962.83 -36,72 7.27 53.46% decrease
Direct PM 2.5 2,903.64 1,736.16 -1,167. 48 40.20% decrease



### E-1

### Comparison of 2005 and 2006 Estimated and 2015 and 2020 3 

### Projected NO x 

### Emissions for the Central Indiana Area

- 10,000 20,000 30,000 40,000 50,000 60,000 70,000 80,000

2005 2006 2015 2020 

### YearTons per Year

NOX



### Comparison of 2005 and 2006 Estimated and 2015 and 2020 1 

### Projected SO 2 

### Emissions for the Central Indiana Area

- 10,000 20,000 30,000 40,000 50,000 60,000 70,000 80,000

2005 2006 2015 2020 YearTons per Year

SO2

1 EGU emission projections for the year 2020 are based on 2018 emission estimates.



### E-2

### Comparison of 2005 and 2006 Estimated and 2015 and 2020 4 

### Projected Direct PM 2.5 

### Emissions for the Central Indiana Area

- 500 1,000 1,500 2,000 2,500 3,000 3,500

2005 2006 2015 2020 YearTons per Year

PM 2.5



### Comparison of 2005 Estimated and 2015 and 2020 2 

### Projected SO 2 

### , NO x 

### and Direct PM 2.5 

### Emission Trends for the Central Indiana Area

- 10,000 20,000 30,000 40,000 50,000 60,000 70,000 80,000

2005 2006 2015 2020 YearTons per Year



### NOX SO2 PM 2.5

2 EGU emission projections for the year 2020 are based on 2018 emission estimates.



### E-3

# APPENDIX G

Indiana Department of Environmental Ma nagement (IDEM) – Area Source Inventory Standard Operating Procedure

### This page left intentionally blank.

### Area Source Inventory S-006-OAQ-R-MO-08-S-R1 

# Standard Operating Procedure

Office: Office of Air Quality Branch: Air Programs Branch Section : Technical Support and Modelin g Section

Rev ised: 02/27/200 8 Rev i sion Cycle: 2 years Effective date: 02/15/07

Scope of operations This SOP is to identify source categories and develop emissions not calculated in point source inventories

. This data is compiled ev ery three years as mandated by EPA.

Scope of applicability This SOP is for the Senior Environmental Manager and the Environmental Manager in the Emissions Group.


### Authorized Signatures I approve and authorize this Standard Operating Procedure:Area Source Inventory S-006-OAQ-R-MO-08-S-R1


### Table of Contents Scope of operations ....................................................................................................................................1 Scope of applicability .................................................................................................................................1 Authorized Signatures

............................................................................................................................... .1 1. Overview work flow chart .......................................................................................................................3 2. Definitions ................................................................................................................................................3 3. Roles .........................................................................................................................................................4 Responsibilities: .........................................................................................................................................4 4. Description of equipment, forms, and/or software to be used ...........................................................4 5. Procedure ................................................................................................................................................4 5.1 Procedural Flowchart ....................................................................................................................4 5.2 Procedure .......................................................................................................................................5 6. Standards and checklists .....................................................................................................................24 7. Records Management ...........................................................................................................................24 8. Quality Assurance / Quality Control ...................................................................................................25 9. Continuous Improvement Cycle ..........................................................................................................25 10. References

............................................................................................................................... ............25 11. History of Revisions ...........................................................................................................................25 12. Appendices

............................................................................................................................... ...........25

2Area Source Inventory S-006-OAQ-R-MO-08-S-R1



### 1. Overview work flow chart The process described is not part of a larger syst em and does not need an Overview work flow chart.



### 2. Definitions

AP-42 – Compilation of Air Pollutant Emission Factors AP- 42, Fifth Edition, Volume I: Stationary Point and Area Sources (January 1995) plus Supplements A – F (Updates 2001 – 2004). AP-42 can be obtained at www.epa.gov/ttn/chief/ap42/

.

Area Sources

- A collection of similar emission units within a geographic area that collectively represent individual sources that are small and numerous and ha ve not been inventoried as a specific point, mobile, or biogenic source.

Authorized - Established by official authority and usage; as with a policy, standard operating procedure (SOP), or quality assurance project pl an (QAPP) that is signed and dated.

EIIP (Emission Inventory Improvement Program) - The EIIP is an EPA program established in 1993 to promote the development and u s e of standard procedures for collecting, calculati ng, storing, reporting, and sharing air emissions date.

Emission Factors - An emissi on facto r is the estimate of the quantity of pollutant released to the atmosphere (because of some operation or activity such as combustion or industrial production) divided by the level of that activity.

Process

- The term “pro ce ss” used when describing area sources is used to name an operation or activity that produces emissions.

NEI - National Emission Inventory Air Pollutant Emiss ion Trends , U.S. EPA.

Standard Industrial Classification (SIC) Code

- A Standa rd Indust rial Cla ssification code from the series of codes devised by the United States O ffice of Management and Budget (OMB) to classify establishments according to the type of economic activity in which they engage.

Source Classification Code (SCC)

- Source Classification Cod e is a process-level code that describes the equipment or operation emitting pollutants.

3Area Source Inventory S-006-OAQ-R-MO-08-S-R1


### 3. Roles

Title # of Staff Experience Qualifications Location

Senior Environmental Manager 1 N/A MS ACCESS, Emission Inventories and familiarity

w ith the EIIP Air Programs Branch

Environmental Manager 1 N/A MS ACCESS, Emission Inventories and familiarity

w ith the EIIP Air Programs Branch

Responsibilities:

Senior Environmental Manager Oversees work of the Environmental Manager and e ns ures that all goals are met. The Senior Environmental Manager also does the final upload to the NEI.

Environmental Manager The Environmental Manager calculates the Area Source Emissions us ing the EIIP or other EPA guidance as provided. The Environmental Manager is also responsible for updating the SOP for the Emissions Group.



### 4. Description of equipment, forms, and/or software to be used

Equipment, Form, &/or Software Who uses it? Location

AP42 Senior Environmental Manager and Environmental Manager EPA’s website: http://www.epa.gov/ttn/chief/ap42/index. html
Emission Inventory Improvement Program (EIIP) Senior Environmental Manager and Environmental Manager EPA’s website: http://www.epa.gov/ttn/chief/eiip/techrep ort/

National Emission Inventory (NEI) Air Pollutant Emission Trends, U.S. EPA Senior Environmental Manager and Environmental Manager EPA’s website http://www.epa.gov/ttn/chief/trends/



### 5. Procedure

5.1 Procedural Flowchart The procedural flowchart below titled “Area Source Inventory” is us ed to calculat e non-point source inventories . This data is compiled every three years as mandated by EPA. The guidance followed is located in the EIIP. Emissions from area source s are calculated at the county level and consist of individual sources that are small, numerous and that have not been inventoried as specific point, mobile, or biogenic sources according to the EIIP.

YES

NO Identify Categories Is the categor y an Area Source?

Then calculate emissions using the SOP for Receiving Emission Statements or the SOP

for On-Road Mobile Source Inventory Calculate Area Source categories using the EIIP or other EPA guidance as provided Enter data into NEI

4Area Source Inventory S-006-OAQ-R-MO-08-S-R1

5.2 Procedure 

### Category 1: Stationary Fuel Combustion

Sub-Category 1.1: Industrial Fuel Combustion

SCC: 2102002000, 210200400, 2102005000, 2102006000, 2102007000

Follow these steps when calculating emissions from industrial fuel combustion:

1. Obtain statewide fuel consumption for “Other Indu stri al” for the following f uels: coal, distillate oil, natural g as, and liquefied petroleum gas (LPG). Us e the Energy Information Administration’s website at http://www.eia.doe.gov/ to find fuel consumption.

Note: As of the date of this SOP, the followin g step s will lead to da ta for fuel con sumption.

a. Go to http://www.eia.doe.gov/ b. Click on link for the various types of fuel consumption c. Click on consumption tab for state totals

2. To avoid double calculating the various fuel comb usti ons, subtract repo rted source totals from the total statewide fuel consumption by querying the to tal process rates for the various SCC codes using the ACCESS data tables at K:\OAQ_INV\Steptool\Stp tl_02.mdb. The remaining number is the area source fuel consumpt ion for the state.

3. To distribute the remaining fuel to the county leve l, calculate the ratio of county to state employ ment for the manuf acturi ng sect or by dividing the numbe r of Manufacturing Employees for each county by the number of manufacturing employees statewide. Use the County Business Patterns website at http://www.census.gov/ to find the number of manufacturing employees for each county.

Note: As of the date of this SOP, the followin g step s will lead to da ta for Econo mic Census.

a. Go to http://www.census.gov/ b. Click on Economic Census c. Under 2002 Reports by State, use the down a r row key to select Indiana d. Now, select each of the counties to find the county manufacturing employees e. Use the total of employees for manuf a cturing u nde r the paid employees’ column

4. Multiply the ratio calculated above in step 3 by t he area so urce fuel con sumpt ion to distribute the fuel to the county level. The remaining number is the pr ocess rate for each county. Multiply the process rate by the appropriate EPA emission factors for t he various fuels for industrial manufacturing found in AP-42, Fifth Edition, Volume 1, Chap ter 1, External Combustion Sources at http://www.epa.gov/ttn/chief/ap42/ch01/

. Sub-Category 1.2: Commercial/ Institutional Fuel Combustion

SCC: 2103004000, 2103005000, 2103006000, 2103007000

Follow these steps when calculating emissions fr om commercial/in stitutional fuel combu s tion:

1. Obtain statewide fuel consumption for “Commercial” for the followi ng fuels: distillate fuel oil, liquefied petrole um ga s (LPG), natural gas, and residual fuel oil. Use the Energy Information Administration’s website at http://www.eia.doe.gov/ to find fuel consumption.

Note: Use the steps in sub-category 1.1-1 to navigate through the Energy Information Ad mini s tration’s website.

5Area Source Inventory S-006-OAQ-R-MO-08-S-R1
2. To avoid double calculating the various fuel comb ustions, subtract reported source totals from the total statewide fuel consumption by querying the to tal process rates for the various fuels using the SIC codes greater than 49 99 using the ACCESS data tables at K :\OAQ_INV\Steptool\Stptl_02.mdb. These are the SIC codes that identify all t he commercial/institutional area sources.

3. To distribute the remaining fuel to the county leve l, calculate the ratio of county to state employ ment for the com m e rcial/institutional sector by dividi ng the number of commercial/ institutional employees for each county by the number of commercial/instit utional employees statewide. Use the County Business Patterns website at http://www.census.gov/ to find the number of commercial/institutional employees for each county.

Note: Use the steps in sub-category 1.1-3 to navi gate through the U.S. Census Burea u’s website.

4. Multiply the ratio calculated above in step 3 by t he area so urce fuel con sumpt ion to distribute the fuel to the county level. The remaining number is the process rate for each county. Multiply the process rate by the appropriate EPA emission factors for t he various fuels for commercial/institutional found in AP-42, Fifth Edition, Volume 1, Chapter 1, External Combustion Sources at http://www.epa.gov/ttn/chief/ap42/ch01/

.

Sub-Category 1.3: Residential Fuel Combustion

SCC: 2104002000, 2104004000, 2104006000, 2104007000

Follow these steps when calculating emissions from residential fuel combustion:

1. Obtain statewide fuel consumpti on for “Residential” for the followi ng fuels: coal, distillate oil, natural gas, an d liqui d petroleum gas. Use the Ener gy Information Administration’s website at http://www.eia.doe.gov/ to find fuel consumption.

Note: Use the steps in sub-category 1.1-1 to navigate through the Energy Information Ad mini s tration’s website.

2. To distribute residential fuel to the county level, calculat e the ratio of cou nty fuel usage to statewide fuel usage using the breakdown of fuels by house hold per county divided by the breakdown of fuels by household per state using the U.S. Census Bureau’s website at http://www.census.gov/

. Note: As of the date of this SOP, the following step s will lead to da ta for brea kdown of fuels by household.

a. Go to http://www.census.gov/ b. On the left hand side click on “American Fact Finder” c. Using the drop down menu, click on Indiana d. Scroll to “Housing Characterist ic s” an d select “show more” e. On the left hand side, select “chan ge geograp h y (state, county, place...)” f. Using the drop down menu, select county, state, and each county name to obtain hou sing

information

3. Multiply the ratio calculated abov e in step 3 by the area residential f uel use by state to distribute the fuel to the co unty level. T he remaining number is the process rate for each county for the various fuels. Multiply the process rate by the approp riate EPA emission factors fo r the various fuels for residential found in AP-42, Fifth Edition, Volume 1, Chapter 1 External Combustion Sources at http://www.epa.gov/ttn/chief/ap42/ch01/

.

6Area Source Inventory S-006-OAQ-R-MO-08-S-R1
Sub-Category 1.4: Residential Heating Using Wood

SCC: 2104008001, 2104008002, 2104008003, 2104008004, 2104008010, 2104008030, 2104008050

Follow these steps when calculating emission s from resid ential heating usi ng wood:

1. Obtain statewide wood consumption for “Residential” using the Energy Information Administration’s web site at http://www.ei a.doe.gov/ . To convert the statewide wood consumption from cords of wood consumed to tons, multiply the total cords consumed by 1.25.

Note: As of the date of this SOP, the followin g steps will lead to da ta for wood consumption.

a. Go to http://www.eia.doe.gov/ b. Click on Households, Buildings & Industry c. Under Consumption Summaries, click on “Annual” d. Now, over to the right c lick on “State Energy” e. Usin g the drop down menu at the bottom, select “Indiana” f. Under “Consumption” click on the “Residential” document

2. Using the ratio estimates provided by EPA found in the “Docume nt ation For Th e Final 2002 NONPOINT SECTOR (FEB 06 version) NATION AL EMISSIONS INVENTORY FOR CRITERIA AND HAZARDOUS AIR POLLUTANTS” at http://www.epa.gov/ttn/chief/net/ 2002inventory.html#documentaiton the number calculated above in step 1 is broken out into three categories (fireplac e without inserts, fireplaces with inserts and woodstoves).

3. To distribute to the county level for the three ca tegories above, calculate a ratio o f county to state using the statewide total of households and the count y total of households that burn wood found at the U.S. Census Bureau website http://www.census.gov/ . The remaining number is the process rate for each county. Multiply the pr ocess rate by the appropriate EPA em ission factors fo r each of the categories using the EIIP, Volume 3, Ch apter 2, Residential Wood Combustion at http://www.epa.gov/ttn/chief/eiip/techreport/volume03/iii02_apr2001.pdf

. Note: Use the steps in sub-category 1.3-2 to navigate through the Energy Information Ad mini s tration’s website.


### Category 2: Industrial Processes

Sub-Category 2.1: Bakeries

SCC: 2302050000

Follow these steps when calculating emissions from bakeries:

1. Calculate a per capita consumption factor using the reporte d weig ht of yeast–ra ised product reported under the Bread, Cake, and Frozen Bakery Products from the Economic Census Bureau at http://www.census.gov/econ/census02/ and the U.S. population at the U.S. Census Bureau at http://census,gov/

. Note: As of the date of this SOP, the following step s will lead to da ta for yeast-raise d product.

a. Go to http://www.census.gov b. Under Business & Industry open “Economic Census” c. Now open “Subject Series” d. Under Manufacturing, open the table “Product Summary” e. Use the yeast – raised product under Commercial Bakerie s (NAICS code 311812) and Frozen cakes, pies, and other pastries manufacturing (NAICS code 311813)

7Area Source Inventory S-006-OAQ-R-MO-08-S-R1

2. Multiply the per capita consumption factor ca lcul ated above in step 1 by the Indiana population found at the U.S. Census Bureau at http://www.census.gov

. Note: As of the date of this SOP, the foll owing steps will lead to In diana population data.

a. Go to http://www.census.gov b. Under Population Finder, use the drop down menu to select Indiana

3. To avoid double calculating the amount consumed for the state, su btract the repo rted p rocess rate for both the straight-dough and sponge-dough by queryi ng the total process rates for the SCC 30203202 (straight-dough) and SCC 30203201 (sponge-do ugh) using the ACC ESS data tables at K:\OAQ_INV\Steptool\Stptl_02.mdb.

4. Multiply the remaining process rate by the strai ght-do ugh emi ssi on factor of .5 lbs VOC/1,000 pounds baked found in the EIIP, Volume 3, Area Source Me thod Abstracts: Baked Goods at Commercial/Retail Bakeries at http://www.epa.gov/ttn/chief/eiip/techreport/volume03/index.html

. 5. Calculate a per capita factor by dividing the I ndiana population found in step 2 by the remaining process rate. No w multiply the per capita factor by each of the county populations to calculate the VOC emissions for each county.

Note: As of the date of this SOP, the fo llowing step s will lead to county population data.

a. Go to http://www.census.gov b. Under Population Finder, use the drop down menu to select Indiana c. Under “View more results”, select the county table


### Category 3: Solvent Utilization

Sub-Category 3.1: Architectural Coatings

SCC: 2401001000

Follow these steps when calculating emissions from architectural coatings:

1. Calculate an emission factor for architectural co ating area sou rces first by adding all the solventbased paints together and all the water based paint s together using the U.S. Census Bureau’s website http://www.census.gov . Use Table 1 to select all solvent-based paints and Table 2 to select all water based paints.

Table 1 National Solvent Coating Sales Solvent Type 1,000 gallons Exterior Solvent Type XX Interior Solvent Type XX Architectural Lacquers XX

Architectural Coating N.S.K. XX Total Solvents XX

Table 2 National Water Based Coating Sales Water Type 1,000 gallons Exterior Water Type XX Interior Water Type XX Total Water Type XX

8Area Source Inventory S-006-OAQ-R-MO-08-S-R1
Note: As of the date of this SOP, the followin g steps will lead to architectural coating data.

a. Go to http://www.census.gov b. Under Business & Industry, select more c. Now select Current Industrial Reports (CIR) d. Select CIRs by Subject e. Tab down to find the report “Paint s and Allied Prod ucts”

2. Now multiply the total national number for solvent -ba sed paint s by the avera ge solvent-based coating content number (3.87 lbs VOC/gallon) and the total national number for water-based paints by the average water-based coating content number (0. 74 lbs VOC/gal) found in the EIIP, Volume 3, Chapter 3: Architectural Surface Coating at http://www.epa.gov/ttn/chief/eiip/techreport/volume03/archsfc.pdf

. 3. Add the total solvent-based coatings and the water-b ased paint s togethe r for a total national VOC emission factor from architectural surface coatin g. Then divide this number by the total national population using the U.S. Census Bureau’s website http://www.census.gov

. 4. Multiply the number calculated abov e in step 3 by each of the co u nty populations to calculate the total emissions per county.

Note: Use the steps in sub-category 2.1-5 to navigate through the Census Burea u ’s website.

Sub-Category 3.2: Automobile Refinishing

SCC: 2401005000

Follow these steps when calculating emissions from automobile refinishing:

1. To avoid double calculating, first query the empl oye es from the re ported sources using the SIC 7532- Body Repair and Paint Shops using the ACCESS data t ables at K:\OAQ_INV\Steptool\Stptl_02.mdb. Subtract this number from the coun ty employment for the same SIC using the U.S. Census Bureau’s website http://www.census.gov

. Note: As of the date of this SOP, the foll owin g steps will lead to co unty employment data.

a. Go to http://www.census.gov b. Under Business & Industry, select more c. Now select the County Business Patterns report for county d. Select Indiana e. Select each of the counties to find the number of employees for the corresponding SIC or NAICS cod e

2. Multiply the emissi on factor 3, 519 lbs VOC/employee found in the EIIP, Volume 3, Chapte r 13 Auto Body Refinishing at http://www.epa.gov/ttn/chief/eiip /techreport/vol ume03/archsfc.pdf and the county employment found above in step 1 to calcul ate the VOC emissions for each county.

Sub-Category 3.3: Traffic Markings

SCC: 2401008000

Follow these steps when calculating for traffic markings:

1. First calculate the national emissions by finding t he a mount of sale s for traffic m arking paints from the U.S. Census Bureau’s website http://www.census.gov and multiply 3.36 lb VOC/gallon the national average VOC content for water and solvent-based paint s from the EIIP, Volume 3, Chapter 14, Traffic Markings at http://www.epa.gov/ttn/chief/eiip/techreport/volume03/iii14.pdf

.

9Area Source Inventory S-006-OAQ-R-MO-08-S-R1
Note: As of the date of this SOP, the foll owing steps will lead to traffic marking paints.

a. Go to http://www.census.gov b. Under Business & Industry, select more c. Now select Current Industrial Reports (CIR) d. Select CIRs by Subject e. Tab down to find the report “Paint s and Allied Prod ucts” f. Use the qu antity amount in 1000/gallons under “Tra ffic marking paints (all type s: shelf go ods and

highway department)

2. Allocate the national emissions calculated above in step 1 to the state level by dividing the amount of money sp ent in Indiana by the money spent nationally on highway maintenance using the category “Total Disbursements” at the Federal Highway Administration’s website http://www.fhwa.dot.gov/po licy/ohim/hs04/htm/sf2.ht m

. 3. Calculate the emission factor for Indiana by divi ding the state level emission s by the total number of roadway mile s in Indian a, given by contacting the Program Development Division, Highway Statistics, Indiana Department of Transportation or the Office of Air Quality, Technical Support and Modeling Section’s mobile inventory preparer.

4. Multiply the emission factor by the total number of ro adway miles i n each co unty using the information supplied from above in step 3.

Sub-Category 3.4: Industrial Surface Coating (employment based emission factor)

SCC: 2401015000, 2401020000, 2401030000, 2401040000, 2401045000, 2401055000, 2401060000, 2401065000, 2401 0700 00, 2401075000, 2401080000

Follow these steps when calculating for industrial surface coatin g u sing the employment based emission factor:

1. Calculate an employee based emission factor for t he following SIC’s in the table below running a query to find the point source employment for each of the SIC’s and the reported VOC emissions for each using the ACCESS data tables at K:\OAQ_INV\Steptool\Stptl_02.mdb.

SCC Description SIC’s

2401015000 Factory Finished Wood 2426-2429,243-245, 2492, 2499

2401020000 Wood Furniture 25

2401030000 Paper Coating 26

2401040000 Metal Cans * 341

2401045000 Metal Coils * 3479

2401055000 Machinery and Equipment 35

2401060000 Appliances * 363

2401065000 Electronic and Other Electrical 3612, 3357

2401070000 New Motor Vehicles ** 3711

2401075000 Other Transportation 37 (not 3711, 373)

2401080000 Marine Coatings 373

10Area Source Inventory S-006-OAQ-R-MO-08-S-R1

* Use the National default emission fact or because the reporting sources are low. ** Emissions reported in point source

2. Divide the reported VOC emission s for each of the SIC’s by the re ported em plo yment for each SIC. Use this number for the emission factor.

3. Subtract the number of report ed emplo y ees found in step 1 from each of the SIC county totals using the U.S. Census Bureau’s website http://www.census.gov . Use the remaining number for the process rate for each of the counties.

Note: Use the steps in sub-category 3.2-1 to navigate through the County Business Patterns.

4. Multiply the process rates above f oun d for ea ch of the SIC’s in step 4 by the emissi on factors found in step 3 to allocate the emissions to each of the counties.

Sub-Category 3.5: Industrial Surface Coating (default emission factor)

SCC: 2401090000, 2401100000, 2401200000

Follow these steps when calculating emissions from i ndu strial surface coatin g using the default emission factor:

1. Calculate industrial surface coat ing emissi on s using the default emission fa ctor in the EIIP, Volume 3, Chapter 8, Industrial Surface Coating at http://www.epa.gov/ttn/chief/eiip/techreport/volume03/iii08.pdf and multiply by the county populations found at the U.S. Census Bureau’s website http://www.census.gov

. Note: Use the steps in 2.1-5 to navigate through U.S. Census Bureau’s website.

SCC’s Description Default Emission Factor

24-01-090-000 Miscellaneous Manuf acturing 0.600 l bs VOC/person

24-01-100-000 Industrial Maintena nce Coatings 0.800 l bs VOC/person

24-01-200-000 Other Special Pur pose Coatings 0.800 lb s VOC/person

Sub-Category 3.6: Degreasing

SCC: 2415230000, 2415245000, 2415345000, 2415360000

Follow these steps when calculating emissions from degreasing activities:

1. Use the U.S. Census Bureau to find employment nu mbers for each of the count ies for the categories in Table 1 below at http://www.census.gov

. Note: Use the steps in 2.1-5 to navigate through U.S. Census Bureau’s website.

Source Classification Codes and Industries Associated with Degreasing SCC SIC Description 2415230000 36 Electronic and other electronic equipment
25 Furniture and fixtures
33 Primary metal industries
34 Fabricated metal products
35 Industrial machinery and equipment
37 Transportation equipment
38 Instruments and related products

11Area Source Inventory S-006-OAQ-R-MO-08-S-R1

39 Miscellaneous manufac turing industries
417 Bus Terminal and Service Facilities
423 Trucking terminal facilities
551 New and used car dealers
552 Used car dealers
554 Gasoline service stations
555 Boat dealers
556 Recreational vehicle dealers 2415245000

753 Automotive repair shops 25 Furniture and fixtures
33 Primary metal industries
34 Fabricated metal products
35 Industrial machinery and equipment
36 Electronic and other electronic equipment
37 Transportation equipment
38 Instruments and related products 2415345000

2415345000 cont. 39 Miscellaneous manufac turing indu stries 417 Bus Terminal and Service Facilities 423 Trucking terminal facilities 551 New and used car dealers 552 Used car dealers 554 Gasoline service stations 555 Boat dealers 556 Recreational vehicle dealers 2415360000

753 Automotive repair shops

2. Run a query to find reported employment numbers for each of the categories in the table above using the ACCESS data tables at K:\O AQ_INV\Steptool\Stptl_02.mdb.

3. Subtract the reported employment from the U.S Census Bureau’ s n umbers to find the process rates for each of the counties.

4 Calculate the VOC emissions by mult iplying the default emission factor in the EIIP, Volume 3, Chapter 6, Solvent Clea ning at http://www.epa.gov/ttn/chief/eiip/techreport/volume03/iii06fin.pdf and the process rate for each of the counties found in step 3.

Sub-Category 3.7: Dry Cleaners

SCC: 2420010370

Follow these steps when calculating emissions from dry cleaners:

1. Calculate an emission factor by finding the numbe r of employees state wide an d county wide for SIC 7216(Laundry and Garment Services) at the U.S. Census Bureau’s website http://www.census.gov

. Note: Use the steps in 2.1-5 to navigate through U.S. Census Bureau’s website

2. Take the sum of the employment from the coun ties, m ultiply by 2000, and divide by the statewi de total found in step 1. Use this number for the emission factor.

3. Calculate the process rate by running a query to find the number of repo rted em ployees for SIC 7216 using the ACCESS data tables at K:\OAQ_INV\St eptool\Stptl_02.mdb and subtract this number from the county total.

4. Multiply the process rate for each of the counties above by the em ission factor to cal culate for VOC emissions.

12Area Source Inventory S-006-OAQ-R-MO-08-S-R1
Sub-Category 3.8: Graphic Arts

SCC: 2425000000

Follow these steps when calculating emissions from graphic arts activities:

1. Multiply the per capita factor found in the EIIP, Volume 3, Chapte r 7, Grap hic Arts at http://www.ep a.gov/ttn/chief/eiip/techreport/volume03/iii07.pdf by the state population from the Census Bureau http://www.census.gov to find the total emissions for the state.

Note: Use the steps in 2.1-2 to navigate th roug h the U.S. Census Burea u’s website.

2. Develop an emission factor by subtracting point source emissions from the total emissions and dividing by the state pop ul ation found in step 1.

3. Distri bute to the counties by multiplying the emission factor by the p opulation for each county.

Note: Use the steps in 2.1-5 to navigate th roug h the U.S. Census Burea u’s website.

Sub-Category 3.9: Rubber and Plastics

SCC: 2430000000

Follow these steps when calculating emissions from rubber and plastics activities:

1. Run a query to find the total of reported emissi on s and numbe r of reporte d employees for all SIC’s beginning with 30 using the ACCESS data tabl es at K:\OAQ_INV\Steptool\Stptl_02.mdb.

2. Calculate the emission factor by dividing the point source emissions by the reported employees.

3. Subtract the reported employment for SIC’s beginning with 30 from total employment for each of the

c o unties

. Note: Use step 3.2-1 to navigate through the County Business Patterns.

4. Multiply the remaining number from above with the emission fa ctor cal c ul ated in step 2.

Sub-Category 3.10: Miscellaneous Industrial Adhesives

SCC: 2440020000

Follow these steps when calculating emissions from industrial adhesives activities:

1. Using the guidance in the Ai r Pollutant Emissi on Trends at http:// www.epa.gov /ttn/chief/trends

, calculate an emission factor by finding the total National Emissions from Industrial Adhesives and divide by the National Manu facturi ng Employm ent from the U.S. Census Bureau’s website http://www.census.gov

. Note: As of the date of this SOP, the following st ep s will lead to e m ission trends data for industrial adhesives.

a. Go to http://www.epa.gov/air /airtrends/aqtrnd03/ b. Select “Appendix A –Data Tables” c. Search for industrial adhesives

Note: As of the date of this SOP, the following step s will lead to National Man u facturing Employment.

a. Go to http://www.census.gov

13Area Source Inventory S-006-OAQ-R-MO-08-S-R1

b. Select Economic Census c. Now select “Businesses with paid employees” d. Use the manufacturing number under “paid employees”

2. To avoid double calculating, run a query c ollec t ing sources re porting adhesives using the ACCESS data tables at K:\OAQ_INV\Steptool\Stptl_02.mdb. Subtract the reported employment from the total amount of manufacturing employment. The remaining number is the process rate.

Sub-Category 3.11: Commercial/Consumer Solvents

SCC: 2460100000, 2460200000, 2460400000, 2460500000, 2460600000, 2460800000, 2460900000

Follow these steps when calculating emissions from commercial/consumer solvent usage:

1. Using the EIIP, Volume 3, Chapter 5, Consume r, and Comme rcial Solvent Use at http://www.epa.gov/ttn/chief/eiip/techreport/volume03/iii05.pdf , multiply the per capita factors for each of SCC codes by the population for each county from the U.S. Census Bureau’s website http://www.census.gov

. Note: Use the steps in 2.1-5 to navigate through the U.S. Census Bureau’s website.

Emission Factors for Commercial/Consumer Solvents

Source Classification Codes Product Category Per Capita Emission Factor (lb VOC/person)

2460100000 Personal Care Products 2.32

2460200000 Household Products 0.79

2460400000 Automotive Aftermarket Products 1.36

2460500000 Coatings and Related Products 0.95

2460600000 Adhesives and Sealants 0.57

2460800000 FIFRA-Regulated Products 1.78

2460900000 Miscellaneous Products 0.07

Sub-Category 3.12: Asphalt Emulsions

SCC: 2461022000

Follow these steps when calculating emissions from asphalt emulsions:

1. To calculate the process rate, find the number of ba rrel s of asp halt used for the state found at the State Energy Data website at http://www.eia.doe.gov/emeu/states/_seds_updates.html

. 2. Obtain the amount of roadway miles for the st ate an d coun ty from the Indiana Department of Transportation’s, Division of Roadway Management Section.

3. Divide the county roadway miles by the state roadw ay miles and multiply by th e total asphalt usage for the state found above in step 1.

4. Multiply the process rate by the default emission factor in the E IIP, Volume 3, Chapter 17 , Asphalt Paving http://www.epa.gov /ttn/chief/eiip/te chreport/volume03/ iii17_apr2001.pdf

.

14Area Source Inventory S-006-OAQ-R-MO-08-S-R1
Sub-Category 3.13: Pesticide Usage

SCC: 2461800000

Follow these steps when calculating emissions from pesticide usage:

1. Calculate pesticide usage by using a state spec ific e missi on facto r. Develop the factor using a methodology that includes the retrieval of informat ion of pesticides used, an emission factor for each pesticide used, a calculation about the inert ingredien ts in each pesticide, and an estimate of the amount of crop oil concentrate (an adjuvant used for the application of herbicides) used in the state of Indiana.

2. Find the amount of active ingredients for herbicides and insecticides applied to Indiana fields at the Indiana Ag ricultural Statistics Se rvice at http://www.u sda.gov/nass/pubs/agr02/acro02.htm

. 3. Insert the numbers for both corn and soybeans to the Excel pesticide table found at K:OAQ_INV\Inv\pestici de.

4. Cal c ulate the emission factor by adding the emis sio ns from crop oil concentrates obtained in the pesticide Excel table, pesticides, and solvent carrie rs and then divide by the total number of acres of corn and soybeans in Indiana found at the National Agricultural Statistics Services, United States Department of Agriculture http://www.nass.usda.gov/QuickStats/

. 5. Multiply the emission factor by the county-specific acreage for both corn and soybeans found at the Nation al Agricultural Statistics Servi c es, United States Department of Agriculture http://www.nass.usda.gov/QuickStats/

. 

### Category 4: Petroleum Marketing

Follow these steps when calculating emissions for bulk terminals:

Sub-Category 4.1: Bulk Terminals

SCC: 2501050120

1. Find the amount of gasoline sold in Indiana at t he Fe deral High wa y Administration, U.S. Department of Transportation http://www.fhwa.dot.gov/po licy/ohim/hs04/htm/mf21.htm

. 2. Find the amount of gasoline sold statewide and by co unty using, the NAICS co d e 447-Gasoline Service Station from the U.S. Cens us Bureau’s, Economic Census at http://www.census.gov/econ/census02/data/in/IN000_44.HTM#N447

. 3. Run a query to find the amount of point source report ed gasoline using t he ACCESS data tables at K:\OAQ_INV\Steptool\Stptl_02.mdb a nd subtract from the amount sold statewide. Use this to allocate to each county.

4. Allocate the amount gasoline sold to each of the coun ties by dividi ng the amount of sales in each county by statewide sales and mult iplying by the number of gallons sold statewide found above in step 1.

5. EPA guidance suggests that only 25% of all gas oline consumed goes through bulk plants. To cal c ulate process rate, multiply each county by 25% to estimate the amount of fuel transferred through bulk terminals.

6. Multiply process rate by the emission factors in the table belo w :

15Area Source Inventory S-006-OAQ-R-MO-08-S-R1

Emission Factors

Source Emission Factor (lb VOC/1000) gal Storage Tanks Breathing Loss 5.0
Storage Tank Working Loss - Filling 9.6
Storage Tank Working Loss - Emptying 3.8 Gasoline Loading Racks (Vapor balance controlled) 11.9 (0.3)

Total 30.3

7. Bulk terminals also have controls set forth in the Indiana rule (326 IAC 8-4 ). This rule says that any source of this type that is new after January 1, 1980 is required to make sure that any transfer between a tank and transport uses a submer ged pipe vapor balance system. Using EPA’s default rule effectiveness, multiply the number in step 2 by the Control Efficiency (CE) 38%, a Rule Effectiveness (RE) of 80%, and a Rule Penetration (RP) of 13%, i.e. process rate X emission factor X (1-(CE x RE x RP)) X 1 ton/2000 lb = VOC tons.

Sub-Category 4.2: Portable Fuel Containers

SCC: 2501011011, 2501011012, 2501011016, 2501012011, 2501012012, 2501012016

Follow these steps when calculating emi ssi ons for po rtable fuel co ntainers:

1. Calculate the emissions for Commercial and Residential gas cans by using the method developed by the California Environmental Protectio n Agency’s docu ment Public Meeting to Consider Approval of California’s Portable Gasoline-Cont ainer Emissions Inventory. Use the excel spreadsheet found at K:\OAQ_INV\Inv\Area Source\Gasoline.zip to calcul ate the emissions for permeation, diurnal, and transport

. Both the Spillage and Vapor losses are esti mated in the nonroad emissions inventory by EPA models.

2. Using the survey results below in Table 1, esti mate the number of fuel contain ers in the state for residential categories. The calculations are set up in an excel spreadsheet at K:\OAQ_INV\Inv\Area Source\ Gasoline.zip\250101\GasCan s.xls, insert the number of oc cupied housing, from the U.S. Census Bureau’s website at http://www.census.gov/ , in the space marked “households”.

Note: As of the data of this SOP, the following step s will lead to nu mber of ho useholds in Indiana.

a. Go to http://www.census.gov/ b. On the left hand side select American Fact finder c. Now select housing d. Under “Occupancy Status”, select occupies housing units e. Now use the drop down menu and select Indiana

Table 1 Residential Survey Results

Percentage of households with at least one gas can 46% Number of gas cans per household 1.8 Percentage of plastic cans/metal cans 76% / 24% Weighted average gas can capacity (gal) 2.34 Percentage of gas cans stored with fuel 70% Weighted average stored fuel volume (% of capacity) 49%

16Area Source Inventory S-006-OAQ-R-MO-08-S-R1

Percentage of all gas cans that are plastic and stored open/closed 23% / 53% Percentage of all gas cans that are metal and stored open/closed 11% / 13% Percent of all cans stored open/closed 34% / 66%

3. Using the survey results below in Table 2, esti mate the number of fuel contain e rs for commercial categories for the state. Do this by using the commercial population based on the number of identified businesses in Table 3 and insert into the excel spreadsheet at K:\OAQ_INV\Inv\Area Source\ Gasoline.zip\250101\GasCans.xls.

Table 2 Commercial Survey Results

Percentage of businesses with at least one gas can 80% Number of gas cans per business 6.9 Percentage of plastic cans/metal cans 72% / 28% Weighted average gas can capacity (gal) 3.43 Weighted average stored fuel volume (% of capacity) 49% Percentage of all gas cans that are plastic and stored open/closed 39% / 33% Percentage of all gas cans that are metal and stored open/closed 10% / 18% Percent of all cans stored open/closed 49% / 51%

Table 3 Category NAICS Agricultural 115 Automotive Club and Towing Services 48841
Service Stations 8111
Lawn and Garden Maintenance Services 81141
General Contractors 23
Construction and Rental Yards 5324 Landscaping Services 561730

4. Calculate permeable emissions separately for bot h residential and comm ercial by using the emission rates given in the California document. Use 1.57g/gal /day for plastic contai ners and 0.6g/gal/day for metal containers. Insert the numbers for both resi dential and commercial into the excel spreadsheet at K:\OAQ_INV\Inv\Area Source\ Gaso line.zip\250101\GasCans.xls.

5. Calculate diurnal emissions by inserting the numbers for both residential and commercial into the excel spre ad she e t at K:\OAQ_INV\Inv\Area Source\ Gasoline.zip\250101\GasCans.xls.

6. Calculate transport spillage emissions by inserting the numbers for both re sid ential and commercial into the excel spreadsheet at K:\OAQ_INV\Inv\Area Source\ Gasoline.zip\250101\GasCans.xls

Sub-Category 4.3: Service Station Tank Loading or Tank Truck Unloading (Stage 1)

SCC: 2501060052 (uncontrolled), 2501060053 (controlled)

Follow these steps when calculating emissions from tank loading and unloading

1. Find the amount of gasoline sold in Indiana at the Fe deral High wa y Administration, U.S. Department of Transportation http://www.fhwa.dot.gov/po licy/ohim/hs04/htm/mf21.htm

. 2. Find the amount of gasoline sold statewide and county wide by using the NAICS code 447-Gasoline Service Station from the U.S. Cens us Bur e au’s, Economic Census at http://www.census.gov/econ/census02/data/in/IN000_44.HTM#N447

.

17Area Source Inventory S-006-OAQ-R-MO-08-S-R1

3. Run a query to find the amount of point source reported gasoline using t he ACCESS data tables at K:\OAQ_INV\Steptool\Stptl_02.mdb a nd subtract from the amount sold statewide. Use this to allocate to each county.

4. Allocate the amount sold to each of the counties by dividing the amount of sales in each county by statewide sales an d multip lying by the number of gallons sold statewide found above in step 1.

5. Find the amount of gasoline tank s from the Underground Storag e Tank d ata files from the Office of Land Quality, Indiana Department of Environmental Management http://www.in.gov/idem/programs/land/ust/ust.html

. 6. Now copy the data into an Excel spreadsheet. Filt er finding the tan ks that have only gasoline. Also filter out the tanks that are “pe rmanently out of service”, “suspended per inspection”, and “unregulated”.

7. Using the Petroleum Sources Applicability Rule 326 IAC 8-4-1, filter out the t anks that are located in Clark, Boone, Dearborn, Elkha r t, Floyd, Hamilton, Hancock, Harrison, Hendricks, Johnson, Lake, Marion, Morgan, Porter, Saint Joseph, and Shelby counties.

8. To find the amount of balanced tanks in Indiana, use the total of gasoline tanks found in step 7 and divide by the numbe r of tanks that constructed after 1985 through current year. Use the spreadsheet created in step 7 and filter out the t anks that constructed prior to 1985.

9. Now apply the percentage found in step 8 to the amount of gasoline found in ea ch county.

10. Apply the controlled emission factor to only those co u nties ide n tified in 326 IAC 8-4, i.e. Boone, Clark, Dearborn, Elkhart, Hamilton, Hancock, Harrison, Hendricks, Johnson, Lake, Marion, Morgan, Porter, Saint Joseph, and Shelby. Use the emission factor s for stage 1 controlled and uncontrolled in the EIIP, Volume 3, Chapter 11, Gasoline Marketing (Stage 1 and Stage 2) http://www.epa.gov/ttn/chief/eiip/techreport/volume03/iii11_apr2001.pdf

.

Sub-Category 4.4: Vehicle Fueling (Stage II) – Vapor Displacement

SCC: 2501060101 (uncontrolled), 2501060102 (controlled)

Follow these steps when calculating emissions from vehicl e fueling – Vapor Displ acement:

1. Find the amount of gasoline sold in Indiana at t he Fe deral High wa y Administration, U.S. Department of Transportation http://www.fhwa.dot.gov/po licy/ohim/hs04/htm/mf21.htm

. 2. Find the amount of gasoline sold statewi de and by co unty using the NAICS co d e 447-Gasoline Service Station from the U.S. Cens us Bureau’s, Economic Census at http://www.census.gov/econ/census02/data/in/IN000_44.HTM#N447

. 3. Allocate the amount sold to each of the counties by dividing the amount of sales in each county by statewi de sales an d multip lying by the number of gallons sold statewide found above in step 1.

4. Calculate an emission factor using the input file s supplied from the mobile mod el. Table 1 and Table 2 show examples of how the emission factors fo r January and July for the Southern Counties were calculated. By using these two months, the other months are distributed. Use the average of all months for the emission factor for the Southern counties. Use the same methodology for the Northern counties, Central Countie s, Clark/Floyd, and Lake/Porter.

18Area Source Inventory S-006-OAQ-R-MO-08-S-R1

Table 1
January Run for Southern Counties

VTYPE GM_MILE MILES MPG VMT G/GAL Month Factor 1 0.0628 29.4642 23.89 0.463793 0.322719 1 1.01 2 0.1058 35.2923 18.77 0.070491 0.009868 2 1.14 3 0.1058 35.2923 18.77 0.234672 0.109364 3 1.28 4 0.1486 34.0851 14.31 0.071379 0.010834 4 1.41 5 0.1486 34.0851 14.31 0.032825 0.002291 5 1.55 6 0.2152 35.8919 9.88 0.028896 0.001775 6 1.69 7 0.2342 32.3617 9.08 0.001027 2.24E-06 7 1.82 8 0.2465 19.9098 8.63 0.000522 5.8E-07 8 1.69 9 0.2719 27.6093 7.82 0.001164 2.88E-06 9 1.55 10 0.2733 27.4686 7.78 0.002489 1.32E-05 10 1.41 11 0.2972 24.3758 7.15 0.001132 2.72E-06 11 1.28 12 0.3169 23.6257 6.71 0.000004 3.4E-11 12 1.14 25 0.3421 27.2301 6.22 0.000496 5.23E-07 Sum 16.97 0.456873 g/gal Average 1.41 1.007222 lb/E3gal

19Area Source Inventory S-006-OAQ-R-MO-08-S-R1

Table 2 July Run for Southern Counties VTYPE GM_MILE MILES MPG VMT G/GAL 1 0.1144 29.1752 23.9 0.456768 0.570447 2 0.1955 34.8826 18.75 0.071404 0.018689 3 0.1955 34.8826 18.75 0.237712 0.207133 4 0.2882 33.944 14.3 0.072838 0.021865 5 0.2882 33.944 14.3 0.033496 0.004624 6 0.4164 35.8288 9.9 0.029201 0.003515 7 0.4529 32.4716 9.1 0.001038 4.44E-06 8 0.4763 19.6757 8.66 0.000509 1.07E-06 9 0.5264 27.4602 7.83 0.00116 5.55E-06 10 0.5283 27.3328 7.8 0.002482 2.54E-05 11 0.5749 24.2458 7.17 0.001122 5.19E-06 12 0.6128 23.3718 6.73 0.000004 6.6E-11 25 0.6629 27.2301 6.22 0.000485 9.7E-07 0.826316 g/gal 1.821697 lb/E3gal

5. Multiply the process rate in step 4 by the emissi on factor found in th e mobile mo del.

Sub-Category 4.5: Vehicle Fue ling (Stage II) – Spillage

SCC: 2501060103

Follow these steps when calculating emi ssi ons from vehicl e fueling – Spillage:

1. Find the amount of gasoline sold in Indiana at t he Fe deral High wa y Administration, U.S. Department of Transportation http://www.fhwa.dot.gov/po licy/ohim/hs04/htm/mf21.htm

. 2. Find the amount of gasoline sold statewi de and by co unty using the NAICS co d e 447-Gasoline Service Station from the U.S. Cens us Bureau’s, Economic Census at http://www.census.gov/econ/census02/data/in/IN000_44.HTM#N447

. 3. Allocate the amount sold to each of the counties by dividing the amount of sales in each county by statewi de sales an d multip lying by the number of gallons sold statewide found above in step 1.

4. Apply the emission factor 0.7 lb VOC/1000 gallons in AP-42, Fifth Edition, Volume 1, Chapter 5, Petroleum In dustry, Transportation, and Marketing of Petroleum Liquids http://www.epa.gov/ttn/chief/ap42/ch05/final/c05s02.pdf to the process rate found in step 4.

Sub-Category 4.6: Underground Tank Breathing

SCC: 2501060200

Follow these steps when calculating emi ssi ons from u nderground t ank breathing:

1. Find the amount of gasoline sold in Indiana at t he Fe deral High wa y Administration, U.S. Department of Transportation http://www.fhwa.dot.gov/po licy/ohim/hs04/htm/mf21.htm

. 2. Find the amount of gasoline sold statewi de and by co unty using the NAICS co d e 447-Gasoline Service Station from the U.S. Cens us Bureau’s, Economic Census at http://www.census.gov/econ/census02/data/in/IN000_44.HTM#N447

.

20Area Source Inventory S-006-OAQ-R-MO-08-S-R1
3. Allocate the amount sold to each of the counties by dividing the amount of sales in each county by statewide sales and multiplying by the number of gallons sold statewide found above in step 1.

4. Apply the emission factor 1.0 lb VOC/1000 gallons in AP-42, Fifth Edition, Volume 1, Chapter 5, Petroleum In dustry, Transportation, and Marketing of Petroleum Liquids http://www.epa.gov/ttn/chief/ap42/ch05/final/c05s02.pdf to the process rate found in step 4.

Sub-Category 4.7: Tank Trucks in Transit

SCC: 2505030120

Follow these steps when calculating emissions from tank trucks in transit:

1. Find the amount of gasoline sold in Indiana at t he Fe deral High wa y Administration, U.S. Department of Transportation http://www.fhwa.dot.gov/po licy/ohim/hs04/htm/mf21.htm

. 2. Find the amount of gasoline sold statewi de and by co unty using the NAICS co d e 447-Gasoline Service Station from the U.S. Cens us Bureau’s, Economic Census at http://www.census.gov/econ/census02/data/in/IN000_44.HTM#N447

. 3. Allocate the amount sold to each of the counties by dividing the amount of sales in each county by statewi de sales an d multip lying by the number of gallons sold statewide found above in step 1.

4. Using the guidance in the EIIP, Volume 3, Chapt er 11 , Gasolin e Marketing (Stage I and State II) at http://www.epa.gov/ttn/chief/eiip/techreport/volume03/iii11_apr2001.pdf ), multiply the activity rate 1.25 by the amount sold per county found in step 4.

5. Now multiply the process rate found in step 5 by the emission factor .06 lb VOC/ gallon transported using the EIIP guidance above.


### Category 5: Waste Management Practices

Sub-Category 5.1: Solid Waste Incineration

5.1.1: Industrial Solid Waste Incineration

SCC: 2601010000

Follow these steps when calculating emissions from i ndustrial solid waste in cineration:

1. Find the number of manufacturing employees, NAICS code 31, for each county using the County Business Patterns at the U.S. Census Bureau’s website http://censtats.census.gov/c gi-bin/cbpnaic/cbpsel.pl

. Note: Use the steps in 3.2-1 to navi gate throug h the county busine ss p atterns.

2. Multiply the county manufacturing employment by the default fuel-lo ading factor 4 20 tons / 1,00 0 manufacturing employees.

3. Multiply the process rate in step 2 by AP-42, Fi fth Edition, Volume 1, Chapter 2

- 1.12, Solid Waste Disposal at http://www.epa.gov/ttn/chief/ap42/ch02/index.html

.

21Area Source Inventory S-006-OAQ-R-MO-08-S-R1

5.1.2: Commercial Solid Waste Incineration

SCC: 2601020000

Follow these steps when calculating emissions from commercial solid waste incineration:

1. Find the population for each county at the U.S. Census Bureau’s website http://www.census.gov/

. Note: Use steps 2.1-5 to navigate thr oug h the U.S. Censu s Bureau’s website.

2. Next find the default factor of .65lb/person/day from U.S. EPA Municipal Solid Waste Report http://www.ep a.gov/epao swer/non-hw/muncpl/msw99.htm

. 3. Find the percent of co mmercial solid waste from the U.S. EPA Mu nicipal Solid Waste Report above.

4. Now, calculate the process rate for commercial solid waste incineration by multiplying popul at ion by the default factor of .65lb/p erson/day by the percent of commercial solid waste and number of days in a year.
5. Multiply the process rate in step 4 by AP-42, Fi fth Edition, Volume 1, Chapter 2

- 1.12, Solid Waste Disposal at http://www.epa.gov/ttn/chief/ap42/ch02/index.html

.
5.1.3: Residential Solid Waste Incineration

SCC: 2601030000

Follow these steps when calculating emissions from resid ential solid waste inci n eration:

1. Find the population for each county at the U.S. Census Bureau’s website http://www.census.gov/

. Note: Use step 2.1-5 to navigate through the U.S. Census Bureau’s website.

2. Next find the default factor of .65lb/person/day from U.S. EPA Municipal Solid Waste Report http://www.ep a.gov/epao swer/non-hw/muncpl/msw99.htm

. 3. Find the percent of residential solid waste from the U. S. EPA Municipal Solid Waste Repo rt above.

4. Now, calculate the process rate for residentia l soli d waste incine rat ion by multiplying population by the default factor of .65lb/person/day by the percent of commercial solid waste and number of days in a year.
5. Multiply the process rate in step 4 by AP-42, Fi fth Edition, Volume 1, Chapter 2

- 1.12, Solid Waste Disposal at http://www.epa.gov/ttn/chief/ap42/ch02/index.html

. Sub-Category 5.2: Residential Open Burning

5.2.1: Leaf and Brush Burning

SCC: 2610000100 and 2610000400

Follow theses step when calculating emissions from leaf and brush burning:

1. Find a per capita factor for l eaf burning and a per capita for brus h burning by us ing the U.S. EPA’s Solid Waste Rep ort at http://www.epa.gov/epaoswer/non-hw/muncpl/msw99.htm

. 2. Allocate the amount burned by adjusting the per c api ta factor for leaves at 25% and for b r ush at 25%. Of the total waste generated only 28% burns.

22Area Source Inventory S-006-OAQ-R-MO-08-S-R1 3. Once all the percentages from above are calculated, multiply the adjusted per capita factor by the rural population for each county from the U.S. Census Bureau at http://www.census.gov/

Note: As of the data of this SOP, the follow ing steps will lead to co unty rural population.

a. Go to http://www.census.gov/ b. On the left hand side, select American Fact Finder c. Select data sets d. Detailed tables e. County f. Indiana g. All counties

4 Use the table below to adjust the amount of wast e g enerated to ac count for the percentage of forest in each county. The percentages come from a doc ument from the United States Department of Agriculture at http://ncrs.fs.fed.us /pubs/rb/rb_nc253b.pdf

. Percent Forested Acres per County Adjusted for Yard Waste Generated

< 10% 0% generated >= 10%, and < 50% 50% generated
>= 50% 100% generated

5. Now, multiply the amount of leaves and brush by the emission factors found in AP-42, Fifth Edition, Volume 1, Chapter 2, Solid Waste Dispo sal, Table 2.5-5, and Table 2.5-6 at http://www.epa.gov/ttn/chief/ap42/ch02/final/c02s05.pdf

.
5.2.2: Residential Waste Incineration

SCC: 2610030000

Follow these steps when calculating emissions from for re sidential wa ste incineration:

1. Find a per capita factor for re si dential waste inci nerati on by using the U.S. EPA’ s Solid Waste Report at http://www.epa.gov/ep aoswer/non-hw /muncpl/pub s/ mswchar05.pdf

. 2. Using the Solid Waste Report above, su btract the pe rcenta ge of recycled and composted material from the per capita factor above.

3. Now, subtract the percentages of combustibles i.e. glass, metal, yard trimmings, and other waste.

4. Using a document from EPA, it states that only 28% of waste ge nerated by rural popul ation burns and of that percen t, 49% is actu ally combu s ted. Using this information multiply the per capita factor by 0.28 and then multiply that number by 0.49 actually burned in rural counties.

5. Once all the percentages are calculated, multiply the adjus ted pe r capita factor by the rural population for each county from the U.S. Census Bureau at http://www.census.gov/

. Note: Use steps 5.2.1-3 to find county rural population.

6. Calculate the amount of residentia l waste by the emission facto r s in the EIIP, Volume 3, Chapter 16, Open Burning at http://www.epa.gov/ttn/chief/eiip/techreport/volume03/index.html

. Sub-Category 5.3: Public Owned Treatment Works (POTW’s)

SCC: 2630020000

Follow these steps when calculating emissions from POTW’s:

23Area Source Inventory S-006-OAQ-R-MO-08-S-R1

1. To calculate the amount of annual flow for public o w ned treatment works, obtain the amount of monthly flow rate for each county. This is data is supplied by the Office of Water Quality. To calculate for annual flow multiply the monthly flow by the default of 0.16 that represents the amount of industrial flow.

2. Calculate the process rate above by the em ission fa ctors in FI RE 6.25 usi ng the SCC code 2630020000.

Sub-Category 5.4: Treatment, St orage, and Disposal Facilities

SCC: 2640000004

Follow these steps when calculating emissions fr om treatment, storage, and di sposal fa cilities:

1. Obtain a list of treatment facilities and the amount of ignitable waste from each facility from IDEM’s Office of Lan d Quality.

2. Usi ng the list of facilities from step 1, run a query using the ACCESS data tables at K:\OAQ_INV\Steptool\Stptl_02.mdb to ob tain the amo unt of ignitable waste reported to IDEM’s Office of Air Quality.

3. Compare the two lists obtained in step 1 and step 2, for each facility subtract any quantity reported to OAQ from th e quantity rep orted to OLQ. Do this in order to avoid double counting quantities reported to both offices. Combine the quantities reported from facilities within the same counties. Use these quantities as the process rate for each county.

4. Multiply the process rate above with th e combin ed e m ission factor in the table below:

Emission Source Emission Factor in AP-42 (lb VOC/Ton) Emission Factor Used (lb VOC/Ton) Storage Tank Vent 0.004-0.09 0.09

Spillage (filling) 0.20 0.20 Loading (filling) 0.00024-1.42 1.42 Spillage (emptying) 0.20 0.20 Loading (emptying) 0.00024-1.42 1.42 Combined Emission Factor 3.33


### Category 6: Submit Data to EPA

Submit data in a format that is acceptable to EPA. At the present time the format is the National Emission Inventory (NEI).



### 6. Standards and checklists The Emission Reporting program does not have any chec klist for the Area Source Inventory at this time. The Emission Group does this electronically through an excel spreadsheet that is created when needed.


### 7. Records Management The Area Source Inventory files are kept el ectronically at K:\OAQ_INV\Inv\Area Source.

The Branch Contact for the Air Programs Branch a nd the Sectio n contac t for the Techni cal Support and Modeling Section will keep copies of the SOPs for the Technical Support and Modeling Section to be referenced as needed. An electronic copy will also be available on K:\OAQ_INV\SOPs.

24Area Source Inventory S-006-OAQ-R-MO-08-S-R1 

### 8. Quality Assuran ce / Quality Control Comparisons are made against the emissions estimates made by The U.S. EPA in the NEI.


### 9. Continuous Improvement Cycle A periodic review will be completed per updates and changes made to the EIIP.



### 10. References The Area Source Inventory is a requirement of 40 CF R Part 51 Subpart A - Emission Inventory Reporting Requirements.


### 11. History of Revisions

Date Month/day/year Revision Number Description

02/27/2008 1 Revised using new SOP template.



### 12. Appendices None

25

# APPENDIX H

Lake Michigan Air Directors Consortium Emission Es timates Technical Support Document

### This page left intentionally blank.

# Regional Air Quality Analyses for

Ozone, PM 2. 5 

# , and Regional Haze:

F inal Technical Support Document

April 25 , 2008

States of Illinois, Indiana, Michigan, Ohio, and Wisconsin

# APPENDIX I

Lake Michigan Air Directors Consortium (LADCO) Ro und 5 Modeling Technical Support Document (Round 5 Photochemical Modeling Based on “Base M” Emissions inventory, revised version of “Base K”)

### This page left intentionally blank.February 27, 2008



## Base M Strategy Modeling: Emissions (Revised)

The purpose of this document is to summarize the emis sion estimates prepared for LADCO’s latest (Base M) 2005 base year and 200 8, 2009, 2012, and 2018 future year modeling

. Base year emissions by state and s ource sector for Base K (2002) and Base M (2005) are compared in Figure 1. A more detailed state and source sector summary is provided in Attachment 1

. A dditional

emission reports are available on the LADCO website : http://www.ladco.org

/tech/emis/r5/round5_reports.htm

.

VOC NOx SO2



### 0 2000 4000 6000 8000 10000 12000

2002

(K) 2005 ( M) 2002

(K) 2005 (M) 2002

(K) 2005 ( M) 

### WI

OH

MI

IN

IL

0 2000 4000 6000 8000 10000 12000

2002

(K) 2005 ( M) 2002

(K) 2005 (M) 2002

(K) 2005 (M) Area

Nonroad+MAR
Onroad
Non-EGU

EGU

Figure 1 . Base K and Base M Emissions for 5

- State LADCO Region : VOC, NOx, and SO2 (TPD, July weekday)



### Base Year Em i ssions In mid

- 2006, LADCO completed modeling analyses for a 2002 base year and several future year control strategies ( LADCO, 2006a and LADCO, 2006b) . Following those analyses, a decision was made to conduct additional modeling using a more current base year (2005). Examin ation of multiple base years provides for a more complete technical assessment. All modeling was conducted in accordance with USEPA modeling guidelines (USEPA, 2007).February 27, 2008



### For on

- road, ammonia, and biogenic sources, 2005 emissions were estimated by emission

m odels. For other sectors in the LADCO States, 2005 emissions were either supplied by a contractor ( railroads and commercial marine ) or by the States (point sources, area sources, and aircraft). For other sectors in non

- LADCO States, a contractor obtained the latest base (2002) and future year emission files (2009, 2018) from the other Regional Planning Organizations (RPOs) (Alpine, 2007 a ) . Specifically, the following versions of these emissions files were used : MANE

- VU: Version 3.1

, WRAP: Pre2002d

, CENRA P: Base F , and VISTAS: Base F

. The 2005 emissions were then estimated by linearly interpolating between the 2002 and 2009 emissions.

Further discussion of t he development of the 2005 base year emissions is provided below:

On

- R oad : CONCEPT was run by a contractor using transportation data (e.g., VMT and vehicle speeds) for 24 networks supplied by the state and local planning agencies in the LADCO States and Minnesota (Environ, 2008 ) . These data were first processed with T3 (Tra vel Demand Modeling [TDM] Transformation Tool) to pro vide inpu t files for CONCEPT

. For some networks, the VMT outputs from T3 were adjusted to match 2005 HPMS data. CONCEPT was then run with meteorological data for a July and January weekday, Satur day, and Sunday (July 15

– 17

a nd January 16

– 18) to produce link

- specific, hourly emission estimates

. A s patial plots of emissions for July 15 are provided in Figure 2

.

VOC Emissions NOx Emissions

Figure 2 . July 15, 2005 motor vehicle emissions for VOC (left) and NOx (r ight)



### For the non

- LADCO States, CONCEPT was run by a contractor using RPO

- based HPMS county

- level data (2002 and 2009) and MOBILE6 inputs (2002) compiled by another contractor (Environ, 2008) . HPMS VMT for 2005 were generated by linearly interpolating b etween the 2002 and 2009 data. The 2002 MOBILE6 inputs were used for the 2005 modeling, with a few adjustments (e.g., fuel sulfur content was set to 30 ppm, as required by the Tier 2/low sulfur regulations). Meteorological data for a July and January wee kday, Saturday, and Sunday (July 15

– 17 and January 16

– 18) were used.

For other months (for both LADCO and non

- LADCO States), weekday, Saturday, and Sunday emissions were linearly interpolated based on the January and July emissions

.February 27, 2008



### Off

- R oad : NMIM2 005 was run by Grant Hetherington (W isconsin DNR) to produce emission s for most off

- road sectors for the LADCO States plus Minnesota, Iowa, and Missouri. Improved model inputs included local data for construction and agricultural equipment prepared by a

c ontractor were incorporated (E.H. Pechan, 2004), and 2005 gasoline parameters. (Note, model updates prepared by AIR to address evaporative emissions were not included.)

EMS was run by LADCO using Grant Hetherington’s NMIM2005 data and , for the non

- LADCO States, using emission files supplied by Alpine based on data from the other R POs to produce weekday, Saturday, and Sunday emissions for each month.

Additional off

- road sectors (i.e., commercial marine, aircraft, and railroads [MAR]) were handled separate ly. Aircraft emissions were supplied by the LADCO States. Updated information for railroads and commercial marine for the LADCO States was prepared by a contractor (Environ

, 2007a and Environ 2007b)

. Table 1 compares the new 2005 emissions with the prev ious 2002 emission estimates. The new 2005 emissions reflect substantially lower commercial marine emissions and lower locomotive NOx emissions.

EMS was run by LADCO using the contractor and state data and , for the non

- LADCO States, using emission files supplied by Alpine based on data from the other R POs to produce weekday, Saturday, and Sunday emissions for each month.

Table 1. Locomotive and Commercial Marine Emissions for 2002 and 2005 Base Year

Railroads (TPY) Commercial Marine (TPY)

2002 2005 2002 2005

VOC 7,890 7,625 1,562 828

CO 20,121 20,017 8,823 6,727

NOx 182,226 145,132 64,441 42,336

PM 5,049 4,845 3,113 1,413

SO2 12,274 12,173 25,929 8,637

NH3 86 85

---- ----



### Area : EMS was run by LADCO using 2005 data supplied by the LAD CO States and, for the

non

- LADCO States, using emission files supplied by Alpine based on data from the other R POs to produce weekday, Saturday, and Sunday emissions for each month. Special attention was given to two source categories: industrial adhesive and sealant solvent emissions and outdoor wood boilers.

Industrial Adhesives and Sealants: T he NEI show s this to be a large VOC emissions category

in the LADCO States ( i.e.

., 50,000 TPY ) US EPA subsequently determined that “ (f) or the Region V states, we no longer believe that there are any activities in the Industrial Adhesives and Sealants category (SCC 2440020000) that have not been inventoried either in the point source Industrial Adhesives and Sealants category or under the Consumer and Commercial Adh esives and Sealants nonpoint category (SCC 2460600000

- all adhesives and sealants).” (USEPA, 2007b) Consequently, this category was omitted from the 2005 regional emissions inventory.February 27, 2008



### Outdoor Wood Boilers: Over the past several years, the installation a nd operation of outdoor wood boilers for residential use has increased dramatically in many northern states. Relying on an emission estimation methodology prepared by Bart Sponseller (WDNR , 2006 ), emissions were calculated by the other states for this cat egory.

EGU Point : EMS was run by LADCO using 2005 data supplied by the LADCO States and, for the non

- LADCO States, using emission files supplied by Alpine based on data from the other R POs to produce weekday, Saturday, and Sunday emissions for each month. 2005 EGU emissions were temporalized for modeling purposes using profiles prepared by Scott Edick (Michigan DEQ) based on CEM data for the period 2004

- 2006. Profiles were generated for monthly weekday/ S aturday/ S unday based on the median hourly emissions for that month, day, and hour of the day for the three years. Over 90% of NOX and SO2 emissions from EGUs in the LADCO states were assigned profiles. In non

- L adco states

, the annual EGUs emissions were replaced with the 2005 sum of hourly emissions for al l 365 days.

Non

- EGU Point : EMS was run by LADCO using 2005 data supplied by the LADCO States and, for the non

- LADCO States, using emission files supplied by Alpine based on data from the other R POs to produce weekday, Saturday, and Sunday emissions for each month. EGUs were removed from th is point source file.

Other improvements to the base year inventory included:

Canadian Emissions : Previous modeling inventories for Canadian sources were flawed due to problems with emissions (e.g., LADCO inventories omitted ammonia emissions) or stack parameters (e.g., VISTAS inventories failed to include proper stack parameters, resulting in emissions getting dumped in the surface layer of the model). For Base M, Scott Edick (Michigan DEQ) processed the 2005 Canadi an National Pollutant Release Inventory ( NPRI

– see http://www.ec.gc.ca/pdb/npri/ )

. Specifically, a subset of the NPRI data which are relevant to the air quality modeling were reformatted. A number of emissi on reports are available on the LADCO website ( http://www.ladco.org/tech/emis/basem/canada/index.htm ). Circle plot of point source emissions are presented in Figure 3

.February 27, 2008

Figure 3

. Base year emission plots for Canada



### Biogenic Emissions : A contractor provided an updated version of the CONCEPT/MEGAN (Model of Emissions of Gases and Aerosols from Nature

– see http://bai.acd.ucar.edu/Megan/ ) biogenics model , which was used to produce base year biogenic emission estimates (Alpine, 2007b)

. MEGAN includes functions for soil moisture plant stress, a more complete canopy model, full plant growth cycle emissions calculations, and state of the science emission rates.

Subsequent to deliver of the updated CONCEPT/MEGAN code, it was found that more recent data sets and model formulations were available. For t he purposes of the Round 5 modeling, LADCO simply scaled the emission estimates from the updated code to reflect these newer data. This resulted in lower emissions for several organic aerosol species and NOx

Compared to the EMS/BIOME emissions used for B ase K , t here is more regional isoprene with MEGAN (see Figure 4)

. Also, with the secondary organic aerosol updates to the CAMx air quality model, Base M includes emissions for monoterpenes and sesquiterpenes , which are pre

cursors of secondary PM 2. 5 

### organ ic carbon mass

.

Figure 4

. Isoprene emissions for Base M (left) v. Base K (right)February 27, 2008



### Ammonia Emissions : The CMU

- based 2002 (Base K) annual ammonia emissions were projected to 2005 using growth factors from the Round 4 emissions modeling. The se annual emis sions were then adjusted by applying monthly temporal factors based on the process

based ammonia emissions model ( http://www.conceptmodel.org/nh3/nh3_index.html ). The model was run for the fo llowing list of model farms using 200 2 meteor o logical data : Dairy (California, Wisconsin), Swine (Iowa, Wisconsin), and Beef (Texas, Washington, Wisconsin)

. Because the model was not complete for the poultry housing model

, swine was use in its place given that both use confined operations.

Each model farms ’ emissions were used to generate monthly average day emissions and a monthly profile. The profiles were applied to geographies most associated with that farm type (e.g., a ll LADCO states used the Wisc onsin fa rm results) . The following figure show s the daily variation in emissions for the model farms

.

Wisconsin

–

dairy Wisconsin

- swine

Daily Total - Swine 55001

0.000 0.500 1.000 1.500 2.000 2.500 3.000 3.500

01/03/02 01/17/02 01/31/02 02/14/02 02/28/02 03/14/02 03/28/02 04/11/02 04/25/02 05/09/02 05/23/02 06/06/02 06/20/02 07/04/02 07/18/02 08/01/02 08/15/02 08/29/02 09/12/02 09/26/02 10/10/02 10/24/02 11/07/02 11/21/02 12/05/02 12/19/02

DateNH3 emissions (Kg / day) Daily Total - Dairy 55001

0.00 2.00 4.00 6.00 8.00 10.00 12.00 14.00

01/03/02 01/17/02 01/31/02 02/14/02 02/28/02 03/14/02 03/28/02 04/11/02 04/25/02 05/09/02 05/23/02 06/06/02 06/20/02 07/04/02 07/18/02 08/01/02 08/15/02 08/29/02 09/12/02 09/26/02 10/10/02 10/24/02 11/07/02 11/21/02 12/05/02 12/19/02

DateNH3 emissions (Kg / day)

Washington

–

beef Texas

- beef

Daily Total - Beef 53001

0.000 0.500 1.000 1.500 2.000 2.500 3.000

01/03/02 01/17/02 01/31/02 02/14/02 02/28/02 03/14/02 03/28/02 04/11/02 04/25/02 05/09/02 05/23/02 06/06/02 06/20/02 07/04/02 07/18/02 08/01/02 08/15/02 08/29/02 09/12/02 09/26/02 10/10/02 10/24/02 11/07/02 11/21/02 12/05/02 12/19/02

DateNH3 emissions (Kg / day) Daily Total - Beef 48001

0.00 5.00 10.00 15.00 20.00 25.00 30.00 35.00 40.00 45.00

01/03/02 01/17/02 01/31/02 02/14/02 02/28/02 03/14/02 03/28/02 04/11/02 04/25/02 05/09/02 05/23/02 06/06/02 06/20/02 07/04/02 07/18/02 08/01/02 08/15/02 08/29/02 09/12/02 09/26/02 10/10/02 10/24/02 11/07/02 11/21/02 12/05/02 12/19/02

DateNH3 emissions (Kg / day)

Figure 5. Daily emissions for 2002 for various model farmsFebruary 27, 2008



### A plot of the resulting average daily emissions by state and month is provided in Figure 6

.

0 300 600 900 1200 1500 1800

Jan Fed March Apr May Jun Jul Aug Sept Oct Nov Dec

Illinois Indiana Io w a Michigan

Minnesota Ohio Wisconsin

Figure 6

. Average daily ammonia emissions for Midwest States by month for 2005



### Fires : For Base K, a contractor (EC/R, 2004) developed a 2001, 2002, and 20 03 fire emissions inventory for eight Midwest States (five LADCO states plus Iowa, Minnesota, and Missouri), including emissions from wild fires, prescribed fires, and agricultural burns. Projected emissions were also developed for 2010 and 2018 assuming “no smoke management” and “optimal smoke management” scenarios. An early model sensitivity run showed very little difference in modeled PM 2.5 

### concentrations. Consequently, the fire emissions were not included in subsequent modeling runs (i.e., they were not in the Base K or Base M modeling inventories).February 27, 2008



### Future Year Emissions Complete e mission inventories were developed for t wo future year s : 2009 and 2018 1



### . Source sector emission summaries for the base years (2002

– Base K and 2005

– Base M) and future years are shown in Figure 7

. A more detailed state and source sector summary is provided in Attachment 1. A dditional emission reports are available on the LADCO website ( http://64.27.125 .175/tech/emis/r5/round5_reports.htm

.

VOC NOx S O2

0 3000 6000 9000 12000

2002 2005 2009 2012 2015 2018 2002 2005 2009 2012 2015 2018 2002 2005 2009 2012 2015 2018 Area

On-road

Nonroad

Non-EGU

EGU

Figure 7 . Base year and future year emissions for 5

- State LADCO Region (TPD, July weekday)

1 A 2008 proxy inventory was prepared to support a preliminary 2008 modeling analysis to assess attainment for the basic nonattainment areas (i.e, for areas with a 2009 attainment date, the appropriate panning year is 2008). This inventory reflects the following assumptions:

On

- road: scale 2005 base year emissions using the Base K 2002

– 2009 trend (except for the Cincinnati

- Dayton area, where 2008 emissions were generated using CONCEPT and 2008 data supplied by the local planning agency)

Off

- road and area: scale 2005 base year emissions using the Base K 2002

- 2009 trend

Point

– EGU: use 2005 base year emissions, with slight adjustment (

- 10%)

Point

– Non

- EGU: use 2005 base year emissions (note: Base K 2002

- 2009 trend suggests little change)

Biogenics: use new 2005 base year emissions

A 2012 proxy inventory was prepared to support a preliminary 2012 modeling analysis to assess the effect of further emission reductions from existing controls. This inventory was derived by interpolating between 2009 and 2018 emissions for all sectors, except p oint sources (for which, the 2009 emissions were used).February 27, 2008



### For on

- road, off

- road, and EGU sources, the future year emissions were estimated by models (i.e., CONCEPT, NMIM2005, and IPM, respectively) and then processed by LADCO with EMS. For other sectors (area, MAR, and non

- EGU point sources)

, the future year emissions for the LADCO States were derived by applying growth and control factors to the base year inventory. These factors were developed by a contractor (E.H. Pechan , 2007 ). Growth factors were based initially on EGAS (version 5.0), and were subsequently modified (for select, priority categories) by examining emissions activity data. For the non

- L ADCO States, future year emission files were supplied by Alpine based on data from the other RPOs. Due to a lack of information on future year conditions, the biogenic VOC and NOx emissions, and all Canadian emissions were assumed to remain constant betwe en the base year and future years.

A “base” control scenario was prepared for each future year based on the following “on the books” controls (E.H. Pechan, 2007):

On

- Highway Mobile Sources

• Federal motor vehicle emission control program, low sulfur gaso line, and ultra

- low sulfur diesel fuel

• Inspection/Maintenance programs (nonattainment areas)

• Reformulated gasoline (nonattainment areas)

Off

- Highway Mobile Sources

• Federal control programs incorporated into NONROAD model (e.g., nonroad diesel rule), plus the evaporative Large Spark Ignition and Recreational Vehicle standards

• Heavy

- duty diesel (2007) engine standard/Low sulfur fuel

• Federal railroad/locomotive standards

• Federal commercial marine vessel engine standards

Area Sources

• Consumer solvents

• AIM coa tings

• Aerosol coatings

• Portable fuel containers

Power Plants

• Title IV (Phases I and II)

• NOx SIP Call

• Clean Air Interstate Rule

• Clean Air Mercury Rule

Other Point Sources

• VOC 2

- , 4

- , 7

- , and 10

- year MACT standards 2



### • Combustion turbine MACT

• Consent decrees (refiner ies, ethanol plants, and ALCOA) 3

2 E.H. Pechan’s original control file included EPA

- default control factor information. Alternative control factors were developed by Wisconsin for a few MACT categories, and were also applied to th e other four LADCO States.February 27, 2008



### • Other ( Illinois and Ohio NOx RACT 4



### , and BART in IN and WI)

Further discus sion of the development of the future year emissions is provided below:

On

- R oad : Similar to the base year modeling, CONCEPT was run using t ransportation data (e.g., VMT and vehicle speeds) supplied by the state and local planning agencies for 2009 and 2018 (Environ, 2008) . CONCEPT was only run with meteorological data for a July weekday (July 15) . The emissions for Saturday and Sunday were derived by using scaling factors based on the 2005 emissions. The state

- level emissions for the five LADCO States plus Minnesota are summarized in Table 2 5



### .

For the non

- LADCO States, CONCEPT was run by Environ using HPMS county

- level data and MOBILE6 inp uts compiled by another contractor for VISTAS. Note, the emissions modeling for IA, MO, and OK was redone for 2009 to reflect the state

- developed registration distribution data. (The initial modeling for 2009 used national default values for registration distribution assumed by VISTAS’ contractor. CENRAP’s contractor developed emissions inventories for 2002 and 2018 using the state

- developed data. For consistency, Environ’s remodeling for these three states for 2009 also used the state

- developed data.) Meteorological data for a July weekday (July 15) were used. The emissions for Saturday and Sunday were derived by using scaling factors based on the 2005 emissions.

For other months (for both LADCO and non

- LADCO States), January weekday, Saturday, and Sunday emissions were derived based on the July:January ratios for 2005, and then the weekday, Saturday, and Sunday emissions for other months were linearly interpolated based on the January and July emissions

.

3 E.H. Pechan’s original control file included control factors for three sources in Wayne County, MI. These control factors were not applied in the regional

- scale modeling to avoid double

- counting with the State’s local

- scale a nalysis for PM2.5.

4 WI believes that NOx RACT for their sources is already included in the 2005 basecase and EGU “will do” scenario, and IN provided NOx RACT information for inclusion as a no

- EGU “may do” scenario.
5 For northeastern IL (CATS region), 2009 and 2018 emissions were increases by 9% and 8%, respectively, to reflect newer transportation modeling by CATS.February 27, 2008

Table 2. Summary of On

- road Emissions (TP D

– July 15, 2005)

Year State CO

- tpd TOG

- tpd NOx

- tpd PM2.5

- tpd SO2

- tpd NH3

- tpd Sum of VMT

2005 IL 3,684.3 341.5 748.2 12.9 9.6 35.9 344,087,819.6

IN 3,384.9 282.0 541.1 8.9 11.1 25.7 245,537,231.9

MI 4,210.3 351.9 722.0 12.4 13.9 35.3 340,834,025.9

MN 2,569.1 218.7 380.5 6.3 7.6 17.7 170,024,599.7

OH 6,113.4 679.8 933.6 16.2 18.8 36.5 360,521,068.6

WI 2,206.0 175.1 457.5 7.8 9.2 19.7 189,123,964.3

Total 22,168.0 2,049.0 3,782.9 64.5 70.2 170.8 1,650,128,709.9

2009 IL 2,824.4 268.0 52 7.8 10.1 4.2 38.9 372,132,591.1

IN 2,839.5 234.9 401.9 6.7 2.8 26.1 249,817,026.3

MI 3,172.0 269.2 500.9 9.2 4.0 37.1 356,347,010.5

MN 2,256.8 206.3 307.5 5.1 2.3 21.5 204,443,017.8

OH 4,619.2 423.7 693.5 11.8 4.7 39.5 387,428,127.2

WI 1,673.4 11 9.4 322.1 5.7 2.3 20.6 197,729,964.9

Total 17,385.3 1,521.5 2,753.6 48.7 20.3 183.6 1,767,897,737.8

2018 IL 2,084.7 151.5 200.7 6.3 3.7 43.1 413,887,887.3

IN 2,217.3 138.4 173.0 4.4 2.6 30.2 288,042,232.1

MI 2,434.3 163.5 204.1 5.9 3.6 40. 5 388,128,431.8

MN 1,799.6 123.1 137.1 3.6 2.2 24.9 237,022,213.7

OH 3,361.5 242.5 274.1 6.8 4.0 43.1 421,694,093.4

WI 1,255.5 68.4 138.5 3.9 2.0 22.2 218,277,167.5

Total 13,152.9 887.5 1,127.5 30.8 18.1 203.9 1,967,052,025.8February 27, 2008



### EGU Point : Future ye ar emissions were based on EPA’s IPM3.0 modeling 6



### . Three CAIR scenarios were addressed:

5 a: EPA’s IPM3.0 was assumed as the future year base for EGUs.

5 b: EPA’s IPM3.0, with several “will do” adjustments identified by the States. These adjustments should reflect a legally binding commitment (e.g., signed contract, consent decree, or operating permit). 7



### 5 c: EPA’s IPM3.0, with several “may do” adjustments identified by the States. These adjustments reflect less rigorous criteria, but should stil l be some type of public reality (e.g., BART determination or press announcement).

Table 3 summarizes the SO2 and NOx emissions for the three scenarios. The individual f acilities affected by the “will do” and “may do” adjustments are identified in Attac hment 2. The net effect of these adjustments is a small increase in regional SO2 and NOx emissions.

Based on initial discussions with USEPA, a decision was made to use the 2010 IPM emissions in the 2009 modeling. USEPA subsequently insisted that 2009 mo deling must represent 2009 conditions. Because 2009 and 2010 EGU NOx emissions are expected to be similar (note: CAIR Phase I compliance date for NOx is 2009), the Round 5.1 ozone modeling was not redone.

USEPA believes that 2009 and 2010 EGU SO2 emissio ns may be significantly different (note: CAIR Phase I compliance date for SO2 is 2010). In particular, USEPA noted that information on projected scrubber installations identifies several facilities are not expected to be completed until 2010. A model sen sitivity run was conducted with adjusted (higher) EGU SO2 emissions.

6 The second set of new IPM runs by EPA were used. These runs were performed at the request of the RPOs and reflect the addition of run y ears 2012 and 2018 , and the use of four load segments for 2032 to decrease model size (instead of six segments). Comparing the results in this run with EPA’s initial v3.0, showed small differences Below is a quick summary of the run year differences.

EP A Base Case for IPM v.3.0 2010: 2009

- 2012 2015: 2013

- 2017 2020: 2018

- 2022 2025: 2023

- 2027 2032: 2028

- 2035

Base Case RPO Run for IPM v3.0 (added 2012 and 2018 run years, 2020 run year merged with the 2025 run year, and four load segments used for the 2032 run year) 2010: 2009

- 2011 2012: 2012

- 2012 2015: 2013

- 2017 2018: 2018

- 2019 2025: 2020

- 2028 2032: 2029

- 2035

7 Scenario 5b and 5c also reflect changes in Minnesota, Missouri, and North Dakota.February 27, 2008



### Table 4 provides information from USEPA s Clean Air Markets Division (CAMD) on scrubber installation dates. This information is based on various sources, including company announcements, consent decrees, v endors, and organizations that track scrubber installations. While there may be uncertainty in any projection of control installations, USEPA conside rs these adequate project ions for SIP planning purposes.

USEPA identified six plants which: (1) are projected in IPM3.0 to have scrubbers in place by 2010 (or 2011), but will not be completed by 2009, and (2) are most likely to impact PM 2. 5 

### air quality in the upper Midwest (see highlighting in Table 4 ). To reflect uncontrolled (2009) emi ssions for those facilities (and units), LADCO substituted actual 2005 emissions for the IPM3.0 projected 2010 emissions. The revised (2009) SO2 emissions for the six facilities (see Table 5) represent a 5

- 6% increase in domainwide SO2 emissions.February 27, 2008

Table 3. Comparison of EGU Emissions for Base (5a), Will Do (5b), and Will Do (5c) Scenarios



### 2010 2018 SO2 5a 5b 5c 5a 5b 5c
IL 958 881 881 869 433 433
IN 1033 1318 1318 1036 1194 1194
MI 667 667 667 725 725 725
OH 1326 1410 1410 983 1127 1127
WI 460 460 421 435 499 235

4444 4736 4697 4048 3978 3714

MN 162 148 148 187 167 157

NOx 5a 5b 5c 5a 5b 5c
IL 275 247 247 224 195 195
IN 370 372 372 255 266 266
MI 242 242 242 243 243 243
OH 281 305 305 285 310 310
WI 165 164 155 176 172 145

1333 1330 1321 1183 1186 1159

MN 116 142 142 132 157 125February 27, 2008

Table 4. Facilities Anticipating SO2 Controls in 2009 and 2010

State Name Plant Name UniqueID_Final ORIS Code Unit

ID Capacity

MW Scrubber

On lineYear Scrubber

OnlineMonth
Alabama Barry 3_B_5 3 5 768 2010
Alabama E C Gaston 26_B_5 26 5 861 2010
Arizona Cholla 113_B_3 113 3 271 2009 Florida Crystal River 628_B_4 628 4 720 2010
Florida Crist 641_B_6 641 6 302 2010 Florida Crist 641_B_ 7 641 7 477 2010
Florida Crystal River 628_B_5 628 5 717 2009 5
Florida Deerhaven Generating Station 663_B_B2 663 B2 228 2009 5 Georgia Bowen 703_B_1BLR 703 1BLR 713 2010 Georgia Wansley 6052_B_2 6052 2 892 2009 5 Georgia Bowen 703_B_2BLR 703 2BLR 7 18 2009 4
Indiana Clifty Creek 983_B_1 983 1 217 2010
Indiana Clifty Creek 983_B_2 983 2 217 2010 Indiana Clifty Creek 983_B_3 983 3 217 2010
Indiana Clifty Creek 983_B_4 983 4 217 2010 Indiana Clifty Creek 983_B_5 983 5 217 2010
Indiana Clifty Creek 983_B_6 983 6 217 2010
Indiana Warrick 6705_B_4 6705 4 300 2010 Kentucky Big Sandy 1353_B_BSU2 1353 BSU2 800 2009 11 Kentucky E W Brown 1355_B_1 1355 1 94 2009 1 Kentucky E W Brown 1355_B_2 1355 2 160 2009 1 Kentucky E W Brown 1355_B_3 1355 3 422 2009 1 Kentucky H L Spurlock 6041_B_1 6041 1 315 2009 Maryland Brandon Shores 602_B_1 602 1 643 2010 Maryland Brandon Shores 602_B_2 602 2 643 2010 Maryland Chalk Point LLC 1571_B_1 1571 1 341 2010 Maryland Chalk Point LLC 1571_B_2 1571 2 342 2010 Maryland Dickerson 1572_B_1 1572 1 182 2010 Maryland Dickerson 1572_B_2 1572 2 182 2010 Maryland Dickerson 1572_B_3 1572 3 182 2010 Maryland Morgantown Generating Plant 1573_B_1 1573 1 624 2009 Maryland Morgantown Generating Plant 1573_B_2 1573 2 620 2009

Michigan Monroe 1733_B_4 1733 4 775 2009 (2010?)
Missouri Sioux 2107_B_1 2107 1 497 2010 Missouri Sioux 2107_B_2 2107 2 497 2010 New Jersey PSEG Mercer Gen. Station 2408_B_1 2408 1 315.3 2010 New Jersey PSEG Mercer Gen

. Station 2408_B_2 2408 2 309.9 2010 New York AES Westover 2526_B_11 2526 11 21.85 2010
New York AES Westover 2526_B_12 2526 12 21.85 2010 New York AES Westover 2526_B_13 2526 13 84 2010
New York AES Greenidge LLC 2527_B_4 2527 4 26.5 2010
New York AES Gr eenidge LLC 2527_B_5 2527 5 26.5 2010 NorthCarolina Cliffside 2721_B_1 2721 1 38 2010February 27, 2008

NorthCarolina Cliffside 2721_B_2 2721 2 38 2010 NorthCarolina Cliffside 2721_B_3 2721 3 61 2010 NorthCarolina Cliffside 2721_B_4 2721 4 61 2010 NorthCarolina Cl iffside 2721_B_5 2721 5 550 2010 NorthCarolina G G Allen 2718_B_1 2718 1 161.73 2009 5 NorthCarolina Roxboro 2712_B_1 2712 1 369 2009 NorthCarolina G G Allen 2718_B_2 2718 2 161.73 2009 NorthCarolina G G Allen 2718_B_3 2718 3 259.77 2009 NorthC arolina G G Allen 2718_B_4 2718 4 274.77 2009 NorthCarolina G G Allen 2718_B_5 2718 5 265 2009 NorthCarolina Mayo 6250_B_1A 6250 1A 361.5 2009 NorthCarolina Mayo 6250_B_1B 6250 1B 361.5 2009 Ohio W H Sammis 2866_B_6 2866 6 630 2011 Ohio W H S ammis 2866_B_7 2866 7 630 2011 Ohio R E Burger 2864_B_7 2864 7 156 2010 Ohio R E Burger 2864_B_8 2864 8 156 2010 Ohio Kyger Creek 2876_B_1 2876 1 217 2010 Ohio Kyger Creek 2876_B_2 2876 2 217 2010 Ohio Kyger Creek 2876_B_3 2876 3 217 2010 Ohio Kyger Creek 2876_B_4 2876 4 217 2010 Ohio Kyger Creek 2876_B_5 2876 5 217 2010 Ohio Conesville 2840_B_4 2840 4 780 2009 4 Ohio Bay Shore 2878_B_4 2878 4 215 2009 Pennsylvania Cheswick Power Plant 8226_B_1 8226 1 580 2010 Pennsylvania Hatfields Fe rry Power Station 3179_B_1 3179 1 530 2009 1 Pennsylvania Hatfields Ferry Power Station 3179_B_2 3179 2 530 2009 1 Pennsylvania Hatfields Ferry Power Station 3179_B_3 3179 3 530 2009 1 Pennsylvania Keystone 3136_B_1 3136 1 850 2009 Pennsylvania Keyst

one 3136_B_2 3136 2 850 2009 Pennsylvania PPL Brunner Island 3140_B_1 3140 1 321 2009 Pennsylvania PPL Brunner Island 3140_B_2 3140 2 378 2009
Tennessee Kingston 3407_B_1 3407 1 135 2010 Tennessee Kingston 3407_B_2 3407 2 135 2010
Tennessee Ki ngston 3407_B_3 3407 3 135 2010
Tennessee Kingston 3407_B_4 3407 4 135 2010 Tennessee Kingston 3407_B_5 3407 5 177 2010
Tennessee Kingston 3407_B_6 3407 6 177 2010 Tennessee Kingston 3407_B_7 3407 7 177 2010
Tennessee Kingston 3407_B_8 3407 8 177 2010
Tennessee Kingston 3407_B_9 3407 9 178 2010 Tennessee Bull Run 3396_B_1 3396 1 881 2009 1
Texas Fayette Power Project 6179_B_1 6179 1 598 2009 Texas Fayette Power Project 6179_B_2 6179 2 598 2009 Virginia Chesterfield 3797_B_5 3797 5 310 2 010 Virginia Yorktown 3809_B_1 3809 1 159 2010February 27, 2008

Table 5. Summary of Adjusted EGU SO2 Emissions (TPD)

State Plant 2010 IPM 2005 BY

Indiana Clifty Creek 41.41 225.32

Missouri Ameren Sioux 22.25 141.92

Ohio Kyger Creek 21.53 197.68

Ohio Sammis 147.97 305.90

Pennsylv a nia Cheswick 11.53 103.98

Tennessee Kingston 41.15 155.20February 27, 2008



### References

Alpine Geophysics, 2007 a , “Emissions Inventory Assistance: 2005 Base Year Biogenic and Other (non

- LADCO) State Emissions, Preparation and Delivery of Non

- MR PO Emission Files< March 12, 2007.

Alpine Geophysics, 2007b, Updated CONCEPT code with new (MEGAN) biogenic emissions delivered via e

- mail from James Wilkinson on February 9, 2007.

EC/R, Incorporated, 2004, “Fire Emissions Inventory Development for the M idwest Regional Planning Organization”, Final Report, September 30, 2004.

E.H. Pechan, 2004, “LADCO Nonroad Emissions Inventory Project

– Development of Local Data for Construction and Agricultural Equipment”, Final Report, September 10, 2004

E.H. Pechan , 2005, “Development of Updated Growth and Control Factors for Lake Michigan Air Directors Consortium (LADCO)”, Draft Report, December 29, 2005.

E. H. Pechan, 2007, “Development of 2005 Base Year Growth and Control Factors for Lake Michigan Air Directors Consortium (LADCO)”, Final Report, September 2007.

Environ, 2004, “LADCO Nonroad Emissions Inventory Project for Locomotive, Commercial Marine, and Recreational Marine Emission Sources, Final Report, December 2004.

Environ, 2007 a , “LADCO 2005 Locomotive Emissions”, Draft, February 2007.

Environ, 2007 b , “LADCO 2005 Commercial Marine Emissions”, Draft, March 2, 2007.

Environ, 200 8 , “LADCO On

- Road Emission Inventory Developm ent Using CONCEPT MV”, January 2008

. LADCO, 2006a, “Base K/Round 4 Strategy Modeli ng” Emissions”, May 16, 2006.

LADCO, 2006b, “Base K/Round 4 Modeling: Summary”, August 31, 2006.

Mansell, G, Z. Wang, R. Zhang, J. Fadel, T. Ramsey, H. Xin, Y. Liang, and J. Arogo, 2005, “An Improved Process

- Based Ammonia Emissions Model for Agricultural Sources

– Emission Estimates”

USEPA, 2007a, "Guidance for on the Use of Models and Other Analyses for Demonstrating Attainment of Air Quality Goals for Ozone, PM 2. 5 

### , and Regional Haze”, EPA

- 454/B07

- 002, April 2007.

USEPA, 2007b, E

- mail from Dennis Bea uregard (OAQPS) dated February 22, 2007.

Zhang, R, T. Ramsey, J. Fadel, J. Arogo, Z. Wang, G. Mansell, and H. Xin, 2005, “An Improved Process

- Based Ammonia Emissions Model for Agricultural Sources

– Model Development”

WDNR, 2006, “ Wisconsin Draft 2005 Ou tdoor Wood Boiler Methodology ”, PowerPoint presentation by Bart Sponseller, November 13, 2006.February 27, 2008



### Web Sites:
http://www.ladco.org/tech/emis/basek/BaseK_Reports.htm
http://www.ladco.org/tech/emis/r5/round5_reports.htm

http://www.ladco.org/tech/emis/basem/canada/index.htm

http://www.ec.gc.ca/pdb/npri/

http://bai.acd.ucar.edu/Megan/

http://www.conceptmodel.org/nh3/nh3_index.htmlFebruary 27, 2008



# ATTACHME NT 1

Emissions SummariesVOC Base M BaseK Base M BaseK BaseK Base M NOx Base M BaseK Base M BaseK BaseK Base M SOX Base M BaseK Base M BaseK BaseK Base M PM2.5 Base M BaseK Base M BaseK BaseK Base M

July 2002 2005 2009 2009 2012 2018 2018 2002 2005 2009 2009 2012 2018 2018 2002 2005 2009 2009 2012 2018 2018 2002 2005 2009 2009 2012 2018 2018
Nonroad
IL 224 321 164 257 149 130 213 324 333 263 275 224 154 155 31 33 5 5 0.6 0.4 0.4 30 24 14
IN 125 195 94 160 95 95 128 178 191 142 158 141 141 89 17 19 3 3 3 0.3 0.2 17 13 7
MI 348 414 307 350 276 222 271 205 239 159 197 133 93 112 19 22 3 3 0.5 0.3 0.3 22 18 11
OH 222 356 161 294 145 126 238 253 304 195 246 162 109 135 23 29 4 5 0.5 0.3 0.4 27 22 13
WI 214 238 194 203 175 140 157 145 157 114 129 97 69 77 13 15 2 2 0.3 0.2 0.2 14 12 7
5-State Total 1133 1524 920 1264 840 713 1007 1105 1224 873 1005 757 566 568 103 118 17 18 4.9 1.5 1.5 110 89 52
U.S. Total 8463 9815 5442 8448 5244 6581 6041 9060 6057 8120 5832 5100 505 654 117 153 104 13 573 750 475

MAR
IL 10 11 10 10 10 10 6 277 246 201 228 195 186 165 0 22 0 19 0 0 17 7 6 4
IN 5 5 5 5 5 5 3 123 93 89 87 87 84 65 0.2 8 0.2 7 0.2 0.2 6 2 2 2
MI 7 7 7 7 7 8 7 114 87 112 82 111 110 65 0.6 21 0.7 14 0.7 0.8 8 3 3 2
OH 8 7 8 7 8 8 5 177 134 128 126 126 122 94 0.4 14 0.3 12 0.3 0.3 10 4 4 2
WI 4 4 4 4 4 4 3 79 58 59 54 59 57 41 12.7 8 9.5 6 9.5 8.7 5 2 2 1
5-State Total 34 34 34 33 34 35 24 770 618 589 577 578 559 430 13.9 73 10.7 58 10.7 10 46 18 17 11
U.S. Total 307 317 321 157 329 346 334 4968 4515 4002 1813 3964 3919 3812 620 512 509 122 509 503 290 147 57 165

OtherArea
IL 679 675 688 594 700 738 582 62 48 68 48 70 73 49 11 11 12 16 12 13 16 40 64 69
IN 354 391 365 358 373 398 384 62 56 65 58 67 69 59 158 32 150 32 151 153 32 2 2 2
MI 518 652 516 562 520 541 549 49 49 52 50 53 54 51 71 29 68 29 68 68 28 111 114 120
OH 546 604 550 506 558 593 487 50 93 59 108 60 62 108 22 6 34 15 35 35 14 19 35 34
WI 458 315 467 290 474 506 293 32 37 34 37 34 35 37 9 17 9 13 10 10 13 11 12 12
5-State Total 2555 2637 2586 2310 2625 2776 2295 255 283 278 301 284 293 304 271 95 273 105 276 279 103 183 227 237
U.S. Total 17876 21093 18638 18683 20512 24300 3856 4899 4100 4220 4418 5357 2075 2947 2062 2559 2189 2709 2735 2621 2570

On-Road
IL 446 341 314 268 260 197 151 890 748 578 528 474 300 201 9 4 3 13 10 6
IN 405 282 237 235 193 150 138 703 541 425 402 313 187 173 11 3 2 9 7 2
MI 522 351 335 269 303 217 163 926 722 680 501 619 385 204 14 4 3 12 9 3
OH 574 680 365 424 340 238 242 1035 934 609 693 512 270 274 18 4 4 16 12 4
WI 238 175 144 119 117 88 68 481 457 303 322 226 118 138 9 2 2 8 6 2
5-State Total 2185 1829 1395 1315 1213 890 762 4035 3402 2595 2446 2144 1260 990 61 17 14 58 44 17
U.S. Total 14263 7825 23499 13170

EGU
IL 9 7 8 6 8 9 7 712 305 227 275 244 231 224 1310 1158 944 958 789 810 869 13 34 77
IN 6 6 6 6 7 6 6 830 393 406 370 424 283 255 2499 2614 1267 1033 1263 1048 1036 16 73 74
MI 12 6 11 4 11 12 4 448 393 218 242 219 247 243 1103 1251 1022 667 1031 1058 725 15 25 29
OH 5 4 6 5 7 7 6 1139 408 330 280 322 271 285 3131 3405 1463 1326 994 701 983 28 94 80
WI 3 5 3 2 4 4 3 293 213 146 165 139 147 177 602 545 512 460 492 500 435 0 22 25
5-State Total 35 28 34 23 37 38 26 3422 1712 1327 1332 1348 1179 1184 8645 8973 5208 4444 4569 4117 4048 72 248 285
U.S. Total 214 140 195 124 197 215 138 14371 10316 7746 7274 7721 7007 6095 31839 34545 20163 16903 17629 14727 14133 685 1131 1571

Non-EGU
IL 313 221 286 218 305 350 258 356 330 334 218 338 343 235 373 423 251 335 257 249 346 16 17 19
IN 150 130 160 137 170 199 167 238 179 212 175 216 225 178 292 218 270 216 274 290 180 35 36 44
MI 123 116 115 119 122 139 140 216 240 208 242 214 229 271 162 158 166 148 171 185 163 20 21 25
OH 77 84 75 87 79 90 104 177 175 157 166 160 167 178 240 289 231 288 210 216 293 27 28 33
WI 88 84 97 87 104 120 106 98 97 91 93 92 94 81 163 156 154 152 155 156 85 0 0.1 0.1
5-State Total 751 635 733 648 780 898 775 1085 1021 1002 894 1020 1058 943 1230 1244 1072 1139 1067 1096 1067 98 102 121
U.S. Total 4087 3877 4409 4700 5378 6446 6730 6129 6435 6952 5759 5630 6093 6340 6970 1444 1777

IL 1681 1576 1470 1353 1432 1434 1217 2621 2010 1671 1572 1545 1287 1029 1725 1656 1212 1337 1059 1072 1251 119 155 189
IN 1045 1009 867 901 843 853 826 2134 1453 1339 1250 1248 989 819 2966 2902 1690 1294 1691 1492 1256 81 133 131
MI 1530 1546 1291 1311 1239 1139 1134 1958 1730 1429 1314 1349 1118 946 1356 1495 1260 865 1271 1312 927 183 190 190
OH 1432 1735 1165 1323 1137 1062 1082 2831 2048 1478 1619 1342 1001 1074 3416 3761 1732 1650 1240 953 1304 121 195 166
WI 1005 821 909 705 878 862 630 1128 1019 747 800 647 520 551 800 750 687 635 667 675 540 35 54 47
5-State Total 6693 6687 5702 5593 5529 5350 4889 10672 8260 6664 6555 6131 4915 4419 10263 10564 6581 5781 5928 5504 5280 539 727 723February 27, 2008



# ATTACHMENT 2

“Will Do” and “May Do” EGU Facility EmissionsFebruary 27, 2008



### 2009

– Difference between base (5a) and “will do” (5b) scenarios

The SAS System 09:55 Wednesday, February 27, 2008 1

------------------------ ------------------------------------ polid=NOX

--------------------------------------------------------

-----
Obs cntryid stid cyid fcid name polid aceebase aceenew diff

1 US 17 97 097190AAC MIDWEST GENERAT NOX 11.54 6.28

- 5.266 2 US 17 197 197810AAK MIDWEST GENERAT NOX 21.11 9.46

- 11.652 3 US 18 73 00008 NIPSCO

- R.M. S NOX 26.50 24.81

- 1.691 4 US 18 77 00001 IKEC

- CLIFTY C NOX 11.58 16.42 4.836 5 US 18 89 00117 NIPSCO

- DEAN H NOX 20.51 19.13

- 1.384 6 US 27 37 2703700003 NSP dba Xcel En NOX 8.03 26.74 18.709 7 US 27 61 2706100004 Minne sota Power NOX 15.43 18.40 2.969 8 US 27 163 2716300005 Xcel Energy

- A NOX 4.21 5.92 1.718 9 US 29 183 0001 AMERENUE

- SIOUX NOX 28.47 12.81

- 15.658 10 US 38 55 126 Coal Creek Stat NOX 30.49 30.36

- 0.132 11 US 38 57 12 Leland Olds Sta NOX 11 .32 36.67 25.348 12 US 38 57 125 Stanton Station NOX 6.11 6.11 0.002 13 US 38 57 13 Antelope Valley NOX 33.00 36.39 3.385 14 US 38 57 289 Coyote NOX 35.12 36.95 1.839 15 US 38 59 172 RM Heskett Stat NOX 5.45 4.72

- 0.727 16 US 38 65 165 M R Young Stati NOX 6.02 71.10 65.081 17 US 39 93 0247030013 AVON LAKE POWER NOX 3.98 20.54 16.561 1 8 US 39 129 0165000006 NOX . 1.69 . 19 US 55 11 606034110 DAIRYLAND POWER NOX 19.24 18.96

- 0.279 20 US 55 21 111003090 Alliant Energy

- NOX 14.23 17.16 2.927 21 US 55 43 122014530 Alliant Energy

- NOX 7.61 7.77 0.160 22 US 55 59 230006260 WIS ELECTRIC PO NOX 7.39 14.03 6.647 23 US 55 71 436035930 MANITOWOC PUBLI NOX 2.06 1.80

- 0.259 24 US 55 79 241007690 WIS ELECTRIC PO NOX 15.25 15.41 0.166 25 US 55 79 241007800 WIS ELECTRIC PO NOX 7.87 6.07

- 1.801 26 US 55 117 460033090 WP & L All iant NOX 19.06 11.85

- 7.215 27 US 55 123 663020930 DAIRYLAND POWER NOX 10.47 8.52

- 1.955

----- -------- ------- -------- polid 382.05 486.07 102.327February 27, 2008

------------------------------------------------------------ polid=SO2

------------------------- -------------------------------

-----
Obs cntryid stid cyid fcid name polid aceebase aceenew diff

28 US 17 97 097190AAC MIDWEST GENERAT SO2 49.9 1 29.27

- 20.636 29 US 17 197 197810AAK MIDWEST GENERAT SO2 91.90 62.70

- 29.198 30 US 18 29 00002 AMERICAN ELECTR SO2 66.34 102.72 36.389 31 US 18 43 00004 PSI ENERGY

- GA SO2 25.53 66.01 40.488 32 US 18 73 00008 NIPSCO

- R.M. S SO2 82.52 63.71

- 18.817 33 US 18 147 00020 INDIANA MICHIGA SO2 71.67 198.71 127.042 34 US 18 167 00021 PSI ENERGY

- WA SO2 76.09 175.87 99.786 35 US 27 31 2703100001 Minnesota Power SO2 12.27 5.75

- 6.512 36 US 27 61 2706100004 Minnesota Power SO2 30.76 20.79

- 9.968 37 US 27 163 2716300005 Xcel Energy

- A SO2 5.33 7.11 1.777 38 US 29 183 0001 AMERENUE

- SIOUX SO2 22.25 8.34

- 13.903 39 US 38 55 126 Coal Creek Stat SO2 27.45 75.37 47.926 40 US 38 57 12 Leland Olds Sta SO2 108.15 126.06 17.906 41 US 38 57 125 Stanton Station SO2 25.29 12.37

- 12.922 42 US 38 57 13 Antelope Valley SO2 26.60 43.72 17.128 43 US 38 57 289 Coyote SO2 19.26 53.19 33.932 44 US 38 59 172 RM Heskett Stat SO2 9.23 30.11 20.872 45 US 38 65 165 M R Young Stati SO2 27.98 82.23 54.249 46 US 39 81 0641160017 W. H. SAMMIS PL SO2 147.97 55.61

- 92.363 47 US 39 93 0247030013 AVON LAKE POWER SO2 7.62 127.04 119.417 48 US 39 129 0165000006 SO2 . 16.55 . 49 US 55 21 111003090 Alliant Energy

- SO2 61.97 74.80 1 2.822 50 US 55 43 122014530 Alliant Energy

- SO2 11.49 42.60 31.111 51 US 55 59 230006260 WIS ELECTRIC PO SO2 7.39 12.34 4.949

52 US 55 71 436035930 MANITOWOC PUBLI SO2 5.90 9.95 4.050 53 US 55 79 241007690 WIS ELECTRIC PO SO2 59.72 41.19

- 18.535 54 US 55 79 241007800 WIS ELECTRIC PO SO2 38.79 21.36

- 17.433 55 US 55 123 663020930 DAIRYLAND POWER SO2 19.56 3.79

- 15.772

----- -------- ------- -------- polid 1138.93 1569.26 413.785

======== ======= ======== 1520.97 2055.32 516.112February 27, 2008



### 2009

– Difference between “will do” (5b) and “may do” (5c) s cenario s

The SAS System 09:55 Wednesday, February 27, 2008 1

------------------------------------------------------------ polid=NOX

----------------------------------------- ---------------

-----
Obs cntryid stid cyid fcid name polid aceebase aceenew diff

1 US 19 139 70

- 01

- 011 MUSCATINE POWER NOX 5.649 3.926

- 1.7226 2 US 55 9 405031990 WI PUBLIC SERVI NOX 9.234 7.786

- 1.4476 3 US 55 11 606034110 DAIRYLAND POWER NOX 18.957 18.994 0.0377 4 US 55 21 111003090 Alliant Energy

- NOX 17.158 17.156

- 0.0021 5 US 55 25 113004430 MADISON GAS & E NOX 3.886 2.639

- 1.2470 6 US 55 43 122014530 Alliant Energy

- NOX 7.765 7.756

- 0.0091 7 US 55 59 230006260 WIS ELECTRIC PO NOX 14.034 9.826

- 4.2074 8 US 55 71 436035930 MANITOWOC PUBLI NOX 1.800 0.439

- 1.3610 9 US 55 79 241007690 WIS ELECTRIC PO NOX 15.413 15.435 0.0219 10 US 55 79 241007800 WIS ELECTRIC PO NOX 6.068 6.072 0.0041 11 US 55 117 460033090 WP & L Alliant NOX 11.847 11.892 0.0456 12 US 55 123 663020930 DAIRYLAND POWER NOX 8.517 8.482

- 0.0343

----- -------- ------- -------- polid 120.325 110.404

- 9.9218

------------------------------------------------------------ polid=SO2

--------------------------------------------------------

-----
Obs cntryid stid cyid fcid name polid aceebase aceenew diff

13 US 19 139 70

- 01

- 011 MUSCATINE POWER SO2 6.237 11.178 4.9415 14 US 55 9 405031990 WI PUBLIC SERVI SO2 21.750 18.074

- 3.6753 15 US 55 21 111003090 Alliant Energy

- SO2 74.796 74.988 0.1924 16 US 55 25 113004430 MADISON GAS & E SO2 16.331 0.063

- 16.2672 17 US 55 43 122014530 Alliant Energy

- SO2 42.604 42.640 0.0362 18 US 55 59 230006260 WIS ELECTRIC PO SO2 12.336 9.850 -2 .4867 19 US 55 71 436035930 MANITOWOC PUBLI SO2 9.949 3.001

- 6.9477 20 US 55 79 241007690 WIS ELECTRIC PO SO2 41.189 41.210 0.0207

21 US 55 79 241007800 WIS ELECTRIC PO SO2 21.360 21.430 0.0699 22 US 55 123 663020930 DAIRYLAND POWER SO2 3.785 3.716

- 0.0694

----- -------- ------- -------- polid 250.336 226.151

- 24.1856

======== ======= ======== 370.662 336.554

- 34.1074

# APPENDIX J

Public Participation Process Documents

### This page left intentionally blank.

### LEGAL NOTICE OF PUBLIC HEARING

Redesignation Petition and Maintenance Plan In Association with the Annual Fine Particle (PM 2.5 

### ) Standard

Ce ntral Indiana Area

Notice is hereby given under 40 CFR 51.102 that the Indiana Department of Environmental Management (IDEM) will hold a public hearing on September 14, 2009. The purpose of this hearing is to receive public comment on the Draft Redesignation Petition and Maintenance Plan in association with the Annual Fine Particle (PM 2.5 

### ) S t andard, for the Central Indiana Area. The meeting will convene at 6:00 p.m. (local time) in the Indianapolis-Marion County Library-West Indianapolis Branch, located at 1216 S. Kappes Street, Indianapolis, Indiana. All interested persons are invited and will be given opportunity to express their views concerning the draft documents.

The Central Indiana Fine Particle Nonattainment Area consists of Hamilton, Hendricks, Marion, Morgan and Johnson counties in Indiana. This area was designated as nonattainment for the annual fine particle standard and subject to the requirements of Section 172 of the Clean Air Act (CAA). One of the compliance requirements mandated by Section 172(c) of the CAA, is the development of a plan demonstrating that the area will continue to meet the annual standard for fine particles. This Redesignation Petition and Maintenance Plan is being drafted and submitted consistent with United States Environmental Protection Agency (U.S. EPA) guidance.

Copies of the draft documents will be available on or before August 14, 2009 to any person upon request and at the following locations:

• Indiana Department of Environmental Management, Office of Air Quality, Indiana Government Center North, 100 North Senate, Room N1003, Indianapolis, Indiana.

• Indianapolis-Marion County Library-West Indianapolis Branch, 1216 S. Kappes Street, Indianapolis, Indiana.

• Danville Public Library, 101 South Indiana Street, Danville, Indiana.

• Johnson County Public Library, 401 State Street, Franklin, Indiana.

• Morgan County Public Library, 110 South Jefferson Street, Martinsville, Indiana.

• Noblesville-Southeastern Public Library, One Library Plaza, Noblesville, Indiana.

The draft documents will also be available on the following web page:

http://www.in.gov/idem/4658.htm

### Oral statements will be heard, but for the accuracy of the record, statements

should be submitted in writing. Written statements may be submitted to the attendant designated to receive written comments at the public hearing.

IDEM will also accept written comments through September 18, 2009. Mailed comments should be addressed to:

Central Indiana Area Fine Particle (PM 2.5 

### ) Redesignation Petition and M a intenance Plan Scott Deloney, Chief Programs Branch Office of Air Quality MC 61-50 100 North Senate Avenue Indiana Department of Environmental Management Indianapolis, IN 46206-2251

A transcript of the hearing and all written submissions provided at the public hearing shall be open to public inspection at IDEM and copies may be made available to any person upon payment of reproduction costs. Any person heard or represented at the hearing or requesting notice shall be given written notice of actions resulting from the hearing.

For additional information contact Ms. Sarah Raymond, at the Indiana Department of Environmental Management, Air Programs Branch, Office of Air Quality, Room 1001, Indiana Government Center North, 100 North Senate Avenue, Indianapolis or call (317) 232-8449 or (800) 451-6027 ext. 2-8449 (in Indiana).

************************************************************************ Individuals requiring reasonable accommodations for participation in this hearing should contact the IDEM Americans with Disabilities Act (ADA) coordinator at:

Attn: ADA Coordinator Indiana Department of Environmental Management – Mail Code 50-10 100 North Senate Avenue Indianapolis, IN 46204-2251

Or call (317) 233-1785 (voice) or (317) 232-6565 (TDD). Please provide a minimum of 72 hours notification.Prescribed by State Board of Accounts 80515-5519337 General Foon No. 99P (Rev. 2009A)

IND DEPT E1'.l'VIRONMENTAL MGMT

'..1ARION COUNTY, INDIANA To: INDIANAPOLIS NEWSPAPERS 307 N PENNSYLVANIA ST

- PO BOX 145 INDIANAPOLIS, IN 46206-0145

LEGAL NOTICE OF PUBUC HEARING Redesign.tion Petition and Maintenance Plan In Assodation With the Annual Rne Particle (PM2.5) Standard Central Indiana Area PUBLISHER'S CLAIM

, 

### , .00 $

__**--'-J78~.9~9**

$,

__**~7U!8~.9z9**

Size of type 1 LINE COUNT Display Matter

- (Must not ex-ceed two actual lines, neither of which shall total more than four solid lines of the type in which the body of the advertisement is set).

- number of equivalent lines Head

- Number lines Body

- Number Tail- Number Totalnum

DATA FOR COMPUTING COST Width of single column 5.8 ems Number of insertions --LQ ne (Cl \lli'e COMPUTATION OF CHARGES**U~~~~C~t~I~~** 91.0 lines 2.0 columns wide equals 182.0 equivalent lines at .434

. y. .• ) guidance. cents per line Copies of the draft documents will be available on or before Addl'tt'onal charge fior nott'ces

. -.il..

mrre work (50 per cent August 14, 2009 to any person upon request and at the 101-. "0" lowing locations: of above amount)
.!

.**nW~~~11 ~:~te~e~~~~,orb~e**  Charges for extra proofs ofpublication ($1. each proof in excess of two)

_. . .' .,anapolis, Indiana.. TOTAL AMOUNT OF CLAIM

•**~~g~[~Pfi~6~aR~ppeCso~rr~e~UIb~3,~~~~1~, I~~\~~~~Olis** 

•**Pn'ill~~I~.** Public Library, 101 South Indiana Street, Danville,

• joi).nson County Public Library, 401 State Street, Franklin,

Indiana.

•**~~il\~~vn?~nfXJ~~~i:C** Library, 

### no South Jefferson Street,

• Noblesvjlle-Southeastern Public Library, One .Library Plaza,

Noblesville, Indlana.- P th·

. d' l' fIC 5 11 10 1 I h b 'fy h th fi'

. The draft documents will also be available on the following • ursuant to e provtstons an pena**~es** 0 - - -,**e~e** y ce:tl tat. e oregomg account tS web page: Just and correct, that the amount clauned IS legally due, after allowmg all Just credtts, and that no part of the same**B~g,://t~t~~~~~o~ipb~/~~~dhtm** curacy. of the has been paid. iting. Written state men s may es deSignated to receive written comm I also certify that the printed matter attached hereto is a true copy, of the same column width and type size,**i~:~0~J~I~~?e~~~e~~~~\~~M3IW~~~~d~:S~~%ht~?Ptember** which was dUly.published in said paper 1 tinIes. The dates of publication being between the**d~es** of::?**~r~H~~~ndiana** Area**Fi~Ta~article** {PM2.5j Redesignation Pe- 08/14/2009 and**08114/2009;~_ 5fP;~~a~**  MC 61-50

. , 100 Nort veijue Additionally, the statement checked below is true and correct: --.l ,.- Indiana Department ot Eijvironmental Management 

### :> Indianapolis, IN 46206-2251

. .. G**subll]ls~lons** PfO- v{ewspaper does not have a Web site. 

### J> c public inspection -N h W b' d h' bli

- d h d . - bli..h d.c:, Ie to an person

_ ewspaper as a e site an t IS pu c notice was poste on t e San!e ay as It was pu =,e Ill:**g~** the newspaper

..**~.**

_ Newspaper has a Web site, but due 'to a technical problem or error, public notice was**post~on** ----;;:z==----

_

_ Newspaper has a Web site but refuses to post the public notice.

Individuals requiring**reason~ble** accommodations for partid**WiihoBi~~bm\Te~~aa'~~Dmo~o~r~r~J~i a\~e**  IDEM Americans

cif Environmental Management·-**~251** DATE:. 08/14/2009
Or call (31.71 233:1785 (vQice) or (317) .232-6565 (TOO). Please provide a minimum ot 7Zhours noliflcatlOn.

_ JS

- 8/14/09

- 5519337) Title: Clerk 

# o

<

### Before The INDIANA DEPARTMENT OF ENVIRONMENTAL MANAGEMENT OFFICE OF AIR QUALITY Indiana Government Center North Indianapolis IN 46206-6015

IN THE MATTER OF DRAFT REDESIGNATION PETITION AND MAINTENANCE PLAN RE: 

### ANNUAL FINE PARTICULATE MATTER STANDARD FOR HAMILTON, HENDRICKS, JOHNSON, MARION AND MORGAN COUNTIES, STATE OF INDIANA

Transcript of proceedings at a public
Hearing held on September 14, 

### 2009 at West Indianapolis
Library, 1216 South Kappes Avenue, Indianapolis, Indiana

before Sarah Raymond, Hearing Officer.

Wm. F. 

### Daniels, d/b/a ACCURATE REPORTING OF INDIANA 12922 Brighton Avenue Carmel IN 46022

(317) 848-0088

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### 25 PERSONS PRESENT:

Sarah Raymond, Hearing officer

Christine E. 

### Pedersen

Scott Deloney

Rob Elstro 2

### 3



### 1 [September 14, 2009. 6:10 p.m.]



### 2 MS RAYMOND: This is a public hearing, to

3 accept comments concerning the draft Redesignation

4 Petition and Maintenance Plan in association with the

5 annual fine particulate matter standard for Hamilton,

6 Hendricks, Johnson, Marion and Morgan counties (herein

7 referred to as the "Central Indiana Area"). This hearing

8 is being held to conform to the provisions in 40 CFR Part

9 51 regarding public hearings for State Implementation Plan

10 submittals.

11 My name is Sarah Raymond. I am a Senior

12 Environmental Manager in the Planning Section of the

13 Indiana Department of Environmental Management's Office of

14 Air Quality. I have been appointed to act as hearing

15 officer for this public hearing. Also here with me from

16 the Office of Air Quality is Scott Deloney, Chris Pedersen

17 and Rob Elstro.

18 Notice of the time and place of the hearing was given

19 as provided by law by publication in the Indianapolis

20 Star, Indianapolis, Indiana on August 14, 2009.

21 The purpose of this public hearing is to provide

22 interested persons an opportunity to offer comments to the

23 State regarding the draft Redesignation Petition and

24 Maintenance Plan for the annual fine particulate matter

25 standard for the Central Indiana Area.

### 4



### 1 Appearance cards have been distributed in the hearing

2 room for all those desiring to be shown appearing on

3 record in this cause. If you have not already filled out

4 the card, please do so, and indicate if you are appearing

5 for yourself or on behalf of a group or organization and

6 identify such group or organization. Also, note the

7 capacity in which you appear, such as attorney, officer or

8 authorized spokesperson.

9 Any person who is heard or represented at this

10 hearing or who requests notice may be given written notice

11 of the final action taken on this State Implementation

12 Plan submittal. Please indicate on the appearance card if

13 you wish to receive this notification. When appearance

14 cards have been completed, they should be handed to me and

15 I will include them with the official record of this

16 proceeding.

17 Oral statements will be heard, but written statements

18 may be handed to me or mailed to the Office of Air Quality

19 on or before the close of business on September 18th of

20 2009. A written transcript of this hearing is being made.

21 The transcript will be open for public inspection and a

22 copy of the transcript will be made available to any

23 person upon payment of the copying cost.

24 After conclusion of the public hearing, I will

25 prepare a written report summarizing the comments received

### 5



### 1 at this hearing and recommending changes which may need to

2 be made to this document.

3 I would like to introduce the following documents

4 into the record:

5 1) The notice of public hearing.

6 2) Draft Request for Redesignation Petition and

7 Maintenance Plan for the annual fine particulate matter

8 standard for the Central Indiana Area.

9 Finally, I would like to briefly go over the contents

10 of the draft document.

11 In 1997, the United States Environmental Protection

12 Agency set daily and annual ambient air quality standards

13 for fine particles at 15.0 micrograms per cubic meter on

14 an annual basis and at 65.0 micrograms per cubic meter on

15 a twenty-four hour or daily basis. Legal challenges to the

16 new standards for fine particles resulted in delayed

17 implementation of the standard until February 2001, when

18 the Supreme Court upheld the standards and ruled that the

19 U.S. 

### EPA could proceed with implementation of the new

20 standards. This submittal pertains solely to the 1997

21 annual fine particulate matter standard. The Central

22 Indiana area complies with the 1997 and 2006 twenty-four

23 hour standards. Indiana began monitoring for fine

24 particles in 1999. The only fine particulate matter

25 monitors in the Central Indiana Area are located in Marion

### 6

1 County. The 

# u.s. EPA originally designated counties under

2 the fine particle standards based on 2001 through 2003

3 monitoring data in December of 2004. The 

# u.s. EPA

4 formally designated areas throughout the country on April

5 5, 2005 as attainment, nonattainment, or unc1assifiab1e

6 including Hamilton, Hendricks, Johnson,Marion and Morgan

7 counties as part of the Indianapolis, Indiana

8 nonattainment area.

9 The highest most recent design value for the area,

10 based on 2006 through 2008 air quality assured ambient air

11 quality data is 14.6 micrograms per cubic meter. This

12 design value represents fine particle concentrations that

13 are below the national ambient air quality standard, thus

14 the area is eligible to be redesignated to attainment

15 under the annual fine particle standard and classed as

16 maintenance.

17 The Indiana Department of Environmental Management

18 has prepared the draft Redesignation Petition and

19 Maintenance Plan for the Central Indiana Area consistent

20 with 

# u.s. EPA guidance. The draft petition outlines a

21 demonstration that the area has attained the standard

22 based on monitored concentrations, and that the reductions

23 in monitored concentrations are attributable to permanent

24 and enforceable reductions in precursor emissions,

25 specifically reductions of nitrogen oxides. Furthermore,

### 7



### the future.

Due to existing and future emission controls,

the area's air quality is not projected to

worsen, and should further improve over time.

A commitment for all existing emission controls

to remain in place.

A commitment to revise the plan within eight

years of redesignation.

A commitment to adopt and expeditiously

implement necessary corrective actions if an

action level response is triggered.



## ** An action level response is triggered
by a violation of the standard (a
three-year average annual arithmetic

mean value of 15.1 micrograms per

cubic meter or greater) occurs. 

## *

*

* *



## *

* the draft maintenance plan outlines the following:



## * The Central Indiana Area counties do not
significantly contribute to violations outside

of the nonattainment area.
Redesignating the Central Indiana Area to

attainment will not adversely affect any

downwind area's ability to attain the standard.
Regional precursor emissions of nitrogen oxides

and sulfur dioxide will continue to decline in 1



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A mobile source budget for transportation
conformity purposes.

When the Indiana Department of Environmental

Management placed the draft Redesignation Petition and

Maintenance Plan for the Central Indiana on public notice,

the 2008 data for Electric Generating units (EGUs) from

u.s. EPA's Clean air Markets Database was still
preliminary. The 2008 data for EGUs has now been

finalized and the updated emissions data will be provided

to u.s. EPA within the final Redesignation Petition and

Maintenance Plan. It should be noted that the final 2008

EGU data was slightly lower that the preliminary data and

will help ensure the area continues to attain the fine
particulate matter standard.

This concludes my comments regarding the draft

Redesignation Petition and Maintenance Plan for the Centra

Indiana Area. Before opening this hearing for public

comments, may I once again remind you that this hearing

pertains solely to this draft Redesignation Petition and

Maintenance Plan in association with the annual fine

particle standard for the Central Indiana Area, and only

comments germane to this matter will be considered as part

of the public record.

Scott, Chris, Rob and I will be available following

this hearing to address any questions you may have that do

### 9

1 not pertain to this specific matter.

2 The hearing is now open for public comment. Are therE

3 any public comments?

4 [There was no response.]

5 In the absence of any further comments, these

6 proceedings are hereby concluded. The hearing is

7 adjourned.

8 [The hearing was adjourned at

9 6:17 p.m.]



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### 10

1 STATE OF INDIANA SS: 2 COUNTY OF MARION

3 CERTIFICATE:

4 I, 

### DAVID R. 

### OESTERREICH, the undersigned Court Reporter and Notary Public residing and maintaining 5 offices in the City of Indianapolis, Indiana, do hereby certify: 6 

### That at the time and place described above in this 7 transcript, I reported to the best of my ability in machine shorthand all of the words spoken by all parties 8 in attendance during the course of the subject proceedings, including objections, if any, made by all 9 counsel present;

10 That I later reduced my shorthand notes into the foregoing typewritten transcript form, which typewritten 11 transcript is a true record of the testimony and/or statements given by those individuals indicated herein; 12 That I am not a relative or employee or attorney or 13 counsel of any of the parties, nor am I a relative or an employee of such attorney or counsel, and that I am not 14 financially interested in this action.

15 IN WITNESS WHEREOF I have affixed my Notarial Seal and subscribed my signature below on this 18th day of 16 September, 2009.

17



### 18

19

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24

25 [Seal]
Notary Public County of Residence: Marion My Commission expires on August 28, 2016

# .I

# I~l anAES company 

# RECEI\/EO

September 3,2009

Scott Deloney, Chief Programs Branch Office of Air Quality MC 61-50 100 North Senate Avenue Indiana Department of Environmental Management Indianapolis, IN 46204-2251 

## StP 0:1 2009

;;lall:: )1 Inalan2 Department of Environrm'lntal Management Office ot All duality 

### 1..-----**.~_":-------'**



### Re: Central Indiana Area Fine Particle (PM 2

. 5 )**~~~~sigIl(lti()IlI:>~titi()_IletrlclMCliIl1~nance** 

### Plan

Dear Mr. 

### Deloney:

On August 14,2009, Indiana Department of Environmental Management (IDEM) published a Legal Notice of Public Hearing, announcing that IDEM will hold a public hearing on September 14,2009, and accept written comments through September 18, 2009. The purpose of the Notice and Hearing is to solicit public comment on the Draft Redesignation Petition and Maintenance Plan in association with the Annual Fine Particle (PM 2

. 5 ) 

### Standard, for the Central Indiana Area. Indianapolis Power & 

### Light (IPL) Company supports IDEM's efforts for redesignation of the Central Indiana Area and appreciates the opportunity to comment on the draft Request for Redesignation.

Section 4.1 (page 16) of the Request for Redesignation specifically identifies IPLHarding Street (HS) Gener(!.ting Station and IPL

- Eagle Valley (BV) Generating Station. IDEM indicates that IPL installed various NO x 

### controls as a result of CAIR. IPL would like to clarify that additional NO x 

### controls were installed voluntarily in anticipation of

more stringent NO x 

### emissions limitations, but that uncertainty still surrounds the final
outcome of CAIR regulations and the results of CAIR remain unknown. The controls specified in the Request for Redesignation are low NO x 

### burner technology with separated overfire air. It 

### should be noted that Units 5, 6, and 7 at IPL

- HS were already equipped with these controls during the 2001-2003 monitoring period (the basis for the nonattainment designation) and that IPL installed additional types of NO x 

### controls after 2003. NO x 

### control technologies installed at IPL

- HS and IPL

- EV are as follows:

INDIANAPOLIS POWER &I LIGHT COMPANY lOne Monument Circle 

### I Indianapolis, IN 46204-2901 

### I IPLpower.com

### Page 2 of3

Plant Unit NOx Control Technology Year Operational Low NOx Burners 1993 5 Neural Net controls 2004 Selective Non-Catalytic Reduction 2004 Low NOx Burners 1996 IPL-HS 6 Neural Net controls 2004 Selective Non-Catalytic Reduction 2004 Low NOx Burners 1994 7 Neural Net controls 2000 Selective Catalytic Reduction 2005

4 Low NOx Burners 2004 Separated Overfire Air 2004

IPL

- EV 5 Low NOx Burners 2004 Separated Overfire Air 2004

6 Low NOx Burners 2004 Closed Couple Overfire Air 1992

The Request for Redesignation also indicates that the flue gas desulphurization (FGD) system at IPL

- HS became operational in 2008. However, the Unit 7 FGD at IPL

- HS became operational in September of 2007.

Finally, the draft Request for Redesignation indicates that the controls identified by IDEM are expected to remain in place and emissions from these plants should not increase in the future. IPL would like to clarify that many control technologies have been installed voluntarily and are not required to be operated. Additionally, the trading scenarios under CAIR remain uncertain and IPL utilizes a NOx Averaging Plan, which includes IPL

- Petersburg Generating Station, located in Pike County (outside of the Central Indiana Area), to comply with the Title IV Acid Rain requirements.

IPL commends IDEM on the improvements made in air quality in the Central Indiana Area since the nonattaimnent designation and supports the ongoing efforts made by IDEM and industrial sources in the Central Indiana Area. As such, IPL would like to

ensure that all information expressed regarding IPL in the Request for Redesignation is clear and accurate. IPL believes that the following revisions would present a clearer and

more accurate representation of IPL

- HS and IPL

- EV (page 16 of the Request for Redesignation) :

A

.. 

## s a result of CAIR, Additional NO x 

### control technologies have been installed on various emission units at the Indianapolis Power 

### afltl & 

### Light Company (IPL)

- Harding Street Generating Station, pO'vver plant located in Marion County, and the IPL

- Eagle Valley Generating Station, power plant located in Morgan County, are currently controlled by Im'l NO* burner technology ','lith scparted overfire air since the 2001- 2003 monitoring period. These control technologies include Selective

### Page 3 of3

Non-Catalytic Reduction, Selective Catalytic Reduction, Neural Net Controls, Low NO x 

### Burners, and Separated Overtlre Air. The SOz data from 2008 reflects the installation of a flue gas desulphurization system at the IPL

- Harding Street Generating Station pO'Ner plant 

### that became operational in 2007. These controls 

### are expected to 

### remain in place and emissions from these plants should not increase in the future. 

### IDEM anticipates that these controls and other controls installed in the Central Indiana Area will remain in place and that emission levels in the Central Indiana Area will not increase in the future.

If 

### you have any questions regarding these comments, please do not hesitate to contact me at (317) 261-5852 or via email atangelique.oliger@aes.com.

Sincer*,

# /~**~~** Angelique Oliger Environmental Coordinator

## Central Indiana Redesignation Request and Maintenance Plan in

Association with the Annual Fine Particle (PM 2.5 

## ) Standard

Su mmary/Response to Comments Received

IDEM requested public comment on the draft Redesignation Request and Maintenance Plan for Central Indiana from August 14, 2009 to September 18, 2009. A public hearing was also held on September 14, 2009. IDEM received no comments at the public hearing and received one written comment from the following party:

Angelique Oliger, Indianapolis Power & Light Company (IPL)

Following is a summary of the written comment received and IDEM’s response thereto:

General

Comment: IPL would like to clarify that additional NO x 

### controls were installed

vo luntarily in anticipation of more stringent NO x 

### emissions limitations, but that

un certainty still surrounds the final outcome of CAIR regulations and the results of CAIR remain unknown. It should be noted that Units 5, 6 and 7 at IPL-HS were already equipped with these controls during the 2001-2003 monitoring period (the basis for the nonattainment designation) and that IPL installed additional types of NO x 

### controls after 20 03. The Request for Redesignation also indicates that the flue gas desulphurization(FGD) system at IPL-HS became operational in 2008. However, the Unit 7 FGD at IPLHS became operational in September of 2007. Finally, the draft Request for Redesignation indicates that the controls identified by IDEM are expected to remain in place and emissions from these plants should not increase in the future. IPL would like to clarify that many control technologies have been installed voluntarily and are not required to be operated. (IPL)

Response: IDEM appreciates the additional information provided by the Indianapolis Power & Light Company (IPL) and will reflect accurate information in the final submittal of the Redesignation Request to U.S. EPA.

Comment: IPL believes that the following revisions would present a clearer and more accurate representation of IPL-HS and IPL-EV (page 16 of the Request for Redesignation):

As a result of CAIR

, Additional NO x 

### control technologies have be en installed on various emission units at the Indianapolis Power and & Light Company (IPL)–Harding Street Generating Station , power plant located in Marion County, and the IPLEagle Valley Generating Station , power plant located in Morgan County, are currently controlled by low NOx burner technology with separated overfire air since the 2001-2003

### monitoring period. These control technologies include Selective Non-Catalytic Reduction, Selective Catalytic Reduction, Neural Net Controls, Low NO x 

### Burners, and Se parated Overfire Air. The SO 2 

### data from 2008 reflects the in stallation of a flue gas desulphurization system at the IPLHarding Street Generating Station power plan t that became operational in 2008 2007 . These controls are expected to remain in place and emissions from these plants should not increase in the future. IDEM anticipated that these controls and other controls installed in the Central Indiana Area will remain in place and that emission levels in the Central Indiana Area will not increase in the future

. (IPL)

Response: IDEM appreciates the additional information provided by IPL and will revise the text accordingly. IDEM will update the final document to reflect the information as clarified by IPL.