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/m3

2006-2008 

Average μg/m3

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 18th Street 2006 14.12 

18-097-0081 Marion W 18th Street 2007 16.07 

18-097-0081 Marion W 18th 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. 75th Street 16.36 16.25 15.68 14.67 13.44 16.88 12.75 14.76 Site 

Discontinued 

180970081 Marion W. 18th 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 PM2.5 Standard 

Source Oriented Monitor NOT used for comparison to the Annual PM2.5 Standard 

Note: The Mann Road and E. 75th 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. 75th Street 16.1 15.5 14.6 15.0 14.4 14.8 Site 

Discontinued

180970081 Marion W. 18th 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 PM2.5 Standard 

Source Oriented Monitor NOT used for comparison to the Annual PM2.5 Standard 

Note: The Mann Road and E. 75th 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

16.5

Anderson

Mann Road

Washington

Park

E. 75th

Street

W. 18th

Street

E. Michigan

Street

ug/m3

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

Note: The Mann Road and E. 75th 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

19.00

20042005200620072008

Year

ug/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. 75th Street monitors were discontinued December 31, 2007 

A - 2 
APPENDIX B 

Nitrogen Oxides (NOx), Sulfur Dioxides (SO2) and 

Direct Fine Particulate Matter (PM2.5) Point 

Source Emissions (2002, 2005/2006) for Central 

Indiana Area 
This page left intentionally blank.
Point Source Totals (Tons per Year)

Year NOx SO2 Direct PM2.5

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 SO2 Direct PM2.5

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-SO2

NON-EGUSO2

EGUDirect 

PM2.5

NON-EGUDirect PM2.5

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 PM2.5

Grand Total 14,062.68 71,834.98 1,005.98 

2006-Point Source Emissions (Tons per Year)

County EGU-NOx NON-EGUNOx EGU-SO2

NON-EGUSO2

EGUDirect 

PM2.5

NON-EGUDirect PM2.5

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 PM2.5

Grand Total 14,334.95 65,150.91 1,024.45 

B-1 
2002 Hamilton County Point Source Inventory (Tons per Year) 

Facility Name NOX PM2.5 SO2 

INDIANA DUCTILE LLC 0.03 4.10 0.03

FIRESTONE INDUSTRIAL PRODUCTS 52.36 6.02 89.54

IRVING MATERIALS, INC./STONY 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 PM2.5 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 PM2.5 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 PM2.5 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 PM2.5 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 OLIN 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 CORPORATION 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-2
2002 Marion County Point Source Inventory (Tons per Year)--continued 

Facility Name NOX PM2.5 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 PLANT #325 8.11 10.96 16.30

RIETH-RILEY89 ASPHALT PLANT #326 9.35 12.36 18.68

CRYOVAC RIGID PACKAGING CRYOVAC, INC. 0.02 

PANHANDLE EASTERN PIPELINE 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--SHREDDING 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 PRODUCTS 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 - INDIANAPOLIS BAKERY 16.32 0.87 0.07

ST. FRANCIS HOSPITAL - BEECH 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-3
2002 Marion County Point Source Inventory (Tons per Year)--continued 

Facility Name NOX PM2.5 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 HEALTH 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-4
2002 Marion County EGU Inventory (Tons per Year) 

Facility Name NOX PM2.5 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 PM2.5 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 PM2.5 SO2 

IPALCO-PRITCHARD STATION 4,494.50 27.60 17,216.30

Total 4,494.50 27.60 17,216.30

B-5
2005 Hamilton County Point Source Inventory (Tons per Year) 

Facility Name NOX PM2.5 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 PM2.5 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 PM2.5 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 PM2.5 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 PM2.5 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 PM2.5 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-6
2005 Morgan County Point Source Inventory (Tons per Year) 

Facility Name NOX PM2.5 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 PM2.5 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 NOx Point Source Emission Trends, 2002, 2005 and 2006 

-

5,000

10,000

15,000

20,000

25,000

2002 2005 2006

Year

Tons per Year

NOX

Central Indiana Area SO2 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 Year

Tons per Year

SO2 

B-8
Central Indiana Area Direct PM2.5 Point Source Emission Trends, 2002, 2005 and 

2006 

-

200

400

600

800

1,000

1,200

2002 2005 2006

Year

Tons per Year

PM 2.5

B-9
APPENDIX C 

Nitrogen Oxides (NOx), Sulfur Dioxides (SO2) and 

Direct Fine Particulate Matter (PM2.5) (2002, 

2005/2006) Emission Trends, All Sources, Central 

Indiana Area 
This page left intentionally blank. 
2002 

COUNTY Sector NOX PM2.5 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 PM2.5 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 – 1 
2005 

COUNTY Sector NOX PM2.5 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 PM2.5 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 - 2 
2006 

COUNTY Sector NOX PM2.5 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 PM2.5 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 
NOx Emission Trends, All Sources in the 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

Year

Tons per Year

NOX

SO2 Emission Trends, All Sources in the 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 Year

Tons per Year

SO2 

C – 4 
Direct PM2.5 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 Year

Tons per Year

PM 2.5 

C – 5 
APPENDIX D 

Nitrogen Oxides (NOx) and Sulfur Dioxides (SO2) 

Emissions from Electric Generating Units, 

Central Indiana Area 
This page left intentionally blank.
Statewide Indiana NOx Emissions from EGUs 

Year NOx 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 NOx Emissions from Electric Generating Units, 1999 to 2008 

0

50,000

100,000

150,000

200,000

250,000

300,000

350,000

400,000

1999200020012002200320042005200620072008

Year

Tons per Year

NOx

D-1
 Central Indiana NOx Emissions from EGUs 

Facility NOx 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 

NOx 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

16,000

1999200020012002200320042005200620072008

Year

Tons per Year

NOx

D-2
 

Central Indiana NOx Emissions from 

EGUs 1999 

Facility NOx 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 NOx 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 NOx 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 NOx 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 NOx 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 NOx 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 NOx 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 NOx 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 NOx 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 NOx 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
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D-6
Statewide Indiana SO2 Emissions from EGUs 

Year SO2 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 SO2 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

1,000,000

1999200020012002200320042005200620072008

Year

Tons per Year

SO2

D-7
 Central Indiana SO2 Emissions from EGUs 

Facility SO2 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 

SO2 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

80,000

1999200020012002200320042005200620072008

Year

Tons per Year

SO2

D-8
 

Central Indiana SO2 Emissions from EGUs 

1999 

Facility NOx 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 SO2 Emissions from EGUs 

2000 

Facility NOx 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 SO2 Emissions from EGUs 

2001 

Facility NOx 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 SO2 Emissions from EGUs 

2002 

Facility NOx 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 SO2 Emissions from EGUs 

2003 

Facility NOx 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 SO2 Emissions from EGUs 

2004 

Facility NOx 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 SO2 Emissions from EGUs 

2005 

Facility NOx Emissions, tons / year 

Noblesville 1.1 

Anderson 0.4 

IPL Georgetown Substation 0.3 

Harding Street Station (EW Stout) 49,350.7 

IPL Eagle Valley Generating Station 17,811.3 

Total 67,163.8 

 

Central Indiana SO2 Emissions from EGUs 

2006 

Facility NOx 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 SO2 Emissions from EGUs 

2007 

Facility NOx 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 SO2 Emissions from EGUs 

2008 

Facility NOx 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 (NOx), Sulfur Dioxides (SO2) and Direct 

Fine Particulate Matter (PM2.5) in Central Indiana 

Area 
This page left intentionally blank.
2005 (Tons per Year)

Area Category NOx Direct PM2.5 SO2

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 NOx Direct PM2.5 SO2

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 NOx Direct PM2.5 SO2

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 NOx Direct PM2.5 SO2

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 

NOx 66,032.06 32,340.01 -33,692.05 51.02% decrease 

SO2 68,690.10 31,962.83 -36,727.27 53.46% decrease 

Direct PM2.5 2,903.64 1,736.16 -1,167.48 40.20% decrease 

E-1 
Comparison of 2005 and 2006 Estimated and 2015 and 20203

 Projected NOx

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 Year

Tons per Year

NOX

 Comparison of 2005 and 2006 Estimated and 2015 and 20201 Projected SO2

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

Year

Tons 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 20204

 Projected Direct PM2.5

Emissions for the Central Indiana Area 

-

500

1,000

1,500

2,000

2,500

3,000

3,500

2005 2006 2015 2020

Year

Tons per Year

PM 2.5

Comparison of 2005 Estimated and 2015 and 20202 Projected SO2, NOx and Direct 

PM2.5 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

Year

Tons 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 

Management (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 Modeling Section

Revised: 02/27/2008 Revision 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 every 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

2 
Area Source Inventory 

S-006-OAQ-R-MO-08-S-R1 

1. Overview work flow chart 

The process described is not part of a larger system 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 have 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 plan (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 use of standard procedures for collecting, calculating, storing, reporting, 

and sharing air emissions date. 

Emission Factors - An emission factor 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 “process” used when describing area sources is used to name an operation or 

activity that produces emissions.

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

Standard Industrial Classification (SIC) Code - A Standard Industrial Classification code from the 

series of codes devised by the United States Office 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 Code is a process-level code that describes 

the equipment or operation emitting pollutants.

3 
Area 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

with the EIIP 

Air Programs 

Branch 

Environmental Manager 1 N/A 

MS ACCESS, Emission 

Inventories and familiarity

with the EIIP 

Air Programs 

Branch 

 Responsibilities: 

Senior Environmental Manager

Oversees work of the Environmental Manager and ensures 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 using 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 used to calculate 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 sources 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 category

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 

4 
Area 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 Industrial” for the following fuels: coal, distillate oil, 

natural gas, and liquefied petroleum gas (LPG). Use 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 following steps will lead to data for fuel consumption. 

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 combustions, subtract reported source totals from the 

total statewide fuel consumption by querying the total process rates for the various SCC codes using 

the ACCESS data tables at K:\OAQ_INV\Steptool\Stptl_02.mdb. The remaining number is the area 

source fuel consumption for the state. 

3. To distribute the remaining fuel to the county level, calculate the ratio of county to state employment 

for the manufacturing sector by dividing the number 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 following steps will lead to data for Economic Census. 

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

b. Click on Economic Census 

c. Under 2002 Reports by State, use the down arrow key to select Indiana 

d. Now, select each of the counties to find the county manufacturing employees 

e. Use the total of employees for manufacturing under the paid employees’ column 

4. Multiply the ratio calculated above in step 3 by the area source fuel consumption 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 the various fuels for industrial manufacturing found 

in AP-42, Fifth Edition, Volume 1, Chapter 1, External Combustion Sources at 

http://www.epa.gov/ttn/chief/ap42/ch01/. 

Sub-Category 1.2: Commercial/Institutional Fuel Combustion 

SCC: 2103004000, 2103005000, 2103006000, 2103007000 

Follow these steps when calculating emissions from commercial/institutional fuel combustion: 

1. Obtain statewide fuel consumption for “Commercial” for the following fuels: distillate fuel oil, liquefied 

petroleum gas (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 

Administration’s website. 

5 
Area Source Inventory 

S-006-OAQ-R-MO-08-S-R1 

2. To avoid double calculating the various fuel combustions, subtract reported source totals from the 

total statewide fuel consumption by querying the total process rates for the various fuels using the 

SIC codes greater than 4999 using the ACCESS data tables at K:\OAQ_INV\Steptool\Stptl_02.mdb. 

These are the SIC codes that identify all the commercial/institutional area sources. 

3. To distribute the remaining fuel to the county level, calculate the ratio of county to state employment 

for the commercial/institutional sector by dividing the number of commercial/institutional employees 

for each county by the number of commercial/institutional 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 navigate through the U.S. Census Bureau’s website. 

4. Multiply the ratio calculated above in step 3 by the area source fuel consumption 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 the 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 consumption for “Residential” for the following fuels: coal, distillate oil, natural 

gas, and liquid petroleum gas. 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 

Administration’s website. 

2. To distribute residential fuel to the county level, calculate the ratio of county fuel usage to statewide 

fuel usage using the breakdown of fuels by household 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 steps will lead to data for breakdown 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 Characteristics” and select “show more” 

e. On the left hand side, select “change geography (state, county, place...)” 

f. Using the drop down menu, select county, state, and each county name to obtain housing 

information 

3. Multiply the ratio calculated above in step 3 by the area residential fuel use by state to distribute the 

fuel to the county level. The remaining number is the process rate for each county for the various 

fuels. Multiply the process rate by the appropriate EPA emission factors for 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/. 

6 
Area 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 emissions from residential heating using wood: 

1. Obtain statewide wood consumption for “Residential” using the Energy Information Administration’s 

website at http://www.eia.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 following steps will lead to data 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 click on “State Energy” 

e. Using 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 “Documentation For The Final 2002 

NONPOINT SECTOR (FEB 06 version) NATIONAL 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 (fireplace without inserts, fireplaces with inserts and 

woodstoves). 

3. To distribute to the county level for the three categories above, calculate a ratio of county to state 

using the statewide total of households and the county 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 process rate by the appropriate EPA emission factors for each of the 

categories using the EIIP, Volume 3, Chapter 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 

Administration’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 reported weight of yeast–raised 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 steps will lead to data for yeast-raised 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 Bakeries (NAICS code 311812) and Frozen cakes, 

pies, and other pastries manufacturing (NAICS code 311813) 

7 
Area Source Inventory 

S-006-OAQ-R-MO-08-S-R1 

2. Multiply the per capita consumption factor calculated 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 following steps will lead to Indiana 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, subtract the reported process rate for 

both the straight-dough and sponge-dough by querying the total process rates for the SCC 30203202 

(straight-dough) and SCC 30203201 (sponge-dough) using the ACCESS data tables at 

K:\OAQ_INV\Steptool\Stptl_02.mdb. 

4. Multiply the remaining process rate by the straight-dough emission factor of .5 lbs VOC/1,000 pounds 

baked found in the EIIP, Volume 3, Area Source Method 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 Indiana population found in step 2 by the remaining process 

rate. Now 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 following steps 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 coating area sources first by adding all the solventbased paints together and all the water based paints 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 

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S-006-OAQ-R-MO-08-S-R1 

Note: As of the date of this SOP, the following 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 “Paints and Allied Products” 

2. Now multiply the total national number for solvent-based paints by the average 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-based paints together for a total national VOC 

emission factor from architectural surface coating. 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 above in step 3 by each of the county populations to calculate the total 

emissions per county. 

Note: Use the steps in sub-category 2.1-5 to navigate through the Census Bureau’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 employees from the reported sources using the SIC 7532- 

Body Repair and Paint Shops using the ACCESS data tables at K:\OAQ_INV\Steptool\Stptl_02.mdb. 

Subtract this number from the county 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 following steps will lead to county 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 

code 

2. Multiply the emission factor 3,519 lbs VOC/employee found in the EIIP, Volume 3, Chapter 13 Auto 

Body Refinishing at http://www.epa.gov/ttn/chief/eiip/techreport/volume03/archsfc.pdf and the county 

employment found above in step 1 to calculate 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 the amount of sales for traffic marking 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 paints from the EIIP, Volume 3, Chapter 14, Traffic 

Markings at http://www.epa.gov/ttn/chief/eiip/techreport/volume03/iii14.pdf. 

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 Note: As of the date of this SOP, the following 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 “Paints and Allied Products” 

f. Use the quantity amount in 1000/gallons under “Traffic marking paints (all types: shelf goods and 

highway department) 

2. Allocate the national emissions calculated above in step 1 to the state level by dividing the amount of 

money spent 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/policy/ohim/hs04/htm/sf2.htm. 

3. Calculate the emission factor for Indiana by dividing the state level emissions by the total number of 

roadway miles in Indiana, 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 roadway miles in each county 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, 2401070000, 2401075000, 2401080000

Follow these steps when calculating for industrial surface coating using the employment based 

emission factor: 

1. Calculate an employee based emission factor for the 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 

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* Use the National default emission factor because the reporting sources are low. 

** Emissions reported in point source 

2. Divide the reported VOC emissions for each of the SIC’s by the reported employment for each SIC. 

Use this number for the emission factor. 

3. Subtract the number of reported employees 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 found for each of the SIC’s in step 4 by the emission 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 industrial surface coating using the default emission 

factor: 

1. Calculate industrial surface coating emissions using the default emission factor 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 Manufacturing 0.600 lbs VOC/person 

24-01-100-000 Industrial Maintenance Coatings 0.800 lbs VOC/person 

24-01-200-000 Other Special Purpose Coatings 0.800 lbs 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 numbers for each of the counties 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 

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S-006-OAQ-R-MO-08-S-R1 

39 Miscellaneous manufacturing 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 manufacturing 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 

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:\OAQ_INV\Steptool\Stptl_02.mdb. 

3. Subtract the reported employment from the U.S Census Bureau’s numbers to find the process rates 

for each of the counties. 

4 Calculate the VOC emissions by multiplying the default emission factor in the EIIP, Volume 3, Chapter 6, 

Solvent Cleaning 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 number of employees state wide and 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 counties, multiply by 2000, and divide by the statewide 

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 reported employees for SIC 7216 

using the ACCESS data tables at K:\OAQ_INV\Steptool\Stptl_02.mdb and subtract this number from 

the county total. 

4. Multiply the process rate for each of the counties above by the emission factor to calculate for VOC 

emissions. 

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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, Chapter 7, Graphic Arts at 

http://www.epa.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 through the U.S. Census Bureau’s website. 

2. Develop an emission factor by subtracting point source emissions from the total emissions and 

dividing by the state population found in step 1. 

3. Distribute to the counties by multiplying the emission factor by the population for each county. 

 Note: Use the steps in 2.1-5 to navigate through the U.S. Census Bureau’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 emissions and number of reported employees for all SIC’s 

beginning with 30 using the ACCESS data tables 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 

counties. 

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

4. Multiply the remaining number from above with the emission factor calculated 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 Air Pollutant Emission 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 Manufacturing Employment from the U.S. Census Bureau’s website 

http://www.census.gov. 

Note: As of the date of this SOP, the following steps will lead to emission 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 steps will lead to National Manufacturing Employment. 

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

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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 collecting sources reporting 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, Consumer, and Commercial 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 barrels of asphalt 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 state and county from the Indiana Department of 

Transportation’s, Division of Roadway Management Section. 

3. Divide the county roadway miles by the state roadway miles and multiply by the total asphalt usage for 

the state found above in step 1. 

4. Multiply the process rate by the default emission factor in the EIIP, Volume 3, Chapter 17, Asphalt 

Paving http://www.epa.gov/ttn/chief/eiip/techreport/volume03/iii17_apr2001.pdf. 

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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 specific emission factor. Develop the factor using a 

methodology that includes the retrieval of information of pesticides used, an emission factor for each 

pesticide used, a calculation about the inert ingredients 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 Agricultural Statistics Service at http://www.usda.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\pesticide. 

4. Calculate the emission factor by adding the emissions from crop oil concentrates obtained in the 

pesticide Excel table, pesticides, and solvent carriers 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 

National Agricultural Statistics Services, 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 the Federal Highway Administration, U.S. Department 

of Transportation http://www.fhwa.dot.gov/policy/ohim/hs04/htm/mf21.htm. 

2. Find the amount of gasoline sold statewide and by county using, the NAICS code 447-Gasoline 

Service Station from the U.S. Census 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 reported gasoline using the ACCESS data tables at 

K:\OAQ_INV\Steptool\Stptl_02.mdb and subtract from the amount sold statewide. Use this to 

allocate to each county. 

 

4. Allocate the amount gasoline 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. 

5. EPA guidance suggests that only 25% of all gasoline consumed goes through bulk plants. To 

calculate 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 below: 

15 
Area 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 submerged 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 emissions for portable fuel containers: 

 

1. Calculate the emissions for Commercial and Residential gas cans by using the method developed by 

the California Environmental Protection Agency’s document Public Meeting to Consider Approval of 

California’s Portable Gasoline-Container Emissions Inventory. Use the excel spreadsheet found at 

K:\OAQ_INV\Inv\Area Source\Gasoline.zip to calculate the emissions for permeation, diurnal, and 

transport. Both the Spillage and Vapor losses are estimated in the nonroad emissions inventory by 

EPA models. 

2. Using the survey results below in Table 1, estimate the number of fuel containers 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\GasCans.xls, insert the number of occupied 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 steps will lead to number of households 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% 

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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, estimate the number of fuel containers 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 both residential and commercial by using the emission 

rates given in the California document. Use 1.57g/gal/day for plastic containers and 0.6g/gal/day for 

metal containers. Insert the numbers for both residential and commercial into the excel spreadsheet at 

K:\OAQ_INV\Inv\Area Source\ Gasoline.zip\250101\GasCans.xls. 

5. Calculate diurnal emissions by inserting the numbers for both residential and commercial into the 

excel spreadsheet at K:\OAQ_INV\Inv\Area Source\ Gasoline.zip\250101\GasCans.xls. 

6. Calculate transport spillage emissions by inserting the numbers for both residential 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 Federal Highway Administration, U.S. Department of 

Transportation http://www.fhwa.dot.gov/policy/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. Census Bureau’s, Economic Census at 

http://www.census.gov/econ/census02/data/in/IN000_44.HTM#N447. 

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3. Run a query to find the amount of point source reported gasoline using the ACCESS data tables at 

K:\OAQ_INV\Steptool\Stptl_02.mdb and 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 and multiplying by the number of gallons sold statewide found above in step 1. 

5. Find the amount of gasoline tanks from the Underground Storage Tank data 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. Filter finding the tanks that have only gasoline. Also 

filter out the tanks that are “permanently out of service”, “suspended per inspection”, and 

“unregulated”. 

7. Using the Petroleum Sources Applicability Rule 326 IAC 8-4-1, filter out the tanks that are located in 

Clark, Boone, Dearborn, Elkhart, 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 number of tanks that constructed after 1985 through current year. Use the spreadsheet 

created in step 7 and filter out the tanks that constructed prior to 1985. 

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

10. Apply the controlled emission factor to only those counties identified 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 factors 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 vehicle fueling – Vapor Displacement: 

1. Find the amount of gasoline sold in Indiana at the Federal Highway Administration, U.S. Department 

of Transportation http://www.fhwa.dot.gov/policy/ohim/hs04/htm/mf21.htm. 

2. Find the amount of gasoline sold statewide and by county using the NAICS code 447-Gasoline 

Service Station from the U.S. Census 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 

statewide sales and multiplying by the number of gallons sold statewide found above in step 1. 

4. Calculate an emission factor using the input files supplied from the mobile model. Table 1 and Table 

2 show examples of how the emission factors for 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 Counties, Clark/Floyd, and Lake/Porter. 

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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 

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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 emission factor found in the mobile model. 

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

SCC: 2501060103 

Follow these steps when calculating emissions from vehicle fueling – Spillage: 

1. Find the amount of gasoline sold in Indiana at the Federal Highway Administration, U.S. Department 

of Transportation http://www.fhwa.dot.gov/policy/ohim/hs04/htm/mf21.htm. 

2. Find the amount of gasoline sold statewide and by county using the NAICS code 447-Gasoline 

Service Station from the U.S. Census 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 

statewide sales and multiplying 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 Industry, 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 emissions from underground tank breathing: 

1. Find the amount of gasoline sold in Indiana at the Federal Highway Administration, U.S. Department 

of Transportation http://www.fhwa.dot.gov/policy/ohim/hs04/htm/mf21.htm. 

2. Find the amount of gasoline sold statewide and by county using the NAICS code 447-Gasoline 

Service Station from the U.S. Census Bureau’s, Economic Census at 

http://www.census.gov/econ/census02/data/in/IN000_44.HTM#N447. 

20 
Area 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 Industry, 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 the Federal Highway Administration, U.S. Department 

of Transportation http://www.fhwa.dot.gov/policy/ohim/hs04/htm/mf21.htm. 

2. Find the amount of gasoline sold statewide and by county using the NAICS code 447-Gasoline 

Service Station from the U.S. Census 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 

statewide sales and multiplying by the number of gallons sold statewide found above in step 1. 

4. Using the guidance in the EIIP, Volume 3, Chapter 11, Gasoline 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 industrial solid waste incineration: 

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/cgi-bin/cbpnaic/cbpsel.pl. 

 Note: Use the steps in 3.2-1 to navigate through the county business patterns. 

2. Multiply the county manufacturing employment by the default fuel-loading factor 420 tons / 1,000 

manufacturing employees. 

3. Multiply the process rate in step 2 by AP-42, Fifth Edition, Volume 1, Chapter 2-1.12, Solid Waste 

Disposal at http://www.epa.gov/ttn/chief/ap42/ch02/index.html. 

21 
Area 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 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.epa.gov/epaoswer/non-hw/muncpl/msw99.htm. 

3. Find the percent of commercial solid waste from the U.S. EPA Municipal Solid Waste Report above. 

4. Now, calculate the process rate for commercial solid waste incineration 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, Fifth 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 residential solid waste incineration: 

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.epa.gov/epaoswer/non-hw/muncpl/msw99.htm. 

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

4. Now, calculate the process rate for residential solid waste incineration 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, Fifth 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 leaf burning and a per capita for brush burning by using the U.S. EPA’s 

Solid Waste Report at http://www.epa.gov/epaoswer/non-hw/muncpl/msw99.htm. 

2. Allocate the amount burned by adjusting the per capita factor for leaves at 25% and for brush at 25%. 

Of the total waste generated only 28% burns. 

22 
Area 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 following steps will lead to county 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 waste generated to account for the percentage of forest 

in each county. The percentages come from a document 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 Disposal, 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 residential waste incineration: 

1. Find a per capita factor for residential waste incineration by using the U.S. EPA’s Solid Waste Report 

at http://www.epa.gov/epaoswer/non-hw/muncpl/pubs/mswchar05.pdf. 

2. Using the Solid Waste Report above, subtract the percentage 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 generated by rural population burns and 

of that percent, 49% is actually combusted. 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 adjusted per 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 residential waste by the emission factors 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: 

23 
Area Source Inventory 

S-006-OAQ-R-MO-08-S-R1 

1. To calculate the amount of annual flow for public owned 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 emission factors in FIRE 6.25 using the SCC code 

2630020000. 

Sub-Category 5.4: Treatment, Storage, and Disposal Facilities 

SCC: 2640000004 

Follow these steps when calculating emissions from treatment, storage, and disposal facilities:

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

Office of Land Quality. 

2. Using the list of facilities from step 1, run a query using the ACCESS data tables at 

K:\OAQ_INV\Steptool\Stptl_02.mdb to obtain the amount 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 the quantity reported 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 the combined emission 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 checklist 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 electronically at K:\OAQ_INV\Inv\Area Source. 

The Branch Contact for the Air Programs Branch and the Section contact for the Technical 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. 

24 
Area Source Inventory 

S-006-OAQ-R-MO-08-S-R1 

8. Quality Assurance / 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 CFR 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 

Estimates Technical Support Document 
This page left intentionally blank. 
Regional Air Quality Analyses for

Ozone, PM2.5, and Regional Haze: 

Final Technical Support Document

April 25, 2008

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

Lake Michigan Air Directors Consortium (LADCO) 

Round 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 emission estimates prepared for LADCO’s

latest (Base M) 2005 base year and 2008, 2009, 2012, and 2018 future year modeling. Base 

year emissions by state and source 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.

Additional 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 Emissions

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). 

Examination of multiple base years provides for a more complete technical assessment. All 

modeling was conducted in accordance with USEPA modeling guidelines (USEPA, 2007).

3
February 27, 2008

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

models. 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, 2007a). Specifically, the following versions of these emissions files were used:

MANE-VU: Version 3.1, WRAP: Pre2002d, CENRAP: Base F, and VISTAS: Base F. The 2005 

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

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

On-Road: 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 (Travel Demand 

Modeling [TDM] Transformation Tool) to provide input 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, Saturday, and Sunday (July 15 – 17 

and January 16 – 18) to produce link-specific, hourly emission estimates. A spatial 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 (right)

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 between 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 weekday, 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.

4
February 27, 2008

Off-Road: NMIM2005 was run by Grant Hetherington (Wisconsin DNR) to produce emissions 

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 

contractor 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 RPOs to produce 

weekday, Saturday, and Sunday emissions for each month.

Additional off-road sectors (i.e., commercial marine, aircraft, and railroads [MAR]) were handled 

separately. 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 previous 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 RPOs 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 LADCO States and, for the 

non-LADCO States, using emission files supplied by Alpine based on data from the other RPOs

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: The NEI shows this to be a large VOC 

emissions category in the LADCO States (i.e.., 50,000 TPY) USEPA 

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 Adhesives and Sealants nonpoint category (SCC 2460600000 - all 

adhesives and sealants).” (USEPA, 2007b) Consequently, this category was 

omitted from the 2005 regional emissions inventory.

5
February 27, 2008

Outdoor Wood Boilers: Over the past several years, the installation and 

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 category.

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 

RPOs 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/Saturday/Sunday 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-Ladco states, the annual EGUs emissions were 

replaced with the 2005 sum of hourly emissions for all 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 

RPOs to produce weekday, Saturday, and Sunday emissions for each month. EGUs were 

removed from this 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 Canadian 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 emission 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.

 

 

6
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 the 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 Base K, there 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 precursors of secondary PM2.5 organic carbon mass.

Figure 4. Isoprene emissions for Base M (left) v. Base K (right)

7
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. These annual

emissions were then adjusted by applying monthly temporal factors based on the processbased ammonia emissions model (http://www.conceptmodel.org/nh3/nh3_index.html). The 

model was run for the following list of model farms using 2002 meteorological 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., all LADCO states used the Wisconsin farm results). The following figure shows 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

01/03/0201/17/0201/31/0202/14/0202/28/0203/14/0203/28/0204/11/0204/25/0205/09/0205/23/0206/06/0206/20/0207/04/0207/18/0208/01/0208/15/0208/29/0209/12/0209/26/0210/10/0210/24/0211/07/0211/21/0212/05/0212/19/02

Date

NH3 emissions (Kg / day)

Daily Total - Dairy 55001

0.00

2.00

4.00

6.00

8.00

10.00

12.00

14.00

01/03/0201/17/0201/31/0202/14/0202/28/0203/14/0203/28/0204/11/0204/25/0205/09/0205/23/0206/06/0206/20/0207/04/0207/18/0208/01/0208/15/0208/29/0209/12/0209/26/0210/10/0210/24/0211/07/0211/21/0212/05/0212/19/02

Date

NH3 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

01/03/0201/17/0201/31/0202/14/0202/28/0203/14/0203/28/0204/11/0204/25/0205/09/0205/23/0206/06/0206/20/0207/04/0207/18/0208/01/0208/15/0208/29/0209/12/0209/26/0210/10/0210/24/0211/07/0211/21/0212/05/0212/19/02

Date

NH3 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

01/03/0201/17/0201/31/0202/14/0202/28/0203/14/0203/28/0204/11/0204/25/0205/09/0205/23/0206/06/0206/20/0207/04/0207/18/0208/01/0208/15/0208/29/0209/12/0209/26/0210/10/0210/24/0211/07/0211/21/0212/05/0212/19/02

Date

NH3 emissions (Kg / day)

Figure 5. Daily emissions for 2002 for various model farms

8
February 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 Iow 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 2003 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 

PM2.5 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).

9
February 27, 2008

Future Year Emissions

Complete emission inventories were developed for two future years: 2009 and 20181. 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. Additional emission reports are available on the LADCO website 

(http://64.27.125.175/tech/emis/r5/round5_reports.htm.

 VOC NOx SO2

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 point sources (for which, the 2009 emissions 

were used).

10
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-LADCO 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 between 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 gasoline, 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 coatings

• 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 standards2

• Combustion turbine MACT

• Consent decrees (refineries, 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 the other four 

LADCO States.

11
February 27, 2008

• Other (Illinois and Ohio NOx RACT4, and BART in IN and WI)

Further discussion of the development of the future year emissions is provided below:

On-Road: Similar to the base year modeling, CONCEPT was run using transportation 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 25.

For the non-LADCO States, CONCEPT was run by Environ using HPMS county-level data and 

MOBILE6 inputs 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 analysis 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.

12
February 27, 2008

Table 2. Summary of On-road Emissions (TPD – 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 2,824.4 268.0 527.8 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 1,673.4 119.4 322.1 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 1,967,052,025.8

13
February 27, 2008

EGU Point: Future year emissions were based on EPA’s IPM3.0 modeling6. Three CAIR 

scenarios were addressed:

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

5b: 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

5c: EPA’s IPM3.0, with several “may do” adjustments identified by the States. These 

adjustments reflect less rigorous criteria, but should still 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 

facilities affected by the “will do” and “may do” adjustments are identified in Attachment 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 modeling 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 emissions 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 sensitivity 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 years 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.

EPA 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.

14
February 27, 2008

Table 4 provides information from USEPAs Clean Air Markets Division (CAMD) on scrubber 

installation dates. This information is based on various sources, including company 

announcements, consent decrees, vendors, and organizations that track scrubber installations. 

While there may be uncertainty in any projection of control installations, USEPA considers these 

adequate projections 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 PM2.5 air 

quality in the upper Midwest (see highlighting in Table 4). To reflect uncontrolled (2009) 

emissions 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.

15
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 116 142 142 132 157 125

16
February 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

OnlineYear

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 718 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 Greenidge LLC 2527_B_5 2527 5 26.5 2010 

NorthCarolina Cliffside 2721_B_1 2721 1 38 2010 

17
February 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 Cliffside 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

NorthCarolina 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 Sammis 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 Ferry 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 Keystone 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 Kingston 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 2010 

Virginia Yorktown 3809_B_1 3809 1 159 2010 

18
February 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

Pennsylvania Cheswick 11.53 103.98

Tennessee Kingston 41.15 155.20

19
February 27, 2008

References

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

Other (non-LADCO) State Emissions, Preparation and Delivery of Non-MRPO 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 Midwest 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, 2007a, “LADCO 2005 Locomotive Emissions”, Draft, February 2007.

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

Environ, 2008, “LADCO On-Road Emission Inventory Development Using CONCEPT MV”, 

January 2008.

LADCO, 2006a, “Base K/Round 4 Strategy Modeling” 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, PM2.5, and Regional Haze”, EPA-454/B07-002, April 

2007. 

USEPA, 2007b, E-mail from Dennis Beauregard (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 Outdoor Wood Boiler Methodology”, PowerPoint 

presentation by Bart Sponseller, November 13, 2006.

20
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.html

21
February 27, 2008

ATTACHMENT 1

Emissions Summaries

22
VOC 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 234419 10263 10564 6581 5781 5928 5504 5280 539 727 723
February 27, 2008

ATTACHMENT 2

“Will Do” and “May Do” EGU Facility Emissions

24
February 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 Minnesota 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

 18 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 Alliant NOX 19.06 11.85 -7.215

 27 US 55 123 663020930 DAIRYLAND POWER NOX 10.47 8.52 -1.955

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

 polid 382.05 486.07 102.327

25
February 27, 2008

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

-----

 Obs cntryid stid cyid fcid name polid aceebase aceenew diff

 28 US 17 97 097190AAC MIDWEST GENERAT SO2 49.91 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 12.822

 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 2055.32 516.112

26
February 27, 2008

2009 – Difference between “will do” (5b) and “may do” (5c) 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 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

27
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 (PM2.5) Standard 

Central 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 (PM2.5) 

Standard, 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 (PM2.5) Redesignation Petition and 

Maintenance 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 oftype 1

LINE COUNT

Display Matter - (Must not ex-ceed two actual lines, neither ofwhich shall

total more than four solid lines ofthe type in which the body ofthe

advertisement is set). - number of equivalent lines

Head - Number lines

Body - Number

Tail- Number

Totalnum

DATA FOR COMPUTING COST

Width ofsingle column 5.8 ems

Number ofinsertions --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 proofin excess oftwo)

_. . .' .,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 allJust credtts, and that no part ofthe same

B~g,://t~t~~~~~o~ipb~/~~~dhtm curacy. of the has been paid. iting. Written

statemen s may es deSignated to

receive written comm I also certify that the printed matter attached hereto is a true copy, ofthe 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~~~ndianaArea Fi~Ta~article {PM2.5j Redesignation Pe- 08/14/2009 and08114/2009;~_

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 partidWiihoBi~~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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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

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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.

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[Seal]

Notary Public

County of Residence: Marion

My Commission expires on August 28, 2016
.I I~lanAES

company

RECEI\/EO

September 3,2009

Scott Deloney, Chief

Programs Branch

Office ofAir Quality MC 61-50

100 North Senate Avenue

Indiana Department ofEnvironmental 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 (PM2.5)

~~~~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 ofthe Notice and Hearing is to solicit public comment on the Draft

Redesignation Petition and Maintenance Plan in association with the Annual Fine Particle

(PM2.5) Standard, for the Central Indiana Area. Indianapolis Power & Light (IPL)

Company supports IDEM's efforts for redesignation ofthe Central Indiana Area and

appreciates the opportunity to comment on the draft Request for Redesignation.

Section 4.1 (page 16) ofthe Request for Redesignation specifically identifies IPLHarding Street (HS) Gener(!.ting Station and IPL - Eagle Valley (BV) Generating Station.

IDEM indicates that IPL installed various NOx controls as a result ofCAIR. IPL would

like to clarify that additional NOx controls were installed voluntarily in anticipation of

more stringent NOx emissions limitations, but that uncertainty still surrounds the final

outcome ofCAIR regulations and the results ofCAIR remain unknown. The controls

specified in the Request for Redesignation are low NOx 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 ofNOx controls after

2003. NOx 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 ofthe

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 ofIPL - HS and IPL - EV (page 16 ofthe Request for

Redesignation):

A..s a result ofCAIR, Additional NOx 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 NOx 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 (PM2.5) Standard 

Summary/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 NOx controls were installed 

voluntarily in anticipation of more stringent NOx emissions limitations, but that 

uncertainty 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 NOx controls after 

2003. 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 NOx control technologies have 

been 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 NOx Burners, and 

Separated Overfire Air. The SO2 data from 2008 reflects the 

installation of a flue gas desulphurization system at the IPLHarding Street Generating Station power plant 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.