APPENDIX A 

Air Quality System (AQS) and Indiana 

Department of Environmental Management 

(IDEM) Fine Particle Monitor Data Values for the 

Louisville Area (2000 – 2010) 
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A-1 

Monitoring Data for Indiana’s Portion of the 

Louisville Area 

SITE ID COUNTY SITE NAME YEAR Annual Average 

μg/m3

2008-2010 Average 

μg/m3

18-019-0006 Clark Jeffersonville – Walnut Street 2008 14.48 

2009 13.01 14.1

2010 14.67 

18-019-0008 Clark Charlestown State Park 2008 13.44 2009 10.84 12.2

2010 12.45 

18-089-2004 Floyd New Albany 2008 12.70 

2009 11.91 12.8

2010 13.80 

Red Text Indicates Incomplete Data 

The Charlestown State Park monitor began operation on July 2, 2008. 

Site ID County Site Name Yearly Annual Means 

2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 

18-019-0005 Clark Spring Street 18.59 16.85 16.02 14.68 

18-019-0006 Clark Jeffersonville - 

Walnut Street 19.12 15.07 18.48E

 14.91E 16.43E 14.48 13.01 14.67 

18-019-0005/6 Clark Combined* 16.85 16.02 15.78 15.07 18.48E

18-019-0008 Clark Charlestown 

State Park 13.44 10.84 12.45 

18-043-1004 Floyd New Albany 16.27 15.73 14.62 14.44 13.68 16.69E 13.32E 14.66E 12.70 11.91 13.80 

* Combined-- These two sites are considered to measure the same air mass, thus the data are combined for the purpose of the Design 

Value calculations 

E Exceptional event data removed from calculations. 

The Jeffersonville – Spring Street monitor was replaced by the Jeffersonville – Walnut Street monitor on June 29, 2003. 

The Charlestown State Park monitor began operation on July 2, 2008. 

 
A-2 

Site ID County Site Name Three Year Design Values 

00-02 01-03 02-04 03-05 04-06 05-07 06-08 07-09 08-10 

18-019-0005 Clark Spring Street 17.2 15.8 

18-019-0006 Clark Jeffersonville – 

Walnut Street 19.1 17.1 17.6 16.2 16.6 15.3 14.6 14.1 

 18-019-0005/6 Clark Combined* 16.2 15.6 16.5 

18-019-0008 Clark Charlestown State 

Park 13.4 12.1 12.2 

18-043-1004 Floyd New Albany 15.5 14.9 14.2 14.9 14.6 14.9 13.6 13.1 12.8 

Value above the annual standard for fine particles 

* Combined-- These two sites are considered to measure the same air mass, thus the data are combined for the purpose of the 

Design Value calculations 

Red Text Indicates Incomplete Data

Blue Text Indicates Design Value Based on One Year of Data 

Green Text Indicates Design Value Based on Two Years of Data 

The Jeffersonville – Spring Street monitor was replaced by the Jeffersonville – Walnut Street monitor on June 29, 2003. 

The Charlestown State Park monitor began operation on July 2, 2008. 

Annual Fine Particle Trends for Indiana’s Portion of the Louisville Area, 

 2006 through 2010 

Red line represents the annual standard for fine particles of 15.0 ug/m3

The Charlestown State Park monitor began operation on July 2, 2008. 

 

8.0

10.0

12.0

14.0

16.0

18.0

2006 2007 2008 2009 2010

ug/m3

Jeffersonville ‐ Walnut Street Charlestown State Park New Albany

Year
A-3 

Fine Particle Design Values for Indiana’s Portion of the Louisville Area, 

2006 through 2010 

Red line represents the annual standard for fine particles of 15 μg/m3

The Charlestown State Park monitor began operation on July 2, 2008. 

6.0

8.0

10.0

12.0

14.0

16.0

2006‐2008 2007‐2009 2008‐2010

ug/m3

Jeffersonville ‐ Walnut Street Charlestown State Park New Albany
A-4 

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A-5 

Monitoring Data for Kentucky’s Portion of the 

Louisville Area 

SITE ID COUNTY SITE NAME YEAR Annual Average 

μg/m3

2008-2010 

Average μg/m3

21-029-0006 Bullitt Shepherdsville 2008 12.84 

2009 11.81 12.70

2010 13.45 

21-111-0043 Jefferson Southern Avenue 2008 13.17 

2009 12.21 12.95

2010 13.47 

21-111-0044 Jefferson Wyandotte Park 2008 13.41 

2009 12.45 13.20

2010 13.74 

21-111-0048 Jefferson Barret Avenue 2008 13.44 

2009 N/A 13.44

2010 N/A 

21-111-0051 Jefferson Watson Elementary 2008 12.78 

2009 11.59 13.07

2010 14.83 

21-111-0067 Jefferson Cannons Lane 2008 N/A 

2009 11.67 12.47

2010 13.27 

Blue Text Indicates Design Value Based on One Year of Data 

Green Text Indicates Design Value Based on Two Years of Data 

The Barrett Avenue monitor discontinued operation on December 31, 2008.

The Cannons Lane monitor began operation on January 1, 2009. 

Site ID County Site Name Yearly Annual Means 

2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 

21-029-0006 Bullitt Shepherdsville 16.43 15.55 14.69 14.37 13.62 16.32* 14.14 15.32 12.84 11.81 13.45 

21-111-0043 Jefferson Southern 

Avenue 17.31 17.10* 17.16 15.96 14.53 16.72 14.96* 15.09 13.17 12.21 13.47 

21-.111-0044 Jefferson Wyandotte 

Park 16.68 17.73 17.45 15.38 14.05 16.48 15.18 14.91 13.41 12.45 13.74 

21-111-0048 Jefferson Barret 16.71* 16.90* 16.43 15.53 13.71* 16.77 13.99 14.96 13.44 

21-111-0051 Jefferson Watson 

Elementary 16.80* 16.27* 15.72* 14.92 12.63 16.48 13.67 15.71 12.78 11.59 14.83 

21-111-0067 Jefferson Cannons Lane 11.67 13.27 

*Indicates that the mean does not satisfy summary criteria. 

The Barrett Avenue monitor discontinued operation on December 31, 2008. 

The Cannons Lane monitor began operation on January 1, 2009. 

 
A-6 

Site ID County Site Name Three Year Design Values 

00-02 01-03 02-04 03-05 04-06 05-07 06-08 07-09 08-10 

21-029-0006 Bullitt Shepherdsville 15.56 14.87 14.23 14.77 14.69 15.26 14.10 13.32 12.70 

21-111-0043 Jefferson Southern Avenue 17.19 16.74 15.88 15.74 15.40 15.59 14.41 13.49 12.95 

21-111-0044 Jefferson Wyandotte Park 17.29 16.85 15.63 15.30 15.24 15.52 14.50 13.59 13.20 

21-111-0048 Jefferson Barret Avenue 16.68 16.29 15.22 15.32 14.77 15.30 14.19 14.28 13.44 

21-111-0051 Jefferson Watson Elementary 16.26 15.64 14.42 14.68 14.26 15.29 14.05 13.36 13.07 

21-111-0067 Jefferson Cannons Lane 11.67 12.47 

 Value above the annual standard for fine particles. 

Blue Text Indicates Design Value Based on One Year of Data 

Green Text Indicates Design Value Based on Two Years of Data 

The Barrett Avenue monitor discontinued operation on December 31, 2008. 

The Cannons Lane monitor began operation on January 1, 2009. 

Annual Fine Particle Trends for Kentucky’s Portion of the Louisville Area, 

2006 through 2010 

 Red line represents the annual standard for fine particles of 15 μg/m3 

 The Barrett Avenue monitor discontinued operation on December 31, 2008. 

 The Cannons Lane monitor began operation on January 1, 2009. 

8.0

10.0

12.0

14.0

16.0

18.0

2006 2007 2008 2009 2010

ug/m3

Shepherdsville Southern Avenue Wyandotte Park

Barret Avenue Watson Elementary Cannons Lane

Year
A-7 

Fine Particle Design Values for Kentucky’s Portion of the Louisville Area, 

2006 through 2010 

Red line represents the annualstandard for fine particles of 15 μg/m3

The Barrett Avenue monitor discontinued operation on December 31, 2008. 

The Cannons Lane monitor began operation on January 1, 2009. 

6.0

8.0

10.0

12.0

14.0

16.0

18.0

Shepherdsville Southern

Avenue

Wyandotte Park Barret Avenue Watson

Elementary

Cannons Lane

21‐029‐0006 21‐111‐0043 21‐111‐0044 21‐111‐0048 21‐111‐0051 21‐111‐0067

ug/m3

2006‐2008 2007‐2009 2008‐2010
APPENDIX B 

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

Direct Fine Particle (PM2.5) Point Source 

Emissions (2005 and 2008), Louisville Area 
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B-1 

Clark, Floyd and Jefferson Counties, IN Point Source Totals (Tons per Year)

Year NOx SO2 Direct PM2.5

2005 30,155.53 134,515.58 953.48 

2008 27,916.08 108,861.34 847.78 

2005-Clark, Floyd and Jefferson Counties, IN Point Source Totals (Tons per Year) 

County EGU- NOx

NONEGUNOx

EGU-SO2

NONEGU-SO2

EGUDirect 

PM2.5

NONEGUDirect 

PM2.5

Clark 0.00 2,220.61 0.00 3,190.07 0.00 611.00

Floyd 5,306.09 0.19 56,666.70 0.00 36.76 12.02

Jefferson 22,620.90 7.74 74,658.70 0.11 283.00 10.70

Sub-Total 27,926.99 2,228.54 131,325.40 3,190.18 319.76 633.72

NOx SO2 Direct PM2.5

Grand Total 30,155.53 134,515.58 953.48 

2008-Clark, Floyd and Jefferson Counties, IN Point Source Totals (Tons per Year) 

County EGU- NOx

NONEGUNOx

EGU-SO2

NONEGU-SO2

EGUDirect 

PM2.5

NONEGUDirect 

PM2.5

Clark 0.00 2,419.41 0.00 3,493.53 0.00 520.25

Floyd 4,941.90 0.19 40,433.40 0.00 31.00 3.79

Jefferson 20,546.70 7.88 64,934.30 0.11 284.50 8.24

Sub-Total 25,488.60 2,427.48 105,367.70 3,493.64 315.50 532.28

 NOx SO2 Direct PM2.5

Grand Total 27,916.08 108,861.34 847.78 

 
B-2 

NOx Point Source Emissions Trend, Clark, Floyd, and Jefferson Counties, Indiana, 

2005 and 2008 

SO2 Point Source Emissions Trend, Clark, Floyd, and Jefferson Counties, Indiana, 

2005 and 2008 

0

20,000

40,000

60,000

80,000

100,000

120,000

140,000

160,000

2005 2008

Tons per Year

Sulfur Dioxide Year

0

5,000

10,000

15,000

20,000

25,000

30,000

35,000

40,000

2005 2008

Tons per Year

Nitrogen Oxides Year
B-3 

Direct PM2.5 Point Source Emissions Trend, Clark, Floyd, and Jefferson Counties, 

Indiana, 2005 and 2008 

0

200

400

600

800

1,000

1,200

1,400

2005 2008

Tons per Year

Fine Particles Year
B-4 

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B-5 

Louisville Area Point Source Totals (Tons per Year) 

Year NOx SO2 Direct PM2.5

2005 52,026.30 179,619.41 4,734.31 

2008 52,867.35 149,991.38 4,304.97 

2005-Louisville Area Point Source Emissions (Tons per Year) 

County EGU 

NOx

NONEGU- NOxEGU 

SO2

NONEGU-SO2EGUDirect PM2.5NON-EGUDirect PM2.5

Clark County, IN 0.00 2,220.61 0.00 3,190.07 0.00 611.00

Floyd County, IN 5,306.09 0.19 56,666.70 0.00 36.76 12.02

Jefferson County, 

IN 22,620.90 7.74 74,658.70 0.11 283.00 10.70

Bullitt County, KY 0.00 204.61 0.00 356.47 0.00 53.35

Jefferson County, 

KY 20,176.48 1,489.68 42,852.96 1,894.40 3,123.24 604.24

Sub-Total 48,103.47 3,922.83 174,178.36 5,441.05 3,443.00 1,291.31

NOx SO2 Direct PM2.5

Grand Total 52,026.30 179,619.41 4,734.31 

2008-Louisville Area Point Source Emissions (Tons per Year) 

County EGU 

NOx

NONEGU- NOxEGU 

SO2

NONEGU-SO2

EGUDirect 

PM2.5

NON-EGUDirect 

PM2.5

Clark County, IN 0.00 2,419.41 0.00 3,493.53 0.00 520.25

Floyd County, IN 4,941.90 0.19 40,433.40 0.00 31.00 3.79

Jefferson County, IN 20,546.70 7.88 64,934.30 0.11 284.50 8.24

Bullitt County, KY 0.00 215.12 0.00 365.07 0.00 54.13

Jefferson County, 

KY 22,749.14 1,987.01 38,684.02 2,080.95 2,763.06 640.00

Sub-Total 48,237.74 4,629.61 144,051.72 5,939.66 3,078.56 1,226.41

NOx SO2 Direct PM2.5

Grand Total 52,867.35 149,991.38 4,304.97 

 
B-6 

NOx Point Source Emissions Trend, Louisville Area, 2005 and 2008 

SO2 Point Source Emissions Trend, Louisville Area, 2005 and 2008 

0

10,000

20,000

30,000

40,000

50,000

60,000

70,000

80,000

2005 2008

Tons per Year

Nitrogen Oxides Year

0

20,000

40,000

60,000

80,000

100,000

120,000

140,000

160,000

180,000

200,000

2005 2008

Tons per Year

Sulfur Dioxide Year
B-7 

Direct PM2.5 Point Source Emissions Trend, Louisville Area, 2005 and 2008 

0

1,000

2,000

3,000

4,000

5,000

6,000

2005 2008

Tons per Year

Fine Particles Year
APPENDIX C 

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

Direct Fine Particle (PM2.5) Emissions, All Sources 

(2005 and 2008), Louisville Area 
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C-1 

Clark, Floyd and Jefferson Counties, IN Totals (Tons per Year) 

Year NOx SO2 Direct PM2.5

2005 41,750.37 135,182.59 1,376.37 

2008 37,526.06 109,372.52 1,202.47 

2005-Clark, Floyd and Jefferson Counties, IN Totals (Tons per Year) 

 AREA NONROAD ONROAD POINT GRAND TOTAL

NOX 797.66 3,246.42 7,550.76 30,155.53 41,750.37

SO2 324.62 305.54 36.85 134,515.58 135,182.59

Direct PM2.5 12.27 160.39 250.23 953.48 1,376.37

2005-Clark, Floyd and Jefferson Counties, IN Totals (Tons per Year) 

COUNTY STATE SECTOR NOX SO2 Direct PM2.5

CLARK INDIANA AREA 358.62 138.17 5.14

CLARK INDIANA NONROAD 1,971.32 178.06 82.06

CLARK INDIANA ONROAD 4,106.81 20.72 135.49

CLARK INDIANA POINT 2,220.61 3,190.07 611.00

FLOYD INDIANA AREA 286.78 113.26 4.63

FLOYD INDIANA NONROAD 754.09 78.04 47.26

FLOYD INDIANA ONROAD 2,922.90 14.03 99.63

FLOYD INDIANA POINT 5,306.28 56,666.70 48.78

JEFFERSON INDIANA AREA 152.26 73.19 2.50

JEFFERSON INDIANA NONROAD 521.01 49.44 31.07

JEFFERSON INDIANA ONROAD 521.05 2.10 15.11

JEFFERSON INDIANA POINT 22,628.64 74,658.81 293.70

 Madison Township Only 

2008-Clark, Floyd and Jefferson Counties, IN Totals (Tons per Year) 

 AREA NONROAD ONROAD POINT GRAND TOTAL

NOX 811.15 2,553.23 6,245.60 27,916.08 37,526.06

SO2 330.32 141.97 38.89 108,861.34 109,372.52

Direct PM2.5 12.37 131.41 210.91 847.78 1,202.47

 
C-2 

2008-Clark, Floyd and Jefferson Counties, IN Totals (Tons per Year) 

COUNTY STATE SECTOR NOX SO2 Direct PM2.5

CLARK INDIANA AREA 364.36 140.18 5.17

CLARK INDIANA NONROAD 1,519.07 86.85 66.05

CLARK INDIANA ONROAD 3,444.07 22.22 117.07

CLARK INDIANA POINT 2,419.41 3,493.53 520.25

FLOYD INDIANA AREA 291.17 114.69 4.68

FLOYD INDIANA NONROAD 611.02 33.26 39.48

FLOYD INDIANA ONROAD 2,397.70 14.58 82.61

FLOYD INDIANA POINT 4,942.09 40,433.40 34.79

JEFFERSON INDIANA AREA 155.62 75.45 2.52

JEFFERSON INDIANA NONROAD 423.14 21.86 25.88

JEFFERSON INDIANA ONROAD 403.83 2.09 11.23

JEFFERSON INDIANA POINT 20,554.58 64,934.41 292.74 

 Madison Township Only 

NOx Emission Trends, All Sources, Clark, Floyd, and Jefferson Counties, Indiana, 

2005 and 2008 

 

0

5,000

10,000

15,000

20,000

25,000

30,000

35,000

40,000

45,000

50,000

2005 2008

Tons per Year

Nitrogen Oxides Year
C-3 

SO2 Emission Trends, All Sources, Clark, Floyd, and Jefferson Counties, Indiana, 

2005 and 2008 

Direct PM2.5 Emission Trends, All Sources, Clark, Floyd, and Jefferson Counties, 

Indiana, 2005 and 2008 

0

20,000

40,000

60,000

80,000

100,000

120,000

140,000

160,000

2005 2008

Tons per Year

Sulfur Dioxide Year

0

500

1,000

1,500

2,000

2005 2008

Tons per Year

Fine Particles Year
C-4 

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C-5 

Louisville Area Totals (Tons per Year) 

Year NOx SO2 Direct PM2.5

2005 101,265.63 181,233.43 7,380.59

2008 97,533.93 151,503.01 6,724.02

2005-Louisville Area Totals (Tons per Year) 

 AREA NONROAD ONROAD POINT GRAND TOTAL

NOX 2,123.83 14,370.95 32,744.55 52,026.30 101,265.63

SO2 418.98 1,050.81 144.23 179,619.41 181,233.43

Direct PM2.5 810.13 780.54 1,055.61 4,734.31 7,380.59

2005-Louisville Area Totals (Tons per Year) 

COUNTY STATE SECTOR NOX SO2 Direct PM2.5

CLARK INDIANA AREA 358.62 138.17 5.14

CLARK INDIANA NONROAD 1,971.32 178.06 82.06

CLARK INDIANA ONROAD 4,106.81 20.72 135.49

CLARK INDIANA POINT 2,220.61 3,190.07 611.00

FLOYD INDIANA AREA 286.78 113.26 4.63

FLOYD INDIANA NONROAD 754.09 78.04 47.26

FLOYD INDIANA ONROAD 2,922.90 14.03 99.63

FLOYD INDIANA POINT 5,306.28 56,666.70 48.78

JEFFERSON INDIANA AREA 152.26 73.19 2.50

JEFFERSON INDIANA NONROAD 521.01 49.44 31.07

JEFFERSON INDIANA ONROAD 521.05 2.10 15.11

JEFFERSON INDIANA POINT 22,628.64 74,658.81 293.70

BULLITT KENTUCKY AREA 53.48 94.36 247.16

BULLITT KENTUCKY NONROAD 533.69 30.94 40.62

BULLITT KENTUCKY ONROAD 2,952.07 12.11 84.08

BULLITT KENTUCKY POINT 204.61 356.47 53.35

JEFFERSON KENTUCKY AREA 1,272.69 0.00 550.70

JEFFERSON KENTUCKY NONROAD 10,590.84 714.33 579.53

JEFFERSON KENTUCKY ONROAD 22,241.72 95.26 721.30

JEFFERSON KENTUCKY POINT 21,666.16 44,747.36 3,727.48

 Madison Township Only 

2008-Louisville Area Totals (Tons per Year) 

 AREA NONROAD ONROAD POINT GRAND TOTAL

NOX 2,249.37 14,256.76 28,160.45 52,867.35 97,533.93

SO2 425.58 932.87 153.18 149,991.38 151,503.01

Direct PM2.5 755.80 739.88 923.37 4,304.97 6,724.02
C-6 

2008-Louisville Area Totals (Tons per Year) 

COUNTY STATE SECTOR NOX SO2 Direct PM2.5

CLARK INDIANA AREA 364.36 140.18 5.17

CLARK INDIANA NONROAD 1,519.07 86.85 66.05

CLARK INDIANA ONROAD 3,444.07 22.22 117.07

CLARK INDIANA POINT 2,419.41 3,493.53 520.25

FLOYD INDIANA AREA 291.17 114.69 4.68

FLOYD INDIANA NONROAD 611.02 33.26 39.48

FLOYD INDIANA ONROAD 2,397.70 14.58 82.61

FLOYD INDIANA POINT 4,942.09 40,433.40 34.79

JEFFERSON INDIANA AREA 155.62 75.45 2.52

JEFFERSON INDIANA NONROAD 423.14 21.86 25.88

JEFFERSON INDIANA ONROAD 403.83 2.09 11.23

JEFFERSON INDIANA POINT 20,554.58 64,934.41 292.74 

BULLITT KENTUCKY AREA 55.99 95.26 247.15

BULLITT KENTUCKY NONROAD 448.45 12.22 37.44

BULLITT KENTUCKY ONROAD 2,820.80 13.28 85.40

BULLITT KENTUCKY POINT 215.12 365.07 54.13

JEFFERSON KENTUCKY AREA 1,382.23 0.00 496.28

JEFFERSON KENTUCKY NONROAD 11,255.08 778.68 571.03

JEFFERSON KENTUCKY ONROAD 19,094.05 101.00 627.06

JEFFERSON KENTUCKY POINT 24,736.15 40,764.97 3,403.06

Madison Township Only 

NOx Emission Trends, All Sources, Louisville Area, 2005 and 2008 

0

20,000

40,000

60,000

80,000

100,000

120,000

2005 2008

Tons per Year

Nitrogen Oxides Year
C-7 

SO2 Emission Trends, All Sources, Louisville Area, 2005 and 2008 

Direct PM2.5 Emission Trends, All Sources, Louisville Area, 2005 and 2008 

0

20,000

40,000

60,000

80,000

100,000

120,000

140,000

160,000

180,000

200,000

2005 2008

Tons per Year

Sulfur Dioxide Year

0

1,000

2,000

3,000

4,000

5,000

6,000

7,000

8,000

9,000

10,000

2005 2008

Tons per Year

Fine Particles Year
APPENDIX D 

Nitrogen Oxides (NOx) and Sulfur Dioxide (SO2) 

Emission Trends from Electric Generating Units 

(EGUs), Louisville Area (1999 through 2009)
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D-1

Trends in EGU NOx Emissions, Floyd and Jefferson Counties, Indiana 

NOx Emissions from EGUs, Floyd and Jefferson Counties, Indiana, 1999 to 2009 

Year Total NOx Emissions, tons/year 

1999 40,042.30 

2000 39,396.60 

2001 37,896.00 

2002 35,364.10 

2003 28,282.60 

2004 28,977.70 

2005 27,926.80 

2006 25,900.50 

2007 25,829.60 

2008 25,488.60 

2009 11,106.90 

0

5,000

10,000

15,000

20,000

25,000

30,000

35,000

40,000

45,000

1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009

Tons per Year

Nitrogen Oxides Year
D-2

Trends in EGU NOx Emissions, Louisville Area 

NOx Emissions from EGUs Louisville Area, 1999 to 2009 

 

Year Total NOx Emissions, tons/year 

1999 69,082.50 

2000 67,565.80 

2001 62,660.60 

2002 56,242.90 

2003 49,343.00 

2004 46,460.50 

2005 48,035.80 

2006 45,286.30 

2007 46,404.00 

2008 45,175.70 

2009 24,752.00 

0

10,000

20,000

30,000

40,000

50,000

60,000

70,000

80,000

1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009

Tons per Year

Nitrogen Oxides Year
D-3

NOx Emissions from EGUs, Louisville Area 1999 

State Facility NOx Emissions, tons/year 

Indiana 

Indiana Kentucky Electric 

Corporation (IKEC) - Clifty 

Creek Power Plant 33,119.00 

Indiana Duke Energy Indiana – 

Gallagher Generating Station 6,923.30 

Kentucky Louisville Gas and Electric – 

Cane Run Station 8,174.70 

Kentucky Louisville Gas and Electric – 

Mill Creek Station 20,865.50 

Total 69,082.50 

NOx Emissions from EGUs, Louisville Area 2000 

State Facility NOx Emissions, tons/year 

Indiana IKEC - Clifty Creek 

Power Plant 31,882.00 

Indiana Duke Energy Indiana – 

Gallagher Generating Station 7,514.60 

Kentucky Louisville Gas and Electric – 

Cane Run Station 7,713.50 

Kentucky Louisville Gas and Electric – 

Mill Creek Station 20,455.70 

Total 67,565.80 

NOx Emissions from EGUs, Louisville Area 2001 

State Facility NOx Emissions, tons/year 

Indiana IKEC - Clifty Creek 

Power Plant 31,232.80 

Indiana Duke Energy Indiana – 

Gallagher Generating Station 6,663.20 

Kentucky Louisville Gas and Electric – 

Cane Run Station 7,188.30 

Kentucky Louisville Gas and Electric – 

Mill Creek Station 17,576.30 

Total 62,660.60 

 
D-4

NOx Emissions from EGUs, Louisville Area 2002 

State Facility NOx Emissions, tons/year 

Indiana IKEC- Clifty Creek 

Power Plant 29,231.00 

Indiana Duke Energy Indiana – 

Gallagher Generating Station 6,133.10 

Kentucky Louisville Gas and Electric – 

Cane Run Station 6,271.80 

Kentucky Louisville Gas and Electric – 

Mill Creek Station 14,607.00 

Total 56,242.90 

NOx Emissions from EGUs, Louisville Area 2003 

State Facility NOx Emissions, tons/year 

Indiana IKEC- Clifty Creek 

Power Plant 21,888.90 

Indiana Duke Energy Indiana – 

Gallagher Generating Station 6,393.70 

Kentucky Louisville Gas and Electric – 

Cane Run Station 6,664.70 

Kentucky Louisville Gas and Electric – 

Mill Creek Station 14,395.70 

Total 49,343.00 

NOx Emissions from EGUs, Louisville Area 2004 

State Facility NOx Emissions, tons/year 

Indiana IKEC- Clifty Creek 

Power Plant 22,678.40 

Indiana Duke Energy Indiana – 

Gallagher Generating Station 6,299.30 

Kentucky Louisville Gas and Electric – 

Cane Run Station 5,585.30 

Kentucky Louisville Gas and Electric – 

Mill Creek Station 11,897.50 

Total 46,460.50 

 
D-5

NOx Emissions from EGUs, Louisville Area 2005 

State Facility NOx Emissions, tons/year 

Indiana IKEC- Clifty Creek 

Power Plant 22,620.90 

Indiana Duke Energy Indiana – 

Gallagher Generating Station 5,305.90 

Kentucky Louisville Gas and Electric – 

Cane Run Station 7,040.50 

Kentucky Louisville Gas and Electric – 

Mill Creek Station 13,068.50 

Total 48,035.80 

NOx Emissions from EGUs, Louisville Area 2006 

State Facility NOx Emissions, tons/year 

Indiana IKEC- Clifty Creek 

Power Plant 21,661.70 

Indiana Duke Energy Indiana – 

Gallagher Generating Station 4,238.80 

Kentucky Louisville Gas and Electric – 

Cane Run Station 6,791.50 

Kentucky Louisville Gas and Electric – 

Mill Creek Station 12,594.30 

Total 45,286.30 

NOx Emissions from EGUs, Louisville Area 2007 

State Facility NOx Emissions, tons/year 

Indiana IKEC- Clifty Creek 

Power Plant 20,453.80 

Indiana Duke Energy Indiana – 

Gallagher Generating Station 5,375.80 

Kentucky Louisville Gas and Electric – 

Cane Run Station 6,543.90 

Kentucky Louisville Gas and Electric – 

Mill Creek Station 14,030.50 

Total 46,404.00 

 
D-6

NOx Emissions from EGUs, Louisville Area 2008 

State Facility NOx Emissions, tons/year 

Indiana IKEC- Clifty Creek 

Power Plant 20,546.70 

Indiana Duke Energy Indiana – 

Gallagher Generating Station 4,941.90 

Kentucky Louisville Gas and Electric – 

Cane Run Station 5,894.10 

Kentucky Louisville Gas and Electric – 

Mill Creek Station 13,793.00 

Total 45,175.70 

NOx Emissions from EGUs, Louisville Area 2009 

State Facility NOx Emissions, tons/year 

Indiana IKEC- Clifty Creek 

Power Plant 8,018.80 

Indiana Duke Energy Indiana – 

Gallagher Generating Station 3,088.10 

Kentucky Louisville Gas and Electric – 

Cane Run Station 5,738.20 

Kentucky Louisville Gas and Electric – 

Mill Creek Station 7,906.90 

Total 24,752.00 

Trends in EGU SO2 Emissions, Floyd and Jefferson Counties, Indiana 

 

Year Total SO2 Emissions, tons/year 

1999 102,552.00 

2000 101,686.40 

2001 86,675.00 

2002 85,964.70 

2003 86,094.40 

2004 115,789.60 

2005 131,325.40 

2006 116,190.90 

2007 126,876.50 

2008 105,367.70 

2009 81,378.50 
D-7

SO2 Emissions from EGUs, Floyd and Jefferson Counties, Indiana, 1999 to 2009 

Trends in EGU SO2 Emissions, Louisville Area 

 

Year Total SO2 Emissions, tons/year 

1999 165,480.70 

2000 153,627.40 

2001 125,310.20 

2002 123,518.00 

2003 127,468.30 

2004 157,252.40 

2005 174,219.30 

2006 158,777.40 

2007 169,651.30 

2008 144,054.60 

2009 114,404.60 

0

20,000

40,000

60,000

80,000

100,000

120,000

140,000

1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009

Tons per Year

Sulfur Dioxide Year
D-8

SO2 Emissions from EGU, Louisville Area, 1999 to 2009 

SO2 Emissions from EGUs, Louisville Area 1999 

State Facility SO2 Emissions, tons/year 

Indiana IKEC - Clifty Creek 

Power Plant 52,675.50 

Indiana Duke Energy Indiana – 

Gallagher Generating Station 49,876.50 

Kentucky Louisville Gas and Electric – 

Cane Run Station 17,877.40 

Kentucky Louisville Gas and Electric – 

Mill Creek Station 45,051.30 

Total 165,480.70 

SO2 Emissions from EGUs, Louisville Area 2000 

State Facility SO2 Emissions, tons/year 

Indiana IKEC- Clifty Creek 

Power Plant 42,678.20 

Indiana Duke Energy Indiana – 

Gallagher Generating Station 59,008.20 

Kentucky Louisville Gas and Electric – 

Cane Run Station 17,438.70 

Kentucky Louisville Gas and Electric – 

Mill Creek Station 34,502.30 

Total 153,627.40 

0

20,000

40,000

60,000

80,000

100,000

120,000

140,000

160,000

180,000

200,000

1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009

Tons per Year

Sulfur Dioxide Year
D-9

SO2 Emissions from EGUs, Louisville Area 2001 

State Facility SO2 Emissions, tons/year 

Indiana IKEC- Clifty Creek 

Power Plant 39,163.80 

Indiana Duke Energy Indiana – 

Gallagher Generating Station 47,511.20 

Kentucky Louisville Gas and Electric – 

Cane Run Station 16,120.50 

Kentucky Louisville Gas and Electric – 

Mill Creek Station 22,514.70 

Total 125,310.20 

SO2 Emissions from EGUs, Louisville Area 2002 

State Facility SO2 Emissions, tons/year 

Indiana IKEC- Clifty Creek 

Power Plant 38,197.50 

Indiana Duke Energy Indiana – 

Gallagher Generating Station 47,767.20 

Kentucky Louisville Gas and Electric – 

Cane Run Station 14,984.60 

Kentucky Louisville Gas and Electric – 

Mill Creek Station 22,568.70 

Total 123,518.00 

SO2 Emissions from EGUs, Louisville Area 2003 

State Facility SO2 Emissions, tons/year 

Indiana IKEC- Clifty Creek 

Power Plant 32,753.60 

Indiana Duke Energy Indiana – 

Gallagher Generating Station 53,340.80 

Kentucky Louisville Gas and Electric – 

Cane Run Station 16,294.00 

Kentucky Louisville Gas and Electric – 

Mill Creek Station 25,079.90 

Total 127,468.30 

 
D-10

SO2 Emissions from EGUs, Louisville Area 2004 

State Facility SO2 Emissions, tons/year 

Indiana IKEC- Clifty Creek 

Power Plant 53,136.00 

Indiana Duke Energy Indiana – 

Gallagher Generating Station 62,653.60 

Kentucky Louisville Gas and Electric – 

Cane Run Station 15,770.00 

Kentucky Louisville Gas and Electric – 

Mill Creek Station 25,692.80 

Total 157,252.40 

SO2 Emissions from EGUs, Louisville Area 2005 

State Facility SO2 Emissions, tons/year 

Indiana IKEC- Clifty Creek 

Power Plant 74,658.70 

Indiana Duke Energy Indiana – 

Gallagher Generating Station 56,666.70 

Kentucky Louisville Gas and Electric – 

Cane Run Station 18,861.70 

Kentucky Louisville Gas and Electric – 

Mill Creek Station 24,032.20 

Total 174,219.30 

SO2 Emissions from EGUs, Louisville Area 2006 

State Facility SO2 Emissions, tons/year 

Indiana IKEC- Clifty Creek 

Power Plant 65,371.80 

Indiana Duke Energy Indiana – 

Gallagher Generating Station 50,819.10 

Kentucky Louisville Gas and Electric – 

Cane Run Station 17,122.10 

Kentucky Louisville Gas and Electric – 

Mill Creek Station 25,464.40 

Total 158,777.40 

 
D-11

SO2 Emissions from EGUs, Louisville Area 2007 

State Facility SO2 Emissions, tons/year 

Indiana IKEC- Clifty Creek 

Power Plant 66,884.40 

Indiana Duke Energy Indiana – 

Gallagher Generating Station 59,992.10 

Kentucky Louisville Gas and Electric – 

Cane Run Station 14,878.50 

Kentucky Louisville Gas and Electric – 

Mill Creek Station 27,896.30 

Total 169,651.30 

SO2 Emissions from EGUs, Louisville Area 2008 

State Facility SO2 Emissions, tons/year 

Indiana IKEC- Clifty Creek 

Power Plant 64,934.30 

Indiana Duke Energy Indiana – 

Gallagher Generating Station 40,433.40 

Kentucky Louisville Gas and Electric – 

Cane Run Station 10,103.70 

Kentucky Louisville Gas and Electric – 

Mill Creek Station 28,583.20 

Total 144,054.60 

SO2 Emissions from EGUs, Louisville Area 2009 

State Facility SO2 Emissions, tons/year 

Indiana IKEC- Clifty Creek 

Power Plant 54,476.00 

Indiana Duke Energy Indiana – 

Gallagher Generating Station 26,902.50 

Kentucky Louisville Gas and Electric – 

Cane Run Station 8,792.10 

Kentucky Louisville Gas and Electric – 

Mill Creek Station 24,234.00 

Total 114,404.60 
APPENDIX E 

2005 and 2008 Base Year Emission Inventories 

and 2015 and 2025 Projected Emission Inventories 

for Nitrogen Oxides (NOx), Sulfur Dioxide (SO2), 

and Direct Fine Particles (PM2.5), Louisville Area 
This page left intentionally blank.
E-1 

2005-Clark, Floyd and Jefferson Counties, IN Totals, All Sources (Tons Per Year)

NOx

 ONROAD NONROAD AREA EGU POINT TOTAL 

CLARK COUNTY, IN 4,106.81 1,971.32 358.62 0.00 2,220.61 8,657.36 

FLOYD COUNTY, IN 2,922.90 754.09 286.78 5,306.09 0.19 9,270.05 

JEFFERSON COUNTY, IN 521.05 521.01 152.26 22,620.90 7.74 23,822.96 

7,550.76 3,246.42 797.66 27,926.99 2,228.54 

GRAND TOTAL 41,750.37 

SO2

 ONROAD NONROAD AREA EGU POINT TOTAL 

CLARK COUNTY, IN 20.72 178.06 138.17 0.00 3,190.07 3,527.02 

FLOYD COUNTY, IN 14.03 78.04 113.26 56,666.70 0.00 56,872.03 

JEFFERSON COUNTY, IN 2.10 49.44 73.19 74,658.70 0.11 74,783.54 

36.85 305.54 324.62 131,325.40 3,190.18 

GRAND TOTAL 135,182.59 

PM2.5

 ONROAD NONROAD AREA EGU POINT TOTAL 

CLARK COUNTY, IN 135.49 82.06 5.14 0.00 611.00 833.69 

FLOYD COUNTY, IN 99.63 47.26 4.63 36.76 12.02 200.30 

JEFFERSON COUNTY, IN 15.11 31.07 2.50 283.00 10.70 342.38 

250.23 160.39 12.27 319.76 633.72 

GRAND TOTAL 1,376.37 

2008-Clark, Floyd, and Jefferson Counties, IN Totals, All Sources (Tons Per Year)

NOx

 ONROAD NONROAD AREA EGU POINT TOTAL 

CLARK COUNTY, IN 3,444.07 1,519.07 364.36 0.00 2,419.41 7,746.91 

FLOYD COUNTY, IN 2,397.70 611.02 291.17 4,941.90 0.19 8,241.98 

JEFFERSON COUNTY, IN 403.83 423.14 155.62 20,546.70 7.88 21,537.17 

6,245.60 2,553.23 811.15 25,488.60 2,427.48 

GRAND TOTAL 37,526.06 

SO2

 ONROAD NONROAD AREA EGU POINT TOTAL 

CLARK COUNTY, IN 22.22 86.85 140.18 0.00 3,493.53 3,742.78 

FLOYD COUNTY, IN 14.58 33.26 114.69 40,433.40 0.00 40,595.93 

JEFFERSON COUNTY, IN 2.09 21.86 75.45 64,934.30 0.11 65,033.81 

38.89 141.97 330.32 105,367.70 3,493.64 

GRAND TOTAL 109,372.52 

PM2.5

 ONROAD NONROAD AREA EGU POINT TOTAL 

CLARK COUNTY, IN 117.07 66.05 5.17 0.00 520.25 708.54 

FLOYD COUNTY, IN 82.61 39.48 4.68 31.00 3.79 161.56 

JEFFERSON COUNTY, IN 11.23 25.88 2.52 284.50 8.24 332.37 

210.91 131.41 12.37 315.50 532.28 

GRAND TOTAL 1,202.47 

 
E-2

2015-Clark, Floyd, and Jefferson Counties, IN Totals, All Sources (Tons Per Year)

NOx

 ONROAD NONROAD AREA EGU POINT TOTAL 

CLARK COUNTY, IN 1,843.80 1,039.80 358.58 0.00 1,360.31 4,602.49 

FLOYD COUNTY, IN 1,306.71 379.02 286.61 2,744.00 0.20 4,716.54 

JEFFERSON COUNTY, IN 199.31 287.45 153.02 12,822.00 7.93 13,469.71 

3,349.82 1,706.27 798.21 15,566.00 1,368.44 

GRAND TOTAL 22,788.74 

SO2

 ONROAD NONROAD AREA EGU POINT TOTAL 

CLARK COUNTY, IN 22.83 25.82 135.94 0.00 1,349.85 1,534.44 

FLOYD COUNTY, IN 15.38 10.68 111.09 5,660.62 0.00 5,797.77 

JEFFERSON COUNTY, IN 1.97 5.37 73.37 27,203.00 0.11 27,283.82 

40.18 41.87 320.40 32,863.62 1,349.96 

GRAND TOTAL 34,616.03 

PM2.5

 ONROAD NONROAD AREA EGU POINT TOTAL 

CLARK COUNTY, IN 61.03 44.37 5.04 0.00 579.58 690.02 

FLOYD COUNTY, IN 43.67 26.01 4.59 28.00 1.02 103.29 

JEFFERSON COUNTY, IN 4.88 17.36 2.45 285.00 7.37 317.06 

109.58 87.74 12.08 313.00 587.97 

GRAND TOTAL 1,110.37 

2025-Clark, Floyd, and Jefferson Counties, IN Totals, All Sources (Tons Per Year)

NOx

 ONROAD NONROAD AREA EGU POINT TOTAL 

CLARK COUNTY, IN 975.12 558.76 354.47 0.00 561.03 2,449.38 

FLOYD COUNTY, IN 726.78 176.87 283.29 2,744.00 0.20 3,931.14 

JEFFERSON COUNTY, IN 109.90 155.39 151.57 12,822.00 8.06 13,246.92 

1,811.80 891.02 789.33 15,566.00 569.29 

GRAND TOTAL 19,627.44 

SO2

 ONROAD NONROAD AREA EGU POINT TOTAL 

CLARK COUNTY, IN 21.70 2.63 131.87 0.00 122.30 278.50 

FLOYD COUNTY, IN 15.30 1.62 107.49 5,660.62 0.00 5,785.03 

JEFFERSON COUNTY, IN 2.01 0.35 71.99 27,203.00 0.11 27,277.46 

39.01 4.60 311.35 32,863.62 122.41 

GRAND TOTAL 33,340.99 

PM2.5

 ONROAD NONROAD AREA EGU POINT TOTAL 

CLARK COUNTY, IN 34.92 23.57 4.90 0.00 613.01 676.40 

FLOYD COUNTY, IN 26.36 13.50 4.50 28.00 0.18 72.54 

JEFFERSON COUNTY, IN 2.65 9.27 2.37 285.00 5.77 305.06 

63.93 46.34 11.77 313.00 618.96 

GRAND TOTAL 1,054.00 
E-3

Comparison of 2008 Estimated and 2025 Projected Emission Estimates, All Sources 

in Clark, Floyd, and Jefferson Counties, Indiana (Tons per Year) 

2008 2025 Change % Change 

NOx 37,526.06 19,627.44 -17,898.62 47.70% decrease 

SO2 109,372.52 33,340.99 -76,031.53 69.52% decrease 

Direct PM2.5 1,202.47 1,054.00 -148.47 12.35% decrease 

Comparison of 2005, 2008, 2015, and 2025 Projected NOx Emissions, Clark, Floyd, 

and Jefferson Counties, Indiana 

 

0

10,000

20,000

30,000

40,000

50,000

60,000

2005 2008 2015 2025

Tons per Year

Nitrogen Oxides Year
E-4

Comparison of 2005, 2008, 2015, and 2025 Projected SO2 Emissions, Sources, Clark, 

Floyd, and Jefferson Counties, Indiana 

Comparison of 2005, 2008, 2015, and 2025 Projected Direct PM2.5 Emissions, Clark, 

Floyd, and Jefferson Counties, Indiana 

0

20,000

40,000

60,000

80,000

100,000

120,000

140,000

160,000

2005 2008 2015 2025

Tons per Year

Sulfur Dioxide Year

0

500

1,000

1,500

2,000

2005 2008 2015 2025

Tons per Year

Fine Particles Year
E-5

Comparison of 2005, 2008, 2015, and 2025 Projected NOx, SO2, and Direct PM2.5

Emissions, Clark, Floyd, and Jefferson Counties, Indiana 

 

0

20,000

40,000

60,000

80,000

100,000

120,000

140,000

160,000

2005 2008 2015 2025

Tons per Year

Nitrogen Oxides Sulfur Dioxide Fine Particles

Year
E-6

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E-7

2005-Louisville Area Totals, All Sources (Tons Per Year)

NOx

 ONROAD NONROAD AREA EGU POINT TOTAL 

CLARK COUNTY, IN 4,106.81 1,971.32 358.62 0.00 2,220.61 8,657.36 

FLOYD COUNTY, IN 2,922.90 754.09 286.78 5,306.09 0.19 9,270.05 

JEFFERSON COUNTY, IN 521.05 521.01 152.26 22,620.90 7.74 23,822.96 

BULLITT COUNTY, KY 2,952.07 533.69 53.48 0.00 204.61 3,743.85 

JEFFERSON COUNTY, KY 22,241.72 10,590.84 1,272.69 20,176.48 1,489.68 55,771.41 

32,744.55 14,370.95 2,123.83 48,103.47 3,922.83 

GRAND TOTAL 101,265.63 

SO2

 ONROAD NONROAD AREA EGU POINT TOTAL 

CLARK COUNTY, IN 20.72 178.06 138.17 0.00 3,190.07 3,527.02 

FLOYD COUNTY, IN 14.03 78.04 113.26 56,666.70 0.00 56,872.03 

JEFFERSON COUNTY, IN 2.10 49.44 73.19 74,658.70 0.11 74,783.54 

BULLITT COUNTY, KY 12.11 30.94 94.36 0.00 356.47 493.88 

JEFFERSON COUNTY, KY 95.26 714.33 0.00 42,852.96 1,894.40 45,556.95 

144.23 1,050.81 418.98 174,178.36 5,441.05 

GRAND TOTAL 181,233.43 

PM2.5

 ONROAD NONROAD AREA EGU POINT TOTAL 

CLARK COUNTY, IN 135.49 82.06 5.14 0.00 611.00 833.69 

FLOYD COUNTY, IN 99.63 47.26 4.63 36.76 12.02 200.30 

JEFFERSON COUNTY, IN 15.11 31.07 2.50 283.00 10.70 342.38 

BULLITT COUNTY, KY 84.08 40.62 247.16 0.00 53.35 425.21 

JEFFERSON COUNTY, KY 721.30 579.53 550.70 3,123.24 604.24 5,579.01 

1,055.61 780.54 810.13 3,443.00 1,291.31 

GRAND TOTAL 7,380.59 

2008-Louisville Area Totals, All Sources (Tons Per Year)

NOx

 ONROAD NONROAD AREA EGU POINT TOTAL 

CLARK COUNTY, IN 3,444.07 1,519.07 364.36 0.00 2,419.41 7,746.91 

FLOYD COUNTY, IN 2,397.70 611.02 291.17 4,941.90 0.19 8,241.98 

JEFFERSON COUNTY, IN 403.83 423.14 155.62 20,546.70 7.88 21,537.17 

BULLITT COUNTY, KY 2,820.80 448.45 55.99 0.00 215.12 3,540.37 

JEFFERSON COUNTY, KY 19,094.05 11,255.08 1,382.23 22,749.14 1,987.01 56,467.51 

28,160.45 14,256.76 2,249.37 48,237.74 4,629.61 

GRAND TOTAL 97,533.93 

SO2

 ONROAD NONROAD AREA EGU POINT TOTAL 

CLARK COUNTY, IN 22.22 86.85 140.18 0.00 3,493.53 3,742.78 

FLOYD COUNTY, IN 14.58 33.26 114.69 40,433.40 0.00 40,595.93 

JEFFERSON COUNTY, IN 2.09 21.86 75.45 64,934.30 0.11 65,033.81 

BULLITT COUNTY, KY 13.28 12.22 95.26 0.00 365.07 485.83 

JEFFERSON COUNTY, KY 101.00 778.68 0.00 38,684.02 2,080.95 41,644.65 

153.18 932.87 425.58 144,051.72 5,939.66 

GRAND TOTAL 151,503.01 

 
E-8

PM2.5

 ONROAD NONROAD AREA EGU POINT TOTAL 

CLARK COUNTY, IN 117.07 66.05 5.17 0.00 520.25 708.54 

FLOYD COUNTY, IN 82.61 39.48 4.68 31.00 3.79 161.56 

JEFFERSON COUNTY, IN 11.23 25.88 2.52 284.50 8.24 332.37 

BULLITT COUNTY, KY 85.40 37.44 247.15 0.00 54.13 424.12 

JEFFERSON COUNTY, KY 627.06 571.03 496.28 2,763.06 640.00 5,097.43 

923.37 739.88 755.80 3,078.56 1,226.41 

GRAND TOTAL 6,724.02 

2015-Louisville Area Totals, All Sources (Tons Per Year)

NOx

 ONROAD NONROAD AREA EGU POINT TOTAL 

CLARK COUNTY, IN 1,843.80 1,039.80 358.58 0.00 1,360.31 4,602.49 

FLOYD COUNTY, IN 1,306.71 379.02 286.61 2,744.00 0.20 4,716.54 

JEFFERSON COUNTY, IN 199.31 287.45 153.02 12,822.00 7.93 13,469.71 

BULLITT COUNTY, KY 1,782.71 317.56 62.25 0.00 240.71 2,403.23 

JEFFERSON COUNTY, KY 10,259.60 9,912.27 1,217.32 21,595.85 1,759.66 44,744.70 

15,392.13 11,936.10 2,077.78 37,161.85 3,368.81 

GRAND TOTAL 69,936.67 

SO2

 ONROAD NONROAD AREA EGU POINT TOTAL 

CLARK COUNTY, IN 22.83 25.82 135.94 0.00 1,349.85 1,534.44 

FLOYD COUNTY, IN 15.38 10.68 111.09 5,660.62 0.00 5,797.77 

JEFFERSON COUNTY, IN 1.97 5.37 73.37 27,203.00 0.11 27,283.82 

BULLITT COUNTY, KY 15.01 1.69 97.38 0.00 400.42 514.50 

JEFFERSON COUNTY, KY 102.55 960.48 0.00 38,684.02 2,080.95 41,828.00 

157.75 1,004.04 417.78 71,547.64 3,831.33 

GRAND TOTAL 76,958.54 

PM2.5

 ONROAD NONROAD AREA EGU POINT TOTAL 

CLARK COUNTY, IN 61.03 44.37 5.04 0.00 579.58 690.02 

FLOYD COUNTY, IN 43.67 26.01 4.59 28.00 1.02 103.29 

JEFFERSON COUNTY, IN 4.88 17.36 2.45 285.00 7.37 317.06 

BULLITT COUNTY, KY 55.96 26.11 247.11 0.00 57.84 387.02 

JEFFERSON COUNTY, KY 339.41 212.51 440.65 2,481.90 568.43 4,042.90 

504.95 326.36 699.84 2,794.90 1,214.24 

GRAND TOTAL 5,540.29 

2025-Louisville Area Totals, All Sources (Tons Per Year)

NOx

 ONROAD NONROAD AREA EGU POINT TOTAL 

CLARK COUNTY, IN 975.12 558.76 354.47 0.00 561.03 2,449.38 

FLOYD COUNTY, IN 726.78 176.87 283.29 2,744.00 0.20 3,931.14 

JEFFERSON COUNTY, IN 109.90 155.39 151.57 12,822.00 8.06 13,246.92 

BULLITT COUNTY, KY 948.69 202.15 72.30 0.00 281.93 1,505.07 

JEFFERSON COUNTY, KY 5,336.69 8,269.43 1,015.56 22,221.35 1,479.63 38,322.66 

8,097.18 9,362.60 1,877.19 37,787.35 2,330.85 

GRAND TOTAL 59,455.17 

 
E-9

SO2

 ONROAD NONROAD AREA EGU POINT TOTAL 

CLARK COUNTY, IN 21.70 2.63 131.87 0.00 122.30 278.50 

FLOYD COUNTY, IN 15.30 1.62 107.49 5,660.62 0.00 5,785.03 

JEFFERSON COUNTY, IN 2.01 0.35 71.99 27,203.00 0.11 27,277.46 

BULLITT COUNTY, KY 16.33 0.09 100.48 0.00 460.24 577.14 

JEFFERSON COUNTY, KY 101.81 1,297.16 0.00 38,684.02 2,080.95 42,163.94 

157.15 1,301.85 411.83 71,547.64 2,663.60 

GRAND TOTAL 76,082.07 

PM2.5

 ONROAD NONROAD AREA EGU POINT TOTAL 

CLARK COUNTY, IN 34.92 23.57 4.90 0.00 613.01 676.40 

FLOYD COUNTY, IN 26.36 13.50 4.50 28.00 0.18 72.54 

JEFFERSON COUNTY, IN 2.65 9.27 2.37 285.00 5.77 305.06 

BULLITT COUNTY, KY 29.89 14.74 247.06 0.00 64.03 355.71 

JEFFERSON COUNTY, KY 187.95 124.16 371.92 2,481.90 479.96 3,645.89 

281.77 185.24 630.75 2,794.90 1,162.95 

GRAND TOTAL 5,055.61 

Comparison of 2008 Estimated and 2025 Projected NOx, SO2, and Direct PM2.5

Emissions, Louisville Area (Tons per Year) 

 2008 2025 Change % Change 

NOx 97,533.93 59,455.17 -38,078.76 39.04% decrease 

SO2 151,503.01 76,082.07 -75,420.94 49.78% decrease 

Direct PM2.5 6,724.02 5,055.61 -1,668.41 24.81% decrease 

Comparison of 2005, 2008, 2015, and 2025 Projected NOx Emissions, Louisville Area 

0

20,000

40,000

60,000

80,000

100,000

120,000

2005 2008 2015 2025

Tons per Year

Nitrogen Oxides Year
E-10

Comparison of 2005, 2008, 2015, and 2025 Projected SO2 Emissions, Louisville Area 

Comparison of 2005, 2008, 2015, and 2025 Projected Direct PM2.5 Emissions, 

Louisville Area 

0

1,000

2,000

3,000

4,000

5,000

6,000

7,000

8,000

9,000

10,000

2005 2008 2015 2025

Tons per Year

Fine Particles Year

0

20,000

40,000

60,000

80,000

100,000

120,000

140,000

160,000

180,000

200,000

2005 2008 2015 2025

Tons per Year

Sulfur Dioxide Year
E-11

Comparison of 2005, 2008, 2015, and 2025 Projected NOx, SO2, and Direct PM2.5

Emissions, Louisville Area 

Year

0

20,000

40,000

60,000

80,000

100,000

120,000

140,000

160,000

180,000

200,000

2005 2008 2015 2025

Tons per Year

Nitrogen Oxides Sulfur Dioxide Fine Particles

Year
APPENDIXF

Example Mobile Source Input and Output

Calculation Files for the Louisville Area
This page left intentionally blank.
A complete copy of the MOVES modeling documentation: including input 

and output calculation files will be provided electronically upon request. 
APeD Technical Documentation for Using EPA Motor Vehicle Emission

Simulator (MOVES) 2010 to Develop Mobile Source Emissions

May 2011

KIPDA supplied Louisville Metro Air Pollution Control District (LMAPCD) VMT data for Jefferson

and Bullitt Counties, Kentucky, and Clark and Floyd Counties, Indiana, using its Travel Demand

Forecasting Model (TDFM). LMAPCD then input this data, along with other local data, into the

MOVES model to produce the data for development of the SIP Motor Vehicle Emission Budgets

(MVEB's). Emissions for the small area of Madison Township in Jefferson County, Indiana were

calculated separately with MOVES by INDOT and were included in the final emission totals.

KIPDA TRAVEL DEMAND MODEL

The KIPDA travel demand model is a mathematical model which relates travel to the

transportation system and basic socioeconomic information. The domain of the model is a study

area which includes the Louisville (KY-IN) Metropolitan Planning Area. The Louisville (KY-IN)

Metropolitan Planning Area consists of Clark and Floyd counties, and 0.1 square miles in

Harrison County, IN, and Bullitt, Jefferson, and Oldham counties, KY. This area is divided into

807 smaller units called traffic analysis zones.

SIP MVEB development was initiated in January, 2010. As of that date, the KIPDA regional

travel demand model had been last updated and calibrated during 2005. This update

established 2000 as the new base year for the model. The model update utilized the information

incorporated into the travel model during previous updates, in particular, information from the

2000 Census and the 2000 KIPDA Household Travel Survey. During the update, the model

parameters were adjusted such that the model output matched within reason, three main

calibration criteria based on measured data. These criteria were: (1) daily VMT for all highway

facilities except local roads for the region; (2) the distribution of trip lengths (duration in time);

and (3) highway traffic volumes crossing the Ohio River screen-line. The result of the update

was a travel model that replicated travel in the Louisville area for 2000. The subsequent 2011

update and calibration of the TDFM (setting 2007 as a base year) was initiated after work for the

PM2.5 Redesignation SIP had begun and, therefore, could not be incorporated into the MOVES

model runs.

The KIPDA travel demand model uses the standard four steps of modeling: trip generation, trip

distribution, mode choice, and trip assignment. In addition, it considers travel by vehicles

entering, leaving, and crossing the study area. These types of trips are known as externalinternal, internal-external, and external-external, respectively. The internal ends of these trips

are determined by the methods described below for internal-internal travel. The external ends

are determined from the volume of traffic crossing the study area boundary at any of the 48

external stations.

Trip generation is the process of determining the number of unlinked trip ends - called

productions and attractions - and their spatial distribution based on socioeconomic variables

such as households and employment. Trip rates used to define these relationships were derived

from the travel data collection efforts described above. This information was supplemented by.

use of the National Cooperative Highway Research Program Report #365 and the Institute of

1
Transportation Engineers' Trip Generation Report. The KIPDA travel demand model uses three

internal-internal trip purposes and uses different trip rates for each. Internal-internal trips are

those that have both ends inside the modeling domain. The three purposes are home-based

work, home-based other, and non home-based. Trip distribution is the process of linking the trip

ends thereby creating trips that traverse the area.

The KIPDA travel model uses a gravity model to link all trips except the external-external ones.

The gravity model is based on the principle that productions are linked to attractions as a direct

function of the number of attractions of a zone and as an inverse function of the travel time

between zones. This inverse function of travel time is used to generate parameters called

friction factors that, in turn, direct the gravity model. The friction factors used in the gravity model

were developed as part of the calibration effort performed during the model update.

Mode choice is the process used to separate the trips that use transit from those which use

automobiles. It is also used to separate the auto drive-alone trips from auto shared-ride trips. In

some previous KIPDA travel demand models, mode choice was based primarily on information

provided by the TARC Travel Forecasting Study. In that model, the user's benefit or utility was

calculated for each mode based on zonal socioeconomic characteristics and the cost and time

of the trip using the various modes. A·nested Logit model was used to determine the probability

of the trip being made by each of the modes. This probability was then multiplied by the number

of trips between zones to determine the number of trips by each mode.

For transit data the results of the 2004 TARe on-board survey was used to supplement the

previous information. This was deemed acceptable for several reasons. The primary reason was

that the transit network envisioned by Horizon 2030 is essentially the same as the existing one.

In addition, the number of total trips from the two models was similar. Therefore, the use of the

transit trip information from previous travel models did not change significantly the proportion of

trips allocated to transit. Finally, the proportion of trips utilizing transit is less than 2% of the total

trips. So small differences in the number of transit trips should provide a negligible effect on

overall travel.

Trip assignment is the process used to determine which links of the network a trip will use.

Several assignment schemes may be used. Two of the more common schemes are AII-orNothing (AON)--in which all trips between two zones follow the shortest time path--and

Stochastic--in which trips between two zones may be assigned to several paths based on their

impedances or travel times. It is not uncommon for travel models to use several assignment

schemes in sequence to converge to a better assignment. A sequence commonly used involves

using several AONs with the traffic volumes reported at the end of each scheme being a

weighted average of the volumes from the most recent scheme and the volumes from the

previous schemes. A capacity restraint provision is used to adjust travel times between

assignment schemes. This sequence is called an equilibrium assignment. The KIPDA travel

model uses an equilibrium assignment which converges when the change in system-wide travel

time over successive iterations is estimated to be within 0.1 percent of the minimum (optimal)

value or less.

The output from the KIPDA travel model is in the form of a series of links with each link having

certain associated data such as number of lanes, capacity, facility type, area type, functional

class, and volume. This data allows for the calculgtion of other link information such as VMT.

2
The VMT can be calculated as the product of the volume of traffic using a link times the distance

of the link.

Adjustment Factors for Travel Model Output

The VMT and speeds from the travel demand model were adjusted before being used in the

calculation of regional emissions. The purpose of these adjustments was to reconcile the model

output with travel estimates from other sources, such as the Highway Performance Monitoring

System (HPMS) estimates of VMT. To perform this adjustment, factors were developed for the

year of the HPMS or other estimates and applied to model output for other years.

The outputs of the travel demand model were compared to estimates of speed based on: (1) the

equations of the Highway Economic Reporting System (HERS) and (2) the use of data from the

Automatic Continuous Traffic Recorders (ATRs) of the Kentucky Transportation Cabinet

(KYTC). The HERS equations were used to estimate speeds on 402 sections of urban

roadways for five functional classifications. The speeds from these roadway sections were used

to determine the average speed for each of five functional classes. The speeds used in the

travel model were also averaged for each urban functional class. The speed adjustment factor

for each urban functional class was calculated as the ratio of the average speed using the

HERS equations to the average speed using the travel model data.

The KYTC ATR data was used to estimate speeds on 84 sections of rural roadways for four

functional classifications. The speeds from these roadway sections were used to determine the

average speed for each of four functional classes. The speeds used in the travel model were

also averaged for each rural functional class. The speed adjustment factor for each rural

functional class was calculated as the ratio of the average speed using the ATR data to the·

average speed using the travel model data.

The procedures described above produced speed adjustment factors for all functional classes

except rural minor collectors and rural and urban local roads and ramps. (Ramps are not '

officially a separate functional class, but the speed behavior of traffic on ramps is not expected

to be like that of any other functional class. Therefore, the ramps were treated as a separate

"functional class.") There was not sufficient data to estimate speeds for the roadways of these

classes. For the rural minor collectors and rural and local roads, the speed adjustment factor of

the next higher functional class was used. For ramps, the speeds in the travel model were used

without adjustment (Le. the speed adjustment factor for ramps =1).

MOVES

The following table (Table 1) summarizes the MOVES specifications for the runs used to

produce data for the four Louisville Metro area counties to develop SIP PM2.5 MVEB's. VMT

data for the runs was supplied by KIPDA's TDFM. The summary reflects the format of the

MOVES input panels, in addition to the 13 input files that the County Database Manager (CDM)

requires. A complete collection the CDM local input files, as well as the specification files, input

databases, and output databases is included separately, along with sample MySQL script and a

linked excel workbook. The file Documentation main.docx lists the contents of the folders.

MOVES was run in the inventory mode ("calculation type" in the "Scale" input panel) in order to

provide the quickest and most accurate emission totals, given the data development schedule

requirements.

3
MOVES RunSpecs: PM2.5 Redesignation SIP MVEB data; Louisville, KY PM2.5 Area

ACPD - cb 4/12/11

MOVES RunSpec Parameter Settings I Assumptions

MOVES Version 2010a, MOVES default database 20100830

Meteorology

Vehicle VMT

All 12 months were input, representing (historical) average annual

temperatures and humidity for each month. Local temperature and

humidity data was collected from NOAA weather stations in Louisville

by APCD. Hourly distributions were then propagated using the EPA

MOBILE6-MOVES conversion workbook customized by APCD, and used

for all four counties.

Floyd), 2 Kentucky counties (Bullitt,

each,analysis year. Th

ale

Vehicle VMT was derived from earlier MOBILE6 modeling work, which

used MOBILE6 default mileage accumulation rates and FHWA 1997

VMT. Fleet VMT mixes in MOBILE6 input format were then converted

using the EPA MOBILE6-MOVES converter workbooks, customized by

APCD.

4
Specific to each county from KIPDA supplied data.

Table 1: MOVES input summary

LMAPCD executed the MOVES runs to produce the onroad emissions data, and also postprocessed the data to calculate the emission totals by county. Totals were calculated by using

MSExcel workbooks that were linked to exported Excel files produced with the MySOL browser

- part of the MOVES 2010a installation suite of programs - which operated on SOL MOVES

output databases created for each run. Inputs were formatted for the MOVES CDM by making

use of the EPA conversion workbooks, customized by APCD for easier 'cut and paste'

transference. Only VMT input data was supplied by KIPDA's TDFM (and converted from

MOBILE6 format to MOVES CDM input records). LMAPCD maintains a 'suite' of data with the

most recent local data for its APeD Mobile Suite. This was used as a source for the MOVES

runs required for the MVEB data (Mobile Suite version g6). For the Indiana Counties (Clark and

Floyd) two sets of runs were made to provide data using both the older '2004' Indiana fleet data

. (actually 2002 fleet data, updated in 2004), and the new, but as yet not quality assured 2009

Indiana fleet data. To date, the older (2002) Indiana fleet data was used in development of the

SIP MVEB's.

5

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 

8 
Area Source Inventory 

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. 

9 
Area Source Inventory 

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

 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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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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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: 

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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. 

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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 (LADCO) 

Emission Estimates Technical Support Document 
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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” 

Emission 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 

Modeling Summary 

 PM2.5 Design Value Trends 

 Regional/Emission Sector Particulate Source 

Apportionment Technology (PSAT) Test Results, 

Jeffersonville, Indiana – Walnut Street PM2.5 

Monitor 

 Speciated Contributions to PM2.5 Concentrations, 

Louisville Area 

 Distribution of PM2.5 Concentration Days using Air 

Quality Index (AQI) Levels 
This page left intentionally blank.
J-1 

PM2.5 Design Value Trends for the Louisville Area, 1999 to 2010 

12.00

13.00

14.00

15.00

16.00

17.00

18.00

1999‐2003 2000‐2004 2001‐2005 2002‐2006 2003‐2007 2004‐2008 2005‐2009 2006‐2010

Concentrations(ug/m3)

Design Value Years

Jeffersonville ‐ Walnut St. Charlestown State Park New Albany

Shepherdsville Southern Avenue Wyandotte Park

Barret Avenue/Cannon Lane Watson Elementary Annual NAAQS
J-2

Regional/Emission Sector Particulate Source Apportionment Technology (PSAT) Test 

Results, Jeffersonville, Indiana – Walnut Street PM2.5 Monitor 

 
J-3

Modeled Contribution by Species at the Jeffersonville, Indiana 

Walnut Street PM 2.5 Monitor 

 

so4

33%

no3

7%

oc

26%

ec

4%

soil

3%

nh4

13%

pbw

11%

blan

3%

Observed 2005 Contributions at the Jeffersonville PM2.5 Monitor

so4

no3

oc

ec

soil

nh4

pbw

blan

so4

27%

no3

9%

oc

31%

ec

4%

soil

4%

nh4

12%

pbw

9%

blan

4%

2009 Modeled Contributions at the Jeffersonville PM2.5 Monitor

so4

no3

oc

ec

soil

nh4

pbw

blan
J-4

Modeled Contribution by Species at the New Albany, Indiana PM2.5 Monitor 

 

so4

35%

no3

7%

oc

23%

ec

4%

soil

4%

nh4

13%

pbw

11%

blan

3%

Observed 2005 Contributions at the New Albany PM2.5 Monitor

so4

no3

oc

ec

soil

nh4

pbw

blan

so4

29%

no3

8%

oc

28%

ec

4%

soil

5%

nh4

12%

pbw

10%

blan

4%

2009 Modeled Contributions at the New Albany PM2.5 Monitor

so4

no3

oc

ec

soil

nh4

pbw

blan
J-5

Modeled Contribution by Species at the Carpenter Street – Shepherdsville, Kentucky 

PM2.5 Monitor 

 

so4

35%

no3

7%

oc

24%

ec

4%

soil

3%

nh4

13%

pbw

11%

blan

3%

Observed 2005 Contributions at the Shepherdsville PM2.5 Monitor

so4

no3

oc

ec

soil

nh4

pbw

blan

so4

28%

no3

8%

oc

29%

ec

5%

soil

6%

nh4

11%

pbw

9%

blan

4%

2009 Modeled Contributions at the Shepherdsville PM2.5 Monitor

so4

no3

oc

ec

soil

nh4

pbw

blan
J-6

Modeled Contribution by Species at the Elizabethtown, Kentucky 

PM2.5 Monitor 

 

so4

35%

no3

7%

oc

24%

ec

4%

soil

3%

nh4

12%

pbw

11%

blan

4%

Observed 2005 Contributions at the Elizabethtown PM2.5 Monitor

so4

no3

oc

ec

soil

nh4

pbw

blan

so4

29%

no3

8%

oc

29%

ec

4%

soil

5%

nh4

12%

pbw

9%

blan

4%

2009 Modeled Contributions at the Elizabethtown PM2.5 Monitor

so4

no3

oc

ec

soil

nh4

pbw

blan
J-7

Modeled Contribution by Species at the Southern Avenue – Louisville, 

Kentucky PM2.5 Monitor 

so4

35%

no3

7%

oc

24%

ec

4%

soil

3%

nh4

13%

pbw

11%

blan

3%

Observed 2005 Contributions at the Southern Avenue PM2.5

Monitor

so4

no3

oc

ec

soil

nh4

pbw

blan

so4

29%

no3

8%

oc

28%

ec

5%

soil

5%

nh4

12%

pbw

9%

blan

4%

2009 Modeled Contributions at the Southern Avenue PM2.5 Monitor

so4

no3

oc

ec

soil

nh4

pbw

blan
J-8

Modeled Contribution by Species at the Wyandotte Park – Louisville, 

Kentucky PM2.5 Monitor 

so4

34%

no3

7%

oc

25%

ec

4%

soil

3%

nh4

13%

pbw

11%

blan

3%

Observed 2005 Contributions at the Wyandotte Park PM2.5 Monitor

so4

no3

oc

ec

soil

nh4

pbw

blan

so4

28%

no3

8%

oc

29%

ec

5%

soil

5%

nh4

12%

pbw

9%

blan

4%

2009 Modeled Contributions at the Wyandotte Park PM2.5 Monitor

so4

no3

oc

ec

soil

nh4

pbw

blan
J-9

Modeled Contribution by Species at the Barret Avenue – 

Louisville, Kentucky PM2.5 Monitor 

so4

34%

no3

7%

oc

25%

ec

4%

soil

3%

nh4

13%

pbw

11%

blan

3%

Observed 2005 Contributions at the Barret Avenue PM2.5 Monitor

so4

no3

oc

ec

soil

nh4

pbw

blan

so4

28%

no3

8%

oc

29%

ec

5%

soil

5%

nh4

12%

pbw

9%

blan

4%

2009 Modeled Contributions at the Barret Avenue PM2.5 Monitor

so4

no3

oc

ec

soil

nh4

pbw

blan
J-10

Modeled Contribution by Species at the Watson Elementary – 

Louisville, Kentucky PM2.5 Monitor 

so4

35%

no3

7%

oc

23%

ec

4%

soil

4%

nh4

13%

pbw

11%

blan

3%

Observed 2005 Contributions at the Watson Elementary PM2.5

Monitor

so4

no3

oc

ec

soil

nh4

pbw

blan

so4

29%

no3

9%

oc

28%

ec

4%

soil

5%

nh4

12%

pbw

9%

blan

4%

2009 Modeled Concentrations at the Watson Elementary PM2.5

Monitor

so4

no3

oc

ec

soil

nh4

pbw

blan
J-11

Distribution of PM2.5 Concentration Days on the AQI Levels of Health Concern for the 

Louisville Area 

0%

10%

20%

30%

40%

50%

60%

70%

80%

90%

100%

2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010

Percentage of Days

Year

Good Moderate USG