# 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 Indi ana’s Portion of the Louisville Area

SITE ID COUNTY SITE NAME YEAR Annual Average μg/m 3 2008-2010 Average μg/m 3

18-019-0006 Clark Jeffersonville – Walnut Street 2008 14.48 14.1 2009 13.01 2010 14.67

18-019-0008 Clark Charlestown State Park 2008 13.44 12.2 2009 10.84 2010 12.45

18-089-2004 Floyd New Albany 2008 12.70 12.8 2009 11.91 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 18.48 E 14.91 E 16.43 E 14.48 13.01 14.67

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

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 16.69 E 13.32 E 14.66 E 12.70 11.91 13.80

* Combined-- These two sites are considered to measure the same ai r mass, thus the data are combined for the purpose of the Des ign Value calculations

E Exceptional event data re moved from ca lculations.

The Jeffersonville – Spring Street monitor was replaced by the Jeffersonville – Wal nut 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 sta ndard 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 Valu e Based on One Year of Data

Green Text Indicates Design Valu e Based on Two Years of Data

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

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



### Annual Fine Particle Trends for Indi ana’s Portion of the Louisville Area, 2006 through 2010

Red line represents the annual sta ndard for fine particles of 15.0 ug/m 3

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 2010ug/m3

Jeffersonville ‐ Walnut Street Charlestown State Park New Albany Year

### A-3 Fine Particle Design Values for Indi ana’s Portion of the Louisville Area, 2006 through 2010

Red line represents the annual sta ndard for fine particles of 15 μg/m 3

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

‐ 2010ug/m3

Jeffersonville ‐ Walnut Street Charlestown State Park New Albany

### A-4 

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### A-5 

# Monitoring Data for Kent ucky’s Portion of the Louisville Area

SITE ID COUNTY SITE NAME YEAR Annual Average μg/m 3 2008-2010 Average μg/m 3

21-029-0006 Bullitt Shepherdsville 2008 12.84 12.70 2009 11.81 2010 13.45

21-111-0043 Jefferson Southern Avenue 2008 13.17 12.95 2009 12.21 2010 13.47

21-111-0044 Jefferson Wyandotte Park 2008 13.41 13.20 2009 12.45 2010 13.74

21-111-0048 Jefferson Barret Avenue 2008 13.44 13.44 2009 N/A 2010 N/A

21-111-0051 Jefferson Watson Elementary 2008 12.78 13.07 2009 11.59 2010 14.83

21-111-0067 Jefferson Cannons Lane 2008 N/A 12.47 2009 11.67 2010 13.27

Blue Text Indicates Design Valu e Based on One Year of Data

Green Text Indicates Design Valu e Based on Two Years of Data

The Barrett Avenue monitor discon tinued operation on December 31, 2008.

The Cannons Lane monitor bega n 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 disconti nued operation on December 31, 2008.

The Cannons Lane monitor bega n 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 standa rd for fine particles.

Blue Text Indicates Design Valu e Based on One Year of Data

Green Text Indicates Design Valu e Based on Two Years of Data

The Barrett Avenue monitor disconti nued operation on December 31, 2008.

The Cannons Lane monitor bega n operation on January 1, 2009.



### Annual Fine Particle Trends for Kentuc ky’s Portion of the Louisville Area, 2006 through 2010

Red line represents the annual st andard for fine particles of 15 μg/m 3

The Barrett Avenue monitor disconti nued operation on December 31, 2008.

The Cannons Lane monitor bega n operation on January 1, 2009. 8.0 10.0 12.0 14.0 16.0 18.0

2006 2007 2008 2009 2010ug/m3

Shepherdsville Southern Avenue Wyandotte Park

Barret Avenue Watson Elementary Cannons Lane Year

### A-7 Fine Particle Design Values for Kent ucky’s Portion of the Louisville Area, 2006 through 2010

Red line represents the annual standard for fine particles of 15 μg/m 3

The Barrett Avenue monitor disconti nued operation on December 31, 2008.

The Cannons Lane monitor bega n 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

‐ 0067ug/m3

2006

‐ 2008 2007

‐ 2009 2008

‐ 2010

# APPENDIX B

Nitrogen Oxides (NO x 

# ), Sulfur Dioxide (SO 2 

# ), and Direct Fine Particle (PM 2.5 

# ) 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 NO x 

### SO 2 

### Direct PM 2.5 

### 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- NO x 

### NONEGUNO x 

### EGU-SO 2 

### NONEGU-SO 2 

### EGUDirect PM 2.5 

### NONEGUDirect PM 2.5 

### 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 NO x 

### SO 2 

### Direct PM 2.5 

### 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- NO x 

### NONEGUNO x 

### EGU-SO 2 

### NONEGU-SO 2 

### EGUDirect PM 2.5 

### NONEGUDirect PM 2.5 

### 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 NO x 

### SO 2 

### Direct PM 2.5 

### Grand Total 27,916.08 108,861.34 847.78

### B-2 NO x 

### Point Source Emissions Trend, Clark, Floyd, and Jefferson Counties, Indiana, 2005 and 2008

SO 2 

### 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 2008TonsperYear

Sulfur Dioxide Year 0 5,000 10,000 15,000 20,000 25,000 30,000 35,000 40,000

2005 2008TonsperYear

Nitrogen Oxides Year

### B-3 Direct PM 2.5 

### 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 2008TonsperYear

Fine Particles Year

### B-4 

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### B-5 Louisville Area Point Source Totals (Tons per Year) Year NO x 

### SO 2 

### Direct PM 2.5 

### 2005 52,026.30 179,619.41 4,734.31 2008 52,867.35 149,991.38 4,304.97

2005-Louisville Area Point Sou rce Emissions (Tons per Year)
County EGU NO x 

### NONEGU- NO x 

### EGU SO 2 

### NONEGU-SO 2 

### EGUDirect PM 2.5 

### NON-EGUDirect PM 2.5 

### 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 NO x 

### SO 2 

### Direct PM 2.5 

### Grand Total 52,026.30 179,619.41 4,734.31

2008-Louisville Area Point Sou rce Emissions (Tons per Year)

County EGU NO x 

### NONEGU- NO x 

### EGU SO 2 

### NONEGU-SO 2 

### EGUDirect PM 2.5 

### NON-EGUDirect PM 2.5 

### 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 NO x 

### SO 2 

### Direct PM 2.5 

### Grand Total 52,867.35 149,991.38 4,304.97

### B-6 NO x 

### Point Source Emissions Tren d, Louisville Area, 2005 and 2008

SO 2 

### Point Source Emissions Tre nd, Louisville Area, 2005 and 2008

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

2005 2008TonsperYear

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 2008TonsperYear

Sulfur Dioxide Year

### B-7 Direct PM 2.5 

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

0 1,000 2,000 3,000 4,000 5,000 6,000

2005 2008TonsperYear

Fine Particles Year

# APPENDIX C

Nitrogen Oxides (NO x 

# ), Sulfur Dioxide (SO 2 

# ), and Direct Fine Particle (PM 2.5 

# ) 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 NO x 

### SO 2 

### Direct PM 2.5 

### 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 Count ies, IN Totals (Tons per Year) AREA NONROAD ONROAD POINT GRAND TOTAL NO X 

### 797.66 3,246.42 7,550.76 30,155.53 41,750.37 SO 2 

### 324.62 305.54 36.85 134,515.58 135,182.59 Direct PM 2.5 

### 12.27 160.39 250.23 953.48 1,376.37

2005-Clark, Floyd and Jefferson Count ies, IN Totals (Tons per Year) COUNTY STATE SECTOR NO X 

### SO 2 

### Direct PM 2.5



### 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 Count ies, IN Totals (Tons per Year) AREA NONROAD ONROAD POINT GRAND TOTAL NO X 

### 811.15 2,553.23 6,245.60 27,916.08 37,526.06 SO 2 

### 330.32 141.97 38.89 108,861.34 109,372.52 Direct PM 2.5 

### 12.37 131.41 210.91 847.78 1,202.47

### C-2 2008-Clark, Floyd and Jefferson Count ies, IN Totals (Tons per Year) COUNTY STATE SECTOR NO X 

### SO 2 

### Direct PM 2.5



### 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



### NO x 

### 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 2008TonsperYear

Nitrogen Oxides Year

### C-3 SO 2 

### Emission Trends, All Sources, Clark, Floyd, and Jefferson Counties, Indiana, 2005 and 2008

Direct PM 2.5 

### Emission Trends, All Sources, Clar k, 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 2008TonsperYear

Sulfur Dioxide Year

0 500 1,000 1,500 2,000

2005 2008TonsperYear

Fine Particles Year

### C-4 

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### C-5 Louisville Area Totals (Tons per Year) Year NO x 

### SO 2 

### Direct PM 2.5 

### 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 NO X 

### 2,123.83 14,370.95 32,744.55 52,026.30 101,265.63 SO 2 

### 418.98 1,050.81 144.23 179,619.41 181,233.43 Direct PM 2.5 

### 810.13 780.54 1,055.61 4,734.31 7,380.59

2005-Louisville Area Totals (Tons per Year) COUNTY STATE SECTOR NO X 

### SO 2 

### Direct PM 2.5



### 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 NO X 

### 2,249.37 14,256.76 28,160.45 52,867.35 97,533.93 SO 2 

### 425.58 932.87 153.18 149,991.38 151,503.01 Direct PM 2.5 

### 755.80 739.88 923.37 4,304.97 6,724.02

### C-6 2008-Louisville Area Totals (Tons per Year) COUNTY STATE SECTOR NO X 

### SO 2 

### Direct PM 2.5



### 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

NO x 

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

0 20,000 40,000 60,000 80,000 100,000 120,000

2005 2008TonsperYear

Nitrogen Oxides Year

### C-7 SO 2 

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

Direct PM 2.5 

### 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 2008TonsperYear

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 2008TonsperYear

Fine Particles Year

# APPENDIX D

Nitrogen Oxides (NO x 

# ) and Sulfur Dioxide (SO 2 

# ) Emission Trends from Electric Generating Units (EGUs), Louisville Area (1999 through 2009)

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### D-1 Trends in EGU NO x 

### Emissions, Floyd and Jefferson Counties, Indiana

NO x 

### Emissions from EGUs, Floyd and Jefferson Counties, Indiana, 1999 to 2009 Year Total NO x 

### 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 2009TonsperYear

Nitrogen Oxides Year

### D-2 Trends in EGU NO x 

### Emissions, Louisville Area

NO x 

### Emissions from EGUs Louisville Area, 1999 to 2009 Year Total NO x 

### 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 2009TonsperYear

Nitrogen Oxides Year

### D-3 NOx Emissions from EGUs, Louisville Area 1999 State Facility NO x 

### 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 NO x 

### 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 NO x 

### 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 NO x 

### 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 NO x 

### 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 NO x 

### 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 NO x 

### 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 NO x 

### 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 NO x 

### 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 NO x 

### 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 NO x 

### 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 SO 2 

### Emissions, Floyd and Jefferson Counties, Indiana

Year Total SO 2 

### 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 SO 2 

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

Trends in EGU SO 2 

### Emissions, Louisville Area

Year Total SO 2 

### 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 2009TonsperYear

Sulfur Dioxide Year

### D-8 SO 2 

### Emissions from EGU, Louisville Area, 1999 to 2009

SO 2 

### Emissions from EGUs, Louisville Area 1999 State Facility SO 2 

### 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

SO 2 

### Emissions from EGUs, Louisville Area 2000 State Facility SO 2 

### 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 2009TonsperYear

Sulfur Dioxide Year

### D-9 SO 2 

### Emissions from EGUs, Louisville Area 2001 State Facility SO 2 

### 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

SO 2 

### Emissions from EGUs, Louisville Area 2002 State Facility SO 2 

### 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

SO 2 

### Emissions from EGUs, Louisville Area 2003 State Facility SO 2 

### 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 SO 2 

### Emissions from EGUs, Louisville Area 2004 State Facility SO 2 

### 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

SO 2 

### Emissions from EGUs, Louisville Area 2005 State Facility SO 2 

### 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

SO 2 

### Emissions from EGUs, Louisville Area 2006 State Facility SO 2 

### 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 SO 2 

### Emissions from EGUs, Louisville Area 2007 State Facility SO 2 

### 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

SO 2 

### Emissions from EGUs, Louisville Area 2008 State Facility SO 2 

### 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

SO 2 

### Emissions from EGUs, Louisville Area 2009 State Facility SO 2 

### 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 (NO x 

# ), Sulfur Dioxide (SO 2 

# ), and Direct Fine Particles (PM 2.5 

# ), Louisville Area

## This page left intentionally blank.

### E-1 2005-Clark, Floyd and Jefferson Counties, IN Totals, All Sources (Tons Per Year)

NO x 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

SO 2 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

PM 2.5 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)

NO x 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

SO 2 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

PM 2.5 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)

NO x 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

SO 2 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

PM 2.5 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)

NO x 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

SO 2 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

PM 2.5 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 Project ed Emission Estimates, All Sources in Clark, Floyd, and Jefferson Counties, Indiana (Tons per Year)

2008 2025 Change % Change NO x 

### 37,526.06 19,627.44 -17,898.62 47.70% decrease SO 2 

### 109,372.52 33,340.99 -76,031.53 69.52% decrease Direct PM 2.5 

### 1,202.47 1,054.00 -148.47 12.35% decrease



### Comparison of 2005, 2008, 2015, and 2025 Projected NO x 

### Emissions, Clark, Floyd, and Jefferson Counties, Indiana

0 10,000 20,000 30,000 40,000 50,000 60,000

2005 2008 2015 2025TonsperYear

Nitrogen Oxides Year

### E-4 Comparison of 2005, 2008, 2015, and 2025 Projected SO 2 

### Emissions, Sources, Clark, Floyd, and Jefferson Counties, Indiana

Comparison of 2005, 2008, 2015, and 2025 Projected Direct PM 2.5 

### 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 2025TonsperYear

Sulfur Dioxide Year

0 500 1,000 1,500 2,000

2005 2008 2015 2025TonsperYear

Fine Particles Year

### E-5 Comparison of 2005, 2008, 2015, and 2025 Projected NO x 

### , SO 2 

### , and Direct PM 2.5 

### Emissions, Clark, Floyd, a nd Jefferson Counties, Indiana

0 20,000 40,000 60,000 80,000 100,000 120,000 140,000 160,000

2005 2008 2015 2025TonsperYear

Nitrogen Oxides Sulfur Dioxide Fine Particles Year

### E-6 

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### E-7 2005-Louisville Area Totals, All Sources (Tons Per Year)

NO x 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

SO 2 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

PM 2.5 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)

NO x 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

SO 2 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 PM 2.5 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)

NO x 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

SO 2 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

PM 2.5 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)

NO x 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 SO 2 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

PM 2.5 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 NO x 

### , SO 2 

### , and Direct PM 2.5 

### Emissions, Louisville Area (Tons per Year)

2008 2025 Change % Change

NO x 

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

SO 2 

### 151,503.01 76,082.07 -75,42 0.94 49.78% decrease

Direct PM 2.5 

### 6,724.02 5,055.61 -1,668.41 24.81% decrease



### Comparison of 2005, 2008, 2015, and 2025 Projected NO x 

### Emissions, Louisville Area

0 20,000 40,000 60,000 80,000 100,000 120,000

2005 2008 2015 2025TonsperYear

Nitrogen Oxides Year

### E-10 Comparison of 2005, 2008, 2015, and 2025 Projected SO 2 

### Emissions, Louisville Area

Comparison of 2005, 2008, 2015, and 2025 Projected Direct PM 2.5 

### 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 2025TonsperYear

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 2025TonsperYear

Sulfur Dioxide Year

### E-11 Comparison of 2005, 2008, 2015, and 2025 Projected NO x 

### , SO 2 

### , and Direct PM 2.5 

### 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 2025TonsperYear

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 mo deling 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 PM 2

. 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.



### 4Specific 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 ev ery three years as mandated by EPA.

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



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


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

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

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

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

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



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



### 2. Definitions

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

.

Area Sources

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

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

EIIP (Emission Inventory Improvement Program) - The EIIP is an EPA program established in 1993 to promote the development and use of standard procedures for collecting, calculati ng, 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 O ffice of Management and Budget (OMB) to classify establishments according to the type of economic activity in which they engage.

Source Classification Code (SCC)

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

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



### 3. Roles

Title # of Staff Experience Qualifications Location

Senior Environmental Manager 1 N/A MS ACCESS, Emission Inventories and familiarity 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 us ed 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 source s are calculated at the county level and consist of individual sources that are small, numerous and that have not been inventoried as specific point, mobile, or biogenic sources according to the EIIP.

YES

NO Identify Categories Is the categor y an Area Source?

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

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

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

5.2 Procedure 

### Category 1: Stationary Fuel Combustion

Sub-Category 1.1: Industrial Fuel Combustion

SCC: 2102002000, 210200400, 2102005000, 2102006000, 2102007000

Follow these steps when calculating emissions from industrial fuel combustion:

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

Note: As of the date of this SOP, the followin g 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 comb ustions, subtract reported source totals from the total statewide fuel consumption by querying the to tal process rates for the various SCC codes using the ACCESS data tables at K:\OAQ_INV\Steptool\Stp tl_02.mdb. The remaining number is the area source fuel consumpt ion for the state.

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

Note: As of the date of this SOP, the followin g 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 manuf acturing under the paid employees’ column

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

. Sub-Category 1.2: Commercial/ Institutional Fuel Combustion

SCC: 2103004000, 2103005000, 2103006000, 2103007000

Follow these steps when calculating emissions fr om commercial/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.

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

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

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

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

.

Sub-Category 1.3: Residential Fuel Combustion

SCC: 2104002000, 2104004000, 2104006000, 2104007000

Follow these steps when calculating emissions from residential fuel combustion:

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

Note: Use the steps in sub-category 1.1-1 to navigate through the Energy Information 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 house hold per county divided by the breakdown of fuels by household per state using the U.S. Census Bureau’s website at http://www.census.gov/

. Note: As of the date of this SOP, the following 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 Characterist ics” and select “show more” e. On the left hand side, select “chan ge 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 abov e in step 3 by the area residential f uel 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 approp riate EPA emission factors fo r the various fuels for residential found in AP-42, Fifth Edition, Volume 1, Chapter 1 External Combustion Sources at http://www.epa.gov/ttn/chief/ap42/ch01/

.

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

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

Follow these steps when calculating emission s from 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 followin g 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) NATION AL EMISSIONS INVENTORY FOR CRITERIA AND HAZARDOUS AIR POLLUTANTS” at http://www.epa.gov/ttn/chief/net/ 2002inventory.html#documentaiton the number calculated above in step 1 is broken out into three categories (fireplac e without inserts, fireplaces with inserts and woodstoves).

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

. Note: Use the steps in sub-category 1.3-2 to navigate through the Energy Information 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)

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

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

. Note: As of the date of this SOP, the foll owing steps will lead to 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 queryi ng the total process rates for the SCC 30203202 (straight-dough) and SCC 30203201 (sponge-do ugh) using the ACC ESS data tables at K:\OAQ_INV\Steptool\Stptl_02.mdb.

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

. 5. Calculate a per capita factor by dividing the I ndiana population found in step 2 by the remaining process rate. 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 fo llowing 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 paint s together using the U.S. Census Bureau’s website http://www.census.gov . Use Table 1 to select all solvent-based paints and Table 2 to select all water based paints.

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

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

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

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

a. Go to http://www.census.gov b. Under Business & Industry, select more c. Now select Current Industrial Reports (CIR) d. Select CIRs by Subject e. Tab down to find the report “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 coatin g. Then divide this number by the total national population using the U.S. Census Bureau’s website http://www.census.gov

. 4. Multiply the number calculated abov e in step 3 by each of the 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 empl oyees from the reported sources using the SIC 7532- Body Repair and Paint Shops using the ACCESS data t ables at K:\OAQ_INV\Steptool\Stptl_02.mdb. Subtract this number from the coun ty employment for the same SIC using the U.S. Census Bureau’s website http://www.census.gov

.
Note: As of the date of this SOP, the foll owing 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/vol ume03/archsfc.pdf and the county employment found above in step 1 to calcul ate the VOC emissions for each county.

Sub-Category 3.3: Traffic Markings

SCC: 2401008000

Follow these steps when calculating for traffic markings:

1. First calculate the national emissions by finding t he 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 paint s from the EIIP, Volume 3, Chapter 14, Traffic Markings at http://www.epa.gov/ttn/chief/eiip/techreport/volume03/iii14.pdf

.

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

a. Go to http://www.census.gov b. Under Business & Industry, select more c. Now select Current Industrial Reports (CIR) d. Select CIRs by Subject e. Tab down to find the report “Paints and Allied Products” f. Use the quantity amount in 1000/gallons under “Tra ffic 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/po licy/ohim/hs04/htm/sf2.htm

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

SCC Description SIC’s

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

2401020000 Wood Furniture 25

2401030000 Paper Coating 26

2401040000 Metal Cans * 341

2401045000 Metal Coils * 3479

2401055000 Machinery and Equipment 35

2401060000 Appliances * 363

2401065000 Electronic and Other Electrical 3612, 3357

2401070000 New Motor Vehicles ** 3711

2401075000 Other Transportation 37 (not 3711, 373)

2401080000 Marine Coatings 373

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

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

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

3. Subtract the number of report ed 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 f ound 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 i ndustrial surface coating using the default emission factor:

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

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

SCC’s Description Default Emission Factor

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

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

24-01-200-000 Other Special Pur pose 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

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

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

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

2415345000 cont. 39 Miscellaneous manufac turing 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:\O AQ_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 mult iplying 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 numbe r 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 coun ties, 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\St eptool\Stptl_02.mdb and subtract this number from the county total.

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

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

SCC: 2425000000

Follow these steps when calculating emissions from graphic arts activities:

1. Multiply the per capita factor found in the EIIP, Volume 3, 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 th rough 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 pop ulation 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 th rough 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 emissi ons and number of reported employees for all SIC’s beginning with 30 using the ACCESS data tabl es at K:\OAQ_INV\Steptool\Stptl_02.mdb.

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

3. Subtract the reported employment for SIC’s beginning with 30 from total employment for each of the 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 Ai r 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 Employm ent from the U.S. Census Bureau’s website http://www.census.gov

. Note: As of the date of this SOP, the following st eps 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

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

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

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

Sub-Category 3.11: Commercial/Consumer Solvents

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

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

1. Using the EIIP, Volume 3, Chapter 5, 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 st ate and county from the Indiana Department of Transportation’s, Division of Roadway Management Section.

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

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

.

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

SCC: 2461800000

Follow these steps when calculating emissions from pesticide usage:

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

2. Find the amount of active ingredients for herbicides and insecticides applied to Indiana fields at the Indiana 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 emis sions from crop oil concentrates obtained in the pesticide Excel table, pesticides, and solvent carrie rs and then divide by the total number of acres of corn and soybeans in Indiana found at the National Agricultural Statistics Services, United States Department of Agriculture http://www.nass.usda.gov/QuickStats/

. 5. Multiply the emission factor by the county-specific acreage for both corn and soybeans found at the 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 t he Federal Highway Administration, U.S. Department of Transportation http://www.fhwa.dot.gov/po licy/ohim/hs04/htm/mf21.htm

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

. 3. Run a query to find the amount of point source reported gasoline using t he 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 mult iplying by the number of gallons sold statewide found above in step 1.

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

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

Emission Factors

Source Emission Factor (lb VOC/1000) gal Storage Tanks Breathing Loss 5.0

Storage Tank Working Loss - Filling 9.6

Storage Tank Working Loss - Emptying 3.8 Gasoline Loading Racks (Vapor balance controlled) 11.9 (0.3)

Total 30.3

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

Sub-Category 4.2: Portable Fuel Containers

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

Follow these steps when calculating emi ssions 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 docu ment Public Meeting to Consider Approval of California’s Portable Gasoline-Cont ainer Emissions Inventory. Use the excel spreadsheet found at K:\OAQ_INV\Inv\Area Source\Gasoline.zip to calcul ate the emissions for permeation, diurnal, and transport

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

2. Using the survey results below in Table 1, esti mate the number of fuel 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\GasCan s.xls, insert the number of oc cupied housing, from the U.S. Census Bureau’s website at http://www.census.gov/ , in the space marked “households”.

Note: As of the data of this SOP, the following 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%

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

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

3. Using the survey results below in Table 2, esti mate the number of fuel 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 bot h residential and commercial by using the emission rates given in the California document. Use 1.57g/gal /day for plastic contai ners and 0.6g/gal/day for metal containers. Insert the numbers for both resi dential and commercial into the excel spreadsheet at K:\OAQ_INV\Inv\Area Source\ Gaso line.zip\250101\GasCans.xls.

5. Calculate diurnal emissions by inserting the numbers for both residential and commercial into the excel 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/po licy/ohim/hs04/htm/mf21.htm

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

.

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

3. Run a query to find the amount of point source reported gasoline using t he ACCESS data tables at K:\OAQ_INV\Steptool\Stptl_02.mdb 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 tank s 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. Filt er 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 t anks 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 t anks 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 co unties 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 factor s for stage 1 controlled and uncontrolled in the EIIP, Volume 3, Chapter 11, Gasoline Marketing (Stage 1 and Stage 2) http://www.epa.gov/ttn/chief/eiip/techreport/volume03/iii11_apr2001.pdf

.

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

SCC: 2501060101 (uncontrolled), 2501060102 (controlled)

Follow these steps when calculating emissions from vehicle fueling – Vapor Displacement:

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

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

. 3. Allocate the amount sold to each of the counties by dividing the amount of sales in each county by statewide sales and multiplying by the number of gallons sold statewide found above in step 1.

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

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

Table 1
January Run for Southern Counties

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

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

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

5. Multiply the process rate in step 4 by the emission factor found in the mobile model.

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

SCC: 2501060103

Follow these steps when calculating emi ssions from vehicle fueling – Spillage:

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

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

. 3. Allocate the amount sold to each of the counties by dividing the amount of sales in each county by 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 emi ssions from underground tank breathing:

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

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

.

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

4. Apply the emission factor 1.0 lb VOC/1000 gallons in AP-42, Fifth Edition, Volume 1, Chapter 5, Petroleum 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 t he Federal Highway Administration, U.S. Department of Transportation http://www.fhwa.dot.gov/po licy/ohim/hs04/htm/mf21.htm

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

. 3. Allocate the amount sold to each of the counties by dividing the amount of sales in each county by 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, Chapt er 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/c gi-bin/cbpnaic/cbpsel.pl

. Note: Use the steps in 3.2-1 to navi gate 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, Fi fth Edition, Volume 1, Chapter 2-1.12, Solid Waste Disposal at http://www.epa.gov/ttn/chief/ap42/ch02/index.html

.

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

5.1.2: Commercial Solid Waste Incineration

SCC: 2601020000

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

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

. Note: Use steps 2.1-5 to navigate thr ough 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 co mmercial 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, Fi fth Edition, Volume 1, Chapter 2-1.12, Solid Waste Disposal at http://www.epa.gov/ttn/chief/ap42/ch02/index.html

.

5.1.3: Residential Solid Waste Incineration

SCC: 2601030000

Follow these steps when calculating emissions from 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 residentia l 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, Fi fth Edition, Volume 1, Chapter 2-1.12, Solid Waste Disposal at http://www.epa.gov/ttn/chief/ap42/ch02/index.html

. Sub-Category 5.2: Residential Open Burning

5.2.1: Leaf and Brush Burning

SCC: 2610000100 and 2610000400

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

1. Find a per capita factor for l eaf burning and a per capita for brus h burning by 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 c apita factor for leaves at 25% and for brush at 25%. Of the total waste generated only 28% burns.

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

Note: As of the data of this SOP, the follow ing steps will lead to 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 wast e generated to account for the percentage of forest in each county. The percentages come from a doc ument from the United States Department of Agriculture at http://ncrs.fs.fed.us /pubs/rb/rb_nc253b.pdf

.
Percent Forested Acres per County Adjusted for Yard Waste Generated

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

>= 50% 100% generated

5. Now, multiply the amount of leaves and brush by the emission factors found in AP-42, Fifth Edition, Volume 1, Chapter 2, Solid Waste 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 re sidential waste incinerati on 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 ge nerated by rural popul ation 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 residentia l 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:

23Area 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 em ission factors in FIRE 6.25 using the SCC code 2630020000.

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

SCC: 2640000004

Follow these steps when calculating emissions fr om treatment, storage, and 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 th e 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 chec klist for the Area Source Inventory at this time. The Emission Group does this electronically through an excel spreadsheet that is created when needed.


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

The Branch Contact for the Air Programs Branch a nd the 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.

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

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


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



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


### 11. History of Revisions

Date Month/day/year Revision Number Description

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



### 12. Appendices None

25

# APPENDIX H

Lake Michigan Air Directors Consortium (LADCO) Emission Estimates Technical Support Document

## This page left intentionally blank.

# Regional Air Quality Analyses for

Ozone, PM 2. 5 

# , and Regional Haze:

F inal Technical Support Document

April 25 , 2008

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

# APPENDIX I

Lake Michigan Air Directors Consortium (LADCO) 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 emis sion estimates prepared for LADCO’s latest (Base M) 200 5 base year and 200 8, 2009, 2012, and 2018 future year modeling

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

. A dditional

emission reports are available on the LADCO website : http://www.ladco.org /tech/emis/r5/round5_reports.htm

.

VOC NOx SO2



### 0 2000 4000 6000 8000 10000 12000

2002

(K) 2005 ( M) 2002

(K) 2005 (M) 2002

(K) 2005 ( M) 

### WI

OH

MI

IN

IL

0 2000 4000 6000 8000 10000 12000

2002

(K) 2005 ( M) 2002

(K) 2005 (M) 2002

(K) 2005 (M) Area

Nonroad+MAR

Onroad

Non-EGU

EGU

Figure 1 . Base K and Base M Emissions for 5

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



### Base Year Em i ssions In mid

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



### For on

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

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

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

- VU: Version 3.1

, WRAP: Pre2002d

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

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

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

On

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

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

– 17

a nd January 16

– 18) to produce link

- specific, hourly emission estimates

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

.

VOC Emissions NOx Emissions

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



### For the non

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

- based HPMS county

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

– 17 and January 16

– 18) were used.

For other months (for both LADCO and non

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

.February 27, 2008



### Off

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

- road sectors for

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

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

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

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

Additional off

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

, 2007a and Environ 2007b)

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

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

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

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

Railroads (TPY) Commercial Marine (TPY)

2002 2005 2002 2005

VOC 7,890 7,625 1,562 828

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

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

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

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

NH3 86 85

---- ----



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

non

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

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

in the LADCO States ( i.e.

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

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



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

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

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

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

- L adco states

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

Non

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

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

Other improvements to the base year inventory included:

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

– see http://www.ec.gc.ca/pdb/npri/ )

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

.February 27, 2008

Figure 3

. Base year emission plots for Canada



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

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

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

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

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

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

cursors of secondary PM 2. 5 

### organ ic carbon mass

.

Figure 4

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



### Ammonia Emissions : The CMU

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

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

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

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

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

.

Wisconsin

–

dairy Wisconsin

- swine

Daily Total - Swine 55001

0.000 0.500 1.000 1.500 2.000 2.500 3.000 3.500

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

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

0.00 2.00 4.00 6.00 8.00 10.00 12.00 14.00

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

DateNH3 emissions (Kg / day)

Washington

–

beef Texas

- beef

Daily Total - Beef 53001

0.000 0.500 1.000 1.500 2.000 2.500 3.000

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

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

0.00 5.00 10.00 15.00 20.00 25.00 30.00 35.00 40.00 45.00

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

DateNH3 emissions (Kg / day)

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



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

.

0 300 600 900 1200 1500 1800

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

Illinois Indiana Io w a Michigan

Minnesota Ohio Wisconsin

Figure 6

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



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

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



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



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

– Base K and 2005

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

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

.

VOC NOx S O2

0 3000 6000 9000 12000

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

On-road

Nonroad

Non-EGU

EGU

Figure 7 . Base year and future year emissions for 5

- State LADCO Region (TPD, July weekday)

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

On

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

– 2009 trend (except for the Cincinnati

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

Off

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

- 2009 trend

Point

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

- 10%)

Point

– Non

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

- 2009 trend suggests little change)

Biogenics: use new 2005 base year emissions

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



### For on

- road, off

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

- EGU point sources)

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

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

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

On

- Highway Mobile Sources

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

- low sulfur diesel fuel

• Inspection/Maintenance programs (nonattainment areas)

• Reformulated gasoline (nonattainment areas)

Off

- Highway Mobile Sources

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

• Heavy

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

• Federal railroad/locomotive standards

• Federal commercial marine vessel engine standards

Area Sources

• Consumer solvents

• AIM coa tings

• Aerosol coatings

• Portable fuel containers

Power Plants

• Title IV (Phases I and II)

• NOx SIP Call

• Clean Air Interstate Rule

• Clean Air Mercury Rule

Other Point Sources

• VOC 2

- , 4

- , 7

- , and 10

- year MACT standards 2



### • Combustion turbine MACT

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

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

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



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



### , and BART in IN and WI)

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

On

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

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



### .

For the non

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

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

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

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

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

For other months (for both LADCO and non

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

.

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

- scale modeling to avoid double

- counting with the State’s local

- scale a nalysis for PM2.5.

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

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

Table 2. Summary of On

- road Emissions (TP D

– July 15, 2005)

Year State CO

- tpd TOG

- tpd NOx

- tpd PM2.5

- tpd SO2

- tpd NH3

- tpd Sum of VMT

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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



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



### . Three CAIR scenarios were addressed:

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

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



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

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

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

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

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

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

- 2012 2015: 2013

- 2017 2020: 2018

- 2022 2025: 2023

- 2027 2032: 2028

- 2035

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

- 2011 2012: 2012

- 2012 2015: 2013

- 2017 2018: 2018

- 2019 2025: 2020

- 2028 2032: 2029

- 2035

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



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

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

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

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

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



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

4444 4736 4697 4048 3978 3714

MN 162 148 148 187 167 157

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

1333 1330 1321 1183 1186 1159

MN 116 142 142 132 157 125February 27, 2008

Table 4. Facilities Anticipating SO2 Controls in 2009 and 2010

State Name Plant Name UniqueID_Final ORIS Code Unit

ID Capacity

MW Scrubber

On lineYear Scrubber

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

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

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

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

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

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

State Plant 2010 IPM 2005 BY

Indiana Clifty Creek 41.41 225.32

Missouri Ameren Sioux 22.25 141.92

Ohio Kyger Creek 21.53 197.68

Ohio Sammis 147.97 305.90

Pennsylv a nia Cheswick 11.53 103.98

Tennessee Kingston 41.15 155.20February 27, 2008



### References

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

- LADCO) State Emissions, Preparation and Delivery of Non

- MR PO Emission Files< March 12, 2007.

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

- mail from James Wilkinson on February 9, 2007.

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

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

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

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

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

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

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

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

Environ, 200 8 , “LADCO On

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

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

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

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

- Based Ammonia Emissions Model for Agricultural Sources

– Emission Estimates”

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

### , and Regional Haze”, EPA

- 454/B07

- 002, April 2007.

USEPA, 2007b, E

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

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

- Based Ammonia Emissions Model for Agricultural Sources

– Model Development”

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



### Web Sites:

http://www.ladco.org/tech/emis/basek/BaseK_Reports.htm

http://www.ladco.org/tech/emis/r5/round5_reports.htm

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

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

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

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



# ATTACHME NT 1

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

July 2002 2005 2009 2009 2012 2018 2018 2002 2005 2009 2009 2012 2018 2018 2002 2005 2009 2009 2012 2018 2018 2002 2005 2009 2009 2012 2018 2018
Nonroad

IL 224 321 164 257 149 130 213 324 333 263 275 224 154 155 31 33 5 5 0.6 0.4 0.4 30 24 14

IN 125 195 94 160 95 95 128 178 191 142 158 141 141 89 17 19 3 3 3 0.3 0.2 17 13 7

MI 348 414 307 350 276 222 271 205 239 159 197 133 93 112 19 22 3 3 0.5 0.3 0.3 22 18 11
OH 222 356 161 294 145 126 238 253 304 195 246 162 109 135 23 29 4 5 0.5 0.3 0.4 27 22 13

WI 214 238 194 203 175 140 157 145 157 114 129 97 69 77 13 15 2 2 0.3 0.2 0.2 14 12 7
5-State Total 1133 1524 920 1264 840 713 1007 1105 1224 873 1005 757 566 568 103 118 17 18 4.9 1.5 1.5 110 89 52
U.S. Total 8463 9815 5442 8448 5244 6581 6041 9060 6057 8120 5832 5100 505 654 117 153 104 13 573 750 475

MAR

IL 10 11 10 10 10 10 6 277 246 201 228 195 186 165 0 22 0 19 0 0 17 7 6 4

IN 5 5 5 5 5 5 3 123 93 89 87 87 84 65 0.2 8 0.2 7 0.2 0.2 6 2 2 2

MI 7 7 7 7 7 8 7 114 87 112 82 111 110 65 0.6 21 0.7 14 0.7 0.8 8 3 3 2
OH 8 7 8 7 8 8 5 177 134 128 126 126 122 94 0.4 14 0.3 12 0.3 0.3 10 4 4 2

WI 4 4 4 4 4 4 3 79 58 59 54 59 57 41 12.7 8 9.5 6 9.5 8.7 5 2 2 1
5-State Total 34 34 34 33 34 35 24 770 618 589 577 578 559 430 13.9 73 10.7 58 10.7 10 46 18 17 11
U.S. Total 307 317 321 157 329 346 334 4968 4515 4002 1813 3964 3919 3812 620 512 509 122 509 503 290 147 57 165

OtherArea

IL 679 675 688 594 700 738 582 62 48 68 48 70 73 49 11 11 12 16 12 13 16 40 64 69

IN 354 391 365 358 373 398 384 62 56 65 58 67 69 59 158 32 150 32 151 153 32 2 2 2

MI 518 652 516 562 520 541 549 49 49 52 50 53 54 51 71 29 68 29 68 68 28 111 114 120
OH 546 604 550 506 558 593 487 50 93 59 108 60 62 108 22 6 34 15 35 35 14 19 35 34

WI 458 315 467 290 474 506 293 32 37 34 37 34 35 37 9 17 9 13 10 10 13 11 12 12
5-State Total 2555 2637 2586 2310 2625 2776 2295 255 283 278 301 284 293 304 271 95 273 105 276 279 103 183 227 237
U.S. Total 17876 21093 18638 18683 20512 24300 3856 4899 4100 4220 4418 5357 2075 2947 2062 2559 2189 2709 2735 2621 2570

On-Road

IL 446 341 314 268 260 197 151 890 748 578 528 474 300 201 9 4 3 13 10 6

IN 405 282 237 235 193 150 138 703 541 425 402 313 187 173 11 3 2 9 7 2

MI 522 351 335 269 303 217 163 926 722 680 501 619 385 204 14 4 3 12 9 3
OH 574 680 365 424 340 238 242 1035 934 609 693 512 270 274 18 4 4 16 12 4

WI 238 175 144 119 117 88 68 481 457 303 322 226 118 138 9 2 2 8 6 2
5-State Total 2185 1829 1395 1315 1213 890 762 4035 3402 2595 2446 2144 1260 990 61 17 14 58 44 17
U.S. Total 14263 7825 23499 13170

EGU

IL 9 7 8 6 8 9 7 712 305 227 275 244 231 224 1310 1158 944 958 789 810 869 13 34 77

IN 6 6 6 6 7 6 6 830 393 406 370 424 283 255 2499 2614 1267 1033 1263 1048 1036 16 73 74

MI 12 6 11 4 11 12 4 448 393 218 242 219 247 243 1103 1251 1022 667 1031 1058 725 15 25 29
OH 5 4 6 5 7 7 6 1139 408 330 280 322 271 285 3131 3405 1463 1326 994 701 983 28 94 80

WI 3 5 3 2 4 4 3 293 213 146 165 139 147 177 602 545 512 460 492 500 435 0 22 25
5-State Total 35 28 34 23 37 38 26 3422 1712 1327 1332 1348 1179 1184 8645 8973 5208 4444 4569 4117 4048 72 248 285
U.S. Total 214 140 195 124 197 215 138 14371 10316 7746 7274 7721 7007 6095 31839 34545 20163 16903 17629 14727 14133 685 1131 1571

Non-EGU

IL 313 221 286 218 305 350 258 356 330 334 218 338 343 235 373 423 251 335 257 249 346 16 17 19

IN 150 130 160 137 170 199 167 238 179 212 175 216 225 178 292 218 270 216 274 290 180 35 36 44

MI 123 116 115 119 122 139 140 216 240 208 242 214 229 271 162 158 166 148 171 185 163 20 21 25
OH 77 84 75 87 79 90 104 177 175 157 166 160 167 178 240 289 231 288 210 216 293 27 28 33

WI 88 84 97 87 104 120 106 98 97 91 93 92 94 81 163 156 154 152 155 156 85 0 0.1 0.1
5-State Total 751 635 733 648 780 898 775 1085 1021 1002 894 1020 1058 943 1230 1244 1072 1139 1067 1096 1067 98 102 121
U.S. Total 4087 3877 4409 4700 5378 6446 6730 6129 6435 6952 5759 5630 6093 6340 6970 1444 1777

IL 1681 1576 1470 1353 1432 1434 1217 2621 2010 1671 1572 1545 1287 1029 1725 1656 1212 1337 1059 1072 1251 119 155 189

IN 1045 1009 867 901 843 853 826 2134 1453 1339 1250 1248 989 819 2966 2902 1690 1294 1691 1492 1256 81 133 131

MI 1530 1546 1291 1311 1239 1139 1134 1958 1730 1429 1314 1349 1118 946 1356 1495 1260 865 1271 1312 927 183 190 190
OH 1432 1735 1165 1323 1137 1062 1082 2831 2048 1478 1619 1342 1001 1074 3416 3761 1732 1650 1240 953 1304 121 195 166

WI 1005 821 909 705 878 862 630 1128 1019 747 800 647 520 551 800 750 687 635 667 675 540 35 54 47
5-State Total 6693 6687 5702 5593 5529 5350 4889 10672 8260 6664 6555 6131 4915 4419 10263 10564 6581 5781 5928 5504 5280 539 727 723February 27, 2008



# ATTACHMENT 2

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



### 2009

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

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

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

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

-----

Obs cntryid stid cyid fcid name polid aceebase aceenew diff

1 US 17 97 097190AAC MIDWEST GENERAT NOX 11.54 6.28

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

- 11.652 3 US 18 73 00008 NIPSCO

- R.M. S NOX 26.50 24.81

- 1.691 4 US 18 77 00001 IKEC

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

- DEAN H NOX 20.51 19.13

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

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

- SIOUX NOX 28.47 12.81

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

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

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

- 0.279 20 US 55 21 111003090 Alliant Energy

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

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

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

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

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

- 1.955

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

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

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

-----

Obs cntryid stid cyid fcid name polid aceebase aceenew diff

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

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

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

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

- R.M. S SO2 82.52 63.71

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

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

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

- 9.968 37 US 27 163 2716300005 Xcel Energy

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

- SIOUX SO2 22.25 8.34

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

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

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

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

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

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

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

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

- 15.772

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

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



### 2009

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

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

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

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

-----

Obs cntryid stid cyid fcid name polid aceebase aceenew diff

1 US 19 139 70

- 01

- 011 MUSCATINE POWER NOX 5.649 3.926

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

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

- NOX 17.158 17.156

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

- 1.2470 6 US 55 43 122014530 Alliant Energy

- NOX 7.765 7.756

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

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

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

- 0.0343

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

- 9.9218

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

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

-----

Obs cntryid stid cyid fcid name polid aceebase aceenew diff

13 US 19 139 70

- 01

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

- 3.6753 15 US 55 21 111003090 Alliant Energy

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

- 16.2672 17 US 55 43 122014530 Alliant Energy

- SO2 42.604 42.640 0.0362 18 US 55 59 230006260 WIS ELECTRIC PO SO2 12.336 9.850

- 2 .4867 19 US 55 71 436035930 MANITOWOC PUBLI SO2 9.949 3.001

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

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

- 0.0694

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

- 24.1856

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

- 34.1074

# APPENDIX J

Modeling Summary

 PM 2.5 

# Design Value Trends

 Regional/Emission Sector Particulate Source Apportionment Technology (PSAT) Test Results, Jeffersonville, Indiana – Walnut Street PM 2.5 

# Monitor

 Speciated Contributions to PM 2.5 

# Concentrations, Louisville Area

 Distribution of PM 2.5 

# Concentration Days using Air Quality Index (AQI) Levels

## This page left intentionally blank.

### J-1 PM 2.5 

### 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

‐ 2010Concentrations(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 Sou rce Apportionment Technology (PSAT) Test Results, Jeffersonville, I ndiana – Walnut Street PM 2.5 

### 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 PM 2.5 

### 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 PM 2.5 

### Monitor

so4

no3

oc

ec soil

nh4 pbw

blan

### J-4 Modeled Contribution by Species at the New Albany, Indiana PM 2.5 

### Monitor

so4 35%

no3 7%

oc 23% ec 4% soil 4% nh4 13% pbw 11% blan 3% 

### Observed 2005 Contributions at the New Albany PM 2.5 

### 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 PM 2.5 

### Monitor

so4

no3

oc

ec
soil

nh4 pbw

blan

### J-5 Modeled Contribution by Species at the Ca rpenter Street – Shepherdsville, Kentucky PM 2.5 

### Monitor

so4 35%

no3 7%
oc 24% ec 4% soil 3% nh4 13% pbw 11% blan 3% 

### Observed 2005 Contributions at the Shepherdsville PM 2.5 

### 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 PM 2.5 

### Monitor

so4

no3

oc

ec soil

nh4 pbw

blan

### J-6 Modeled Contribution by Species at the Elizabethtown, Kentucky PM 2.5 

### Monitor

so4 35%

no3 7% oc 24% ec 4% soil 3% nh4 12% pbw 11% blan 4% 

### Observed 2005 Contributions at the Elizabethtown PM 2.5 

### 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 PM 2.5 

### Monitor

so4
no3

oc

ec soil
nh4 pbw
blan

### J-7 Modeled Contribution by Species at the Southern Avenue – Louisville, Kentucky PM 2.5 

### Monitor

so4 35%

no3 7%
oc 24% ec 4% soil 3% nh4 13% pbw 11% blan 3% 

### Observed 2005 Contributions at the Southern Avenue PM 2.5 

### 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 PM 2.5 

### Monitor

so4
no3

oc

ec soil
nh4 pbw
blan

### J-8 Modeled Contribution by Species at the Wyandotte Park – Louisville, Kentucky PM 2.5 

### Monitor

so4 34%

no3 7%

oc 25% ec 4% soil 3% nh4 13% pbw 11% blan 3% 

### Observed 2005 Contributions at the Wyandotte Park PM 2.5 

### 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 PM 2.5 

### Monitor

so4
no3

oc

ec soil
nh4 pbw
blan

### J-9 Modeled Contribution by Species at the Barret Avenue – Louisville, Kentucky PM 2.5 

### Monitor

so4 34%

no3 7%

oc 25% ec 4% soil 3% nh4 13% pbw 11% blan 3% 

### Observed 2005 Contributions at the Barret Avenue PM 2.5 

### 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 PM 2.5 

### Monitor

so4

no3

oc

ec soil

nh4 pbw

blan

### J-10 Modeled Contribution by Species at the Watson Elementary – Louisville, Kentucky PM 2.5 

### Monitor

so4 35%

no3 7%

oc 23% ec 4% soil 4% nh4 13% pbw 11% blan 3% 

### Observed 2005 Contributions at the Watson Elementary PM 2.5 

### 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 PM 2.5 

### Monitor

so4

no3

oc

ec
soil

nh4 pbw

blan

### J-11 Distribution of PM 2.5 

### Concentration Days on the AQI Le vels 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 2010Percentage of Days

Year

Good Moderate USG