21 161 2116100009 1 001 99 10100202 SO2 42.17 45.92 4.592 0.0 0.900 SCRUBBER Scrubber added by LADCO

 21 161 2116100009 2 002 99 10100212 SO2 55.39 60.31 6.031 0.0 0.900 SCRUBBER Scrubber added by LADCO

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

fcid 97.55 106.23 10.623 

cyid 97.55 106.23 10.623 

stid 202.07 220.04 22.004 

STID=27 CYID=61 fcid=2706100004 name=Minnesota Power Inc - Boswell Energy Ctr

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 27 61 2706100004 SV003 EU003 001 10100226 SO2 33.99 39.15 16.778 0.3 0.700 SCRUBBER Scrubber added by LADCO

 27 61 2706100004 SV003 EU003 002 10100501 SO2 0.00 0.00 0.000 0.3 0.700 SCRUBBER Scrubber added by LADCO

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

fcid 33.99 39.15 16.778 

cyid 33.99 39.15 16.778 

STID=27 CYID=109 fcid=2710900011 name=Rochester Public Utilities - Silver Lake

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 27 109 2710900011 SV003 EU004 001 10100202 SO2 7.86 9.05 1.357 0.0 0.850 SCRUBBER Scrubber added by LADCO

STID=27 CYID=141 fcid=2714100004 name=NSP - Sherburne Generating Plant

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 27 141 2714100004 SV001 EU001 001 10100222 SO2 16.76 19.31 4.138 0.3 0.850 SCRUBBER Scrubber added by LADCO

 27 141 2714100004 SV001 EU002 001 10100222 SO2 22.55 25.97 5.565 0.3 0.850 SCRUBBER Scrubber added by LADCO

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

fcid 39.31 45.28 9.703 

cyid 39.31 45.28 9.703 

stid 81.16 93.48 27.838 

STID=39 CYID=13 fcid=0607130015 name=R. E. BURGER PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 39 13 0607130015 R6 B011 B011P1 10100202 SO2 29.83 32.48 3.248 0.0 0.900 SCRUBBER Scrubber added by LADCO

 39 13 0607130015 R7 B012 B012P1 10100202 SO2 34.77 37.86 3.786 0.0 0.900 SCRUBBER Scrubber added by LADCO

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

fcid 64.60 70.34 7.034 

cyid 64.60 70.34 7.034 

STID=39 CYID=31 fcid=0616000000 name=CONESVILLE POWER PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 39 31 0616000000 R4 B004 B004P1 10100212 SO2 316.00 344.11 34.411 0.0 0.900 SCRUBBER Scrubber added by LADCO

STID=39 CYID=167 fcid=0684000000 name=MUSKINGUM RIVER POWER PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes
 39 167 0684000000 R2 B002 B002P1 10100201 SO2 65.07 70.85 7.085 0.0 0.900 SCRUBBER Scrubber added by LADCO

 39 167 0684000000 R2 B002 B002P2 10100501 SO2 0.00 0.00 0.000 0.0 0.900 SCRUBBER Scrubber added by LADCO

 39 167 0684000000 R3 B003 B003P1 10100201 SO2 94.58 103.00 10.300 0.0 0.900 SCRUBBER Scrubber added by LADCO

 39 167 0684000000 R3 B003 B003P2 10100501 SO2 0.00 0.00 0.000 0.0 0.900 SCRUBBER Scrubber added by LADCO

 39 167 0684000000 R4 B004 B004P1 10100203 SO2 81.64 88.90 8.890 0.0 0.900 SCRUBBER Scrubber added by LADCO

 39 167 0684000000 R4 B004 B004P2 10100501 SO2 0.00 0.00 0.000 0.0 0.900 SCRUBBER Scrubber added by LADCO

 39 167 0684000000 R5 B005 B005P1 10100203 SO2 97.22 105.87 10.587 0.0 0.900 SCRUBBER Scrubber added by LADCO

 39 167 0684000000 R5 B005 B005P2 10100501 SO2 0.00 0.00 0.000 0.0 0.900 SCRUBBER Scrubber added by LADCO

 39 167 0684000000 R6 B006 B006P1 10100202 SO2 113.96 124.10 12.410 0.0 0.900 SCRUBBER Scrubber added by LADCO

 39 167 0684000000 R6 B006 B006P2 10100501 SO2 0.00 0.00 0.000 0.0 0.900 SCRUBBER Scrubber added by LADCO

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

fcid 452.48 492.72 49.272 

cyid 452.48 492.72 49.272 

stid 833.08 907.16 90.716 

STID=47 CYID=1 fcid=0009 name=TVA BULL RUN FOSSIL PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 47 1 0009 S-1 001 99 10100212 SO2 130.81 136.82 13.682 0.0 0.900 SCRUBBER Scrubber added by LADCO

STID=47 CYID=73 fcid=0007 name=TVA JOHN SEVIER FOSSIL PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 47 73 0007 S-1A 001 99 10100212 SO2 20.15 21.07 2.107 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 73 0007 S-1B 002 99 10100212 SO2 20.25 21.18 2.118 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 73 0007 S-2A 003 99 10100212 SO2 19.62 20.52 2.052 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 73 0007 S-2B 004 99 10100212 SO2 18.93 19.80 1.980 0.0 0.900 SCRUBBER Scrubber added by LADCO

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

fcid 78.95 82.57 8.257 

cyid 78.95 82.57 8.257 

STID=47 CYID=85 fcid=0011 name=TVA JOHNSONVILLE FOSSIL PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 47 85 0011 S1-01 001 99 10100212 SO2 17.06 17.84 1.784 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 85 0011 S1-04 004 99 10100212 SO2 19.85 20.76 2.076 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 85 0011 S1-05 005 99 10100212 SO2 24.11 25.22 2.522 0.0 0.900 SCRUBBER Scrubber added by LADCO

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

fcid 61.02 63.82 6.382 

cyid 61.02 63.82 6.382 

STID=47 CYID=145 fcid=0013 name=TVA KINGSTON FOSSIL PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 47 145 0013 S-1 001 99 10100202 SO2 12.68 13.26 1.326 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 145 0013 S-1 002 99 10100202 SO2 14.00 14.65 1.465 0.0 0.900 SCRUBBER Scrubber added by LADCO
 47 145 0013 S-1 003 99 10100202 SO2 13.80 14.44 1.444 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 145 0013 S-1 004 99 10100202 SO2 12.24 12.80 1.280 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 145 0013 S-1 005 99 10100202 SO2 19.57 20.47 2.047 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 145 0013 S-2 006 99 10100202 SO2 18.92 19.79 1.979 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 145 0013 S-2 007 99 10100202 SO2 21.30 22.28 2.228 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 145 0013 S-2 008 99 10100202 SO2 18.54 19.39 1.939 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 145 0013 S-2 009 99 10100202 SO2 20.72 21.68 2.168 0.0 0.900 SCRUBBER Scrubber added by LADCO

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

fcid 151.77 158.75 15.875 

cyid 151.77 158.75 15.875 

STID=47 CYID=165 fcid=0025 name=TVA GALLATIN FOSSIL PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 47 165 0025 S-01 001 99 10100212 SO2 13.91 14.54 1.454 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 165 0025 S-01 002 99 10100212 SO2 14.87 15.56 1.556 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 165 0025 S-02 003 99 10100212 SO2 16.33 17.08 1.708 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 165 0025 S-02 004 99 10100212 SO2 20.39 21.32 2.132 0.0 0.900 SCRUBBER Scrubber added by LADCO

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

fcid 65.49 68.50 6.850 

cyid 65.49 68.50 6.850 

stid 488.04 510.46 51.046 

STID=54 CYID=39 fcid=0006 name=APPALACHIAN POWER - KANAWHA RIVER PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 54 39 0006 012 001 99 10100202 SO2 19.45 21.18 10.591 0.0 0.500 SCRUBBER Scrubber added by LADCO

 54 39 0006 012 002 99 10100202 SO2 20.94 22.80 11.399 0.0 0.500 SCRUBBER Scrubber added by LADCO

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

fcid 40.39 43.98 21.990 

cyid 40.39 43.98 21.990 

STID=54 CYID=51 fcid=0005 name=OHIO POWER - MITCHELL PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 54 51 0005 012 001 99 10100202 SO2 17.77 19.36 1.936 0.0 0.900 SCRUBBER Scrubber added by LADCO

 54 51 0005 012 002 99 10100202 SO2 5.69 6.19 0.619 0.0 0.900 SCRUBBER Scrubber added by LADCO

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

fcid 23.46 25.55 2.555 

STID=54 CYID=51 fcid=0006 name=OHIO POWER - KAMMER PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 54 51 0006 013 001 99 10100203 SO2 47.06 51.25 5.125 0.0 0.900 SCRUBBER Scrubber added by LADCO

 54 51 0006 013 002 99 10100203 SO2 47.66 51.90 5.190 0.0 0.900 SCRUBBER Scrubber added by LADCO

 54 51 0006 013 003 99 10100203 SO2 41.94 45.67 4.567 0.0 0.900 SCRUBBER Scrubber added by LADCO
---- -------- -------- ----------

fcid 136.67 148.82 14.882 

cyid 160.13 174.37 17.437 

STID=54 CYID=53 fcid=0001 name=APPALACHIAN POWER CO.-PHILIP SPORN PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 54 53 0001 014 001 99 10100202 SO2 18.65 20.31 2.031 0.0 0.900 SCRUBBER Scrubber added by LADCO

 54 53 0001 014 002 99 10100202 SO2 15.87 17.28 1.728 0.0 0.900 SCRUBBER Scrubber added by LADCO

 54 53 0001 014 003 99 10100202 SO2 21.46 23.36 2.336 0.0 0.900 SCRUBBER Scrubber added by LADCO

 54 53 0001 014 004 99 10100202 SO2 20.53 22.36 2.236 0.0 0.900 SCRUBBER Scrubber added by LADCO

 54 53 0001 005 005 99 10100202 SO2 46.82 50.98 5.098 0.0 0.900 SCRUBBER Scrubber added by LADCO

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

fcid 123.33 134.30 13.430 

STID=54 CYID=53 fcid=0009 name=APPALACHIAN POWER - MOUNTAINEER PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 54 53 0009 001 001 99 10100202 SO2 11.20 12.19 1.219 0.0 0.900 SCRUBBER Scrubber added by LADCO

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

cyid 134.53 146.49 14.649 

STID=54 CYID=79 fcid=0006 name=APPALACHIAN POWER - JOHN E AMOS PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 54 79 0006 012 001 99 10100202 SO2 79.63 86.72 8.672 0.0 0.900 SCRUBBER Scrubber added by LADCO

 54 79 0006 012 002 99 10100202 SO2 100.33 109.26 10.926 0.0 0.900 SCRUBBER Scrubber added by LADCO

 54 79 0006 003 003 99 10100202 SO2 139.38 151.77 15.177 0.0 0.900 SCRUBBER Scrubber added by LADCO

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

fcid 319.35 347.75 34.775 

cyid 319.35 347.75 34.775 

stid 654.39 712.59 88.851 

STID=55 CYID=79 fcid=241007690 name=WIS ELECTRIC POWER OAK CREEK STATION

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 55 79 241007690 S13 B25 01 10100202 SO2 12.75 14.48 3.475 0.0 0.760 SCRUBBER Scrubber added by LADCO

 55 79 241007690 S13 B26 01 10100202 SO2 8.68 9.85 2.462 0.0 0.750 SCRUBBER Scrubber added by LADCO

 55 79 241007690 S14 B27 01 10100212 SO2 10.97 12.45 2.864 0.0 0.770 SCRUBBER Scrubber added by LADCO

 55 79 241007690 S14 B28 01 10100212 SO2 11.28 12.81 2.945 0.0 0.770 SCRUBBER Scrubber added by LADCO

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

fcid 43.68 49.59 11.746 

cyid 43.68 49.59 11.746 

stid 43.68 49.59 11.746 

 ======== ======== ==========

 3099.41 3381.52 400.481 
Appendix II

Scenario C Controls (CAMD List)
1

NOx Controls (SCRs, 2007 – 2013))

Plant Name UniqueID_Final State Name County

Capacity 

MW

On Line 

Year

SCR 

Online 

Year

Chesterfield 3797_B_4 Virginia Chesterfield 166 1960 2013

Chesterfield 3797_B_5 Virginia Chesterfield 310 1964 2012

Scherer 6257_B_3 Georgia Monroe 875 1987 2011

Chesterfield 3797_B_6 Virginia Chesterfield 658 1969 2011

Sandow No 4 6648_B_4 Texas Milam 545 1981 2011

Beech Hollow Power Project 82704_B_1 Pennsylvania Washington 272 2011 2011

Longview Power 82702_B_1 West Virginia Monongalia 695 2011 2011

Cliffside 2721_B_6 North Carolina Cleveland 800 2011 2011

AES Westover 2526_B_11 New York Broome 22 1943 2010

AES Westover 2526_B_12 New York Broome 22 1943 2010

AES Westover 2526_B_13 New York Broome 84 1951 2010

Iatan 2 6065_B_2 Missouri Platte 850 2010 2010

Southwest 6195_B_2 Missouri Greene 300 2010 2010

Trimble Station (LGE) 6071_B_2 Kentucky Trimble 732 2010 2010

Elm Road Generating Station 56068_B_2 Wisconsin Milwaukee 615 2010 2010

Clay Boswell 1893_B_3 Minnesota Itasca 350 1973 2009

Asheville 2706_B_2 North Carolina Buncombe 184 1971 2009

Conesville 2840_B_4 Ohio Coshocton 780 1973 2009

Marshall 2727_B_3 North Carolina Catawba 657 1969 2009

St Johns River Power Park 207_B_1 Florida Duval 626 1987 2009

Ghent 1356_B_2 Kentucky Carroll 469 1977 2009

Chalk Point LLC 1571_B_1 Maryland Prince George's 341 1964 2009

Chalk Point LLC 1571_B_2 Maryland Prince George's 342 1965 2009

San Juan 2451_B_2 New Mexico San Juan 320 1973 2009

Big Bend 645_B_BB01 Florida Hillsborough 411 1970 2009

Big Bend 645_B_BB02 Florida Hillsborough 391 1973 2009

Big Bend 645_B_BB03 Florida Hillsborough 414 1976 2009

Nebraska City Unit 2 6096_B_2 Nebraska Otoe 663 2009 2009

Cross 130_B_4 South Carolina Berkeley 652 2009 2009

Springerville 8223_B_4 Arizona Apache 400 2009 2009

Sandow 5 82010_B_5 Texas Milam 600 2009 2009

Oak Grove 82011_B_1 Texas Robertson 800 2009 2009

Oak Grove 82011_B_2 Texas Robertson 800 2009 2009

TS Power Plant 82013_B_1 Nevada Eureka 200 2009 2009

Plum Point Energy 82014_B_1 Arkansas Mississippi 665 2009 2009

Comanche 470_B_3 Colorado Pueblo 750 2009 2009

Elm Road Generating Station 56068_B_1 Wisconsin Milwaukee 615 2009 2009

Two Elk Generating Station 55360_B_1 Wyoming Campbell 300 2009 2009

J K Spruce 7097_B_BLR2 Texas Bexar 750 2009 2009

Dallman 963_B_34 Illinois Sangamon 200 2009 2009

AES Greenidge LLC 2527_B_4 New York Yates 27 1950 2008

AES Greenidge LLC 2527_B_5 New York Yates 27 1950 2008

AES Greenidge LLC 2527_B_6 New York Yates 106 1953 2008

Charles R Lowman 56_B_2 Alabama Washington 238 1979 2008

Charles R Lowman 56_B_3 Alabama Washington 238 1980 2008

Barry 3_B_5 Alabama Mobile 750 1971 2008

St Johns River Power Park 207_B_2 Florida Duval 626 1988 2008

Morgantown Generating Plant 1573_B_2 Maryland Charles 620 1971 2008
2

Bailly 995_B_7 Indiana Porter 160 1962 2008

San Juan 2451_B_1 New Mexico San Juan 322 1976 2008

San Juan 2451_B_3 New Mexico San Juan 495 1979 2008

Weston 4078_B_4 Wisconsin Marathon 519 2008 2008

AES Deepwater 10670_B_AAB001 Texas Harris 140 1986 2007

La Cygne 1241_B_1 Kansas Linn 724 1973 2007

Morgantown Generating Plant 1573_B_1 Maryland Charles 624 1970 2007

PSEG Hudson Generating Station 2403_B_2 New Jersey Hudson 583 1967 2007

San Juan 2451_B_4 New Mexico San Juan 506 1982 2007

Big Bend 645_B_BB04 Florida Hillsborough 457 1985 2007

Cross 130_B_3 South Carolina Berkeley 620 2007 2007

Wygen II 55479_B_4 Wyoming Campbell 90 2007 2007

Council Bluffs 1082_B_4 Iowa Pottawattamie 790 2007 2007

SO2 Controls (FGDs, 2007 – 2012)

Plant Name UniqueID_Final State Name County

Capacity 

MW

On Line 

Year

Scrubber 

Online 

Year

James H Miller Jr 6002_B_1 Alabama Jefferson 684 1978 2011

James H Miller Jr 6002_B_2 Alabama Jefferson 687 1985 2011

James H Miller Jr 6002_B_3 Alabama Jefferson 687 1989 2011

James H Miller Jr 6002_B_4 Alabama Jefferson 688 1991 2011

Cape Fear 2708_B_5 North Carolina Chatham 143 1956 2011

Baldwin Energy Complex 889_B_1 Illinois Randolph 624 1970 2011

Baldwin Energy Complex 889_B_2 Illinois Randolph 629 1973 2011

Baldwin Energy Complex 889_B_3 Illinois Randolph 629 1975 2011

Scherer 6257_B_3 Georgia Monroe 875 1987 2011

Milton R Young 2823_B_B1 North Dakota Oliver 250 1970 2011

W H Sammis 2866_B_6 Ohio Jefferson 630 1969 2011

W H Sammis 2866_B_7 Ohio Jefferson 630 1971 2011

PSEG Hudson Generating Station 2403_B_2 New Jersey Hudson 583 1967 2011

John Sevier 3405_B_1 Tennessee Hawkins 176 1955 2011

John Sevier 3405_B_2 Tennessee Hawkins 176 1955 2011

John Sevier 3405_B_3 Tennessee Hawkins 176 1956 2011

John Sevier 3405_B_4 Tennessee Hawkins 176 1957 2011

Beech Hollow Power Project 82704_B_1 Pennsylvania Washington 272 2011 2011

Longview Power 82702_B_1 West Virginia Monongalia 695 2011 2011

Cliffside 2721_B_6 North Carolina Cleveland 800 2011 2011

AES Greenidge LLC 2527_B_4 New York Yates 27 1950 2010

AES Greenidge LLC 2527_B_5 New York Yates 27 1950 2010

Barry 3_B_5 Alabama Mobile 750 1971 2010

E C Gaston 26_B_5 Alabama Shelby 861 1974 2010

Warrick 6705_B_4 Indiana Warrick 300 1970 2010

Coffeen 861_B_01 Illinois Montgomery 340 1965 2010

Coffeen 861_B_02 Illinois Montgomery 560 1972 2010

Cardinal 2828_B_3 Ohio Jefferson 630 1977 2010

Brandon Shores 602_B_1 Maryland Anne Arundel 643 1984 2010

Brandon Shores 602_B_2 Maryland Anne Arundel 643 1991 2010

Monroe 1733_B_4 Michigan Monroe 775 1974 2010

Cliffside 2721_B_5 North Carolina Cleveland 550 1972 2010

Crystal River 628_B_4 Florida Citrus 720 1982 2010

Bowen 703_B_1BLR Georgia Bartow 713 1971 2010
3

Crist 641_B_6 Florida Escambia 302 1970 2010

Crist 641_B_7 Florida Escambia 477 1973 2010

Clifty Creek 983_B_1 Indiana Jefferson 217 1955 2010

Clifty Creek 983_B_2 Indiana Jefferson 217 1955 2010

Clifty Creek 983_B_3 Indiana Jefferson 217 1955 2010

Clifty Creek 983_B_4 Indiana Jefferson 217 1955 2010

Clifty Creek 983_B_5 Indiana Jefferson 217 1955 2010

Clifty Creek 983_B_6 Indiana Jefferson 217 1956 2010

Chalk Point LLC 1571_B_1 Maryland Prince George's 341 1964 2010

Chalk Point LLC 1571_B_2 Maryland Prince George's 342 1965 2010

Dickerson 1572_B_1 Maryland Montgomery 182 1959 2010

Dickerson 1572_B_2 Maryland Montgomery 182 1960 2010

Dickerson 1572_B_3 Maryland Montgomery 182 1962 2010

R E Burger 2864_B_7 Ohio Belmont 156 1955 2010

R E Burger 2864_B_8 Ohio Belmont 156 1955 2010

Kyger Creek 2876_B_1 Ohio Gallia 217 1955 2010

Kyger Creek 2876_B_2 Ohio Gallia 217 1955 2010

Kyger Creek 2876_B_3 Ohio Gallia 217 1955 2010

Kyger Creek 2876_B_4 Ohio Gallia 217 1955 2010

Kyger Creek 2876_B_5 Ohio Gallia 217 1955 2010

Cheswick 8226_B_1 Pennsylvania Allegheny 580 1970 2010

PSEG Mercer Generating Station 2408_B_1 New Jersey Mercer 315 1960 2010

PSEG Mercer Generating Station 2408_B_2 New Jersey Mercer 310 1961 2010

Silver Lake 2008_B_4 Minnesota Olmsted 61 1969 2010

Kingston 3407_B_1 Tennessee Roane 135 1954 2010

Kingston 3407_B_2 Tennessee Roane 135 1954 2010

Kingston 3407_B_3 Tennessee Roane 135 1954 2010

Kingston 3407_B_4 Tennessee Roane 135 1954 2010

Kingston 3407_B_5 Tennessee Roane 177 1955 2010

Kingston 3407_B_6 Tennessee Roane 177 1955 2010

Kingston 3407_B_7 Tennessee Roane 177 1955 2010

Kingston 3407_B_8 Tennessee Roane 177 1955 2010

Kingston 3407_B_9 Tennessee Roane 178 1955 2010

Sioux 2107_B_1 Missouri St. Charles 497 1967 2010

Sioux 2107_B_2 Missouri St. Charles 497 1968 2010

Chesterfield 3797_B_5 Virginia Chesterfield 310 1964 2010

Yorktown 3809_B_1 Virginia York 159 1957 2010

AES Westover 2526_B_11 New York Broome 22 1943 2010

AES Westover 2526_B_12 New York Broome 22 1943 2010

AES Westover 2526_B_13 New York Broome 84 1951 2010

Iatan 2 6065_B_2 Missouri Platte 850 2010 2010

Southwest 6195_B_2 Missouri Greene 300 2010 2010

Trimble Station (LGE) 6071_B_2 Kentucky Trimble 732 2010 2010

Elm Road Generating Station 56068_B_2 Wisconsin Milwaukee 615 2010 2010

Cholla 113_B_3 Arizona Navajo 271 1980 2009

Mayo 6250_B_1A North Carolina Person 362 1983 2009

Mayo 6250_B_1B North Carolina Person 362 1983 2009

Conesville 2840_B_4 Ohio Coshocton 780 1973 2009

G G Allen 2718_B_1 North Carolina Gaston 162 1957 2009

G G Allen 2718_B_2 North Carolina Gaston 162 1957 2009

G G Allen 2718_B_3 North Carolina Gaston 260 1959 2009
4

G G Allen 2718_B_4 North Carolina Gaston 275 1960 2009

G G Allen 2718_B_5 North Carolina Gaston 265 1961 2009

H L Spurlock 6041_B_1 Kentucky Mason 315 1977 2009

Crystal River 628_B_5 Florida Citrus 717 1984 2009

Deerhaven Generating Station 663_B_B2 Florida Alachua 228 1981 2009

Bowen 703_B_2BLR Georgia Bartow 718 1972 2009

Wansley 6052_B_2 Georgia Heard 892 1978 2009

E W Brown 1355_B_1 Kentucky Mercer 94 1957 2009

E W Brown 1355_B_2 Kentucky Mercer 160 1963 2009

E W Brown 1355_B_3 Kentucky Mercer 422 1971 2009

Ghent 1356_B_2 Kentucky Carroll 469 1977 2009

Fayette Power Project 6179_B_1 Texas Fayette 598 1979 2009

Fayette Power Project 6179_B_2 Texas Fayette 598 1980 2009

Morgantown Generating Plant 1573_B_1 Maryland Charles 624 1970 2009

Morgantown Generating Plant 1573_B_2 Maryland Charles 620 1971 2009

PPL Brunner Island 3140_B_1 Pennsylvania York 321 1961 2009

PPL Brunner Island 3140_B_2 Pennsylvania York 378 1965 2009

Keystone 3136_B_1 Pennsylvania Armstrong 850 1967 2009

Keystone 3136_B_2 Pennsylvania Armstrong 850 1968 2009

Bull Run 3396_B_1 Tennessee Anderson 881 1967 2009

Bay Shore 2878_B_4 Ohio Lucas 215 1968 2009

Hatfields Ferry Power Station 3179_B_1 Pennsylvania Greene 530 1969 2009

Hatfields Ferry Power Station 3179_B_2 Pennsylvania Greene 530 1970 2009

Hatfields Ferry Power Station 3179_B_3 Pennsylvania Greene 530 1971 2009

Nebraska City Unit 2 6096_B_2 Nebraska Otoe 663 2009 2009

Cross 130_B_4 South Carolina Berkeley 652 2009 2009

Springerville 8223_B_4 Arizona Apache 400 2009 2009

Sandow 5 82010_B_5 Texas Milam 600 2009 2009

Oak Grove 82011_B_1 Texas Robertson 800 2009 2009

Oak Grove 82011_B_2 Texas Robertson 800 2009 2009

TS Power Plant 82013_B_1 Nevada Eureka 200 2009 2009

Plum Point Energy 82014_B_1 Arkansas Mississippi 665 2009 2009

Comanche 470_B_3 Colorado Pueblo 750 2009 2009

Elm Road Generating Station 56068_B_1 Wisconsin Milwaukee 615 2009 2009

Two Elk Generating Station 55360_B_1 Wyoming Campbell 300 2009 2009

J K Spruce 7097_B_BLR2 Texas Bexar 750 2009 2009

Dallman 963_B_34 Illinois Sangamon 200 2009 2009

Charles R Lowman 56_B_1 Alabama Washington 86 1969 2008

John E Amos 3935_B_1 West Virginia Putnam 800 1971 2008

John E Amos 3935_B_2 West Virginia Putnam 800 1972 2008

Cholla 113_B_4 Arizona Navajo 380 1981 2008

Roxboro 2712_B_1 North Carolina Person 369 1966 2008

Roxboro 2712_B_3A North Carolina Person 341 1973 2008

Roxboro 2712_B_3B North Carolina Person 341 1973 2008

Miami Fort 2832_B_7 Ohio Hamilton 500 1975 2008

Miami Fort 2832_B_8 Ohio Hamilton 500 1978 2008

Cogentrix Virginia Leasing Corp 10071_B_2A Virginia Portsmouth 19 1988 2008

Cogentrix Virginia Leasing Corp 10071_B_2B Virginia Portsmouth 19 1988 2008

Cogentrix Virginia Leasing Corp 10071_B_2C Virginia Portsmouth 19 1988 2008

J M Stuart 2850_B_1 Ohio Adams 585 1971 2008

J M Stuart 2850_B_2 Ohio Adams 597 1970 2008
5

J M Stuart 2850_B_3 Ohio Adams 597 1972 2008

J M Stuart 2850_B_4 Ohio Adams 597 1974 2008

Monroe 1733_B_3 Michigan Monroe 795 1973 2008

Belews Creek 8042_B_1 North Carolina Stokes 1,115 1974 2008

Belews Creek 8042_B_2 North Carolina Stokes 1,115 1975 2008

Bowen 703_B_3BLR Georgia Bartow 902 1974 2008

Bowen 703_B_4BLR Georgia Bartow 929 1975 2008

Hammond 708_B_1 Georgia Floyd 112 1954 2008

Hammond 708_B_2 Georgia Floyd 112 1954 2008

Hammond 708_B_3 Georgia Floyd 112 1955 2008

Hammond 708_B_4 Georgia Floyd 510 1970 2008

Wansley 6052_B_1 Georgia Heard 891 1976 2008

Harding Street 990_B_70 Indiana Marion 435 1973 2008

Cogentrix Hopewell 10377_B_1A Virginia Hopewell (city) 18 1987 2008

Cogentrix Hopewell 10377_B_1B Virginia Hopewell (city) 18 1987 2008

Cogentrix Hopewell 10377_B_1C Virginia Hopewell (city) 18 1987 2008

Ghent 1356_B_4 Kentucky Carroll 478 1984 2008

Council Bluffs 1082_B_3 Iowa Pottawattamie 690 1978 2008

PPL Brunner Island 3140_B_3 Pennsylvania York 749 1969 2008

PPL Montour 3149_B_1 Pennsylvania Montour 774 1972 2008

PPL Montour 3149_B_2 Pennsylvania Montour 766 1973 2008

Comanche 470_B_1 Colorado Pueblo 366 1973 2008

Comanche 470_B_2 Colorado Pueblo 370 1975 2008

Cayuga 1001_B_2 Indiana VermilIon 473 1972 2008

Winyah 6249_B_1 South Carolina Georgetown 295 1975 2008

Winyah 6249_B_2 South Carolina Georgetown 295 1977 2008

Winyah 6249_B_3 South Carolina Georgetown 295 1980 2008

Chesterfield 3797_B_6 Virginia Chesterfield 658 1969 2008

Brayton Point 1619_B_1 Massachusetts Bristo 243 1963 2008

Brayton Point 1619_B_2 Massachusetts Bristo 244 1964 2008

Weston 4078_B_4 Wisconsin Marathon 519 2008 2008

Gorgas 8_B_10 Alabama Walker 690 1972 2007

Gorgas 8_B_8 Alabama Walker 165 1956 2007

Gorgas 8_B_9 Alabama Walker 175 1958 2007

John E Amos 3935_B_3 West Virginia Putnam 1,300 1973 2007

Mountaineer 6264_B_1 West Virginia Mason 1,300 1980 2007

Cardinal 2828_B_1 Ohio Jefferson 600 1967 2007

Cardinal 2828_B_2 Ohio Jefferson 600 1967 2007

Roxboro 2712_B_2 North Carolina Person 639 1968 2007

Roxboro 2712_B_4A North Carolina Person 343 1980 2007

Roxboro 2712_B_4B North Carolina Person 343 1980 2007

Cogentrix Virginia Leasing Corp 10071_B_1A Virginia Portsmouth 19 1988 2007

Cogentrix Virginia Leasing Corp 10071_B_1B Virginia Portsmouth 19 1988 2007

Cogentrix Virginia Leasing Corp 10071_B_1C Virginia Portsmouth 19 1988 2007

Killen Station 6031_B_2 Ohio Adams 615 1982 2007

Marshall 2727_B_2 North Carolina Catawba 378 1966 2007

Marshall 2727_B_3 North Carolina Catawba 657 1969 2007

Cogentrix Hopewell 10377_B_2A Virginia Hopewell (city) 18 1987 2007

Cogentrix Hopewell 10377_B_2B Virginia Hopewell (city) 18 1987 2007

Cogentrix Hopewell 10377_B_2C Virginia Hopewell (city) 18 1987 2007

Ghent 1356_B_3 Kentucky Carroll 478 1981 2007
6

Louisa 6664_B_101 Iowa Louisa 700 1983 2007

Allen S King 1915_B_1 Minnesota Washington 571 1968 2007

Mitchell 3948_B_1 West Virginia Marshall 800 1971 2007

Gibson 6113_B_1 Indiana Gibson 630 1975 2007

Gibson 6113_B_2 Indiana Gibson 628 1975 2007

Winyah 6249_B_4 South Carolina Georgetown 270 1981 2007

Pleasant Prairie 6170_B_2 Wisconsin Kenosha 617 1985 2007

Cross 130_B_3 South Carolina Berkeley 620 2007 2007

Wygen II 55479_B_4 Wyoming Campbell 90 2007 2007

Council Bluffs 1082_B_4 Iowa Pottawattamie 790 2007 2007

Assumed BART Facilities and Units

State County Fac ID Facility Name Unit ID

MI Bay B2840 CE - KARN/WEADOCK EU00036

MI Bay B2840 CE - KARN/WEADOCK EU00037

MI Eaton B4001 LAN. BW&L ERICKSON EU00007

MI Houghton B6553 UP POWER CO / PORTAGE EU00008

MI Huron B2815 DTE - HARBOR BEACH EU00009

MI Ingham B2647 LAN. BW&L Eckert RG00023

MI Ingham B2647 LAN. BW&L Eckert RG00023

MI Ingham B2647 LAN. BW&L Eckert RG00023

MI Ingham B2647 LAN. BW&L Moores Park RG00021

MI Marquette B4261 WE-ENERGIES EU00029

MI Marquette B4261 WE-ENERGIES EU00030

MI Marquette B4261 WE-ENERGIES EU00031

MI Marquette B4261 WE-ENERGIES EU00032

MI Marquette B4261 WE-ENERGIES EU00033

MI Monroe B2816 DTE - MONROE EU00062

MI Monroe B2816 DTE - MONROE EU00068

MI Monroe B2816 DTE - MONROE EU00063

MI Monroe B2816 DTE - MONROE EU00064

MI Ottawa B2835 CE – CAMPBELL EU00062

MI Ottawa B2835 CE – CAMPBELL EU00061

MI Saint Clair B2796 DTE - ST. CLAIR / BELLE RIVER EU00111

MI Saint Clair B6145 DTE – GREENWOOD EU00009

MI Wayne B2132 WYANDOTTE EU00036

MI Wayne B2185 DETROIT PLD, MISTERSKY EU00014

MI Wayne B2811 DTE – TRENTON EU00035

OH Lake 0243160009 CEI., EASTLAKE PLANT B005

OH 0247030013 Orion Power Midwest B012

OH 0285010188 Dept of Public Utilities, City of Orrville B001

OH 0285010188 Dept of Public Utilities, City of Orrville B004

OH 0448020006 Toledo Edison Co., Bay Shore B003

OH 0448020006 Toledo Edison Co., Bay Shore B004

OH 0616000000 Conesville Power Plant B003

OH 0616000000 Conesville Power Plant B004

OH 0616000000 Conesville Power Plant B007

OH 0641050002 Cardinal Power Plant B001

OH 0641050002 Cardinal Power Plant B002
7

OH 0641050002 Cardinal Power Plant B003

OH 0641050002 Cardinal Power Plant B004

OH 0641050002 Cardinal Power Plant B008

OH 0641050002 Cardinal Power Plant B009

OH 0641050002 Cardinal Power Plant B009

OH Jefferson 0641160017 W. H. SAMMIS PLANT B011

OH Jefferson 0641160017 W. H. SAMMIS PLANT B012

OH Jefferson 0641160017 W. H. SAMMIS PLANT B013

OH 0684000000 Muskingum River Power Plant B006

OH Adams 0701000007 DP&L, J.M. Stuart Generating Station B001

OH Adams 0701000007 DP&L, J.M. Stuart Generating Station B002

OH Adams 0701000007 DP&L, J.M. Stuart Generating Station B003

OH Adams 0701000007 DP&L, J.M. Stuart Generating Station B004

OH 0701000060 DP&L, Killen Station B001

OH 1409040243 City of Hamilton Dept of Public Utilities B002

OH 1409040243 City of Hamilton Dept of Public Utilities B008

OH 1409040243 City of Hamilton Dept of Public Utilities B009

OH 1413100008 CG&E W. C. BECKJORD B005

OH 1413100008 CG&E W. C. BECKJORD B006

OH 1431350093 CG&E MIAMI FORT STATION B015

IL Peoria 856 Ameren – Edwards 2

IL Sangamon 963 CWLP – Dallman 31

IL Sangamon 963 CWLP – Dallman 32

IL Christian 876 Dominion – Kincaid 1

IL Christian 876 Dominion – Kincaid 2

WI COLUMBIA 111003090 Alliant Energy-Columbia Generating B20

WI COLUMBIA 111003090 Alliant Energy-Columbia Generating B21

WI COLUMBIA 111003090 Alliant Energy-Columbia Generating B22

WI GRANT 122014530 Alliant Energy, Nelson Dewey B22 (unit 2)

WI MILWAUKEE 241007690 We Energies-Oak Creek Station B26 (Unit 6)

WI MILWAUKEE 241007690 We Energies-Oak Creek Station B27 (Unit 7)

WI MILWAUKEE 241007690 We Energies-Oak Creek Station B28

WI MILWAUKEE 241007800 We Energies-Valley Station B21

WI MILWAUKEE 241007800 We Energies-Valley Station B23

WI MILWAUKEE 241007800 We Energies-Valley Station B24

WI BROWN 405031990 WI Public Service Corp - JP Pulliam B27 (unit 8)

WI SHEBOYGAN 460033090 WP & L Alliant Energy – Edgewater B24 

WI BUFFALO 606034110

Dairyland Power Coop Alma Station 

(J.P. Madgett boilers) B25 (+B26)

WI BUFFALO 606034110 Dairyland Power Coop Alma Station B27

WI VERNON 663020930 Dairyland Power Coop Genoa Station B20

WI VERNON 663020930 Dairyland Power Coop Genoa Station B25

IN Porter 995 Bailly 7

IN Porter 995 Bailly 8

IN Vermillion 1001 Cayuga 1

IN Vermillion 1001 Cayuga 2

IN Montgomery 1024 Crawfordsville 6

IN Warrick 1012 Culley 2
8

IN Warrick 1012 Culley 3

IN Gibson 6113 Gibson 1

IN Gibson 6113 Gibson 2

IN Cass 1032 Logansport 6

IN Sullivan 6213 Merom 1

IN Sullivan 6213 Merom 2

IN LaPorte 997 Michigan City 12

IN Lake 996 Mitchell 11

IN Pike 994 Petersburg 1

IN Pike 994 Petersburg 2

IN Pike 994 Petersburg 3

IN Pike 1043 Ratts 1

IN Pike 1043 Ratts 2

IN Wayne 7335 RPL 2

IN Jasper 6085 Schahfer 14

IN Jasper 6085 Schahfer 15

IN Lake 981 Stateline 4

IN Marion 990 Stout 70

IN Dearborn 988 Tanners Creek 4

IN Vigo 1010 Wabash River 6

IN Warrick 6705 Warrick 4

IA 07-02-005 Cedar Falls Utilities Unit #7 (EU10.1A)

IA 88-01-004

Central Iowa Power Cooperative 

(CIPCO) – Summit Lake Station

CombTurbines (EU 

1/1G, EU2/2G)

IA 70-08-003

Central Iowa Power Cooperative 

(CIPCO) – Fair Station

Unit # 2 (EU 2 & 

EU 2G)

IA 85-01-006 City of Ames - Steam Electric Plant Boiler #7 (EU 2)

IA 29-01-013 Interstate Power & Light - Burlington Main Plant Boiler.

IA 03-03-001 Interstate Power & Light - Lansing

Boiler #4. Sixteen 

units in total.

IA 23-01-014 Interstate Power & Light - ML Kapp

Boiler #2. Six units 

in total.

IA 57-01-042 Interstate Power & Light - Prairie Creek

Boiler #4. Fourteen 

units in total.

IA 78-01-026 MidAmerican Energy Co - Council Bluffs Boiler #3 (EU003)

IA 97-04-010 MidAmerican Energy Co - Neal North

Boilers #1-3 

(EU001 - EU003)

IA 97-04-011 MidAmerican Energy Co - Neal South Boiler #4 (EU003)

IA 70-01-011 Muscatine Power and Water Boiler #8

IA 63-02-005 Pella Municipal Power Plant Boilers #6-8

MN 2709900001 Austin Utilities NE Power Station EU001

MN 2713700027 Hibbing Public Utilities EU003

MN 2703100001 MN Power, Taconite Harbor EU003

MN 2706100004 MN Power, Boswell Energy Center EU003

MN 2701500010 New Ulm Public Utilities EU003 - Boiler 4

MN 2711100002 Otter Tail Power Hoot Lake EU003

MN 2710900011 Rochester Public Utilities, Silver Lake EU003

MN 2710900011 Rochester Public Utilities, Silver Lake EU004

MN 2713700028 Virginia Public Utilities EU003 - Boiler 9

MN 2714100004 Xcel Energy, Sherco EU001, EU002

MN 2716300005 Xcel Energy, Allen S King EU001 - Boiler 1
9

MN 2705300015 Xcel Energy, Riverside EU003 - Boiler 8

MO 290710003 Ameren -Labadie B1, B2, B3, B4

MO 291830001 Ameren - Sioux B1, B2

MO 290990016 Ameren - Rush Island B1, B2

MO 290950031 Auila - Sibley B3 - 5C

MO 291430004 Assoc. Electric - New Madrid

B1(EP-01), B2 

(EP-02)

MO 290770039 City Utilities Springfield - Southwest B1 (E09)

MO 290770005 City Utilities Springfield - James River EO7, EO8

MO 290970001 Empire Distric Electric - Asbury B7

MO 290830001 KC Power and Light - Montrose EP08

MO 290210004 Aqula - Lake Road EP06

MO 291750001 Assoc. Electric - Thomas Hill EP01, EP02

MO 290950021 Trigen - Kansas City B1A

MO 290190002 City of Columbia Municipal Power Plant EP02

MO 291950010 Marshall Munipal Utilities EP05

MO 290950050 Independence Power & Light-Blue Valley B3 (EP05)

WV 3943 Fort Martin

WV 6004 Pleasants

WV 3948 Mitchell

WV 3935 Amos

WV 6264 Mountaineer

WV 3944 Harrison

TN 3396 TVA Bull Run

TN 3399 TVA Cumberland

KY 1363 Cane Run

KY 1364 Mill Creek

KY 6041 Spurlock

KY 1384 John Sherman Cooper

KY 1353 Big Sandy

KY 1356 Ghent

KY 1355 Brown

KY 1374 Owensboro Municipal

KY 1372 Henderson Municipal

KY 1378 Paradise

KY 1361 Coleman

KY 1382 Reid/Henderson 2

KY 6639 Green
Appendix E

Mobile Inventory  

Technical Support Document for

Ohio, Kentucky, Indiana Regional

Council of Governments (OKI)
Mobile Source Emissions Inventory 

for Cincinnati PM2.5 Nonattainment 

Area 

Includes a portion of Dearborn County, Indiana, the counties of Boone, Campbell, 

Kenton in Kentucky, and the counties of Butler, Clermont, Hamilton, and Warren in 

Ohio. Emission estimates for the Year 2005, 2008, 2011, 2015, 2018, and 2021 

developed in support of the PM2.5 State Implementation Plan 

August 2010 (text revised Dec 2010) 

Prepared for the Indiana Department of Environmental Management, the Kentucky Division 

for Air Quality and the Ohio Environmental Protection Agency by 

OKI Regional Council of Governments

Acknowledgments 

Title Mobile Source Emissions Inventory for Cincinnati PM2.5 Nonattainment 

Area 

Abstract This report was prepared for the Indiana Department of Environmental 

Management, the Kentucky Division for Air Quality and the Ohio 

Environmental Protection Agency. The Cincinnati PM2.5 nonattainment 

area includes a portion of Dearborn County Indiana, the counties of Boone, 

Campbell, Kenton in Kentucky, and the counties of Butler, Clermont, 

Hamilton, and Warren in Ohio. This report includes emission estimates for 

the years 2005, 2008, 2011, 2015, 2018 and 2021 was generated to support 

the attainment SIPs for the annual PM2.5 standard. EPA’s Motor Vehicle 

Emission Simulation (MOVES) 2010 was used to generate the emission 

rates. 

Date August 2010 

Agency Ohio-Kentucky-Indiana Regional Council of Governments 

 Mark Policinski, Executive Director 

 Robert Koehler, P.E., Deputy Director 

 

Project Manager Andrew J. Reser, AICP 

Project Staff Harikishan Perugu, PTP 

 Larry Buckler 

 

 

The preparation of this document was financed cooperatively by the Federal Highway Administration, 

the Federal Transit Administration, the Commonwealth of Kentucky Transportation Cabinet, the Ohio 

Department of Transportation, and the units of local and county government in the OKI region. The 

opinions, findings, and conclusions expressed in this document are those of the OKI Regional Council of 

Governments and are not necessarily those of the U.S. Department of Transportation. This report does 

not constitute a standard, specification, or regulation. 

MOBILE Source Emissions Inventory for the 

Cincinnati PM2.5 nonattainment area 

This report was prepared for the Indiana Department of Environmental Management, the Kentucky 

Division for Air Quality and the Ohio Environmental Protection Agency. The Cincinnati PM2.5 

nonattainment area includes a portion of Dearborn County Indiana, the counties of Boone, Campbell, 

Kenton in Kentucky, and the counties of Butler, Clermont, Hamilton, and Warren in Ohio. This report 

includes emission estimates for the years 2005, 2008, 2011, 2015, 2018 and 2021 was generated to 

support the attainment SIPs for the annual PM2.5 standard. EPA’s Motor Vehicle Emissions Simulator 

(MOVES) 2010 model was used to generate the vehicle emission rates. In December 2009, MOVES 

replaced MOBILE6.2 as the EPA’s official emission factor model. Technical details on OKI’s use of 

MOVES can be found in the Appendix. The OKI travel demand model version 7.6 was used to generate 

VMT and speed estimates. MOVES emission rates were generated for direct PM2.5, PM2.5 tirewear, 

PM2.5 brakewear, NOx

 and SO2. 

OKI, as the MPO, is responsible for transportation planning and air quality/transportation conformity.

Transportation conformity is a mechanism to ensure that federal funding and approval are given to 

those transportation activities that are consistent with the air quality goals of the State Implementation 

Plans (SIPs) for Indiana, Kentucky and Ohio. The SIPs include an inventory of projected emissions from 

vehicles. One or more of the analysis years in the projected inventory may be designated as the motor

vehicle emissions budget (MVEB). This budget establishes a maximum allowable limit on future 

emissions from vehicles (mobile sources). OKI’s transportation plans and programs must be shown to 

be in conformity with all SIP provisions. The conformity process is a quantitative analysis, using 

U.S.EPA’s vehicle emissions software (currently MOVES), demonstrating that forecasted regional vehicle

emissions do not exceed the established budget. 

Table 1 shows daily and annual mobile source emissions for the combined Indiana and Ohio portions of 

the nonattainment area, as well as the Kentucky portion of the nonattainment area. Separate MVEB’s 

are typically designated for these two areas. Although official federal guidance on the use of MOVES for 

PM2.5 SIP development was not available at the time of this analysis, the Federal Highway 

Administration (FHWA) along with state and local air quality staff were consulted periodically 

throughout the development of these emissions. An additional safety margin should be added to the 

MVEB’s due uncertainty with growth assumptions utilized in the OKI travel demand model and 

uncertainty regarding the use of MOVES. Daily and annual mobile source emissions for each county in 

the nonattainment area are shown in Table 2. 
Table 1. Mobile Source Emissions for the Cincinnati PM2.5 Nonattainment Area (tons)

Year Pollutant Name DailyEmissions AnnualEmissions

Kentucky Portion of NA Area

2005 Vehicle Population: 364,081 Daily VMT: 9,621,110 Annual VMT: 3,289,109,202

Oxides of Nitrogen 39.10 13,496.54

Primary Exhaust PM2.5 - Total 1.36 466.23

Primary PM2.5 - Brakewear Particulate 0.16 54.04

Primary PM2.5 - Tirewear Particulate 0.05 17.52

Sulfur Dioxide (SO2) 0.12 41.46

2008 Vehicle Population: 375,873 Daily VMT: 9,991,179 Annual VMT: 3,425,339,505

Oxides of Nitrogen 37.91 13,114.20

Primary Exhaust PM2.5 - Total 1.64 562.84

Primary PM2.5 - Brakewear Particulate 0.18 62.10

Primary PM2.5 - Tirewear Particulate 0.06 20.70

Sulfur Dioxide (SO2) 0.12 42.74

2011 Vehicle Population: 381,911 Daily VMT: 10,490,143 Annual VMT: 3,587,796,186

Oxides of Nitrogen 29.33 10,141.52

Primary Exhaust PM2.5 - Total 1.19 407.74

Primary PM2.5 - Brakewear Particulate 0.20 68.38

Primary PM2.5 - Tirewear Particulate 0.07 22.68

Sulfur Dioxide (SO2) 0.13 45.36

2015 Vehicle Population: 394,278 Daily VMT: 11,495,496 Annual VMT: 3,931,385,741

Oxides of Nitrogen 20.18 6,996.21

Primary Exhaust PM2.5 - Total 0.78 267.30

Primary PM2.5 - Brakewear Particulate 0.23 77.94

Primary PM2.5 - Tirewear Particulate 0.08 25.88

Sulfur Dioxide (SO2) 0.15 50.50

2018 Vehicle Population: 403,817 Daily VMT: 12,173,549 Annual VMT: 4,163,203,435

Oxides of Nitrogen 15.78 5,480.81

Primary Exhaust PM2.5 - Total 0.59 202.15

Primary PM2.5 - Brakewear Particulate 0.27 91.15

Primary PM2.5 - Tirewear Particulate 0.09 30.09

Sulfur Dioxide (SO2) 0.16 56.28

2021 Vehicle Population: 413,587 Daily VMT: 12,534,236 Annual VMT: 4,286,834,360

Oxides of Nitrogen 12.75 4,435.96

Primary Exhaust PM2.5 - Total 0.43 146.79

Primary PM2.5 - Brakewear Particulate 0.28 96.84

Primary PM2.5 - Tirewear Particulate 0.09 31.74

Sulfur Dioxide (SO2) 0.17 58.63

17-Aug-10 MOVES 2010 and OKI Travel Demand Model v7.6 Page 1 of 2
Year Pollutant Name DailyEmissions AnnualEmissions

Ohio/Indiana Portion of NA Area

2005 Vehicle Population: 1,754,582 Daily VMT: 39,564,030 Annual VMT: 13,541,324,003

Oxides of Nitrogen 168.89 58,423.36

Primary Exhaust PM2.5 - Total 5.74 1,979.63

Primary PM2.5 - Brakewear Particulate 0.65 223.20

Primary PM2.5 - Tirewear Particulate 0.20 69.67

Sulfur Dioxide (SO2) 0.48 165.35

2008 Vehicle Population: 1,811,406 Daily VMT: 40,858,751 Annual VMT: 14,015,754,874

Oxides of Nitrogen 148.02 51,357.02

Primary Exhaust PM2.5 - Total 4.85 1,675.04

Primary PM2.5 - Brakewear Particulate 0.80 273.84

Primary PM2.5 - Tirewear Particulate 0.25 85.37

Sulfur Dioxide (SO2) 0.54 185.13

2011 Vehicle Population: 1,840,505 Daily VMT: 42,044,841 Annual VMT: 14,383,526,419

Oxides of Nitrogen 135.95 47,061.53

Primary Exhaust PM2.5 - Total 5.54 1,904.61

Primary PM2.5 - Brakewear Particulate 0.85 290.00

Primary PM2.5 - Tirewear Particulate 0.27 91.52

Sulfur Dioxide (SO2) 0.53 182.01

2015 Vehicle Population: 1,900,111 Daily VMT: 43,316,281 Annual VMT: 14,830,453,053

Oxides of Nitrogen 89.45 31,064.21

Primary Exhaust PM2.5 - Total 3.57 1,227.86

Primary PM2.5 - Brakewear Particulate 0.82 280.25

Primary PM2.5 - Tirewear Particulate 0.26 90.54

Sulfur Dioxide (SO2) 0.53 182.69

2018 Vehicle Population: 1,946,080 Daily VMT: 45,314,292 Annual VMT: 15,513,701,656

Oxides of Nitrogen 70.34 24,451.43

Primary Exhaust PM2.5 - Total 2.78 958.57

Primary PM2.5 - Brakewear Particulate 0.90 307.39

Primary PM2.5 - Tirewear Particulate 0.29 99.03

Sulfur Dioxide (SO2) 0.57 195.09

2021 Vehicle Population: 1,993,161 Daily VMT: 46,689,707 Annual VMT: 15,521,916,278

Oxides of Nitrogen 55.50 18,911.05

Primary Exhaust PM2.5 - Total 2.10 705.30

Primary PM2.5 - Brakewear Particulate 0.96 320.17

Primary PM2.5 - Tirewear Particulate 0.31 102.89

Sulfur Dioxide (SO2) 0.60 199.14

17-Aug-10 MOVES 2010 and OKI Travel Demand Model v7.6 Page 2 of 2
Table 2. Mobile Source Emissions by County for the Cincinnati PM2.5 Nonattainment Area (tons)

County Year Pollutant Name DailyEmissions AnnualEmissions

Indiana

Dearborn NA

2005 Vehicle Population: 24,915 Daily VMT: 578,642 Annual VMT: 196,738,031

Oxides of Nitrogen 2.40 865.46

Primary Exhaust PM2.5 - Total 0.08 29.68

Primary PM2.5 - Brakewear Particulate 0.01 3.28

Primary PM2.5 - Tirewear Particulate 0.00 1.02

Sulfur Dioxide (SO2) 0.01 2.45

2008 Vehicle Population: 25,722 Daily VMT: 587,583 Annual VMT: 199,778,078

Oxides of Nitrogen 2.09 748.81

Primary Exhaust PM2.5 - Total 0.07 24.72

Primary PM2.5 - Brakewear Particulate 0.01 3.94

Primary PM2.5 - Tirewear Particulate 0.00 1.23

Sulfur Dioxide (SO2) 0.01 2.69

2011 Vehicle Population: 26,135 Daily VMT: 605,621 Annual VMT: 205,911,005

Oxides of Nitrogen 1.92 685.40

Primary Exhaust PM2.5 - Total 0.08 27.88

Primary PM2.5 - Brakewear Particulate 0.01 4.19

Primary PM2.5 - Tirewear Particulate 0.00 1.32

Sulfur Dioxide (SO2) 0.01 2.65

2015 Vehicle Population: 26,982 Daily VMT: 657,779 Annual VMT: 223,644,622

Oxides of Nitrogen 1.31 482.33

Primary Exhaust PM2.5 - Total 0.05 19.43

Primary PM2.5 - Brakewear Particulate 0.01 4.32

Primary PM2.5 - Tirewear Particulate 0.00 1.39

Sulfur Dioxide (SO2) 0.01 2.87

2018 Vehicle Population: 27,635 Daily VMT: 684,362 Annual VMT: 232,682,971

Oxides of Nitrogen 1.03 376.85

Primary Exhaust PM2.5 - Total 0.04 15.09

Primary PM2.5 - Brakewear Particulate 0.01 4.70

Primary PM2.5 - Tirewear Particulate 0.00 1.51

Sulfur Dioxide (SO2) 0.01 3.04

2021 Vehicle Population: 28,303 Daily VMT: 706,829 Annual VMT: 240,321,759

Oxides of Nitrogen 0.81 297.95

Primary Exhaust PM2.5 - Total 0.03 11.44

Primary PM2.5 - Brakewear Particulate 0.01 5.05

Primary PM2.5 - Tirewear Particulate 0.00 1.62

Sulfur Dioxide (SO2) 0.01 3.19

17-Aug-10 MOVES 2010 and OKI Travel Demand Model v7.6 Page 1 of 8
County Year Pollutant Name DailyEmissions AnnualEmissions

Kentucky

Boone

2005 Vehicle Population: 129,823 Daily VMT: 3,924,117 Annual VMT: 1,273,226,967

Oxides of Nitrogen 14.94 5,126.88

Primary Exhaust PM2.5 - Total 0.52 177.58

Primary PM2.5 - Brakewear Particulate 0.06 20.86

Primary PM2.5 - Tirewear Particulate 0.02 6.77

Sulfur Dioxide (SO2) 0.05 15.91

2008 Vehicle Population: 134,028 Daily VMT: 4,076,584 Annual VMT: 1,350,001,539

Oxides of Nitrogen 14.73 5,067.94

Primary Exhaust PM2.5 - Total 0.64 219.29

Primary PM2.5 - Brakewear Particulate 0.07 24.42

Primary PM2.5 - Tirewear Particulate 0.02 8.14

Sulfur Dioxide (SO2) 0.05 16.71

2011 Vehicle Population: 136,181 Daily VMT: 4,383,716 Annual VMT: 1,448,879,491

Oxides of Nitrogen 11.61 3,990.01

Primary Exhaust PM2.5 - Total 0.48 162.47

Primary PM2.5 - Brakewear Particulate 0.08 27.55

Primary PM2.5 - Tirewear Particulate 0.03 9.14

Sulfur Dioxide (SO2) 0.05 18.16

2015 Vehicle Population: 140,590 Daily VMT: 4,950,741 Annual VMT: 1,628,041,282

Oxides of Nitrogen 8.11 2,788.45

Primary Exhaust PM2.5 - Total 0.32 108.49

Primary PM2.5 - Brakewear Particulate 0.09 32.17

Primary PM2.5 - Tirewear Particulate 0.03 10.69

Sulfur Dioxide (SO2) 0.06 20.67

2018 Vehicle Population: 143,991 Daily VMT: 5,260,102 Annual VMT: 1,729,595,156

Oxides of Nitrogen 6.34 2,182.28

Primary Exhaust PM2.5 - Total 0.24 82.19

Primary PM2.5 - Brakewear Particulate 0.11 37.76

Primary PM2.5 - Tirewear Particulate 0.04 12.47

Sulfur Dioxide (SO2) 0.07 23.14

2021 Vehicle Population: 147,476 Daily VMT: 5,478,224 Annual VMT: 1,800,571,684

Oxides of Nitrogen 5.14 1,772.72

Primary Exhaust PM2.5 - Total 0.18 60.19

Primary PM2.5 - Brakewear Particulate 0.12 40.56

Primary PM2.5 - Tirewear Particulate 0.04 13.30

Sulfur Dioxide (SO2) 0.07 24.37

17-Aug-10 MOVES 2010 and OKI Travel Demand Model v7.6 Page 2 of 8
County Year Pollutant Name DailyEmissions AnnualEmissions

Campbell

2005 Vehicle Population: 86,065 Daily VMT: 2,286,217 Annual VMT: 741,790,595

Oxides of Nitrogen 8.87 3,041.21

Primary Exhaust PM2.5 - Total 0.31 104.22

Primary PM2.5 - Brakewear Particulate 0.04 12.14

Primary PM2.5 - Tirewear Particulate 0.01 3.94

Sulfur Dioxide (SO2) 0.03 9.30

2008 Vehicle Population: 88,853 Daily VMT: 2,339,542 Annual VMT: 774,762,718

Oxides of Nitrogen 8.63 2,988.33

Primary Exhaust PM2.5 - Total 0.37 127.73

Primary PM2.5 - Brakewear Particulate 0.04 14.05

Primary PM2.5 - Tirewear Particulate 0.01 4.68

Sulfur Dioxide (SO2) 0.03 9.69

2011 Vehicle Population: 90,279 Daily VMT: 2,421,600 Annual VMT: 800,372,692

Oxides of Nitrogen 6.61 2,287.81

Primary Exhaust PM2.5 - Total 0.27 91.36

Primary PM2.5 - Brakewear Particulate 0.04 15.26

Primary PM2.5 - Tirewear Particulate 0.01 5.06

Sulfur Dioxide (SO2) 0.03 10.15

2015 Vehicle Population: 93,204 Daily VMT: 2,663,159 Annual VMT: 875,774,487

Oxides of Nitrogen 4.55 1,570.14

Primary Exhaust PM2.5 - Total 0.17 59.30

Primary PM2.5 - Brakewear Particulate 0.05 17.31

Primary PM2.5 - Tirewear Particulate 0.02 5.75

Sulfur Dioxide (SO2) 0.03 11.21

2018 Vehicle Population: 95,458 Daily VMT: 2,771,476 Annual VMT: 911,300,097

Oxides of Nitrogen 3.52 1,216.21

Primary Exhaust PM2.5 - Total 0.13 44.14

Primary PM2.5 - Brakewear Particulate 0.06 19.90

Primary PM2.5 - Tirewear Particulate 0.02 6.57

Sulfur Dioxide (SO2) 0.04 12.28

2021 Vehicle Population: 97,768 Daily VMT: 2,849,127 Annual VMT: 936,445,352

Oxides of Nitrogen 2.84 985.28

Primary Exhaust PM2.5 - Total 0.09 32.07

Primary PM2.5 - Brakewear Particulate 0.06 21.10

Primary PM2.5 - Tirewear Particulate 0.02 6.92

Sulfur Dioxide (SO2) 0.04 12.77

17-Aug-10 MOVES 2010 and OKI Travel Demand Model v7.6 Page 3 of 8
County Year Pollutant Name DailyEmissions AnnualEmissions

Kenton

2005 Vehicle Population: 148,193 Daily VMT: 3,927,743 Annual VMT: 1,274,091,641

Oxides of Nitrogen 15.29 5,328.44

Primary Exhaust PM2.5 - Total 0.53 184.43

Primary PM2.5 - Brakewear Particulate 0.06 21.04

Primary PM2.5 - Tirewear Particulate 0.02 6.82

Sulfur Dioxide (SO2) 0.05 16.24

2008 Vehicle Population: 152,992 Daily VMT: 3,927,332 Annual VMT: 1,300,575,248

Oxides of Nitrogen 14.55 5,057.93

Primary Exhaust PM2.5 - Total 0.62 215.81

Primary PM2.5 - Brakewear Particulate 0.07 23.63

Primary PM2.5 - Tirewear Particulate 0.02 7.87

Sulfur Dioxide (SO2) 0.05 16.34

2011 Vehicle Population: 155,451 Daily VMT: 4,049,886 Annual VMT: 1,338,544,003

Oxides of Nitrogen 11.11 3,863.70

Primary Exhaust PM2.5 - Total 0.45 153.90

Primary PM2.5 - Brakewear Particulate 0.07 25.57

Primary PM2.5 - Tirewear Particulate 0.02 8.48

Sulfur Dioxide (SO2) 0.05 17.05

2015 Vehicle Population: 160,484 Daily VMT: 4,341,124 Annual VMT: 1,427,569,972

Oxides of Nitrogen 7.51 2,637.63

Primary Exhaust PM2.5 - Total 0.29 99.51

Primary PM2.5 - Brakewear Particulate 0.08 28.45

Primary PM2.5 - Tirewear Particulate 0.03 9.44

Sulfur Dioxide (SO2) 0.05 18.62

2018 Vehicle Population: 164,368 Daily VMT: 4,629,694 Annual VMT: 1,522,308,182

Oxides of Nitrogen 5.93 2,082.32

Primary Exhaust PM2.5 - Total 0.22 75.82

Primary PM2.5 - Brakewear Particulate 0.10 33.49

Primary PM2.5 - Tirewear Particulate 0.03 11.04

Sulfur Dioxide (SO2) 0.06 20.86

2021 Vehicle Population: 168,343 Daily VMT: 4,715,306 Annual VMT: 1,549,817,325

Oxides of Nitrogen 4.76 1,677.96

Primary Exhaust PM2.5 - Total 0.16 54.53

Primary PM2.5 - Brakewear Particulate 0.10 35.19

Primary PM2.5 - Tirewear Particulate 0.03 11.52

Sulfur Dioxide (SO2) 0.06 21.48

17-Aug-10 MOVES 2010 and OKI Travel Demand Model v7.6 Page 4 of 8
County Year Pollutant Name DailyEmissions AnnualEmissions

Ohio

Butler

2005 Vehicle Population: 401,759 Daily VMT: 7,452,293 Annual VMT: 2,469,168,490

Oxides of Nitrogen 32.00 10,910.37

Primary Exhaust PM2.5 - Total 1.06 361.06

Primary PM2.5 - Brakewear Particulate 0.12 40.31

Primary PM2.5 - Tirewear Particulate 0.04 12.60

Sulfur Dioxide (SO2) 0.09 30.01

2008 Vehicle Population: 414,771 Daily VMT: 7,745,693 Annual VMT: 2,598,061,793

Oxides of Nitrogen 28.56 9,803.70

Primary Exhaust PM2.5 - Total 0.91 311.45

Primary PM2.5 - Brakewear Particulate 0.15 50.45

Primary PM2.5 - Tirewear Particulate 0.05 15.74

Sulfur Dioxide (SO2) 0.10 34.25

2011 Vehicle Population: 421,434 Daily VMT: 8,050,709 Annual VMT: 2,693,718,927

Oxides of Nitrogen 26.50 9,074.89

Primary Exhaust PM2.5 - Total 1.05 356.91

Primary PM2.5 - Brakewear Particulate 0.16 53.99

Primary PM2.5 - Tirewear Particulate 0.05 17.06

Sulfur Dioxide (SO2) 0.10 34.00

2015 Vehicle Population: 435,082 Daily VMT: 8,361,495 Annual VMT: 2,792,190,918

Oxides of Nitrogen 17.64 6,064.61

Primary Exhaust PM2.5 - Total 0.68 231.78

Primary PM2.5 - Brakewear Particulate 0.16 52.42

Primary PM2.5 - Tirewear Particulate 0.05 16.96

Sulfur Dioxide (SO2) 0.10 34.28

2018 Vehicle Population: 445,608 Daily VMT: 8,806,051 Annual VMT: 2,940,852,857

Oxides of Nitrogen 13.98 4,813.27

Primary Exhaust PM2.5 - Total 0.54 182.29

Primary PM2.5 - Brakewear Particulate 0.17 57.91

Primary PM2.5 - Tirewear Particulate 0.06 18.68

Sulfur Dioxide (SO2) 0.11 36.85

2021 Vehicle Population: 456,389 Daily VMT: 9,150,040 Annual VMT: 2,966,040,396

Oxides of Nitrogen 11.13 3,757.91

Primary Exhaust PM2.5 - Total 0.41 135.39

Primary PM2.5 - Brakewear Particulate 0.19 60.81

Primary PM2.5 - Tirewear Particulate 0.06 19.56

Sulfur Dioxide (SO2) 0.12 37.90

17-Aug-10 MOVES 2010 and OKI Travel Demand Model v7.6 Page 5 of 8
County Year Pollutant Name DailyEmissions AnnualEmissions

Clermont

2005 Vehicle Population: 232,380 Daily VMT: 5,083,336 Annual VMT: 1,684,261,582

Oxides of Nitrogen 21.21 7,295.87

Primary Exhaust PM2.5 - Total 0.72 245.48

Primary PM2.5 - Brakewear Particulate 0.08 27.67

Primary PM2.5 - Tirewear Particulate 0.03 8.64

Sulfur Dioxide (SO2) 0.06 20.51

2008 Vehicle Population: 239,906 Daily VMT: 5,262,494 Annual VMT: 1,765,146,867

Oxides of Nitrogen 18.81 6,516.40

Primary Exhaust PM2.5 - Total 0.61 211.40

Primary PM2.5 - Brakewear Particulate 0.10 34.46

Primary PM2.5 - Tirewear Particulate 0.03 10.74

Sulfur Dioxide (SO2) 0.07 23.32

2011 Vehicle Population: 243,760 Daily VMT: 5,489,550 Annual VMT: 1,836,770,645

Oxides of Nitrogen 17.48 6,039.51

Primary Exhaust PM2.5 - Total 0.71 243.25

Primary PM2.5 - Brakewear Particulate 0.11 37.00

Primary PM2.5 - Tirewear Particulate 0.03 11.68

Sulfur Dioxide (SO2) 0.07 23.23

2015 Vehicle Population: 251,654 Daily VMT: 5,687,704 Annual VMT: 1,899,319,930

Oxides of Nitrogen 11.54 3,993.63

Primary Exhaust PM2.5 - Total 0.46 156.92

Primary PM2.5 - Brakewear Particulate 0.11 35.82

Primary PM2.5 - Tirewear Particulate 0.03 11.58

Sulfur Dioxide (SO2) 0.07 23.34

2018 Vehicle Population: 257,742 Daily VMT: 5,952,609 Annual VMT: 1,987,922,558

Oxides of Nitrogen 9.09 3,146.47

Primary Exhaust PM2.5 - Total 0.36 122.57

Primary PM2.5 - Brakewear Particulate 0.12 39.31

Primary PM2.5 - Tirewear Particulate 0.04 12.67

Sulfur Dioxide (SO2) 0.07 24.94

2021 Vehicle Population: 263,978 Daily VMT: 6,186,447 Annual VMT: 2,005,373,961

Oxides of Nitrogen 7.22 2,449.31

Primary Exhaust PM2.5 - Total 0.27 90.84

Primary PM2.5 - Brakewear Particulate 0.12 41.28

Primary PM2.5 - Tirewear Particulate 0.04 13.27

Sulfur Dioxide (SO2) 0.08 25.66

17-Aug-10 MOVES 2010 and OKI Travel Demand Model v7.6 Page 6 of 8
County Year Pollutant Name DailyEmissions AnnualEmissions

Hamilton

2005 Vehicle Population: 862,422 Daily VMT: 21,859,473 Annual VMT: 7,241,536,812

Oxides of Nitrogen 89.30 31,127.09

Primary Exhaust PM2.5 - Total 3.06 1,064.67

Primary PM2.5 - Brakewear Particulate 0.35 119.94

Primary PM2.5 - Tirewear Particulate 0.11 37.41

Sulfur Dioxide (SO2) 0.26 88.85

2008 Vehicle Population: 890,352 Daily VMT: 22,124,524 Annual VMT: 7,421,012,594

Oxides of Nitrogen 77.45 27,020.93

Primary Exhaust PM2.5 - Total 2.56 889.81

Primary PM2.5 - Brakewear Particulate 0.42 145.42

Primary PM2.5 - Tirewear Particulate 0.13 45.31

Sulfur Dioxide (SO2) 0.28 98.30

2011 Vehicle Population: 904,655 Daily VMT: 22,426,043 Annual VMT: 7,503,619,525

Oxides of Nitrogen 70.18 24,435.59

Primary Exhaust PM2.5 - Total 2.88 997.06

Primary PM2.5 - Brakewear Particulate 0.44 151.73

Primary PM2.5 - Tirewear Particulate 0.14 47.86

Sulfur Dioxide (SO2) 0.28 95.30

2015 Vehicle Population: 933,953 Daily VMT: 22,849,516 Annual VMT: 7,630,239,650

Oxides of Nitrogen 45.58 15,925.19

Primary Exhaust PM2.5 - Total 1.83 634.62

Primary PM2.5 - Brakewear Particulate 0.42 144.67

Primary PM2.5 - Tirewear Particulate 0.14 46.71

Sulfur Dioxide (SO2) 0.27 94.43

2018 Vehicle Population: 956,548 Daily VMT: 23,630,577 Annual VMT: 7,891,625,119

Oxides of Nitrogen 35.51 12,422.37

Primary Exhaust PM2.5 - Total 1.41 490.62

Primary PM2.5 - Brakewear Particulate 0.45 156.90

Primary PM2.5 - Tirewear Particulate 0.15 50.52

Sulfur Dioxide (SO2) 0.29 99.78

2021 Vehicle Population: 979,689 Daily VMT: 24,098,721 Annual VMT: 7,811,745,310

Oxides of Nitrogen 27.80 9,530.16

Primary Exhaust PM2.5 - Total 1.06 357.87

Primary PM2.5 - Brakewear Particulate 0.48 161.69

Primary PM2.5 - Tirewear Particulate 0.15 51.92

Sulfur Dioxide (SO2) 0.30 100.82

17-Aug-10 MOVES 2010 and OKI Travel Demand Model v7.6 Page 7 of 8
County Year Pollutant Name DailyEmissions AnnualEmissions

Warren

2005 Vehicle Population: 233,106 Daily VMT: 5,884,222 Annual VMT: 1,949,619,088

Oxides of Nitrogen 23.98 8,224.57

Primary Exhaust PM2.5 - Total 0.82 278.74

Primary PM2.5 - Brakewear Particulate 0.09 32.00

Primary PM2.5 - Tirewear Particulate 0.03 10.00

Sulfur Dioxide (SO2) 0.07 23.54

2008 Vehicle Population: 240,655 Daily VMT: 6,057,344 Annual VMT: 2,031,755,542

Oxides of Nitrogen 21.11 7,267.18

Primary Exhaust PM2.5 - Total 0.69 237.65

Primary PM2.5 - Brakewear Particulate 0.12 39.57

Primary PM2.5 - Tirewear Particulate 0.04 12.34

Sulfur Dioxide (SO2) 0.08 26.57

2011 Vehicle Population: 244,521 Daily VMT: 6,406,290 Annual VMT: 2,143,506,318

Oxides of Nitrogen 19.88 6,826.15

Primary Exhaust PM2.5 - Total 0.82 279.53

Primary PM2.5 - Brakewear Particulate 0.13 43.09

Primary PM2.5 - Tirewear Particulate 0.04 13.60

Sulfur Dioxide (SO2) 0.08 26.83

2015 Vehicle Population: 252,440 Daily VMT: 6,842,835 Annual VMT: 2,285,057,933

Oxides of Nitrogen 13.37 4,598.44

Primary Exhaust PM2.5 - Total 0.54 185.12

Primary PM2.5 - Brakewear Particulate 0.13 43.02

Primary PM2.5 - Tirewear Particulate 0.04 13.91

Sulfur Dioxide (SO2) 0.08 27.77

2018 Vehicle Population: 258,547 Daily VMT: 7,368,042 Annual VMT: 2,460,618,151

Oxides of Nitrogen 10.73 3,692.47

Primary Exhaust PM2.5 - Total 0.43 148.00

Primary PM2.5 - Brakewear Particulate 0.14 48.57

Primary PM2.5 - Tirewear Particulate 0.05 15.66

Sulfur Dioxide (SO2) 0.09 30.49

2021 Vehicle Population: 264,802 Daily VMT: 7,707,508 Annual VMT: 2,498,434,852

Oxides of Nitrogen 8.54 2,875.72

Primary Exhaust PM2.5 - Total 0.33 109.76

Primary PM2.5 - Brakewear Particulate 0.16 51.34

Primary PM2.5 - Tirewear Particulate 0.05 16.51

Sulfur Dioxide (SO2) 0.10 31.58

17-Aug-10 MOVES 2010 and OKI Travel Demand Model v7.6 Page 8 of 8
Mobile Source Emission Forecast Process 

Emission Factor Model 

OKI’s conformity assessment utilized U.S.EPA’s emissions model MOVES 2010 to develop emission 

factors for SO2, NOX and PM2.5. Table 3 summarizes the settings used in the MOVES run specification 

file. Table 4 lists the data used in the MOVES County-Data Manager. Further details on the use of 

MOVES are found in the Appendix. 

Table 3 

MOVES RunSpec Parameter Settings

MOVES Version 2009/05/15, MOVES default 

database 20100515

Scale County, Emission Rates

Time Span Time aggregation = Hour

1 month representing average annual 

temperatures 

All hours of day selected 

Weekdays only 

Geographic Bounds 2 Custom Domains – 4 Ohio counties, 3 Kentucky 

counties 

Vehicles/Equipment All source types, gasoline and diesel

Road Type All road types including off-network

Pollutants and Processes NOx, All PM2.5 categories, SO2, Total Energy 

Consumption 

Strategies Modified AVFT strategy file to reflect 0% CNG 

buses in the transit fleet 

General Output Units= grams, joules and miles

Output Emissions Time = hour, Location =county, on-road emission 

rates by road type and source use type. 

Advanced Performance none

Table 4 

County Data Manager Data Source

Source Type Population Local and default. Local data (2010) from KYTC and ODOT from 

motor vehicle registration data. Default data used for source types 

41, 61 and 62. In addition , default data for source types 31, 32 and 

54 used for KY. 

Vehicle Type VMT Local and default. HPMSVTypeYear VMT=daily VMT from OKI travel 

demand model with EPA’s daily to annual VMT converter applied. 

monthVMTFraction = default. dayVMTFraction=default,

hourVMTFraction=local. 

I/M Programs Default modified to reflect discontinued I/M program
Fuel Formulation Default

Fuel Supply Default

Meteorology Data Local. Kentucky Division for Air Quality.

Ramp Fraction Local. Ramp emissions calculated outside of MOVES

Road Type Distribution Local. OKI travel demand model.

Age Distribution Local and default. Local data (2010) from KYTC and ODOT from 

motor vehicle registration data. Default data used for source types 

41, 61 and 62. In addition , default data for source types 31, 32 and 

54 used for KY. 

Average Speed Distribution Local. OKI travel demand model.

OKI Travel Demand Model 

Transportation system performance was estimated using the OKI Travel Demand Model Version 7.6. 

The OKI Travel Demand Model is composed of TRANPLAN programs, CUBE Voyager programs and a 

series of FORTRAN programs written by OKI. It is a state of the practice model that uses the standard 4 

phase sequential modeling approach of trip generation, distribution, modal choice and assignment. The 

model uses demographic and land use data and capacity and free-flow speed characteristics for each 

roadway segment in the network to produce a “loaded” highway network with forecasted traffic 

volumes with revised speeds based on specified speed/capacity relationships. 

Travel analysis zones are the basic geographic unit for estimating travel in the OKI model. The OKI region 

is subdivided into 1608 traffic analysis zones to permit detail as well as manageability. A variety of 

socioeconomic data items are used in the OKI transportation planning process. These data are used 

primarily to forecast future travel patterns by serving as independent variables in OKI trip generation 

equations. The following categories of planning data are utilized: 

• Population (household and group quarter) 

• Households 

• Household vehicles 

• Employment (by employment category and zone of work) 

• Labor force participation (by zone of residence) 

• Area type 

The principal data requirements of the OKI travel demand forecasting model are population and 

employment. From these variables, other characteristics including households, labor force, and personal 

vehicles may be derived. Chapter 5 of OKI 2030 Regional Transportation Plan 2008 Update provides a 

complete demographic overview of the region. 

OKI utilizes both base year (2005) and future year data (2010, 2020 and 2030) in the planning process.

Planning data are maintained at the Traffic Analysis Zone (TAZ) level, and originate in the 2000 Census of 

Population and Housing. Base year 2005 and future year data for each variable are developed through 

various methods. More detailed explanation of base year and future year data generation for each of 

the above-mentioned categories of planning data follows. All of the variables represent the latest OKI 

planning assumptions. 
Population 

Base and Future Year Data: Population data for base year 2005 and future years 2010, 2020 and 2030 

originate with the 2000 Census of Population and Housing. Utilizing ArcView GIS, population data at the 

zonal level for 2000 was derived from the area proportion allocation of block level population. 

As a tri-state regional planning agency, OKI uses county level projections as prepared by the respective 

state data centers (Ohio Department of Development Office of Strategic Research, Kentucky State Data 

Center and Indiana Business Research Center) as control totals. The most current projections (years 

2005 to 2030) were released by the Ohio and Indiana state data centers in 2003 and the Kentucky State 

Data Center in 2004. Population projections at the zonal level are calculated by multiplying household

size by the projected zonal households. Household size is factored so that, in each county, the sum of

the zonal populations equals the control total. 

Households 

Base Year Data: Household data for base year 2005 originates with the 2000 Census of Population and 

Housing. Utilizing the geographic information system ArcMap, household data at the zonal level for 2000 

was derived from the area proportion allocation of block level households. Year 2000 household data 

was updated to 2005 with residential building permits issued between January 2000 and December 

2004. The residential building locations were geo-coded in ArcMap, then aggregated to the TAZs. The 

housing unit totals for each TAZ were converted to households by applying a vacancy rate, an 

adjustment for permitted but unbuilt units, and subtracting demolitions (where data was available). 

These households were then added to the year Census 2000 zonal household total to arrive at 2005 

households for each TAZ. 

Future Year Data: The preparation of household projections was accomplished by calculating the 

number of households for a projected county population using ratios of householders to total 

population by age specific cohorts derived from the 2000 Census for each analysis year. Disaggregation

to TAZs was determined by historical trends, existing and future land use, topography, flood plain 

information, availability of land, local knowledge and other factors. 

Household Vehicles 

Base and Future Year Data: Base and future year household vehicle data were obtained from the 2000 

Census of Population and Housing. The 2000 Census is the only source of household vehicle data 

available at the block group level. Average vehicles per household were calculated for block groups then 

applied to the TAZs associated with each block group. The 2005, 2010, 2020 and 2030 vehicles per 

household level was held at the 2000 level based on the fact that, since 2002, the number of vehicles 

per household has exceeded the number of drivers per household. 

Labor Force 

Base and Future Year Data: The OKI labor force is a function of the population as determined by a labor 

force participation ratio (the number of employed persons in the labor force per persons 16 and over).

Household data for base year 2005 originates with the 2000 Census of Population and Housing. Utilizing

the geographic information system ArcMap, household data at the zonal level for 2000 was derived 
from the area proportion allocation of block group level employed labor force. The labor force 

projections for 2005, 2010, 2020 and 2030 were based on the most recent projections of national labor 

force participation rates by age and sex cohorts from the U.S. Department of Labor, Bureau of Labor 

Statistics for each of those years. These rates were then applied to the projected county age/sex cohorts 

and adjusted to eliminate the unemployed to arrive at a county employed labor force control total. 

Employed labor force at the zonal level is calculated by multiplying the labor force participation rate by 

the zonal population. The labor force participation rate is adjusted so that, in each county, the sum of 

the zonal labor force counts equals the control total. 

Employment 

Base Year Data: Quarterly Census of Employment and Wages (QCEW or ES202) data for 2005 was 

utilized as the primary tool to calculate employment at the zonal level. Individual business records 

containing physical location, number of employees and SIC code were geocoded through ArcMap and 

aggregated to the TAZ level. This data set was supplemented by other sources of data to complete the 

commuting employment picture in the OKI region. Each zone’s employment was divided according to 

the SIC code into three classes (retail, office, industrial) based upon the potential for generating trips. 

Future Year Data: For future year employment projection, calculation was first made of the 

employment at the regional level. At the regional level, employment is a calculation of the region’s 

employed labor force minus workers who live in the region but commute out to work, plus workers who 

live outside the region but commute in to work. The regional total was disaggregated first to the county 

level based on historic trends and expected changes in the county’s share of the region’s employment 

and then to the TAZ level. Disaggregation to TAZs was determined by historical trends, existing and 

future land use, topography, flood plain information, availability of land, local knowledge and other 

factors. 

Area Type 

Base and Future Year Data: For each analysis year, each TAZ is assigned an area type designation as 

CBD, Urban, Suburban or Rural based on population and employment densities. 

Model Calibration 

OKI’s Travel Demand Model has been validated to observed traffic volumes for the model base year 

2005. The modeling network encompasses the entire ozone nonattainment area with the exception of 

Clinton County, Ohio. The modeling network also includes Greene, Miami and Montgomery counties in 

Ohio and the remainder of Dearborn County Indiana. The difference between estimated vehicle miles 

traveled (VMT) and 2005 observed VMT is less than 1%. A highway screenline analysis compares the 

screenline observed and simulated traffic volume discrepancies with the ODOT standard of maximum 

desirable deviation. The comparison shows that the model performs at a satisfactory level and all the

errors were under the ODOT curve. Further information can be found in OKI’s 2007 report, “OKI/MVRPC 

Travel Demand Model Methodology/ Validation Report”. For the calibration, OKI used over 3000 traffic

counts collected through 2006 by the Ohio Department of Transportation (ODOT), the Kentucky 

Transportation Cabinet, many county and local governments, transportation engineering consultants, 

and OKI. These traffic counts cover nearly 50% percent of the links in the OKI portion of the modeling 
network. The methodology provides consistency with past emission inventory and conformity analysis 

work performed by OKI. 

Local Inputs and Post-Model Processing 

OKI incorporates a variety of sources of local data to both improve and confirm the accuracy of VMT, as 

well as other travel-related parameters. Free flow speeds used on the highway and transit networks are 

based on travel time studies performed locally. The OKI post-processing program, IMPACT, uses the 

loaded highway network to generate VMT by hour, VMT by speed distribution and VMT by facility type. 

These tables are then included as input into MOVES. Two separate sets of VMT tables are generated: 

one for the four Ohio counties plus Dearborn County Indiana, and a second for the three Kentucky 

counties. The VMT by hour tables utilize hourly traffic distribution and directional split factors for 

different roadway types as developed by OKI. The main source of the data was the permanent traffic 

counting stations located throughout the OKI region for the years of 2004-2006. This data was 

supplemented with data collected at coverage count stations (locations with counts taken on only onetwo days). The stations were classified by area type: urban and rural, and functional classification:

freeway, arterial and collector. Speeds representing various “loaded” conditions (with traffic volumes) 

are estimated using techniques from the 1997 Highway Capacity Manual. This permits the estimation of 

speeds as conditions vary from hour to hour on the different facility types throughout the region. The 

IMPACT program performs the appropriate summation by area and roadway type as well as regional 

totals. OKI has also developed seasonal conversion factors to adjust traffic volumes to summer 

conditions. The factors were derived from local data collected at permanent traffic counting stations

during 1994-1997 utilizing the average daily traffic monthly conversion factors for June, July and August. 

Further information on OKI’s IMPACT program is documented in the report, “Travel Demand Model 

Summary Reporting and Impact Summary Reporting: OKI/MVRPC Travel Demand Model User’s Guide”, 

OKI 2003.

 
11 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

APPENDIX 

OKI Technical Documentation for Using 

EPA Motor Vehicle Emission Simulator 

(MOVES) 2010 to develop mobile Source 

Emissions 

August 2010 

 
12 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

1. Using MOVES 

To determine specific emission profiles and inventory, user has to define the input data like 

area, time span, type of vehicles, road types, fuel types, emission producing processes etc. 

These data are stored in a run specification (RunSpec) XML file. Using graphical user interface, 

the user can modify all these attributes of the RunSpec. In the following sections, how input 

data is entered and modified is explained. All these input options are found in the navigation 

panel of Graphical User Interface of MOVES software. 

1.1 Description 

The description text box is useful to list the specifications of the RunSpec and to distinguish 

between the RunSpecs. We can provide a brief overview of the particular RunSpec. In all of our 

current RunSpecs, we have details such as analysis years, area and pollutants analyzed. 

1.2 Scale/Calculation Type 

In this option, we need to specify about the Domain/Scale and Calculation type. The Domain 

specifies the level of default data we need to use for analysis and also the scale of the analysis. 

We have used the County scale. The county scale requires user supplied local data for most 

inputs. We have selected “Emission Rates” as the calculation type. 

1.3 Time Spans 

This input panel has different time-related input data like time aggregation level, year of 

analysis, month of analysis, whether analysis day is weekday or weekend, and hours of analysis. 

In all of our runs, time aggregation level is considered as hour, which is the most disaggregated 

level possible in MOVES and it is also specified in EPA’s technical guidance for all SIP runs. In In 

consultation with the states, the analysis years of 2005, 2008, 2011, 2015, 2018, and 2021 were 

selected. Each analysis year requires a separate MOVES run. We have used the month of April 

for analysis. Annual analysis uses one 24-hour set of average annual temperatures. The annual 

average minimum temperature, maximum temperature and humidity values for each hour 

were calculated and assigned the April month ID. The annual average temperature profile was 

used for the PM2.5 SIP inventory. Weekdays only, and all hours were selected. 

1.4 Geographic Bounds 

In this input screen, we need to specify the region of analysis (eg. Nation, State, Custom 

Domain). We have created a two separate input database through combining the four OKI Ohio 

counties (Hamilton, Butler, Clermont, and Warren) and the three OKI Kentucky counties 

(Boone, Campbell, and Kenton). Upon selecting the custom domain, MOVES will consider this 

region as separate generic County. The state ID is fixed as 99 and we have assigned an arbitrary 

CountyID of 390 for Ohio, and 210 for Kentucky to distinguish between the two states (39 and 
13 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

21 are used in post-processing as state id’s). The user also needs to provide a fraction 

geographic phase in area. In this case we do not have any phase in area fraction and we also 

provided average barometric pressure (MOVES default value for Hamilton County Ohio) to 

identify whether it is low altitude area or high altitude area. Since we do not have I/M program 

in the region the refueling program adjustment fraction and refueling spill program adjustment 

fractions are assigned as 0.00. In this input panel we also need to specify the Domain Input 

Databases. For all of our runs we have defined different input databases for each year. 

1.5 Vehicles/Equipment 

 

In MOVES, the user also needs to provide the different type of vehicles considered for analysis 

in the region. MOVES provide us with 13 different types of vehicles or equipment and four 

different fuel types and we need to select appropriate fuel and vehicle combinations. In 

MOVES, vehicle types are called SourceUseTypes . We have considered all possible types of 

fuel/vehicle type combinations. 

1.6 Road Type 

There are five road types available in MOVES. All five road types are selected in the RunSpecs, 

however OKI travel demand model does not predict the off-network vehicle miles traveled. The 

off-network road type in MOVES is used to assign activity for vehicle starts and for evaporative 

emissions while vehicles are parked. The other four road types are relatively simple and are 

based on area type, whether it is urban or rural. All expressways and freeways are considered 

as restricted roadways and all other road types are considered as unrestricted roadways. 

1.7 Pollutants and Processes 

There are different pollutants and corresponding processes are available in MOVES. A separate 

panel is available for selecting different pollutants and processes. In consultation with the 

states, PM2.5, NOx, SO2 were selected. To perform calculation of PM2.5 it is also required to 

select total energy consumption, elemental carbon, organic carbon, and sulfate particulate. In 

addition, brake wear and tire wear are also selected. 

1.8 Miscellaneous 

Information about present and future alternative vehicle fuels & technologies, on-road retrofit 

and rate of progress information can be input with the MOVES Strategies section of the 

RunSpec. If we do not specify future Alternative Vehicle Fuel & Technologies, MOVES is going 

to assume default alternative fuels. The default AVFT strategy file was modified to reflect 0% 

CNG buses in the transit fleet (default is 6%). MOVES also provides options whether we would 

like to save the MOVESactivityoutput and MOVESOutput databases or not. We did not select 

these options, although these were selected in subsequent runs as an error checking method, 

and to obtain values utilized in the post-processing. 
14 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

Table 1.8 : Alternative Vehicle and Fueling Technology used in all RunSpecs 

sourceTypeID modelYearID fuelTypeID engTechID fuelEngFraction

42 1960 2 1 1 

42 1961 2 1 1 

42 1962 2 1 1 

42 1963 2 1 1 

42 1964 2 1 1 

42 1965 2 1 1 

42 1966 2 1 1 

42 1967 2 1 1 

42 1968 2 1 1 

42 1969 2 1 1 

42 1970 2 1 1 

42 1971 2 1 1 

42 1972 2 1 1 

42 1973 2 1 1 

42 1974 2 1 1 

42 1975 2 1 1 

42 1976 2 1 1 

42 1977 2 1 1 

42 1978 2 1 1 

42 1979 2 1 1 

42 1980 2 1 1 

42 1981 2 1 1 

42 1982 2 1 1 

42 1983 2 1 1 

42 1984 2 1 1 

42 1985 2 1 1 

42 1986 2 1 1 

42 1987 2 1 1 

42 1988 2 1 1 

42 1989 2 1 1 

42 1990 2 1 1 

42 1991 2 1 1 

42 1992 2 1 1 

42 1993 2 1 1 

42 1994 2 1 1 

42 1995 2 1 1 

42 1996 2 1 1 

42 1997 2 1 1 

42 1998 2 1 1 

42 1999 2 1 1 

42 2000 2 1 1 

42 2001 2 1 1 

42 2002 2 1 1 

42 2003 2 1 1 
15 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

42 2004 2 1 1 

42 2005 2 1 1 

42 2006 2 1 1 

42 2007 2 1 1 

42 2008 2 1 1 

42 2009 2 1 1 

42 2010 2 1 1 

42 2011 2 1 1 

42 2012 2 1 1 

42 2013 2 1 1 

42 2014 2 1 1 

42 2015 2 1 1 

42 2016 2 1 1 

42 2017 2 1 1 

42 2018 2 1 1 

42 2019 2 1 1 

42 2020 2 1 1 

42 2021 2 1 1 

42 2022 2 1 1 

42 2023 2 1 1 

42 2024 2 1 1 

42 2025 2 1 1 

42 2026 2 1 1 

42 2027 2 1 1 

42 2028 2 1 1 

42 2029 2 1 1 

42 2030 2 1 1 

42 2031 2 1 1 

42 2032 2 1 1 

42 2033 2 1 1 

42 2034 2 1 1 

42 2035 2 1 1 

42 2036 2 1 1 

42 2037 2 1 1 

42 2038 2 1 1 

42 2039 2 1 1 

42 2040 2 1 1 

42 2041 2 1 1 

42 2042 2 1 1 

42 2043 2 1 1 

42 2044 2 1 1 

42 2045 2 1 1 

42 2046 2 1 1 

42 2047 2 1 1 

42 2048 2 1 1 

42 2049 2 1 1 

42 2050 2 1 1 
16 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

1.9 Output 

The MOVES output section requires the designation of an output database. A new database 

was created for each new RunSpec. Output units selected for mass, energy and distance were 

grams, joules and miles. Activity output was not selected. The second output screen requires 

further selection for data aggregation and data options. Hour was selected for Time, and 

County was selected for Location. Road Type and Source Type were also selected. 

2. Data Importers 

In order to enter local data into RunSpec, we need to use pre processing option in the MOVES. 

We can select either Data Importer or County Importer for Custom Domain option. These 

Importers convert the data in excel format to MySQL tables. This is the preferred input format 

of MOVES software. 

2.1 Meteorology Data Importer 

In this type of Importer, meteorology data is converted to a MOVES input format. This dataset 

has different data items like month ID, Zone ID, hour ID, Temperature and Relative Humidity. 

The Ohio and Kentucky custom domains use the identical temperature data obtained from the 

Kentucky Division for Air Quality (KDAQ). Even though ODOT has provided the temperature 

data (collected from local airports), KDAQ data appeared to be more applicable. A portion of 

the KDAQ temperature file is shown in Table 2.1. As previously discussed, annual average 

minimum and maximum temperatures and humidity values were calculated and used in the 

PM2.5 analysis. 

Table 2.1 : Meteorology Data 

monthID zoneID hourID temperature relHumidity 

1 993900 1 23.2 100 

1 993900 2 22.2 100 

1 993900 3 21.4 100 

1 993900 4 20.9 100 

1 993900 5 20.4 100 

1 993900 6 19.9 100 

1 993900 7 19.5 100 

1 993900 8 19.9 100 

1 993900 9 22 100 

1 993900 10 25.4 100 

1 993900 11 28.9 87.6 
17 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

1 993900 12 31.9 77.5 

1 993900 13 34.5 69.7 

1 993900 14 36 65.9 

1 993900 15 36.5 64.6 

1 993900 16 36.6 64.2 

1 993900 17 36.2 65.1 

1 993900 18 35.2 67.8 

1 993900 19 33.5 72.6 

1 993900 20 31.3 79.3 

1 993900 21 29.1 86.8 

1 993900 22 27.2 93.9 

1 993900 23 25.8 99.4 

1 993900 24 24.5 100 

2.2 Source Type Population Importer 

The source type population importer converts vehicle type, and registered vehicle population in 

into MOVES database format. ODOT has provided us with the registered vehicle population in 

each county in the Ohio portion of the region for 13 MOVES vehicle types. KYTC has provided 

registered vehicle population by county for 6 HPMS vehicle types. The KYTC data was 

converted to the 13 MOVES vehicle types based on the Ohio distribution. Same vehicle 

population was used for all analysis years. As per suggestions made by FHWA, the source type 

population has been forecasted for future years with +0.8 % per year. Similarly, the source type 

populations has been estimated for past years. The MOVES default source type population for 

intercity bus, refuse trucks, motor homes and combination trucks was used. In addition, 

MOVES default source type population for passenger trucks and light commercial trucks was 

used for Kentucky. The MOVES default source type population was acquired from the MOVES 

activity output tables from county-level inventory runs. 

Table 2.21: Ohio Source Type Population (acquired from ODOT and default)

yearID sourceTypeID sourceTypePopulation

2008 11 68559 

2008 21 1191067 

2008 31 482420 

2008 32 15817 

2008 41 454 

2008 42 81 

2008 43 3651 

2008 51 409 

2008 52 366 

2008 53 361 

2008 54 4888 

2008 61 4839 
18 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

2008 62 5548 

Table 2.22: Kentucky Source Type population (acquired from KYTC and default) 

yearID sourceTypeID sourceTypePopulation

2008 11 7975 

2008 21 197009 

2008 31 120518 

2008 32 40263 

2008 41 127 

2008 42 21 

2008 43 977 

2008 51 115 

2008 52 761 

2008 53 751 

2008 54 1379 

2008 61 1580 

2008 62 1811 

2.3 Age Distribution Importer 

For emission calculation, MOVES requires vehicle Age Distribution by Source Type. Vehicle Age 

Distribution is divided into 30 years based on vehicle model years. For each vehicle type, the 

distribution sum adds up to one. ODOT has obtained vehicle registration data from the Ohio 

Bureau of Motor Vehicles for all the counties in Ohio and processed them to convert into 

MOVES Age Distribution for 13 vehicle types. KYTC also provided vehicle registration data. We 

have used the same Age Distribution for all year runs. All the vehicles older than 30 years are 

considered as 30-years old. Identical age distribution is used for all analysis years. KYTC also 

provided similar information, but for the 6 HPMS types only. For Kentucky, identical age 

distributions are used within each HPMS vehicle type. 

Table 2.3: Ohio Custom Domain Age 

distribution 

Source

TypeID

yearID ageID ageFraction

11 2008 0 0.0019 

11 2008 1 0.0191 

11 2008 2 0.0531 

11 2008 3 0.0688 

11 2008 4 0.0773 

11 2008 5 0.0737 

11 2008 6 0.0611 

11 2008 7 0.0780 

11 2008 8 0.0636 

11 2008 9 0.0537 

11 2008 10 0.0435 

11 2008 11 0.0359 

11 2008 12 0.0282 

11 2008 13 0.0230 

11 2008 14 0.0220 

11 2008 15 0.0183 

11 2008 16 0.0160 

11 2008 17 0.0146 

11 2008 18 0.0097 

11 2008 19 0.0080 

11 2008 20 0.0072 

11 2008 21 0.0086 
19 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

11 2008 22 0.0084 

11 2008 23 0.0121 

11 2008 24 0.0171 

11 2008 25 0.0179 

11 2008 26 0.0137 

11 2008 27 0.0171 

11 2008 28 0.0249 

11 2008 29 0.0172 

11 2008 30 0.0862 

21 2008 0 0.0121 

21 2008 1 0.0331 

21 2008 2 0.0440 

21 2008 3 0.0528 

21 2008 4 0.0534 

21 2008 5 0.0566 

21 2008 6 0.0570 

21 2008 7 0.0592 

21 2008 8 0.0591 

21 2008 9 0.0542 

21 2008 10 0.0590 

21 2008 11 0.0568 

21 2008 12 0.0507 

21 2008 13 0.0499 

21 2008 14 0.0438 

21 2008 15 0.0453 

21 2008 16 0.0368 

21 2008 17 0.0308 

21 2008 18 0.0261 

21 2008 19 0.0207 

21 2008 20 0.0165 

21 2008 21 0.0132 

21 2008 22 0.0095 

21 2008 23 0.0073 

21 2008 24 0.0059 

21 2008 25 0.0043 

21 2008 26 0.0033 

21 2008 27 0.0017 

21 2008 28 0.0011 

21 2008 29 0.0010 

21 2008 30 0.0346 

31 2008 0 0.0103 

31 2008 1 0.0279 

31 2008 2 0.0502 

31 2008 3 0.0570 

31 2008 4 0.0659 

31 2008 5 0.0806 

31 2008 6 0.0796 

31 2008 7 0.0733 

31 2008 8 0.0727 

31 2008 9 0.0599 

31 2008 10 0.0625 

31 2008 11 0.0603 

31 2008 12 0.0516 

31 2008 13 0.0432 

31 2008 14 0.0380 

31 2008 15 0.0386 

31 2008 16 0.0302 

31 2008 17 0.0260 

31 2008 18 0.0165 

31 2008 19 0.0125 

31 2008 20 0.0093 

31 2008 21 0.0084 

31 2008 22 0.0067 

31 2008 23 0.0051 

31 2008 24 0.0037 

31 2008 25 0.0025 

31 2008 26 0.0017 

31 2008 27 0.0009 

31 2008 28 0.0004 

31 2008 29 0.0002 

31 2008 30 0.0041 

32 2008 0 0.0178 

32 2008 1 0.0459 

32 2008 2 0.0871 

32 2008 3 0.0699 

32 2008 4 0.0707 

32 2008 5 0.0357 

32 2008 6 0.0355 

32 2008 7 0.0369 

32 2008 8 0.0366 

32 2008 9 0.0407 

32 2008 10 0.0491 

32 2008 11 0.0547 

32 2008 12 0.0427 

32 2008 13 0.0413 

32 2008 14 0.0383 

32 2008 15 0.0602 

32 2008 16 0.0476 

32 2008 17 0.0381 

32 2008 18 0.0304 

32 2008 19 0.0181 

32 2008 20 0.0212 

32 2008 21 0.0184 

32 2008 22 0.0135 

32 2008 23 0.0134 

32 2008 24 0.0095 

32 2008 25 0.0070 

32 2008 26 0.0054 
20 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

32 2008 27 0.0021 

32 2008 28 0.0014 

32 2008 29 0.0008 

32 2008 30 0.0100 

41 2008 0 0.0000 

41 2008 1 0.0309 

41 2008 2 0.0884 

41 2008 3 0.0890 

41 2008 4 0.0768 

41 2008 5 0.0746 

41 2008 6 0.0967 

41 2008 7 0.0635 

41 2008 8 0.0486 

41 2008 9 0.0801 

41 2008 10 0.0751 

41 2008 11 0.0624 

41 2008 12 0.0254 

41 2008 13 0.0271 

41 2008 14 0.0188 

41 2008 15 0.0193 

41 2008 16 0.0133 

41 2008 17 0.0177 

41 2008 18 0.0094 

41 2008 19 0.0177 

41 2008 20 0.0171 

41 2008 21 0.0099 

41 2008 22 0.0039 

41 2008 23 0.0055 

41 2008 24 0.0061 

41 2008 25 0.0011 

41 2008 26 0.0033 

41 2008 27 0.0033 

41 2008 28 0.0028 

41 2008 29 0.0017 

41 2008 30 0.0105 

42 2008 0 0.0000 

42 2008 1 0.0366 

42 2008 2 0.1098 

42 2008 3 0.0366 

42 2008 4 0.1585 

42 2008 5 0.0366 

42 2008 6 0.0610 

42 2008 7 0.0610 

42 2008 8 0.0244 

42 2008 9 0.1098 

42 2008 10 0.0366 

42 2008 11 0.0976 

42 2008 12 0.0366 

42 2008 13 0.0244 

42 2008 14 0.0244 

42 2008 15 0.0122 

42 2008 16 0.0244 

42 2008 17 0.0244 

42 2008 18 0.0366 

42 2008 19 0.0000 

42 2008 20 0.0000 

42 2008 21 0.0122 

42 2008 22 0.0000 

42 2008 23 0.0000 

42 2008 24 0.0000 

42 2008 25 0.0000 

42 2008 26 0.0122 

42 2008 27 0.0000 

42 2008 28 0.0000 

42 2008 29 0.0122 

42 2008 30 0.0122 

43 2008 0 0.0905 

43 2008 1 0.0302 

43 2008 2 0.0549 

43 2008 3 0.0467 

43 2008 4 0.0592 

43 2008 5 0.0723 

43 2008 6 0.0481 

43 2008 7 0.0334 

43 2008 8 0.0668 

43 2008 9 0.0647 

43 2008 10 0.0842 

43 2008 11 0.0864 

43 2008 12 0.0473 

43 2008 13 0.0500 

43 2008 14 0.0242 

43 2008 15 0.0185 

43 2008 16 0.0106 

43 2008 17 0.0228 

43 2008 18 0.0109 

43 2008 19 0.0130 

43 2008 20 0.0125 

43 2008 21 0.0092 

43 2008 22 0.0062 

43 2008 23 0.0079 

43 2008 24 0.0090 

43 2008 25 0.0035 

43 2008 26 0.0030 

43 2008 27 0.0011 

43 2008 28 0.0027 

43 2008 29 0.0016 

43 2008 30 0.0087 

51 2008 0 0.0054 
21 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

51 2008 1 0.0488 

51 2008 2 0.0623 

51 2008 3 0.0705 

51 2008 4 0.0867 

51 2008 5 0.0434 

51 2008 6 0.0434 

51 2008 7 0.0542 

51 2008 8 0.0542 

51 2008 9 0.0759 

51 2008 10 0.0217 

51 2008 11 0.0407 

51 2008 12 0.0786 

51 2008 13 0.0542 

51 2008 14 0.0515 

51 2008 15 0.0678 

51 2008 16 0.0325 

51 2008 17 0.0081 

51 2008 18 0.0163 

51 2008 19 0.0027 

51 2008 20 0.0081 

51 2008 21 0.0000 

51 2008 22 0.0027 

51 2008 23 0.0027 

51 2008 24 0.0136 

51 2008 25 0.0000 

51 2008 26 0.0000 

51 2008 27 0.0000 

51 2008 28 0.0027 

51 2008 29 0.0000 

51 2008 30 0.0515 

52 2008 0 0.0054 

52 2008 1 0.0488 

52 2008 2 0.0623 

52 2008 3 0.0705 

52 2008 4 0.0867 

52 2008 5 0.0434 

52 2008 6 0.0434 

52 2008 7 0.0542 

52 2008 8 0.0542 

52 2008 9 0.0759 

52 2008 10 0.0217 

52 2008 11 0.0407 

52 2008 12 0.0786 

52 2008 13 0.0542 

52 2008 14 0.0515 

52 2008 15 0.0678 

52 2008 16 0.0325 

52 2008 17 0.0081 

52 2008 18 0.0163 

52 2008 19 0.0027 

52 2008 20 0.0081 

52 2008 21 0.0000 

52 2008 22 0.0027 

52 2008 23 0.0027 

52 2008 24 0.0136 

52 2008 25 0.0000 

52 2008 26 0.0000 

52 2008 27 0.0000 

52 2008 28 0.0027 

52 2008 29 0.0000 

52 2008 30 0.0515 

53 2008 0 0.0000 

53 2008 1 0.0062 

53 2008 2 0.0373 

53 2008 3 0.0093 

53 2008 4 0.0280 

53 2008 5 0.0342 

53 2008 6 0.0186 

53 2008 7 0.0186 

53 2008 8 0.0124 

53 2008 9 0.0155 

53 2008 10 0.0217 

53 2008 11 0.0373 

53 2008 12 0.0093 

53 2008 13 0.0311 

53 2008 14 0.0217 

53 2008 15 0.0373 

53 2008 16 0.0217 

53 2008 17 0.0342 

53 2008 18 0.0124 

53 2008 19 0.0186 

53 2008 20 0.0248 

53 2008 21 0.0373 

53 2008 22 0.0186 

53 2008 23 0.0248 

53 2008 24 0.0062 

53 2008 25 0.0373 

53 2008 26 0.0155 

53 2008 27 0.0186 

53 2008 28 0.0217 

53 2008 29 0.0186 

53 2008 30 0.3509 

54 2008 0 0.0077 

54 2008 1 0.0170 

54 2008 2 0.0377 

54 2008 3 0.0424 

54 2008 4 0.0471 

54 2008 5 0.0579 
22 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

54 2008 6 0.0552 

54 2008 7 0.0485 

54 2008 8 0.0406 

54 2008 9 0.0439 

54 2008 10 0.0505 

54 2008 11 0.0539 

54 2008 12 0.0435 

54 2008 13 0.0360 

54 2008 14 0.0348 

54 2008 15 0.0375 

54 2008 16 0.0303 

54 2008 17 0.0231 

54 2008 18 0.0196 

54 2008 19 0.0150 

54 2008 20 0.0183 

54 2008 21 0.0208 

54 2008 22 0.0218 

54 2008 23 0.0217 

54 2008 24 0.0186 

54 2008 25 0.0173 

54 2008 26 0.0163 

54 2008 27 0.0118 

54 2008 28 0.0084 

54 2008 29 0.0059 

54 2008 30 0.0968 

61 2008 0 0.0030 

61 2008 1 0.0167 

61 2008 2 0.0334 

61 2008 3 0.0393 

61 2008 4 0.0506 

61 2008 5 0.0530 

61 2008 6 0.0620 

61 2008 7 0.0625 

61 2008 8 0.0562 

61 2008 9 0.0551 

61 2008 10 0.0595 

61 2008 11 0.0569 

61 2008 12 0.0458 

61 2008 13 0.0493 

61 2008 14 0.0380 

61 2008 15 0.0435 

61 2008 16 0.0425 

61 2008 17 0.0312 

61 2008 18 0.0262 

61 2008 19 0.0235 

61 2008 20 0.0201 

61 2008 21 0.0225 

61 2008 22 0.0212 

61 2008 23 0.0141 

61 2008 24 0.0137 

61 2008 25 0.0096 

61 2008 26 0.0069 

61 2008 27 0.0039 

61 2008 28 0.0030 

61 2008 29 0.0027 

61 2008 30 0.0343 

62 2008 0 0.0078 

62 2008 1 0.0232 

62 2008 2 0.0307 

62 2008 3 0.0907 

62 2008 4 0.0721 

62 2008 5 0.0808 

62 2008 6 0.0564 

62 2008 7 0.0520 

62 2008 8 0.0360 

62 2008 9 0.0552 

62 2008 10 0.1019 

62 2008 11 0.0813 

62 2008 12 0.0603 

62 2008 13 0.0425 

62 2008 14 0.0439 

62 2008 15 0.0442 

62 2008 16 0.0273 

62 2008 17 0.0202 

62 2008 18 0.0122 

62 2008 19 0.0101 

62 2008 20 0.0103 

62 2008 21 0.0080 

62 2008 22 0.0079 

62 2008 23 0.0058 

62 2008 24 0.0050 

62 2008 25 0.0036 

62 2008 26 0.0038 

62 2008 27 0.0001 

62 2008 28 0.0012 

62 2008 29 0.0010 

62 2008 30 0.0046 
23 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

Table 2 : Kentucky Custom Domain Age 

distribution 

Source

TypeID

yearID ageID ageFraction

11 2008 0 0.0020 

11 2008 1 0.0323 

11 2008 2 0.0606 

11 2008 3 0.0826 

11 2008 4 0.0831 

11 2008 5 0.0774 

11 2008 6 0.0667 

11 2008 7 0.0830 

11 2008 8 0.0650 

11 2008 9 0.0495 

11 2008 10 0.0424 

11 2008 11 0.0345 

11 2008 12 0.0287 

11 2008 13 0.0214 

11 2008 14 0.0240 

11 2008 15 0.0208 

11 2008 16 0.0138 

11 2008 17 0.0129 

11 2008 18 0.0092 

11 2008 19 0.0051 

11 2008 20 0.0052 

11 2008 21 0.0058 

11 2008 22 0.0078 

11 2008 23 0.0108 

11 2008 24 0.0153 

11 2008 25 0.0168 

11 2008 26 0.0124 

11 2008 27 0.0160 

11 2008 28 0.0228 

11 2008 29 0.0152 

11 2008 30 0.0568 

21 2008 0 0.0118 

21 2008 1 0.0665 

21 2008 2 0.0596 

21 2008 3 0.0642 

21 2008 4 0.0611 

21 2008 5 0.0705 

21 2008 6 0.0694 

21 2008 7 0.0699 

21 2008 8 0.0719 

21 2008 9 0.0619 

21 2008 10 0.0633 

21 2008 11 0.0591 

21 2008 12 0.0490 

21 2008 13 0.0442 

21 2008 14 0.0348 

21 2008 15 0.0318 

21 2008 16 0.0241 

21 2008 17 0.0191 

21 2008 18 0.0142 

21 2008 19 0.0111 

21 2008 20 0.0088 

21 2008 21 0.0066 

21 2008 22 0.0049 

21 2008 23 0.0039 

21 2008 24 0.0028 

21 2008 25 0.0024 

21 2008 26 0.0018 

21 2008 27 0.0009 

21 2008 28 0.0005 

21 2008 29 0.0005 

21 2008 30 0.0094 

31 2008 0 0.0000 

31 2008 1 0.0000 

31 2008 2 0.0000 

31 2008 3 0.0000 

31 2008 4 0.0238 

31 2008 5 0.0119 

31 2008 6 0.0119 

31 2008 7 0.0119 

31 2008 8 0.0119 

31 2008 9 0.0000 

31 2008 10 0.0238 

31 2008 11 0.0357 

31 2008 12 0.0119 

31 2008 13 0.0952 

31 2008 14 0.0833 

31 2008 15 0.0595 

31 2008 16 0.1071 

31 2008 17 0.0357 

31 2008 18 0.0357 

31 2008 19 0.0357 

31 2008 20 0.0119 

31 2008 21 0.0476 

31 2008 22 0.0238 

31 2008 23 0.0119 

31 2008 24 0.0119 

31 2008 25 0.0595 
24 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

31 2008 26 0.0357 

31 2008 27 0.0000 

31 2008 28 0.0238 

31 2008 29 0.0238 

31 2008 30 0.1548 

32 2008 0 0.0000 

32 2008 1 0.0000 

32 2008 2 0.0000 

32 2008 3 0.0000 

32 2008 4 0.0238 

32 2008 5 0.0119 

32 2008 6 0.0119 

32 2008 7 0.0119 

32 2008 8 0.0119 

32 2008 9 0.0000 

32 2008 10 0.0238 

32 2008 11 0.0357 

32 2008 12 0.0119 

32 2008 13 0.0952 

32 2008 14 0.0833 

32 2008 15 0.0595 

32 2008 16 0.1071 

32 2008 17 0.0357 

32 2008 18 0.0357 

32 2008 19 0.0357 

32 2008 20 0.0119 

32 2008 21 0.0476 

32 2008 22 0.0238 

32 2008 23 0.0119 

32 2008 24 0.0119 

32 2008 25 0.0595 

32 2008 26 0.0357 

32 2008 27 0.0000 

32 2008 28 0.0238 

32 2008 29 0.0238 

32 2008 30 0.1548 

41 2008 0 0.0455 

41 2008 1 0.1136 

41 2008 2 0.0000 

41 2008 3 0.0114 

41 2008 4 0.0227 

41 2008 5 0.0000 

41 2008 6 0.0000 

41 2008 7 0.0114 

41 2008 8 0.0114 

41 2008 9 0.0227 

41 2008 10 0.0114 

41 2008 11 0.0568 

41 2008 12 0.1250 

41 2008 13 0.0227 

41 2008 14 0.0000 

41 2008 15 0.0341 

41 2008 16 0.0341 

41 2008 17 0.0682 

41 2008 18 0.0455 

41 2008 19 0.0909 

41 2008 20 0.0568 

41 2008 21 0.0455 

41 2008 22 0.0341 

41 2008 23 0.0455 

41 2008 24 0.0227 

41 2008 25 0.0227 

41 2008 26 0.0114 

41 2008 27 0.0000 

41 2008 28 0.0227 

41 2008 29 0.0000 

41 2008 30 0.0114 

42 2008 0 0.0455 

42 2008 1 0.1136 

42 2008 2 0.0000 

42 2008 3 0.0114 

42 2008 4 0.0227 

42 2008 5 0.0000 

42 2008 6 0.0000 

42 2008 7 0.0114 

42 2008 8 0.0114 

42 2008 9 0.0227 

42 2008 10 0.0114 

42 2008 11 0.0568 

42 2008 12 0.1250 

42 2008 13 0.0227 

42 2008 14 0.0000 

42 2008 15 0.0341 

42 2008 16 0.0341 

42 2008 17 0.0682 

42 2008 18 0.0455 

42 2008 19 0.0909 

42 2008 20 0.0568 

42 2008 21 0.0455 

42 2008 22 0.0341 

42 2008 23 0.0455 

42 2008 24 0.0227 

42 2008 25 0.0227 

42 2008 26 0.0114 

42 2008 27 0.0000 

42 2008 28 0.0227 

42 2008 29 0.0000 

42 2008 30 0.0114 
25 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

43 2008 0 0.0455 

43 2008 1 0.1136 

43 2008 2 0.0000 

43 2008 3 0.0114 

43 2008 4 0.0227 

43 2008 5 0.0000 

43 2008 6 0.0000 

43 2008 7 0.0114 

43 2008 8 0.0114 

43 2008 9 0.0227 

43 2008 10 0.0114 

43 2008 11 0.0568 

43 2008 12 0.1250 

43 2008 13 0.0227 

43 2008 14 0.0000 

43 2008 15 0.0341 

43 2008 16 0.0341 

43 2008 17 0.0682 

43 2008 18 0.0455 

43 2008 19 0.0909 

43 2008 20 0.0568 

43 2008 21 0.0455 

43 2008 22 0.0341 

43 2008 23 0.0455 

43 2008 24 0.0227 

43 2008 25 0.0227 

43 2008 26 0.0114 

43 2008 27 0.0000 

43 2008 28 0.0227 

43 2008 29 0.0000 

43 2008 30 0.0114 

51 2008 0 0.0025 

51 2008 1 0.0200 

51 2008 2 0.0386 

51 2008 3 0.0436 

51 2008 4 0.0495 

51 2008 5 0.0579 

51 2008 6 0.0667 

51 2008 7 0.0698 

51 2008 8 0.0620 

51 2008 9 0.0611 

51 2008 10 0.0675 

51 2008 11 0.0619 

51 2008 12 0.0508 

51 2008 13 0.0529 

51 2008 14 0.0397 

51 2008 15 0.0397 

51 2008 16 0.0375 

51 2008 17 0.0276 

51 2008 18 0.0204 

51 2008 19 0.0184 

51 2008 20 0.0158 

51 2008 21 0.0174 

51 2008 22 0.0152 

51 2008 23 0.0108 

51 2008 24 0.0108 

51 2008 25 0.0071 

51 2008 26 0.0052 

51 2008 27 0.0031 

51 2008 28 0.0021 

51 2008 29 0.0021 

51 2008 30 0.0220 

52 2008 0 0.0025 

52 2008 1 0.0200 

52 2008 2 0.0386 

52 2008 3 0.0436 

52 2008 4 0.0495 

52 2008 5 0.0579 

52 2008 6 0.0667 

52 2008 7 0.0698 

52 2008 8 0.0620 

52 2008 9 0.0611 

52 2008 10 0.0675 

52 2008 11 0.0619 

52 2008 12 0.0508 

52 2008 13 0.0529 

52 2008 14 0.0397 

52 2008 15 0.0397 

52 2008 16 0.0375 

52 2008 17 0.0276 

52 2008 18 0.0204 

52 2008 19 0.0184 

52 2008 20 0.0158 

52 2008 21 0.0174 

52 2008 22 0.0152 

52 2008 23 0.0108 

52 2008 24 0.0108 

52 2008 25 0.0071 

52 2008 26 0.0052 

52 2008 27 0.0031 

52 2008 28 0.0021 

52 2008 29 0.0021 

52 2008 30 0.0220 

53 2008 0 0.0025 

53 2008 1 0.0200 

53 2008 2 0.0386 

53 2008 3 0.0436 

53 2008 4 0.0495 
26 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

53 2008 5 0.0579 

53 2008 6 0.0667 

53 2008 7 0.0698 

53 2008 8 0.0620 

53 2008 9 0.0611 

53 2008 10 0.0675 

53 2008 11 0.0619 

53 2008 12 0.0508 

53 2008 13 0.0529 

53 2008 14 0.0397 

53 2008 15 0.0397 

53 2008 16 0.0375 

53 2008 17 0.0276 

53 2008 18 0.0204 

53 2008 19 0.0184 

53 2008 20 0.0158 

53 2008 21 0.0174 

53 2008 22 0.0152 

53 2008 23 0.0108 

53 2008 24 0.0108 

53 2008 25 0.0071 

53 2008 26 0.0052 

53 2008 27 0.0031 

53 2008 28 0.0021 

53 2008 29 0.0021 

53 2008 30 0.0220 

54 2008 0 0.0025 

54 2008 1 0.0200 

54 2008 2 0.0386 

54 2008 3 0.0436 

54 2008 4 0.0495 

54 2008 5 0.0579 

54 2008 6 0.0667 

54 2008 7 0.0698 

54 2008 8 0.0620 

54 2008 9 0.0611 

54 2008 10 0.0675 

54 2008 11 0.0619 

54 2008 12 0.0508 

54 2008 13 0.0529 

54 2008 14 0.0397 

54 2008 15 0.0397 

54 2008 16 0.0375 

54 2008 17 0.0276 

54 2008 18 0.0204 

54 2008 19 0.0184 

54 2008 20 0.0158 

54 2008 21 0.0174 

54 2008 22 0.0152 

54 2008 23 0.0108 

54 2008 24 0.0108 

54 2008 25 0.0071 

54 2008 26 0.0052 

54 2008 27 0.0031 

54 2008 28 0.0021 

54 2008 29 0.0021 

54 2008 30 0.0220 

61 2008 0 0.0000 

61 2008 1 0.0064 

61 2008 2 0.0295 

61 2008 3 0.0205 

61 2008 4 0.0321 

61 2008 5 0.0346 

61 2008 6 0.0423 

61 2008 7 0.0308 

61 2008 8 0.0269 

61 2008 9 0.0179 

61 2008 10 0.0462 

61 2008 11 0.0410 

61 2008 12 0.0359 

61 2008 13 0.0513 

61 2008 14 0.0333 

61 2008 15 0.0359 

61 2008 16 0.0423 

61 2008 17 0.0269 

61 2008 18 0.0295 

61 2008 19 0.0231 

61 2008 20 0.0385 

61 2008 21 0.0397 

61 2008 22 0.0333 

61 2008 23 0.0346 

61 2008 24 0.0295 

61 2008 25 0.0192 

61 2008 26 0.0346 

61 2008 27 0.0128 

61 2008 28 0.0141 

61 2008 29 0.0128 

61 2008 30 0.1244 

62 2008 0 0.0000 

62 2008 1 0.0064 

62 2008 2 0.0295 

62 2008 3 0.0205 

62 2008 4 0.0321 

62 2008 5 0.0346 

62 2008 6 0.0423 

62 2008 7 0.0308 

62 2008 8 0.0269 

62 2008 9 0.0179 
27 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

62 2008 10 0.0462 

62 2008 11 0.0410 

62 2008 12 0.0359 

62 2008 13 0.0513 

62 2008 14 0.0333 

62 2008 15 0.0359 

62 2008 16 0.0423 

62 2008 17 0.0269 

62 2008 18 0.0295 

62 2008 19 0.0231 

62 2008 20 0.0385 

62 2008 21 0.0397 

62 2008 22 0.0333 

62 2008 23 0.0346 

62 2008 24 0.0295 

62 2008 25 0.0192 

62 2008 26 0.0346 

62 2008 27 0.0128 

62 2008 28 0.0141 

62 2008 29 0.0128 

62 2008 30 0.1244 
28 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

2.4 Vehicle Type VMT and VMT Fractions 

This option is useful to import the annual VMT by source type into MOVES format. It has input 

option as HPMS Base Year VMT, for which we can either use HPMS data or the Travel Demand 

Model output. We have used daily VMT from the OKI Regional Travel Demand Model and 

converted to annual VMT using the VMT converter. Options include Month VMT fraction, Day 

VMT fraction and Hour VMT fraction, which are useful for calculating emissions for different 

time periods. We have used default Monthly VMT distribution factors provided in the VMT 

Converter provided by EPA. Hourly distribution factors are developed from traffic count data 

collected in the region from 2004-2006 and the same set of hourly distribution factors are used 

for all vehicle types and road types. OKI model could only predict VMT of two different vehicle 

types’ autos and trucks. So, we have distributed total Annual VMT based on vehicle population 

in the region. 

Table 2.41 : Annual VMT for Ohio Custom Domain from OKI travel demand model for 2005 

HPMSVtypeID yearID HPMSBaseYearVMT baseYearOffNetVMT

10 2005 67065022 0 

20 2005 7405961237 0 

30 2005 4943917030 0 

40 2005 24512225 0 

50 2005 334351024 0 

60 2005 567810955 0 

Table 2.41a :Annual VMT for Kentucky Custom Domain from OKI travel demand model for 2005 

HPMSVtypeID yearID HPMSBaseYearVMT baseYearOffNetVMT

10 2005 16658465 0 

20 2005 1815341688 0 

30 2005 1209494070 0 

40 2005 5968488 0 

50 2005 82065068 0 

60 2005 160708291 0 

Table 2.42: Annual VMT for Ohio Custom Domain from OKI travel demand model for 2008 

HPMSVtypeID yearID HPMSBaseYearVMT baseYearOffNetVMT

10 2008 69438850 0 

20 2008 7668102136 0 

30 2008 5118911580 0 

40 2008 25379858 0 

50 2008 346185690 0 

60 2008 587909153 0 
29 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

Table 2.42a : Annual VMT for Kentucky Custom Domain from OKI travel demand model for 2008 

HPMSVtypeID yearID HPMSBaseYearVMT baseYearOffNetVMT

10 2008 17342291 0 

20 2008 1889861055 0 

30 2008 1259143528 0 

40 2008 6213493 0 

50 2008 85433821 0 

60 2008 167305330 0 

Table 2.43: Annual VMT for Ohio Custom Domain from OKI travel demand model for 2011 

HPMSVtypeID yearID HPMSBaseYearVMT baseYearOffNetVMT

10 2008 69438850.44 0 

20 2008 7668102136 0 

30 2008 5118911580 0 

40 2008 25379858.39 0 

50 2008 346185689.5 0 

60 2008 587909153 0 

Table2.43a: Annual VMT for Kentucky Custom Domain from OKI travel demand model for 2011 

Table 2.44 : Annual VMT for Ohio Custom Domain from OKI travel demand model for 2015 

HPMSVtypeID yearID HPMSBaseYearVMT baseYearOffNetVMT

10 2015 73413634 0 

20 2015 8107035747 0 

30 2015 5411925719 0 

40 2015 26832639 0 

50 2015 366001875 0 

60 2015 621561950 0 

Table 2.44a: Annual VMT for Kentucky Custom Domain from OKI travel demand model for 2015 

HPMSVtypeID yearID HPMSBaseYearVMT baseYearOffNetVMT

10 2015 19903870 0 

HPMSVtypeID yearID HPMSBaseYearVMT baseYearOffNetVMT

10 2011 18163152 0 

20 2011 1979313603 0 

30 2011 1318742406 0 

40 2011 6507596 0 

50 2011 89477649 0 

60 2011 175224371 0 
30 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

20 2015 2169006811 0 

30 2015 1445127874 0 

40 2015 7131270 0 

50 2015 98052996 0 

60 2015 192017502 0 

Table 2.45: Annual VMT for Kentucky Custom Domain from OKI travel demand model for 2018 

HPMSVtypeID yearID HPMSBaseYearVMT baseYearOffNetVMT

10 2018 76802311 0 

20 2018 8481245879 0 

30 2018 5661733109 0 

40 2018 28071199 0 

50 2018 382896041 0 

60 2018 650252434 0 

Table 2.45a: Annual VMT for Kentucky Custom Domain from OKI travel demand model for 2018 

HPMSVtypeID yearID HPMSBaseYearVMT baseYearOffNetVMT

10 2018 21077884 0 

20 2018 2296944011 0 

30 2018 1530367631 0 

40 2018 7551902 0 

50 2018 103836577 0 

60 2018 203343507 0 

Table 2.46 : Annual VMT for Ohio Custom Domain from OKI travel demand model for 2021 

HPMSVtypeID yearID HPMSBaseYearVMT baseYearOffNetVMT

10 2021 79128218 0 

20 2021 8738094842 0 

30 2021 5833194979 0 

40 2021 28921317 0 

50 2021 394491797 0 

60 2021 669944902 0 

Table 2.46a : Annual VMT for Kentucky Custom Domain from OKI travel demand model for 2021 

HPMSVtypeID yearID HPMSBaseYearVMT baseYearOffNetVMT

10 2021 21702396 0

20 2021 2364999583 0

30 2021 1575710506 0

40 2021 7775656 0

50 2021 106913124 0

60 2021 209368320 0
31 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

Table 2.47 : Day VMT Fractions used in all RunSpecs

sourceTypeID monthID roadTypeID dayID dayVMTFraction

11 1 1 2 0.237635

11 1 1 5 0.762365 

11 1 2 2 0.237635 

11 1 2 5 0.762365 

11 1 3 2 0.237635 

11 1 3 5 0.762365 

11 1 4 2 0.237635 

11 1 4 5 0.762365 

11 1 5 2 0.237635 

11 1 5 5 0.762365 

Table 2.48: Hour VMT Fractions used in all RunSpecs

sourceTypeID roadTypeID dayID hourID hourVMTFraction

11 1 2 1 0.021474 

11 1 2 2 0.014443 

11 1 2 3 0.010968 

11 1 2 4 0.007495 

11 1 2 5 0.006839 

11 1 2 6 0.010359 

11 1 2 7 0.01843 

11 1 2 8 0.026812 

11 1 2 9 0.036385 

11 1 2 10 0.047541 

11 1 2 11 0.057466 

11 1 2 12 0.065079 

11 1 2 13 0.071323 

11 1 2 14 0.071492 

11 1 2 15 0.071723 

11 1 2 16 0.072006 

11 1 2 17 0.071149 

11 1 2 18 0.067887 

11 1 2 19 0.061772 

11 1 2 20 0.051688 

11 1 2 21 0.042866 

11 1 2 22 0.03803 

11 1 2 23 0.032207 

11 1 2 24 0.024568 
32 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

2.5 Average Speed Distribution Importer 

This importer allows the user to input average speed data specific to vehicle type, road type, 

and time of day/ type of day. The MOVES model defines 16 “speed bins” which describe the 

average driving speed on each road type. Unlike MOBILE 6.2 model, which uses VMT-based 

speed distribution, MOVES uses fraction of driving time in each speed bin for each vehicle type, 

for each road type, and for each hour. Thus, for each combination of vehicle type, road type, 

and hour/day type, the fractions will add to one. This importer was not used for the PM2.5 

analysis. OKI utilized a FORTRAN program to post-process OKI Travel Demand Model results 

into VHT distribution by the MOVES 16 average speed bins. 

2.6 Road Type Distribution Importer 

VHT distribution by the fives MOVES roadway types is provided from the OKI Travel Demand 

Model thru the use of post-processing FORTRAN program. OKI travel demand model can 

calculate the VMT or VHT distribution by functional class, which is further processed to obtain 

road type VMT/VHT distribution. But, our model could not predict off network VMT, which is 

assumed as zero. 

2.7 Ramp Fraction Importer 

This option allows the user to modify the fraction of ramp driving time on selected road types. 

But, in the current version of MOVES model (MOVES2010), the emission rates for ramps are 

erroneously calculated. To circumvent this problem, FHWA has suggested a temporary 

solution. This solution discussed in the Section 3. 

2.8 Fuel Formulation Importer and Fuel Supply Importer 

The Fuel formulation importer allows the user to select an existing fuel in the MOVES database 

and change its properties, or create a new fuel formulation with different fuel properties. But 

we have used only default fuels available in MOVES default database. The default values were 

verified by ODOT and KDAQ. Fuel supply importer allows the user to assign existing fuels to 

counties, months, and years, and the associated market share for each fuel. We have used 

default fuel supply from MOVES default database. The same type of fuel is used for the entire 

custom domain. 

Table 2.81 : Fuel supply data for Ohio Custom Domain ( same for all years) 

countyID fuelYearID monthGroupID fuelFormulationID marketShare marketShareCV

99390 2008 1 3982 1 

99390 2008 1 20011 1 
33 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

99390 2008 2 3982 1 

99390 2008 2 20011 1 

99390 2008 3 3982 1 

99390 2008 3 20011 1 

99390 2008 4 3982 1 

99390 2008 4 20011 1 

99390 2008 5 3982 1 

99390 2008 5 20011 1 

99390 2008 6 3982 1 

99390 2008 6 20011 1 

99390 2008 7 3982 1 

99390 2008 7 20011 1 

99390 2008 8 3982 1 

99390 2008 8 20011 1 

99390 2008 9 3982 1 

99390 2008 9 20011 1 

99390 2008 10 3982 1 

99390 2008 10 20011 1 

99390 2008 11 3982 1 

99390 2008 11 20011 1 

99390 2008 12 3982 1 

99390 2008 12 20011 1 

Table2.82: Fuel supply data for Kentucky Custom Domain (same for all years) 

countyID fuelYearID monthGroupID fuelFormulationID marketShare marketShareCV

99210 2012 1 3982 1 

99210 2012 1 20011 1 

99210 2012 2 3982 1 

99210 2012 2 20011 1 

99210 2012 3 3982 1 

99210 2012 3 20011 1 

99210 2012 4 3982 1 

99210 2012 4 20011 1 

99210 2012 5 3982 1 

99210 2012 5 20011 1 

99210 2012 6 3982 1 

99210 2012 6 20011 1 

99210 2012 7 3982 1 

99210 2012 7 20011 1 

99210 2012 8 3982 1 

99210 2012 8 20011 1 

99210 2012 9 3982 1 

99210 2012 9 20011 1 

99210 2012 10 3982 1 

99210 2012 10 20011 1 

99210 2012 11 3982 1 
34 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

99210 2012 11 20011 1 

99210 2012 12 3982 1 

99210 2012 12 20011 1 

2.9 Inspection and Maintenance (I/M) Importer 

The I/M Importer allows the user to import information describing the inspection and 

maintenance programs. The MOVES default database includes an I/M program for this regional 

although it was suspended in 2005. The default I/M program was turned “off” for all analysis 

years 2008 and later, by inserting “N” in the “useIMyn” field. 

2.10 Zone Road Activity Importer 

The Zone Road Activity Importer is used only if the Custom Domain option is chosen in the 

County Domain Manager. We have used value 1 for SHOallocfactor for each road type which 

means that all of the VMT input by the users is assigned to custom domain. 

Table 2.11 : Kentucky Custom Domain Zone road activity data (same for all years) 

zoneID roadTypeID SHOAllocFactor 

992100 1 1 

992100 2 1 

992100 3 1 

992100 4 1 

992100 5 1 

Table 2.12 : Ohio Custom Domain Zone road activity data (same for all years) 

zoneID roadTypeID SHOAllocFactor 

993900 1 1 

993900 2 1 

993900 3 1 

993900 4 1 

993900 5 1 

3. Ramp Inventory Runs 

As discussed earlier, current version of the MOVES (MOVES2010) model cannot calculate 

Emission Rates for Ramps. To deal with this problem, FHWA has suggested an approach. The 

steps involved in this method are: (a) Calculating Emission Inventory for Urban Restricted and 

Rural Restricted road types keeping Ramp fraction as 1 (b) Finding out total VMT of Urban 

Restricted and Rural Restricted road types using MOVESactivityoutput option (c) Calculation 
35 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

Emission Rates for Ramps through dividing Emission Inventory with VMT (d) Finally, using the 

Emission Rates in post processing for calculating regional Emission Inventory. 

Table 3.1 :Ramp fraction Input 

roadTypeID rampFraction

2 1

4 1
36 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

4. Post-Processing of MOVES Output 

4.1 Linking SQL tables to Microsoft Access 

Microsoft Access 2007 was used for the post-processing. An ODBC connection with the MOVES 

output directory was established. Information on how to link or import SQL tables to Access 

can be found in the MOVES Users Guide. 

4.2 Creating Emission Rate Lookup Tables 

The ratepervehicle and rateperdistance SQL tables, one set for each state (Kentucky and Ohio) 

and analysis year, were imported into Access. Ohio emission rates are used for the 

nonattainment portion of Dearborn County Indiana. Rateperprofile output was not generated 

by MOVES because evaporative output was not selected (i.e. VOC). Tables were renamed with 

state and analysis year in the format OH_20xxrateperdistance. All rateperdistance tables were 

merged with a Union query. The SQL commands are shown in Figure 4.21. ratepervehicle 

tables were merged in the same manner. 

 

Table 4.21 :Rateperdistance Union Query 

SELECT * 

FROM OH_2008rateperdistance 

WHERE MOVESRunID = (select max (MOVESRunID) from OH_2008rateperdistance) AND 

pollutantID = 3 Or MOVESRunID = (select max (MOVESRunID) from 

OH_2008rateperdistance) AND pollutantID=110 Or MOVESRunID = (select max 

(MOVESRunID) from OH_2008rateperdistance) AND pollutantID=116 Or MOVESRunID = 

(select max (MOVESRunID) from OH_2008rateperdistance) AND pollutantID=117 Or 

MOVESRunID = (select max (MOVESRunID) from OH_2008rateperdistance) AND 

pollutantID = 31 

UNION ALL select * 

FROM OH_2011rateperdistance 

WHERE ..... (repeated for each file) 

“Rateperdistance_state” and “Ratepervehicle_state” tables were created from the union query 

output using a Make Table query. Emission rates for each process were summed by pollutant 

and a stateID field is created. The SQL commands for creating the “Rateperdistance_state” 

table are shown in Table 4.22. Unique index fields were identified for each of the two tables. 

Indexes facilitate more efficient data processing. 

Table 4.22: Rateperdistance_State Query 

SELECT Val(Mid([LinkID],3,2)) AS StateID, Union_rateperdistance_state.yearID, 

Union_rateperdistance_state.monthID, Union_rateperdistance_state.linkID, 

Union_rateperdistance_state.hourID, Union_rateperdistance_state.sourceTypeID, 

Union_rateperdistance_state.roadTypeID, 

Union_rateperdistance_state.avgSpeedBinID, 

Union_rateperdistance_state.pollutantID, 

Sum(Union_rateperdistance_state.ratePerDistance) AS SumOfratePerDistance INTO 

rateperdistance_state 
37 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

FROM Union_rateperdistance_state 

GROUP BY Val(Mid([LinkID],3,2)), Union_rateperdistance_state.yearID, 

Union_rateperdistance_state.monthID, Union_rateperdistance_state.linkID, 

Union_rateperdistance_state.hourID, Union_rateperdistance_state.sourceTypeID, 

Union_rateperdistance_state.roadTypeID, 

Union_rateperdistance_state.avgSpeedBinID, 

Union_rateperdistance_state.pollutantID 

ORDER BY Union_rateperdistance_state.linkID, 

Union_rateperdistance_state.hourID, Union_rateperdistance_state.pollutantID; 

4.3 Creating a VMT Table by County 

The VMT table includes Daily VMT by county by analysis year from the OKI Travel Demand 

Model (TDM). Summer factors and applied by functional class to create Summer VMT. 

Seasonal factors by functional class are contained in the report, “OKI Travel Demand 

Forecasting Model, Update of Hourly and Seasonal Factors as Used in Air Quality Impact 

Calculations”, September 2001. Annual VMT is calculated by using EPA’s VMT converter to 

grow daily VMT to annual VMT. In order to accommodate an error in MOVES 2010, all VMT 

values are exclusive of ramp VMT. Ramp VMT and emission are added in later in the process. 

In order to apply the emission rates, it is necessary to factor the county VMT by source type, 

hour, road type and speed bin. 

Table 4.3 : VMT and Source Type Population by County and Year 

County Daily VMT Summer 

VMT 

Annual VMT yearID SourceType

Population 

stateID

Boone 3924117 4186006 1273226984 2005 129823 21

Boone 4076584 4355527 1350001557 2008 134028 21

Boone 4383716 4681593 1448879510 2011 136181 21

Boone 4950741 5276742 1628041303 2015 140590 21

Boone 5260102 5597287 1729595179 2018 143991 21

Boone 5478224 5826768 1800571708 2021 147476 21

Campbell 2286217 2437698 741790605 2005 86065 21

Campbell 2339542 2495174 774762729 2008 88853 21

Campbell 2421600 2582758 800372702 2011 90279 21

Campbell 2663159 2844504 875774499 2015 93204 21

Campbell 2771476 2958827 911300109 2018 95458 21

Campbell 2849127 3041704 936445364 2021 97768 21

Kenton 3927743 4182042 1274091658 2005 148193 21

Kenton 3927332 4185652 1300575265 2008 152992 21

Kenton 4049886 4327836 1338544021 2011 155451 21

Kenton 4341124 4614242 1427569992 2015 160484 21

Kenton 4629694 4880614 1522308203 2018 164368 21

Kenton 4715306 5006383 1549817345 2021 168343 21

Butler 578641 7804476 196737836 2005 24915 39
38 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

Butler 587582 8133554 199777880 2008 25722 39

Butler 605620 8454053 205910800 2011 26135 39

Butler 657778 8768598 223644400 2015 26982 39

Butler 684361 9232457 232682740 2018 27635 39

Butler 706828 9592567 240321520 2021 28303 39

Clermont 7452286 5391578 2469166037 2005 401759 39

Clermont 7745685 5599530 2598059212 2008 414771 39

Clermont 8050701 5841102 2693716250 2011 421434 39

Clermont 8361487 6035155 2792188144 2015 435082 39

Clermont 8806042 6314640 2940849935 2018 445608 39

Clermont 9150031 6562428 2966037449 2021 456389 39

Dearborn NA 5083331 599761 1684259908 2005 232380 39

Dearborn NA 5262489 613027 1765145113 2008 239906 39

Dearborn NA 5489545 631914 1836768820 2011 243760 39

Dearborn NA 5687698 685272 1899318043 2015 251654 39

Dearborn NA 5952603 712461 1987920583 2018 257742 39

Dearborn NA 6186441 735862 2005371969 2021 263978 39

Hamilton 21859452 23170766 7241529618 2005 862422 39

Hamilton 22124503 23447460 7421005221 2008 890352 39

Hamilton 22426021 23803187 7503612070 2011 904655 39

Hamilton 22849494 24259554 7630232069 2015 933953 39

Hamilton 23630554 25096560 7891617279 2018 956548 39

Hamilton 24098698 25596996 7811737549 2021 979689 39

Warren 5884216 6263010 1949617151 2005 233106 39

Warren 6057338 6464217 2031753523 2008 240655 39

Warren 6406284 6835660 2143504189 2011 244521 39

Warren 6842828 7279441 2285055662 2015 252440 39

Warren 7368035 7836746 2460615706 2018 258547 39

Warren 7707500 8194596 2498432370 2021 264802 39

4.4 Source type population and source type VMT distribution 

A combination of local and MOVES default data were used for the source type populations. The 

source type VMT fractions are based on the ratio of MOVES default source type population and 

MOVES default source type VMT. It is assumed that the growth rate of source type populations 

is equal to the regional annual household growth rate of 0.8%. Source type VMT fractions are 

the same for all analysis years. 
39 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

Table 4.4: Base Year Source Type Population and VMT Fraction 

stateID sourceTypeID sourceType

Population 

sourceTypeFraction sourceTypeVMTFraction

39 11 69121 0.038559 0.005026

39 21 1200827 0.669872 0.555019

39 31 486373 0.271319 0.277725

39 32 15947 0.008896 0.092783

39 41 458 0.000255 0.000754

39 42 82 0.000046 0.000225

39 43 3681 0.002053 0.000858

39 51 0 0.000000 0.000644

39 52 369 0.000206 0.020527

39 53 364 0.000203 0.002663

39 54 4928 0.002749 0.001224

39 61 4879 0.002722 0.017977

39 62 5593 0.003120 0.024576

21 11 8040 0.021370 0.005063

21 21 198623 0.527931 0.551736

21 31 121506 0.322958 0.275546

21 32 40593 0.107894 0.092055

21 41 128 0.000340 0.000745

21 42 21 0.000056 0.000222

21 43 985 0.002618 0.000847

21 51 0 0.000000 0.000641

21 52 767 0.002039 0.020433

21 53 757 0.002012 0.002650

21 54 1390 0.003695 0.001218

21 61 1593 0.004234 0.020634

21 62 1826 0.004853 0.028210

4.5 Hourly distribution 

Hourly distribution factors were derived from OKI’s traffic count database using 2004-2006 

counts. 

4.6 Road type distribution 

Road type VMT fractions by source type are default values, except for passenger cars (source 

type 21) and passenger trucks (source type 31). VMT fractions from the OKI TDM are used for 

passenger cars and passenger trucks. 
40 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

Table 4.6: Base Year Source Type Population and VMT Fraction

sourceTypeID roadTypeID roadTypeVMTFraction stateID

21 1 0 21

21 2 0.0952 21

21 3 0.0818 21

21 4 0.4741 21

21 5 0.3489 21

31 1 0 21

31 2 0.0952 21

31 3 0.0818 21

31 4 0.4741 21

31 5 0.3489 21

21 1 0 39

21 2 0.0436 39

21 3 0.1256 39

21 4 0.4143 39

21 5 0.4165 39

31 1 0 39

31 2 0.0436 39

31 3 0.1256 39

31 4 0.4143 39

31 5 0.4165 39

4.7 Average speed distribution 

Average speed fractions for each of the 16 speed bins are provided by the OKI TDM. The 

average speed fractions vary by state, year, road type and hour. 

Table 4.7: Average Speed Distribution (Example: only road type 2, year 2011, Ohio values shown) 

roadTypeID hourID avgSpeedBinID avgSpeedFraction YearID stateID

2 1 1 0.00000000 2011 39

2 1 2 0.00000000 2011 39

2 1 3 0.00000000 2011 39

2 1 4 0.00000000 2011 39

2 1 5 0.00000000 2011 39

2 1 6 0.00000000 2011 39

2 1 7 0.00000000 2011 39

2 1 8 0.00000000 2011 39
41 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

2 1 9 0.00000000 2011 39

2 1 10 0.11922233 2011 39

2 1 11 0.12547629 2011 39

2 1 12 0.19752816 2011 39

2 1 13 0.00589550 2011 39

2 1 14 0.00000000 2011 39

2 1 15 0.55187773 2011 39

2 1 16 0.00000000 2011 39

2 2 1 0.00000000 2011 39

2 2 2 0.00000000 2011 39

2 2 3 0.00000000 2011 39

2 2 4 0.00000000 2011 39

2 2 5 0.00000000 2011 39

2 2 6 0.00000000 2011 39

2 2 7 0.00000000 2011 39

2 2 8 0.00000000 2011 39

2 2 9 0.00000000 2011 39

2 2 10 0.11922233 2011 39

2 2 11 0.12547629 2011 39

2 2 12 0.19752816 2011 39

2 2 13 0.00589550 2011 39

2 2 14 0.00000000 2011 39

2 2 15 0.55187773 2011 39

2 2 16 0.00000000 2011 39

2 3 1 0.00000000 2011 39

2 3 2 0.00000000 2011 39

2 3 3 0.00000000 2011 39

2 3 4 0.00000000 2011 39

2 3 5 0.00000000 2011 39

2 3 6 0.00000000 2011 39

2 3 7 0.00000000 2011 39

2 3 8 0.00000000 2011 39

2 3 9 0.00000000 2011 39

2 3 10 0.11922233 2011 39

2 3 11 0.12547629 2011 39

2 3 12 0.19752816 2011 39

2 3 13 0.00589550 2011 39

2 3 14 0.06436270 2011 39
42 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

2 3 15 0.48751503 2011 39

2 3 16 0.00000000 2011 39

2 4 1 0.00000000 2011 39

2 4 2 0.00000000 2011 39

2 4 3 0.00000000 2011 39

2 4 4 0.00000000 2011 39

2 4 5 0.00000000 2011 39

2 4 6 0.00000000 2011 39

2 4 7 0.00000000 2011 39

2 4 8 0.00000000 2011 39

2 4 9 0.00000000 2011 39

2 4 10 0.11922233 2011 39

2 4 11 0.12547629 2011 39

2 4 12 0.19752816 2011 39

2 4 13 0.00589550 2011 39

2 4 14 0.12369152 2011 39

2 4 15 0.42818621 2011 39

2 4 16 0.00000000 2011 39

2 5 1 0.00000000 2011 39

2 5 2 0.00000000 2011 39

2 5 3 0.00000000 2011 39

2 5 4 0.00000000 2011 39

2 5 5 0.00000000 2011 39

2 5 6 0.00000000 2011 39

2 5 7 0.00000000 2011 39

2 5 8 0.00000000 2011 39

2 5 9 0.00000000 2011 39

2 5 10 0.11922233 2011 39

2 5 11 0.12547629 2011 39

2 5 12 0.26189086 2011 39

2 5 13 0.09782827 2011 39

2 5 14 0.06250896 2011 39

2 5 15 0.33307330 2011 39

2 5 16 0.00000000 2011 39

2 6 1 0.00000000 2011 39

2 6 2 0.12369152 2011 39

2 6 3 0.03260396 2011 39

2 6 4 0.03085494 2011 39
43 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

2 6 5 0.01601927 2011 39

2 6 6 0.01563475 2011 39

2 6 7 0.00000000 2011 39

2 6 8 0.00000000 2011 39

2 6 9 0.00000000 2011 39

2 6 10 0.11922233 2011 39

2 6 11 0.12547629 2011 39

2 6 12 0.19752816 2011 39

2 6 13 0.00589550 2011 39

2 6 14 0.00278921 2011 39

2 6 15 0.33028409 2011 39

2 6 16 0.00000000 2011 39

2 7 1 0.21880443 2011 39

2 7 2 0.00000000 2011 39

2 7 3 0.00278921 2011 39

2 7 4 0.00000000 2011 39

2 7 5 0.01131028 2011 39

2 7 6 0.03548550 2011 39

2 7 7 0.03519436 2011 39

2 7 8 0.03514937 2011 39

2 7 9 0.00617093 2011 39

2 7 10 0.08564905 2011 39

2 7 11 0.14691446 2011 39

2 7 12 0.13064235 2011 39

2 7 13 0.00589550 2011 39

2 7 14 0.14352342 2011 39

2 7 15 0.14247115 2011 39

2 7 16 0.00000000 2011 39

2 8 1 0.21880443 2011 39

2 8 2 0.00278921 2011 39

2 8 3 0.01131028 2011 39

2 8 4 0.01356074 2011 39

2 8 5 0.05711912 2011 39

2 8 6 0.03514937 2011 39

2 8 7 0.02902228 2011 39

2 8 8 0.01193860 2011 39

2 8 9 0.07229727 2011 39

2 8 10 0.05473480 2011 39
44 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

2 8 11 0.08493157 2011 39

2 8 12 0.11645227 2011 39

2 8 13 0.04360641 2011 39

2 8 14 0.20648097 2011 39

2 8 15 0.04180267 2011 39

2 8 16 0.00000000 2011 39

2 9 1 0.21880443 2011 39

2 9 2 0.00000000 2011 39

2 9 3 0.00000000 2011 39

2 9 4 0.00000000 2011 39

2 9 5 0.00000000 2011 39

2 9 6 0.00278921 2011 39

2 9 7 0.00000000 2011 39

2 9 8 0.04679577 2011 39

2 9 9 0.03519436 2011 39

2 9 10 0.08369185 2011 39

2 9 11 0.14590244 2011 39

2 9 12 0.15349370 2011 39

2 9 13 0.02733367 2011 39

2 9 14 0.03771092 2011 39

2 9 15 0.24828365 2011 39

2 9 16 0.00000000 2011 39

2 10 1 0.15629548 2011 39

2 10 2 0.04687421 2011 39

2 10 3 0.01563475 2011 39

2 10 4 0.00000000 2011 39

2 10 5 0.00000000 2011 39

2 10 6 0.00000000 2011 39

2 10 7 0.00000000 2011 39

2 10 8 0.00000000 2011 39

2 10 9 0.00000000 2011 39

2 10 10 0.11922233 2011 39

2 10 11 0.13957578 2011 39

2 10 12 0.18621788 2011 39

2 10 13 0.00589550 2011 39

2 10 14 0.04428952 2011 39

2 10 15 0.28599457 2011 39

2 10 16 0.00000000 2011 39
45 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

2 11 1 0.06436270 2011 39

2 11 2 0.12278771 2011 39

2 11 3 0.01601927 2011 39

2 11 4 0.01563475 2011 39

2 11 5 0.00000000 2011 39

2 11 6 0.00000000 2011 39

2 11 7 0.00000000 2011 39

2 11 8 0.00000000 2011 39

2 11 9 0.00000000 2011 39

2 11 10 0.11922233 2011 39

2 11 11 0.13678656 2011 39

2 11 12 0.18900709 2011 39

2 11 13 0.00589550 2011 39

2 11 14 0.02285135 2011 39

2 11 15 0.30743274 2011 39

2 11 16 0.00000000 2011 39

2 12 1 0.06436270 2011 39

2 12 2 0.09193278 2011 39

2 12 3 0.04687421 2011 39

2 12 4 0.01563475 2011 39

2 12 5 0.00000000 2011 39

2 12 6 0.00000000 2011 39

2 12 7 0.00000000 2011 39

2 12 8 0.00000000 2011 39

2 12 9 0.00000000 2011 39

2 12 10 0.11922233 2011 39

2 12 11 0.12547629 2011 39

2 12 12 0.20031737 2011 39

2 12 13 0.00589550 2011 39

2 12 14 0.02285135 2011 39

2 12 15 0.30743274 2011 39

2 12 16 0.00000000 2011 39

2 13 1 0.06436270 2011 39

2 13 2 0.09193278 2011 39

2 13 3 0.04687421 2011 39

2 13 4 0.01563475 2011 39

2 13 5 0.00000000 2011 39

2 13 6 0.00000000 2011 39
46 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

2 13 7 0.00000000 2011 39

2 13 8 0.00000000 2011 39

2 13 9 0.00000000 2011 39

2 13 10 0.11922233 2011 39

2 13 11 0.12547629 2011 39

2 13 12 0.19752816 2011 39

2 13 13 0.00868471 2011 39

2 13 14 0.00000000 2011 39

2 13 15 0.33028409 2011 39

2 13 16 0.00000000 2011 39

2 14 1 0.06436270 2011 39

2 14 2 0.09193278 2011 39

2 14 3 0.03085494 2011 39

2 14 4 0.03165402 2011 39

2 14 5 0.00000000 2011 39

2 14 6 0.00000000 2011 39

2 14 7 0.00000000 2011 39

2 14 8 0.00000000 2011 39

2 14 9 0.00000000 2011 39

2 14 10 0.11922233 2011 39

2 14 11 0.12547629 2011 39

2 14 12 0.19752816 2011 39

2 14 13 0.00868471 2011 39

2 14 14 0.00000000 2011 39

2 14 15 0.33028409 2011 39

2 14 16 0.00000000 2011 39

2 15 1 0.06436270 2011 39

2 15 2 0.09193278 2011 39

2 15 3 0.04687421 2011 39

2 15 4 0.01563475 2011 39

2 15 5 0.00000000 2011 39

2 15 6 0.00000000 2011 39

2 15 7 0.00000000 2011 39

2 15 8 0.00000000 2011 39

2 15 9 0.00000000 2011 39

2 15 10 0.11922233 2011 39

2 15 11 0.12547629 2011 39

2 15 12 0.19752816 2011 39
47 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

2 15 13 0.00868471 2011 39

2 15 14 0.02285135 2011 39

2 15 15 0.30743274 2011 39

2 15 16 0.00000000 2011 39

2 16 1 0.12369152 2011 39

2 16 2 0.07947816 2011 39

2 16 3 0.01563475 2011 39

2 16 4 0.00000000 2011 39

2 16 5 0.00000000 2011 39

2 16 6 0.00000000 2011 39

2 16 7 0.00000000 2011 39

2 16 8 0.00000000 2011 39

2 16 9 0.00000000 2011 39

2 16 10 0.11922233 2011 39

2 16 11 0.13957578 2011 39

2 16 12 0.18621788 2011 39

2 16 13 0.00589550 2011 39

2 16 14 0.04428952 2011 39

2 16 15 0.28599457 2011 39

2 16 16 0.00000000 2011 39

2 17 1 0.20316968 2011 39

2 17 2 0.01563475 2011 39

2 17 3 0.00000000 2011 39

2 17 4 0.00000000 2011 39

2 17 5 0.00000000 2011 39

2 17 6 0.00000000 2011 39

2 17 7 0.00278921 2011 39

2 17 8 0.02487101 2011 39

2 17 9 0.05711912 2011 39

2 17 10 0.05722137 2011 39

2 17 11 0.15811770 2011 39

2 17 12 0.14489757 2011 39

2 17 13 0.05018502 2011 39

2 17 14 0.00000000 2011 39

2 17 15 0.28599457 2011 39

2 17 16 0.00000000 2011 39

2 18 1 0.15629548 2011 39

2 18 2 0.04687421 2011 39
48 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

2 18 3 0.01563475 2011 39

2 18 4 0.00000000 2011 39

2 18 5 0.00000000 2011 39

2 18 6 0.00000000 2011 39

2 18 7 0.00000000 2011 39

2 18 8 0.00000000 2011 39

2 18 9 0.00000000 2011 39

2 18 10 0.11922233 2011 39

2 18 11 0.13957578 2011 39

2 18 12 0.18621788 2011 39

2 18 13 0.00589550 2011 39

2 18 14 0.04428952 2011 39

2 18 15 0.28599457 2011 39

2 18 16 0.00000000 2011 39

2 19 1 0.00000000 2011 39

2 19 2 0.00000000 2011 39

2 19 3 0.00000000 2011 39

2 19 4 0.00000000 2011 39

2 19 5 0.06436270 2011 39

2 19 6 0.00000000 2011 39

2 19 7 0.05932882 2011 39

2 19 8 0.03260396 2011 39

2 19 9 0.00000000 2011 39

2 19 10 0.15007727 2011 39

2 19 11 0.14149556 2011 39

2 19 12 0.21316291 2011 39

2 19 13 0.00589550 2011 39

2 19 14 0.00000000 2011 39

2 19 15 0.33307330 2011 39

2 19 16 0.00000000 2011 39

2 20 1 0.00000000 2011 39

2 20 2 0.00000000 2011 39

2 20 3 0.00000000 2011 39

2 20 4 0.00000000 2011 39

2 20 5 0.00000000 2011 39

2 20 6 0.00000000 2011 39

2 20 7 0.00000000 2011 39

2 20 8 0.00000000 2011 39
49 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

2 20 9 0.00000000 2011 39

2 20 10 0.11922233 2011 39

2 20 11 0.12547629 2011 39

2 20 12 0.19752816 2011 39

2 20 13 0.00589550 2011 39

2 20 14 0.15629548 2011 39

2 20 15 0.39558226 2011 39

2 20 16 0.00000000 2011 39

2 21 1 0.00000000 2011 39

2 21 2 0.00000000 2011 39

2 21 3 0.00000000 2011 39

2 21 4 0.00000000 2011 39

2 21 5 0.00000000 2011 39

2 21 6 0.00000000 2011 39

2 21 7 0.00000000 2011 39

2 21 8 0.00000000 2011 39

2 21 9 0.00000000 2011 39

2 21 10 0.11922233 2011 39

2 21 11 0.12547629 2011 39

2 21 12 0.19752816 2011 39

2 21 13 0.00589550 2011 39

2 21 14 0.00000000 2011 39

2 21 15 0.55187773 2011 39

2 21 16 0.00000000 2011 39

2 22 1 0.00000000 2011 39

2 22 2 0.00000000 2011 39

2 22 3 0.00000000 2011 39

2 22 4 0.00000000 2011 39

2 22 5 0.00000000 2011 39

2 22 6 0.00000000 2011 39

2 22 7 0.00000000 2011 39

2 22 8 0.00000000 2011 39

2 22 9 0.00000000 2011 39

2 22 10 0.11922233 2011 39

2 22 11 0.12547629 2011 39

2 22 12 0.19752816 2011 39

2 22 13 0.00589550 2011 39

2 22 14 0.00000000 2011 39
50 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

2 22 15 0.55187773 2011 39

2 22 16 0.00000000 2011 39

2 23 1 0.00000000 2011 39

2 23 2 0.00000000 2011 39

2 23 3 0.00000000 2011 39

2 23 4 0.00000000 2011 39

2 23 5 0.00000000 2011 39

2 23 6 0.00000000 2011 39

2 23 7 0.00000000 2011 39

2 23 8 0.00000000 2011 39

2 23 9 0.00000000 2011 39

2 23 10 0.11922233 2011 39

2 23 11 0.12547629 2011 39

2 23 12 0.19752816 2011 39

2 23 13 0.00589550 2011 39

2 23 14 0.00000000 2011 39

2 23 15 0.55187773 2011 39

2 23 16 0.00000000 2011 39

2 24 1 0.00000000 2011 39

2 24 2 0.00000000 2011 39

2 24 3 0.00000000 2011 39

2 24 4 0.00000000 2011 39

2 24 5 0.00000000 2011 39

2 24 6 0.00000000 2011 39

2 24 7 0.00000000 2011 39

2 24 8 0.00000000 2011 39

2 24 9 0.00000000 2011 39

2 24 10 0.11922233 2011 39

2 24 11 0.12547629 2011 39

2 24 12 0.19752816 2011 39

2 24 13 0.00589550 2011 39

2 24 14 0.00000000 2011 39

2 24 15 0.55187773 2011 39

2 24 16 0.00000000 2011 39
51 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

4.8 Creating a VMT Table by State, Year, Source Type, Hour, Road Type, and 

Average Speed Bin 

The ‘StateVMT_MakeTableQuery’ query creates a VMT Table by state, source type, hour, road 

type and average speed utilizing the VMT distribution factors described in 4.4, 4.5, 4.6 and 4.7. 

The SQL commands for this query are shown in Table 4.8. 

Table 4.8 :State VMT Table Query 

SELECT VMT_byBudgetArea.yearID, VMT_byBudgetArea.stateID, 

VMT_byBudgetArea.budgetID, roadtypedistribution1.sourceTypeID, 

hourvmtfraction.hourID, roadtypedistribution1.roadTypeID, 

avgSpeedDistribution.avgSpeedBinID, 

sourecetypepopulation.sourceTypeVMTFraction, hourvmtfraction.hourVMTFraction, 

roadtypedistribution1.roadTypeVMTFraction, 

avgSpeedDistribution.avgSpeedFraction, First(VMT_byBudgetArea.[Annual VMT]) 

AS [FirstOfAnnual VMT], First(VMT_byBudgetArea.[Daily VMT]) AS [FirstOfDaily 

VMT], [FirstOfDaily 

VMT]*[hourVMTFraction]*[sourceTypeVMTFraction]*[roadTypeVMTFraction]*[avgSpee

dFraction] AS DailyVMT, [FirstOfAnnual 

VMT]*[sourceTypeVMTFraction]*[hourVMTFraction]*[roadTypeVMTFraction]*[avgSpee

dFraction] AS AnnualizedVMT INTO StateVMT_Table 

FROM VMT_byBudgetArea INNER JOIN (((avgSpeedDistribution INNER JOIN 

hourvmtfraction ON (avgSpeedDistribution.hourDayID = hourvmtfraction.hourID) 

AND (avgSpeedDistribution.roadTypeID = hourvmtfraction.roadTypeID) AND 

(avgSpeedDistribution.sourceTypeID = hourvmtfraction.sourceTypeID)) INNER 

JOIN roadtypedistribution1 ON (avgSpeedDistribution.stateID = 

roadtypedistribution1.stateID) AND (avgSpeedDistribution.roadTypeID = 

roadtypedistribution1.roadTypeID) AND (avgSpeedDistribution.sourceTypeID = 

roadtypedistribution1.sourceTypeID)) INNER JOIN sourecetypepopulation ON 

(avgSpeedDistribution.sourceTypeID = sourecetypepopulation.sourceTypeID) AND 

(avgSpeedDistribution.stateID = sourecetypepopulation.stateID)) ON 

(VMT_byBudgetArea.yearID = avgSpeedDistribution.YearID) AND 

(VMT_byBudgetArea.stateID = avgSpeedDistribution.stateID) 

GROUP BY VMT_byBudgetArea.yearID, VMT_byBudgetArea.stateID, 

VMT_byBudgetArea.budgetID, roadtypedistribution1.sourceTypeID, 

hourvmtfraction.hourID, roadtypedistribution1.roadTypeID, 

avgSpeedDistribution.avgSpeedBinID, 

sourecetypepopulation.sourceTypeVMTFraction, hourvmtfraction.hourVMTFraction, 

roadtypedistribution1.roadTypeVMTFraction, 

avgSpeedDistribution.avgSpeedFraction 

HAVING (((avgSpeedDistribution.avgSpeedFraction)>0)) 

ORDER BY VMT_byBudgetArea.yearID, VMT_byBudgetArea.stateID, 

hourvmtfraction.hourID; 

5. Combining VMT and Emission Rates; Calculating Total Emissions 

5.1 Summarizing Distance-based Emissions by Source Type 

The daily VMT and annual VMT in each state, year, hour, source type, road type, and speed bin 

is multiplied by the appropriate rate per distance for each pollutant. This query is shown in 

Table 5.1. 
52 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

Table 5.1 :Emissions distance Query 

SELECT StateVMT_Table.stateID, StateVMT_Table.budgetID, 

StateVMT_Table.yearID, rateperdistance_state.monthID, StateVMT_Table.hourID, 

StateVMT_Table.sourceTypeID, StateVMT_Table.roadTypeID, 

StateVMT_Table.avgSpeedBinID, rateperdistance_state.pollutantID, 

StateVMT_Table.DailyVMT, StateVMT_Table.AnnualizedVMT, 

rateperdistance_state.SumOfratePerDistance, [DailyVMT]*[SumOfratePerDistance] 

AS EmissionsDist, [AnnualizedVMT]*[SumOfratePerDistance] AS 

AnnualEmissionsDist 

FROM StateVMT_Table INNER JOIN rateperdistance_state ON 

(StateVMT_Table.stateID = rateperdistance_state.StateID) AND 

(StateVMT_Table.yearID = rateperdistance_state.yearID) AND 

(StateVMT_Table.sourceTypeID = rateperdistance_state.sourceTypeID) AND 

(StateVMT_Table.hourID = rateperdistance_state.hourID) AND 

(StateVMT_Table.roadTypeID = rateperdistance_state.roadTypeID) AND 

(StateVMT_Table.avgSpeedBinID = rateperdistance_state.avgSpeedBinID) 

GROUP BY StateVMT_Table.stateID, StateVMT_Table.budgetID, 

StateVMT_Table.yearID, rateperdistance_state.monthID, StateVMT_Table.hourID, 

StateVMT_Table.sourceTypeID, StateVMT_Table.roadTypeID, 

StateVMT_Table.avgSpeedBinID, rateperdistance_state.pollutantID, 

StateVMT_Table.DailyVMT, StateVMT_Table.AnnualizedVMT, 

rateperdistance_state.SumOfratePerDistance; 

A second query further summarizes the emissions by source type. This is necessary in order to 

combine with vehicle-based emissions that are independent of road type and speed. 

5.2 Summarizing Vehicle-based Emissions by Source type 

The source population for each county, year, hour, and source type is multiplied by the rate per 

vehicle for each pollutant. This query is shown in Table 5.2. 

 

Table 5.2: Emissions Vehicle Query 

SELECT VMT_byBudgetArea.budgetID, VMT_byBudgetArea.stateID, 

ratepervehicle_state.yearID, ratepervehicle_state.monthID, 

ratepervehicle_state.hourID, ratepervehicle_state.sourceTypeID, 

sourecetypepopulation.sourceTypeFraction, 

VMT_byBudgetArea.SourceTypePopulation, ratepervehicle_state.pollutantID, 

ratepervehicle_state.SumOfratePerVehicle, 

((Nz([VMT_byBudgetArea]!sourceTypePopulation*[sourceTypeFraction],0)/24)) AS 

STPop, Nz([VMT_byBudgetArea]!sourceTypePopulation*[sourceTypeFraction],0) AS 

STPop2, 

Nz([VMT_byBudgetArea]!sourceTypePopulation*[sourceTypeFraction]*[SumOfratePer

Vehicle],0) AS emissionsVehicle, 

Nz(([VMT_byBudgetArea]!sourceTypePopulation*[sourceTypeFraction]*[SumOfratePe

rVehicle])*365,0) AS AnnualemissionsVehicle 

FROM (sourecetypepopulation INNER JOIN ratepervehicle_state ON 

(sourecetypepopulation.sourceTypeID = ratepervehicle_state.sourceTypeID) AND 

(sourecetypepopulation.stateID = ratepervehicle_state.StateID)) INNER JOIN 

VMT_byBudgetArea ON (ratepervehicle_state.StateID = VMT_byBudgetArea.stateID) 

AND (ratepervehicle_state.yearID = VMT_byBudgetArea.yearID) 

GROUP BY VMT_byBudgetArea.budgetID, VMT_byBudgetArea.stateID, 

ratepervehicle_state.yearID, ratepervehicle_state.monthID, 

ratepervehicle_state.hourID, ratepervehicle_state.sourceTypeID, 

sourecetypepopulation.sourceTypeFraction, 

VMT_byBudgetArea.SourceTypePopulation, ratepervehicle_state.pollutantID, 

ratepervehicle_state.SumOfratePerVehicle; 
53 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

5.3 Ramp Emissions 

Ramp emission rates, calculated as discussed in Section 3, are multiplied by ramp VMT in each 

state, year and source type. This query is shown in Table 5.3.

Table 5.3: Ramp Emissions Query

SELECT VMT_byBudgetArea.stateID, VMT_byBudgetArea.yearID, 

hourvmtfraction.hourID, hourvmtfraction.sourceTypeID, 

hourvmtfraction.hourVMTFraction, ramp_rate.pollutantID, 

VMT_byBudgetArea.[Ramp VMT], ([Ramp VMT]*[hourVMTFraction])/13 AS 

HourlyRampVMT, ramp_rate.ramprate, [HourlyRampVMT]*[ramprate] AS 

RampEmissions, ([HourlyRampVMT]*[ramprate])*340 AS RampEmissionsAnnual 

FROM (hourvmtfraction INNER JOIN ramp_rate ON hourvmtfraction.hourID = 

ramp_rate.hourID) INNER JOIN VMT_byBudgetArea ON (ramp_rate.yearID = 

VMT_byBudgetArea.yearID) AND (ramp_rate.StateID = VMT_byBudgetArea.stateID) 

WHERE (((hourvmtfraction.roadTypeID)=4)) 

ORDER BY VMT_byBudgetArea.stateID, VMT_byBudgetArea.yearID, 

hourvmtfraction.hourID, hourvmtfraction.sourceTypeID, ramp_rate.pollutantID;

5.4 Summarizing Results 

Distance-based emissions by source type, vehicle-based emissions by source type, and ramp emissions 

by source type are summed by state, year and pollutant. This query is shown below. This is also where 

criteria may be set for limiting the results. A sum of VMT and source type population is also useful as a 

verification that all steps were run properly. The appropriate monthID criteria should be set here. The 

annual average temperature profile is contained in April (monthID=4). 

Table 5.41:Results by State Query 

SELECT EmissionsDistance_bySourceType_State.stateID, 

EmissionsDistance_bySourceType_State.budgetID, EmissionsDistance_bySourceType_State.yearID, 

EmissionsDistance_bySourceType_State.pollutantName,

Sum(EmissionsDistance_bySourceType_State.SumOfDailyVMT) AS SumOfSumOfDailyVMT, 

Sum(RampEmissions_Query_State.HourlyRampVMT) AS SumOfHourlyRampVMT1, 

Sum(EmissionsDistance_bySourceType_State.SumOfAnnualizedVMT) AS SumOfSumOfAnnualizedVMT, 

First(EmissionsVehicle_Query_State.SourceTypePopulation) AS FirstOfSourceTypePopulation, 

Sum(EmissionsVehicle_Query_State.SourceTypePopulation) AS SumOfSourceTypePopulation, 

Sum(EmissionsDistance_bySourceType_State.SumOfEmissionsDist) AS SumOfSumOfEmissionsDist, 

Sum(EmissionsDistance_bySourceType_State.SumOfAnnualEmissionsDist) AS 

SumOfSumOfAnnualEmissionsDist, Sum(Nz([emissionsVehicle],0)) AS EmissionsVeh, 

Sum(Nz([AnnualemissionsVehicle],0)) AS AnnualEmissionsVeh, 

Sum(RampEmissions_Query_State.RampEmissions) AS SumOfRampEmissions, 

Sum(RampEmissions_Query_State.RampEmissionsAnnual) AS SumOfRampEmissionsAnnual, 

(([SumOfSumOfEmissionsDist]+[EmissionsVeh]+[SumOfRampEmissions])/1000)*0.001102 AS 

DailyEmissionsTONS, 

(([SumOfSumOfAnnualEmissionsDist]+[AnnualEmissionsVeh]+[SumOfRampEmissionsAnnual])/1000)*0.0

01102 AS AnnualEmissionsTONS 

FROM (EmissionsDistance_bySourceType_State LEFT JOIN EmissionsVehicle_Query_State ON 
54 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

(EmissionsDistance_bySourceType_State.yearID = EmissionsVehicle_Query_State.yearID) AND 

(EmissionsDistance_bySourceType_State.stateID = EmissionsVehicle_Query_State.stateID) AND 

(EmissionsDistance_bySourceType_State.monthID = EmissionsVehicle_Query_State.monthID) AND 

(EmissionsDistance_bySourceType_State.hourID = EmissionsVehicle_Query_State.hourID) AND 

(EmissionsDistance_bySourceType_State.sourceTypeID = EmissionsVehicle_Query_State.sourceTypeID) 

AND (EmissionsDistance_bySourceType_State.pollutantID = EmissionsVehicle_Query_State.pollutantID)) 

INNER JOIN RampEmissions_Query_State ON (EmissionsDistance_bySourceType_State.stateID = 

RampEmissions_Query_State.stateID) AND (EmissionsDistance_bySourceType_State.yearID = 

RampEmissions_Query_State.yearID) AND (EmissionsDistance_bySourceType_State.sourceTypeID = 

RampEmissions_Query_State.sourceTypeID) AND (EmissionsDistance_bySourceType_State.pollutantID = 

RampEmissions_Query_State.pollutantID) AND (EmissionsDistance_bySourceType_State.hourID = 

RampEmissions_Query_State.hourID) 

GROUP BY EmissionsDistance_bySourceType_State.stateID, 

EmissionsDistance_bySourceType_State.budgetID, EmissionsDistance_bySourceType_State.yearID, 

EmissionsDistance_bySourceType_State.pollutantName,

EmissionsDistance_bySourceType_State.monthID, EmissionsDistance_bySourceType_State.pollutantID 

HAVING (((EmissionsDistance_bySourceType_State.monthID)=4)); 

County-level emissions are also calculated based on county VMT, as reported by the OKI Travel Demand 

Model. Table 5.42 shows the query for calculating the county level results. 

Table 5.42:Results by County Query 

SELECT VMT.State, VMT.County, EmissionsDistance_bySourceType_State.stateID, 

EmissionsDistance_bySourceType_State.budgetID, EmissionsDistance_bySourceType_State.yearID, 

EmissionsDistance_bySourceType_State.pollutantName, VMT.SourceTypePopulation, VMT.[Daily VMT], 

VMT.[Annual VMT], VMT.[All Daily VMT], [Daily VMT]/[SumOfSumOfDailyVMT] AS CountyFraction, 

Sum(EmissionsDistance_bySourceType_State.SumOfDailyVMT) AS SumOfSumOfDailyVMT, 

Sum(RampEmissions_Query_State.HourlyRampVMT) AS SumOfHourlyRampVMT1, 

Sum(EmissionsDistance_bySourceType_State.SumOfAnnualizedVMT) AS SumOfSumOfAnnualizedVMT, 

First(EmissionsVehicle_Query_State.SourceTypePopulation) AS FirstOfSourceTypePopulation, 

Sum(EmissionsVehicle_Query_State.SourceTypePopulation) AS SumOfSourceTypePopulation, 

Sum(EmissionsDistance_bySourceType_State.SumOfEmissionsDist) AS SumOfSumOfEmissionsDist, 

Sum(EmissionsDistance_bySourceType_State.SumOfAnnualEmissionsDist) AS 

SumOfSumOfAnnualEmissionsDist, Sum(Nz([emissionsVehicle],0)) AS EmissionsVeh, 

Sum(Nz([AnnualemissionsVehicle],0)) AS AnnualEmissionsVeh, 

Sum(RampEmissions_Query_State.RampEmissions) AS SumOfRampEmissions, 

Sum(RampEmissions_Query_State.RampEmissionsAnnual) AS SumOfRampEmissionsAnnual, 

(([SumOfSumOfEmissionsDist]+[EmissionsVeh]+[SumOfRampEmissions])/1000)*0.001102 AS 

DailyEmissionsTONS, 

(([SumOfSumOfAnnualEmissionsDist]+[AnnualEmissionsVeh]+[SumOfRampEmissionsAnnual])/1000)*0.0

01102 AS AnnualEmissionsTONS, [DailyEmissionsTONS]*[CountyFraction] AS CountyDailyEmissions, 

[AnnualEmissionsTONS]*[CountyFraction] AS CountyAnnualEmissions 

FROM VMT INNER JOIN ((EmissionsDistance_bySourceType_State LEFT JOIN 

EmissionsVehicle_Query_State ON (EmissionsDistance_bySourceType_State.pollutantID = 

EmissionsVehicle_Query_State.pollutantID) AND (EmissionsDistance_bySourceType_State.sourceTypeID 

= EmissionsVehicle_Query_State.sourceTypeID) AND (EmissionsDistance_bySourceType_State.hourID = 
55 Appendix: OKI Technical Documentation for Using EPA MOVES to Develop Mobile Source Emissions

EmissionsVehicle_Query_State.hourID) AND (EmissionsDistance_bySourceType_State.monthID = 

EmissionsVehicle_Query_State.monthID) AND (EmissionsDistance_bySourceType_State.stateID = 

EmissionsVehicle_Query_State.stateID) AND (EmissionsDistance_bySourceType_State.yearID = 

EmissionsVehicle_Query_State.yearID)) INNER JOIN RampEmissions_Query_State ON 

(EmissionsDistance_bySourceType_State.hourID = RampEmissions_Query_State.hourID) AND 

(EmissionsDistance_bySourceType_State.pollutantID = RampEmissions_Query_State.pollutantID) AND 

(EmissionsDistance_bySourceType_State.sourceTypeID = RampEmissions_Query_State.sourceTypeID) 

AND (EmissionsDistance_bySourceType_State.yearID = RampEmissions_Query_State.yearID) AND 

(EmissionsDistance_bySourceType_State.stateID = RampEmissions_Query_State.stateID)) ON 

(VMT.yearID = EmissionsDistance_bySourceType_State.yearID) AND (VMT.stateID = 

EmissionsDistance_bySourceType_State.stateID) 

GROUP BY VMT.State, VMT.County, EmissionsDistance_bySourceType_State.stateID, 

EmissionsDistance_bySourceType_State.budgetID, EmissionsDistance_bySourceType_State.yearID, 

EmissionsDistance_bySourceType_State.pollutantName, VMT.SourceTypePopulation, VMT.[Daily VMT], 

VMT.[Annual VMT], VMT.[All Daily VMT], EmissionsDistance_bySourceType_State.monthID, 

EmissionsDistance_bySourceType_State.pollutantID 

HAVING (((EmissionsDistance_bySourceType_State.monthID)=4));
Appendix F

Section 110 Provisions and

Infrastructure Submittal
Steven L. Beshear 

Governor 

Leonard K. Peters 

Secretary 

Energy and Environment cabinet 

Department for Environmental Protection 

Division for Air Quality 200 Fair Oaks Lane, ld Floor 

Frankfort, Kentucky 40601-1403 

www.air.ky.gov 

September 8,2009 

Stan Meiburg 

Acting Regional Administrator 

U.S. EPA, Region 4 

Atlanta Federal Center 

61 Forsyth Street, SW 

Atlanta, Georgia 30365 

Dear Mr. Meiburg: 

The Kentucky Energy and Environment Cabinet (EEC) hereby submits to the U.S. 

Environmental Protection Agency (EPA) a letter certifying that Kentucky's existing State 

Implementation Plan (SIP) contains Section 110 provisions that address the requirements for the 

PM2 5 8-hour ozone, and Lead National Ambient Air Quality Standards (NAAQS). 

Under section 110(a)(l) and (2) of the Clean Air Act (CAA), all states are required to 

submit plans to provide for the implementation, maintenance, and enforcement of any new or 

revised National Ambient Air Quality Standard (NAAQS). Section 110(a)(l) and (2) require 

states to address basic program elements, including requi&ments for emissions inventories, 

monitoring, and modeling, among other things. States are required to submit SIPS to EPA which 

demonstrate that these basic program elements have been addressed within 3 years of the 

promulgation of any new or revised NAAQS. Subsections (A) through (M) of section 110(a)(2), 

set forth the elements that a state's program must contain in the SIP. The list of section 110(a)(2) 

NAAQS requirements and Kentucky's provisions are listed below. 

Emission limits and other control measures: Section 110(a)(2)(A) of the CAA requires SIPS to 

include enforceable emission limits and other control measures, means or techniques, schedules 

or compliance and other related matters. 

Kentucky Authority: 

0 Kentucky Revised Statute Chapter 224 Section 10-100 (KRS 224.10-100) provides the 

Energy and Environment Cabinet the authority to administer all rules, regulations and 

orders promulgated under Chapter 224, and to provide for the prevention, abatement, and 

control of all water, land, and air pollution. 

Chapter 50 General Administrative Procedures. 

Printedon Recycled Paper 
Stan Meiburg 

US. EPA, Region 4 

Page 2 

September 8,2009 

Regulation 40 1 KAR 5 1 :010 Attainment Status Designations, establishes nonattainment 

areas and timetables for these areas to achieve the standard. The division is in the 

process of updating this regulation to specify PM2 5 as well as PMlo but, continues to use 

PMlo as the surrogate for PM2 5 as recommended by U.S. EPA. 

0 Regulation 401 KAR 50:055 General Compliance Requirements. Section 1 Emissions 

shutdown and malfunction. 

Chapter 51 Attainment and Maintenance of the National Ambient Air Quality Standards. 

Regulation 401 KAR 51:005 Purpose and General Provisions. Section 3 Notification 

and Recordkeeping. Section 4 Monitoring Regs. 

Chapter 52 Permits, Registrations, and Prohibitory Rules. 

401 KAR 52:020 Title V Permits establishes requirements for air contaminant sources 

located in Kentucky that are required to obtain a Title V permit. 

401 KAR 52:030 Federally-Enforceable Permits for Nonmajor Sources establishes 

requirements for air contaminant sources located in Kentucky that accept emissions 

limitations to avoid the New Source Review requirements under Title I of the Clean Air 

Act or the Operating Permit Program requirements under Title V of the Clean Air Act. 

401 KAR 52:040 State-Origin Permits establishes requirements for minor sources whose 

permits are not required to be federally enforceable. 

Regulation 401 KAR 53:010, Ambient Air Quality Standards. Serves to establish the 

requirement for regulations for the prevention, abatement, and control of air pollution. 

Ambient air quality monitoringldata system: Section 110(a)(2)(B) of the CAA requires SIPS 

to include provisions to provide for establishment and operation of ambient air quality monitors, 

collecting and analyzing ambient air quality data, and presentation of these data available to EPA 

upon request. 

Kentucky Authority: 

KRS 224.10-100 (22) requires the installation, maintenance, and use of equipment, 

devices, or test and methodologies to monitor the nature and amount of any substance 

emitted into the ambient air and to provide the information to the cabinet. 

Chapter 50 General Administrative Procedures spells out the requirements for 

monitoring. 

Regulation 401 KAR 51:017 Prevention of SignzJicant Deterioration of Air Quality 

(PSD) applies to the construction of any new major stationary source or any project at an 

existing major stationary source in an area designated as attainment or unclassifiable. 

Regulation 401 KAR 50:050 authorize the monito'ring of ambient air quality. 

Regulation 401 KAR 53:010 Ambient Air Quality Standards sets ambient air quality 

standards necessary for the protection of the public health, welfare, and property. 

Regulation 401 KAR 50:045 Performance Test establishes the requirements for these 

tests. 
Stan Meiburg 

U.S. EPA, Region 4 

Page 3 

September 8,2009 

Program for enforcement of control measures: Section 110(a)(2)(C) of the CAA requires 

States to include a program that provides for enforcement of all SIP measures and the regulation 

of construction of new or modified stationary sources to meet prevention of significant 

deterioration (PSD) and nonattainment new source review (NSR) requirements. 

Kentucky Authority: 

Chapter 5 1 Attainment and Maintenance of the NAAQS. 

Regulation 401 KAR 51:017 Prevention of SigniJicant Deterioration of Air Quality 

applies to the construction of any new major stationary source or any project at an 

existing major stationary source in an area designated as attainment or unclassifiable. 

The division is in the process of updating this regulation to specify PM2 5 as well as PMlo 

but, continues to use PMlo as the surrogate for PM2 5 as recommended by U.S. EPA. 

Regulation 401 KAR 50:060 Enforcement, provides for enforcement of the terms and 

conditions of permits and compliance schedules. 

interstate transport: Section 110(a)(2)(D) of the CAA requires SIPS to include provisions 

prohibiting any source of other type of emissions activity in one state from contributing 

significantly to nonattainment of the NAAQS in another State. States are required to submit 

1 lO(a)(2)(D)(i) plans to demonstrate compliance with these provisions. 

Kentucky Authority: 

Finding regarding section llO(a)(2)(D)(i) promulgated submitted on 12/10/07 for the 

1997 8-hour ozone and PM? -. 5 National Ambient Air Oualitv . Standards.. 

Kentucky submitted the 110(a)(l) plan on 12/7/07 for the 1997 &hour ozone and PM2.5 

NAAQS. 

~entuck~'s Clean Air Interstate Rule (CAB) was approved 10/4/07 (72 FR 56623) 

The Final Regional Haze SIP was submitted to U.S. EPA on 6/25/08. 

The Final 8-Hour Ozone Attainment Demonstration was submitted to U.S. EPA on 

12/07/07. 

The Final PM,, Attainment Demonstration was submitted to U.S. EPA on 12/03/08. 

Adequate resources: Section 110(a)(2)(E) of the CAA requires states to provide for adequate 

personnel, funding and legal authority under State law to carry out its SIP and related issues. 

Kentucky Authority: 

KRS 224.10-100 Powers and Duties of the Cabinet, provides for authority under State 

law to carry out its SIP and related issues. 
Stan Meiburg 

U.S. EPA, Region 4 

Page 4 

September 8,2009 

KRS 224.10-100 Powers and Duties of the Cabinet, Section (11) provides for the 

authority to accept, receive, and administer grants or other funds or gifts from public and 

private agencies including the federal government for the purpose of carrying out any fo 

the functions of the cabinet. 

Regulation 401 KAR 50:038 Air Emissions Fee provides for the assessment of fees 

necessary to fund the state Title V permit program. 

Stationary source monitoring system: Section 110(a)(2)(F) of the CAA requires States to 

establish a system to monitor emissions from stationary sources and to submit periodic emissions 

reports. 

Kentucky Authority: 

Chapter 50 General Administrative Procedures. 

Regulation 401 KAR 50:050 Monitoring, Section 1 Monitoring Records and Reporting 

establishes the requirements for the installation, use, and maintenance of stack gas and 

ambient air monitoring equipment. 

Regulation 401 KAR 50:055 General Compliance Requirements, Section 1 Emission 

During Shut Down Malfunction. 

Emergency power: Section 110(a)(2)(G) of the CAA requires States to provide for authority to 

address activities causing imminent and substantial endangerment to public health, including 

contingency plans to implement the emergency episode provisions in their SIPS. 

Kentucky Authority: 

Chapter 55 Emergency Episodes. 

Regulation 401 KAR 55:005 Signzjkant Harm Criteria, Section 1 Purpose defines those 

levels of pollutant concentration whicli must be prevented in order to avoid significant 

harm to the health of persons. 

Regulation 401 KAR 55:010 Episodic Criteria defines those levels of pollutant 

concentrations which justify the proclamation of an air pollution alert, air pollution 

warning, an air pollution emergency. 

Regulation 401 KAR 55:015 Episode Declaration provides for the curtailment or 

reduction of processes or operations which emit an air contaminant or an air contaminant 

precursor whose criteria has been reached and are located in the affected areas for which 

an episode level has been declared. 

All of Kentucky is considered a Priority 111 Area, and therefore no emergency episode 

plan for PM, , is required. 

An emergency episode was already included for the 1-hour ozone standard and would 

suffice for the 8-hour ozone standard. 
Stan Meiburg 

US. EPA, Region 4 

Page 5 

September 8,2009 

Future SIP revisions: Section 110(a)(2)(H) of the CAA requires States to have the authority to 

revise their SIPS in response to chhges in the NAAQS, availability of improved methods for 

attaining the NAAQS, or in response to an EPA finding that the SIP is substantially inadequate. 

Kentucky Authority: 

Chapter 53 Ambient Air Quality. 

Regulation 401 KAR 53:OlO Ambient Air Quality Standards. 

Regulation 401 KAR 51:010 Attainment Status Designations contains provisions for the 

cabinet to review applicable data and submit to US. EPA revisions to the attainmentnonattainment list pursuant to 42 USC 7407. 

Consultation with government officials: Section 110(a)(2)(J) of the CAA requires States to 

provide a process for consultation with local governments and Federal Land Managers carrying 

out NAAQS implementation requirements pursuant to CAA Section 121 relating to consultation. 

Kentucky Authority: 

Chapter 50 General Administrative Procedures. 

Regulation 401 KAR 51:017 Prevention of Signz$cant Deterioration of Air Quality. 

Section 15 Public Participation. 

Regulation 401 KAR 52100 Public, Affected State, and US. EPA Review establishes the 

procedures used by the cabinet to provide for the review of federally-enforceable permits 

by the public, affected states, and the U.S. EPA. 

Regulation 401 KAR 50:066 Conformity of Transportation Plans, Programs, and 

Projects establishes criteria and procedures for the interagency consultation process used 

in demonstrating conformity of federal transportation plans to the SIP. 

Public notification: Section 110(a)(2)(J) of the CAA further requires States to notify the public 

if NAAQS are exceeded in an area and to enhance public awareness of measure that can be taken 

to prevent exceedances. 

Kentucky Authority: 

Chapter 5 1 Attainment and Maintenance ofthe National Ambient Air Quality Standards. 

Regulation 401 KAR 51:017 Prevention of Signijkant Deterioration (PSD) of Air 

Quality. Section 15 Public Participation. 
Stan Meiburg 

U.S. EPA, Region 4 

Page 6 

September 8,2009 

Regulation 401 KAR 52:100 Public, Affected State, and US. EPA Review establishes the 

procedures used by the cabinet to provide for the review of federally-enforceable permits 

by the public, affected states, and the U.S. EPA. 

PSD and visibility protection: Section 110(a)(2)(J) of the CAA also requires States to meet 

applicable requirements of Part C related to PSD and visibility protection. 

Kentucky Authority: 

Chapter 51. Attainment and Maintenance of the National Ambient Air Quality Standards. 

Regulation 401 KAR 51 :O17 Prevention of Signzjkant Deterioration ofAiv Quality. 

0 Regulation 401 KAR 63:005 Open Burning establishes requirements for the control of 

open burning. 

Regulation 401 KAR 63:010 Fugitive Emissions provides for the control of figitive 

emissions. 

Air quality modelmg/data: Section 110(a)(2)(K) of the CAA requires that SIPS provide for 

performing air quality modeling so that effects on air quality of emissions from NAAQS 

pollutants can be predicted and submission of such data to EPA can be made. 

Kentucky Authority: 

* Chapter 50 General Administrative Procedures. 

Regulation 401 KAR 50:040 Air Quality Models specifies general provisions for the use 

of air quality models. 

Regulation 401 KAR 50:050 Monitoring. 

Permitting fees: Section 110(a)(2)(L) of the CAA requires SrPs to require each major stationary 

source to pay permitting fees to cover the costs of reviewing, approving, implementing, and 

enforcing a permit. 

Kentucky Authority: 

401 KAR 50:038 Air Emissions Fee provides for the assessment of fees necessary to fknd 

the state permit program. 
Stan Meiburg 

U.S. EPA, Region 4 

Page 7 

September 8,2009 

Consultation/participation by affected local entities: Section 110(a)(2)(M) of the CAA 

requires States to provide for consultation and participation in SIP development by local political 

subdivision affected by the SIP. 

Kentucky Authority: 

Chapter 65 Mobile Source Related Emissions. 

Regulation 401 KAR 50:066 Conformity of Transportation Plans, Programs, and 

Projects. 

Regulation 401 KAR 50:035 Permits. Section 7 Procedures for public participation. 

KRS Chapter 77 Local Authority. 

If you have any questions or comments concerning this matter, please contact John 

Gowins at the Division for Air Quality at (502) 564-3999. 
Appendix G

Kentucky Regulations (KAR)

CAIR

NOx SIP Call

KY Cabinet Powers and Duties

Reasonably Available Control Measures

Open Burning

Fugitive Emissions
 401 KAR 51:210. CAIR NOx annual trading program.

 

 RELATES TO: KRS 224.10-100, 224.20-100, 224.20-110, 224.20-120, 40 C.F.R. 51.121, 51.122, 72.2, 75.1, 75.2, 75.4, 75.11-75.13, 75.17, 75.19, 

75.20, 75.24, 75.70, 75.72, 75.74, 75.75, Part 96, 42 U.S.C. 7410

 STATUTORY AUTHORITY: KRS 224.10-100(5), 42 U.S.C. 7410

 NECESSITY, FUNCTION, AND CONFORMITY: KRS 224.10-100(5) requires the Environmental and Public Protection Cabinet to promulgate 

administrative regulations for the prevention, abatement, and control of air pollution. This administrative regulation establishes requirements for the

control of nitrogen oxides (NOx) emissions from large boilers and turbines used in power plants, pursuant to the federal mandate published under the

Clean Air Interstate Rule (CAIR), 40 C.F.R. 96.101 to 96.188. This administrative regulation is not more stringent than the provisions allowed under the

federal mandate.

 

 Section 1. Applicability. This administrative regulation shall apply to CAIR NOx units in Kentucky that are subject to 40 C.F.R. 96.104.

 

 Section 2. Compliance Requirements. CAIR NOx units shall comply with the following requirements:

 (1) 40 C.F.R. 96.101 to 96.108 (Subpart AA), "CAIR NOx Annual Trading Program General Provisions";

 (2) 40 C.F.R. 96.110 to 96.115 (Subpart BB), "CAIR Designated Representative for CAIR NOx Sources";

 (3) 40 C.F.R. 96.120 to 96.124 (Subpart CC), "Permits";

 (4) 40 C.F.R. 96.150 to 96.157 (Subpart FF), "CAIR NOx Allowance Tracking System";

 (5) 40 C.F.R. 96.160 to 96.162 (Subpart GG), "CAIR NOx Allowance Transfers";

 (6) 40 C.F.R. 96.170 to 96.175 (Subpart HH), "Monitoring and Reporting"; and

 (7) 40 C.F.R. 96.180 to 96.188 (Subpart II), "Cair Nox Opt-in Units".

 

 Section 3. Methodology for the Allocation and Sale of CAIR NOx Annual Allowances. The number of CAIR NOx allowances to be allocated to each

CAIR NOx unit by the cabinet and to be sold by the Commonwealth of Kentucky shall be determined pursuant to this section.

 (1) The total number of CAIR NOx allowances shall be:

 (a) For the 2009 through 2014 control periods, 83,205 tons, as specified in 40 C.F.R. 96.140; and

 (b) For the 2015 control periods and thereafter, 69,337 tons, as specified in 40 C.F.R. 96.140.

 (2) The total number of CAIR NOx allowances assigned to Kentucky shall be divided into separate pools as follows:

 (a) Ninety-eight (98) percent of this amount allocated for each control period to units that commence commercial operation before:

 1. January 1, 2006, for the control periods 2009, 2010, 2011, 2012, 2013, and 2014;

 2. January 1, 2009, for the control period 2015; and

 3. Thereafter, January 1 of the year that is six (6) years before the first year of the next control period; and

 (b) Two (2) percent of this amount for each control period sold by the Commonwealth of Kentucky with the proceeds deposited into Kentucky's

general fund.

 (3) For each CAIR NOx unit, the baseline heat input or adjusted control period heat input in mmBtu shall be determined and shall be used to

determine CAIR NOx allowances for the pool specified in subsection (2)(a) of this section as follows:

 (a) For CAIR NOx units commencing operation before January 1, 2001, and

 1. Operating each calendar year during a period of five (5) or more consecutive years, the baseline heat input shall be the average of the three (3) 

highest amounts of the unit's adjusted control period heat input for 2001 through 2005; or

 2. For units not having operated each calendar year for a period of five (5) or more consecutive years, the baseline heat input shall be established

during the next allocation period when the unit has five (5) consecutive years of operation, using the average of the three (3) highest amounts of the

unit's adjusted control period heat input for the most recent five (5) consecutive years of operation;

 (b) For units commencing operation on or after January 1, 2001, and operating each calendar year during a period of five (5) or more consecutive

years, the baseline heat input shall be the average of the three (3) highest amounts of the unit's adjusted control period heat input for the most recent

five (5) consecutive years of operation; or

 (c) For units that have not operated each calendar year during a period of five (5) or more consecutive years, the baseline heat input shall not be

established. For purposes of allocations, the heat input shall be the average of the three (3) highest amounts of the unit's adjusted control period heat

input for the previous five (5) years of operation, the:

 1. Adjusted control period heat input for a control period of not operating shall equal zero; and

 2. Cabinet shall allocate CAIR NOx allowances for the unit.

 (4) The adjusted control period heat input for each year shall be calculated as follows:

 (a) If the unit is coal-fired during the year, the unit's control period heat input for that year shall be multiplied by 100 percent;

 (b) If the unit is oil-fired during the year, the unit's control period heat input for that year shall be multiplied by sixty (60) percent; and

 (c) If the unit is not subject to paragraphs (a) or (b) of this subsection, the unit's control period heat input for that year shall be multiplied by forty (40)

percent.

 (5) For a calendar year, the unit's control period heat input and the unit's status as coal-fired or oil-fired shall be determined:

 (a) In accordance with 40 C.F.R. Part 75, if the unit is subject to 40 C.F.R. Part 75;

 (b) By the best available data reported to the cabinet for the unit if the unit is not otherwise subject to 40 C.F.R. Part 75; or

 (c) By the best available data obtained by the cabinet.

 (6) For CAIR NOx units included in the pool specified in subsection (2)(a) of this section, the cabinet shall allocate CAIR NOx allowances to each

CAIR NOx unit in an amount equal to the result obtained by:

 (a) Multiplying the total amount of CAIR NOx allowances specified in subsection (2)(a) of this section by the baseline heat input for each unit or the

heat input established under subsection (3)(c) of this section;

 (b) Dividing by the total amount of baseline heat input and the heat input established under subsection (3)(c) of this section for all applicable CAIR

NOx units; and

 (c) Rounding to the nearest whole CAIR NOx allowance, as appropriate.

 (7) The cabinet shall submit to the U.S. EPA and CAIR NOx sources the CAIR NOx allowances to be allocated and sold from the pools specified in

subsection (2) of this section in a format prescribed by the U.S. EPA by:

 (a) October 31, 2006, for the control periods in 2009, 2010, 2011, 2012, 2013, and 2014;

 (b) October 31, 2009, for control period 2015; and

 (c) October 31 of each year thereafter, for the control period in the sixth year after the year of the applicable deadline for submission under this

paragraph.

 

 Section 4. Compliance Supplement Pool. The CAIR designated representative may request early reduction credits and the allocation of CAIR NOx

401 KAR 51:210. CAIR NOx annual trading program. Page 1 of 2

mhtml:file://S:\Program Planning\Eval\PM2.5 Redesignation NKY Nov 2010\FINAL Doc Appe... 11/10/2010
allowances from the compliance supplement pool established under 40 C.F.R. 96.143(a) for any CAIR NOx unit in the Commonwealth that achieves

emission reductions in 2007 or 2008 or in both years when compared to the unit’s NOx emission rate during the 2005 control period. Only emission 

reductions achieved in 2007 or 2008 or in both years that are not necessary to comply with any state or federal emissions limitation applicable during

2007 and 2008 may be used to request early reduction credits as specified in this section.

 (1) The owners and operators of the CAIR NOx unit shall monitor and report the NOx emissions rate and the heat input of the unit in accordance with

40 C.F.R. 96.170 to 96.175 in each control period for which the early reduction is requested and for the 2005 control period. The difference resulting

from subtracting the applicable 2007 or 2008 control period NOx emission rate from the 2005 control period NOx emission rate multiplied by the

applicable 2007 or 2008 control period heat input divided by 2000, shall provide the amount in tons of the early reduction credit request.

 (2) The CAIR designated representative shall submit to the cabinet by July 1, 2009, a request for allocation of an amount of CAIR NOx allowances

from the compliance supplement pool:

 (a) Not exceeding the sum of the amounts, in tons, of the unit's NOx emission reductions in 2007 and 2008 that are not necessary to comply with any

state or federal emissions limitation applicable during the years, determined in accordance with 40 C.F.R. 96.170 to 96.175; or

 (b) Not exceeding the minimum amount of CAIR NOx allowances necessary to remove undue risk to the reliability of electricity supply.

 (3) To request allocations pursuant to subsection (2)(b) of this section, the CAIR designated representative shall demonstrate that, in the absence of

allocation of an amount of CAIR NOx allowances requested, the unit's compliance with CAIR NOx emissions limitation for the control period in 2009

would create an undue risk to the reliability of electricity supply during the control period. This demonstration shall include a showing that the owners and

operators cannot feasibly obtain a sufficient amount of:

 (a) Electricity from other electricity generating facilities during the installation of control technology at the unit for compliance with the CAIR NOx

emissions limitation to prevent undue risk; or

 (b) CAIR NOx allowances in accordance with this section, or otherwise, to prevent undue risk.

 (4) Early reduction credits shall be rounded to the nearest whole number and distributed in the form of one (1) NOx allowance for one (1) ton of NOx

emission reduction.

 (5) The cabinet shall distribute the early reduction credits on a proportional basis.

 (a) The total amount of early reduction credit available to a CAIR NOx unit shall be determined by the following calculation:

 1. The unit's baseline heat input determined in Section 3(3)(a)1 of this administrative regulation;

 2. Divided by the total amount baseline heat input from all sources pursuant to Section 3(3)(a)1 of this administrative regulation; and

 3. Multiplied by the early reduction credits available pursuant to 40 C.F.R. 96.143(a).

 (b) The unused early reduction credits shall be combined together and distributed pro rata to those CAIR NOx units with early reduction credits that

exceeded the amount of credits made available by the cabinet pursuant to paragraph (a) of this subsection by the following calculation:

 1. The applicable unit's emission reductions that exceeded the credits made available pursuant to paragraph (a) of this subsection;

 2. Divided by the total NOx emission reductions that exceeded the credits provided under paragraph (a) of this subsection from all applicable units;

 3. Multiplied by the total number of unused early reduction credits.

 (c) Early reduction credits provided under paragraph (b) of this subsection shall not cause the early reduction credits allocated to the source to

exceed the number of early reduction credits requested.

 (6) By November 30, 2009, the cabinet shall determine and submit to the U.S. EPA the allocations under this section.

 (7) By January 1, 2010, the U.S. EPA shall record the allocations submitted under subsection (6) of this section.

 

 Section 5. Sale of CAIR NOx Allowances by the Commonwealth of Kentucky. (1) The Commonwealth of Kentucky shall establish an account

pursuant to 40 C.F.R. 96.151(b) for the purpose of selling the CAIR NOx allowances in the pool specified in Section 3(2)(b) of this administrative

regulation.

 (2) The proceeds from the sale of the CAIR NOx allowances shall be deposited in the general fund of the Commonwealth of Kentucky. (33 

Ky.R. 1015; Am. 1611; 1798; eff. 2-2-2007.)

401 KAR 51:210. CAIR NOx annual trading program. Page 2 of 2

mhtml:file://S:\Program Planning\Eval\PM2.5 Redesignation NKY Nov 2010\FINAL Doc Appe... 11/10/2010
 401 KAR 51:220. CAIR NOx ozone season trading program.

 

 RELATES TO: KRS 224.10-100, 224.20-100, 224.20-110, 224.20-120, 40 C.F.R. 51.121, 51.122, 72.2, 75.1, 75.2, 75.4, 75.11-75.13, 75.17, 75.19, 

75.20, 75.24, 75.70, 75.72, 75.74, 75.75, Part 96, 42 U.S.C. 7410

 STATUTORY AUTHORITY: KRS 224.10-100(5), 42 U.S.C. 7410

 NECESSITY, FUNCTION, AND CONFORMITY: KRS 224.10-100(5) authorizes the Environmental and Public Protection Cabinet to promulgate 

administrative regulations for the prevention, abatement, and control of air pollution. This administrative regulation establishes requirements for the

control of nitrogen oxides (NOx) emissions from large boilers and turbines used in power plants and other industrial applications, pursuant to the federal

mandate published under the Clean Air Interstate Rule (CAIR), 40 C.F.R. 96.301 to 96.388. This administrative regulation is not more stringent than the

provisions allowed under the federal mandate.

 

 Section 1. Applicability. This administrative regulation shall apply to:

 (1) CAIR NOx Ozone Season units in Kentucky subject to 40 C.F.R. 96.304;

 (2) A new or existing industrial boiler or turbine; or

 (3) A new or existing electric generating unit including a fossil fuel-fired boiler, combustion turbine, or combined cycle system:

 (a) Serving a generator with a nameplate capacity greater than twenty-five (25) megawatts of electricity; and

 (b) Offering some electricity for sale..

 

 Section 2. Compliance Requirements. CAIR NOx Ozone Season units shall comply with the following requirements:

 (1) 40 C.F.R. 96.301 to 96.308 (Subpart AAAA), "CAIR NOx Ozone Season Trading Program General Provisions";

 (2) 40 C.F.R. 96.310 to 96.315 (Subpart BBBB), "CAIR Designated Representative for CAIR NOx Ozone Season Sources";

 (3) 40 C.F.R. 96.320 to 96.324 (Subpart CCCC), "Permits";

 (4) 40 C.F.R. 96.350 to 96.357 (Subpart FFFF), "CAIR NOx Ozone Season Allowance Tracking System";

 (5) 40 C.F.R. 96.360 to 96.362 (Subpart GGGG), "CAIR NOx Ozone Season Allowance Transfers";

 (6) 40 C.F.R. 96.370 to 96.375 (Subpart HHHH), "Monitoring and Reporting"; and

 (7) 40 C.F.R. 96.380 to 96.388 (Subpart IIII), "CAIR NOx Ozone Season Opt-in Units".

 

 Section 3. Methodology for the Allocation of CAIR NOx Ozone Season Allowances. The number of CAIR NOx Ozone Season allowances to be

allocated to each CAIR NOx Ozone Season unit by the cabinet and to be sold by the Commonwealth of Kentucky shall be determined pursuant to this

section.

 (1) The total number of CAIR NOx Ozone Season allowances shall be as follows:

 (a) For the 2009 through 2014 control periods, 36,109 tons, which includes 36,045 tons as specified in 40 C.F.R. 96.340, and sixty-four (64) 

allowances previously allocated under 401 KAR 51:160 for units specified in Section 1(2) of this administrative regulation; and

 (b) For the 2015 control periods and thereafter, 30,651 tons, which includes 30,587 tons as specified in 40 C.F.R. 96.340 and sixty-four (64) 

allowances previously allocated under 401 KAR 51:160 for units specified in Section 1(2) of this administrative regulation.

 (2) The total number of CAIR NOx Ozone Season allowances assigned to Kentucky shall be divided into separate pools as follows:

 (a) Ninety-eight (98) percent of the total number of allowances shall be allocated for each control period to units that commence operation or

commence commercial operation before:

 1. January 1, 2006, for the control periods 2009, 2010, 2011, 2012, 2013, and 2014;

 2. January 1, 2009, for the 2015 control period; and

 3. Thereafter, before January 1 of the year that is six (6) years before the next control period; and

 (b) Two (2) percent of the total number of allowances for each control period shall be sold by the Commonwealth of Kentucky in accordance with

Section 4 of this administrative regulation.

 (3) For each CAIR NOx Ozone Season unit, the baseline heat input or adjusted control period heat input in mmBtu shall be determined and shall be

used to determine CAIR NOx Ozone Season allowances for the pool specified in subsection (2) of this section as follows:

 (a) For CAIR NOx Ozone Season units commencing operation or commencing commercial operation before January 1, 2001, and:

 1. Operating each calendar year during a period of five (5) or more consecutive years, the baseline heat input shall be the average of the three (3) 

highest amounts of the unit's adjusted control period heat input for 2001 through 2005;or

 2. For units not having operated each calendar year for a period of five (5) or more consecutive years, the baseline heat input shall be established

during the next allocation period after the unit has five (5) consecutive years of operation, using the average of the three (3) highest amounts of the unit's

adjusted control period heat input for the most recent five (5) consecutive years of operation;

 (b) For CAIR NOx Ozone Season units commencing operation or commencing commercial operation on or after January 1, 2001, and operating

each calendar year during a period of five (5) or more consecutive years, the baseline heat input shall be the average of the three (3) highest amounts of

the unit's adjusted control period heat input over the most recent consecutive five (5) years of operation; or

 (c) For CAIR NOx Ozone Season units that have not operated each calendar year during a period of five (5) or more consecutive years, the baseline

heat input shall not be established. For purposes of allocations, the heat input shall be the average of the three (3) highest amounts of the unit's adjusted

control period heat input for the previous five (5) years of operation, the:

 1. Adjusted control period heat input for a control period of not operating shall equal zero; and

 2. Cabinet shall allocate CAIR NOx Ozone Season allowances for the unit.

 (4) The adjusted control period heat input for each ozone season shall be calculated for CAIR NOx Ozone Season units specified in subsection (2)

(a) of this section as follows:

 (a) If the unit is coal-fired during the year, the unit's control period heat input for that year shall be multiplied by 100 percent;

 (b) If the unit is oil-fired during the year, the unit's control period heat input for that year shall be multiplied by sixty (60) percent; and

 (c) If the unit is not subject to paragraphs (a) or (b) of this subsection, the unit's control period heat input for that year shall be multiplied by forty (40)

percent.

 (5) The adjusted control period heat input for CAIR NOx Ozone Season units specified in subsection (2)(b) of this section shall equal the unit's

control period heat input multiplied by 100 percent.

 (6) For an ozone season, the unit's control period heat input and the unit's status as coal-fired or oil-fired shall be determined:

 (a) In accordance with 40 C.F.R. Part 75, if the unit is subject to 40 C.F.R. Part 75;

 (b) By the best available data reported to the cabinet for the unit if the unit is not otherwise subject to 40 C.F.R. Part 75; or

 (c) By the best available data obtained by the cabinet.

 (7) For CAIR NOx Ozone Season units included in the pool specified in subsection (2)(a) of this section, the cabinet shall allocate CAIR NOx Ozone

Season allowances to each CAIR NOx Ozone Season unit in an amount equal to the result obtained by:

 (a) Multiplying the total amount of CAIR NOx Ozone Season allowances specified in subsection (2)(a) of this section by the baseline heat input for

each unit or the heat input established under subsection (3)(c) of this section;

401 KAR 51:220. CAIR NOx ozone season trading program. Page 1 of 2

mhtml:file://S:\Program Planning\Eval\PM2.5 Redesignation NKY Nov 2010\FINAL Doc Appe... 11/10/2010
 (b) Dividing by the total amount of baseline heat input and the heat input established under subsection (3)(c) of this section for all applicable CAIR

NOx Ozone Season units; and

 (c) Rounding to the nearest whole CAIR NOx Ozone Season allowance, as appropriate.

 (8) The cabinet shall submit to the U.S. EPA the CAIR NOx Ozone Season allowances to be allocated and sold from the pools specified in

subsection (2) of this section in a format prescribed by the U.S. EPA by:

 (a) October 31, 2006, for the control periods in 2009, 2010, 2011, 2012, 2013, and 2014;

 (b) October 31, 2009, for the control period 2015; and

 (c) October 31 of each year thereafter, for the control period in the sixth year after the year of the applicable deadline for submission.

 

 Section 4. Sale of CAIR NOx Allowances by the Commonwealth of Kentucky.

 (1) The Commonwealth of Kentucky shall establish an account pursuant to 40 C.F.R. 96.351(b) for the purpose of selling the CAIR NOx Ozone

Season allowances in the pool specified in Section 3(2)(b) of this administrative regulation.

 (2) The proceeds from the sale of the CAIR NOx Ozone Season allowances shall be deposited in the general fund of the Commonwealth of

Kentucky. (33 Ky.R. 1018; Am. 1614; 1799; eff. 2-2-2007; 3036; 4159; eff. 6-13-2007.)

401 KAR 51:220. CAIR NOx ozone season trading program. Page 2 of 2

mhtml:file://S:\Program Planning\Eval\PM2.5 Redesignation NKY Nov 2010\FINAL Doc Appe... 11/10/2010
 401 KAR 51:230. CAIR SO2 trading program.

 

 RELATES TO: KRS 224.10-100, 224.20-100, 224.20-110, 224.20-120, 40 C.F.R. 51.124, 51.125, 73, 74, 77, 78, Part 96, 42 U.S.C. 7410

 STATUTORY AUTHORITY: KRS 224.10-100(5), 42 U.S.C. 7410

 NECESSITY, FUNCTION, AND CONFORMITY: KRS 224.10-100(5) requires the Environmental and Public Protection Cabinet to promulgate 

administrative regulations for the prevention, abatement, and control of air pollution. This administrative regulation establishes the provisions of the CAIR 

SO2 Trading Program as codified at 40 C.F.R. 96.201 to 96.288 for applicable sources located in the Commonwealth of Kentucky.

 

 Section 1. Applicability. This administrative regulation shall apply to CAIR SO2 sources and CAIR SO2 units under the CAIR SO2 Trading Program 

located in Kentucky that are subject to 40 C.F.R. 96.204.

 

 Section 2. Compliance requirements. CAIR SO2 sources and CAIR SO2 units shall comply with the following requirements:

 (1) 40 C.F.R. 96.201 to 96.208 (Subpart AAA), "CAIR SO2 Trading Program General Provisions";

 (2) 40 C.F.R. 96.210 to 96.215 (Subpart BBB), "CAIR Designated Representative for CAIR SO2 Sources";

 (3) 40 C.F.R. 96.220 to 96.224 (Subpart CCC), "Permits";

 (4) 40 C.F.R. 96.250 to 96.257 (Subpart FFF), "CAIR SO2 Allowance Tracking System";

 (5) 40 C.F.R. 96.260 to 96.262 (Subpart GGG), "CAIR SO2 Allowance Transfers";

 (6) 40 C.F.R. 96.270 to 96.275 (Subpart HHH), "Monitoring and Reporting"; and

 (7) 40 C.F.R. 96.280 to 96.288 (Subpart III), "CAIR SO2 Opt-in Units". (33 Ky.R. 1020; Am. 1617; eff. 2-2-2007.)

401 KAR 51:230. CAIR SO2 trading program. Page 1 of 1

mhtml:file://S:\Program Planning\Eval\PM2.5 Redesignation NKY Nov 2010\FINAL Doc Appe... 11/10/2010
 401 KAR 51:150. NOx requirements for stationary internal combustion engines.

 

 RELATES TO: KRS 224.10-100, 224.20-100, 224.20-110, 224.20-120, 40 C.F.R. 51.121, 51.122, 40 C.F.R. 78, 97, 42 U.S.C. 7401-7671q

 STATUTORY AUTHORITY: KRS 224.10-100(5), 224.20-110, 42 U.S.C. 7410

 NECESSITY, FUNCTION, AND CONFORMITY: KRS 224.10-100(5) requires the Environmental and Public Protection Cabinet to promulgate 

administrative regulations for the prevention, abatement, and control of air pollution. 42 U.S.C. 7410 requires each state to promulgate a plan which

provides for implementation, maintenance, and enforcement of the national primary and secondary ambient air quality standard in each air quality

control region within the state. Pursuant to the federal NOx SIP Call, this administrative regulation provides for the regional control of nitrogen oxides

(NOx) emissions by establishing requirements for large stationary internal combustion engines. This administrative regulation is not more stringent than

the federal mandate.

 

 Section 1. Definitions. (1) "Affected engine" means any stationary internal combustion engine or turbine that is:

 (a) A Large NOx SIP Call Engine; or

 (b) Another stationary internal combustion engine or turbine that is subject to NOx control under a compliance plan pursuant to this administrative

regulation.

 (2) "Facility seasonal NOx 2007 tonnage reduction" means the total of the engine seasonal NOx 2007 tonnage reductions attributable to all large

NOx SIP Call Engines of an owner or operator.

 (3) "Large NOx SIP Call Engine" means a stationary internal combustion engine identified and designated in the NOx SIP Call Engine inventory as

emitting more than one (1) ton of NOx per average ozone season day in 1997.

 (4) "NOx potential to emit" means the maximum capacity of an engine to emit NOx under its physical and operational design or applicable permit

condition for a given period of time. Any physical limitation on the capacity of a source's potential to emit an air pollutant, including air pollution control

equipment or combustion modification, shall be treated as part of its design if the limitation is enforceable by the cabinet.

 (5) "NOx SIP Call baseline period" or "baseline period" means the period beginning May 1, 1997, and ending September 30, 1997, inclusive.

 (6) "NOx SIP Call baseline period utilization" means the amount of work performed by a NOx SIP Call Engine during the baseline period in brake

horsepower-hours (bhp-hr).

 (7) "NOx SIP Call Engine inventory" means the NOx emission inventory, compiled by the U.S. EPA, that includes:

 (a) Technical amendments pursuant to 65 Fed. Reg. 11222, March 2, 2000; and

 (b) The adjustment of the 2007 budget NOx control efficiency to eighty-two (82) percent for large gas-fired engines pursuant to 69 Fed. Reg. 21603, 

April 21, 2004.

 (8) "Past NOx emission rate" means the emission rate of an affected engine in grams per brake horsepower-hour (g/bhp-hr), as determined by 

performance testing consistent with the requirements of 40 C.F.R. Part 60, Appendix A. If the performance test data are not available, the rate means:

 (a) The uncontrolled emission rate for Large NOx SIP Call Engines; or

 (b) A rate determined by the cabinet on a case-by-case basis, using appropriate emission factors or data from the NOx SIP Call Engine inventory.

 (9) "Projected 2007 NOx tonnage reduction" means the projected NOx reduction in tons during the 2007 control period, calculated as the difference

between the 2007 base emissions and the 2007 budget emissions. The Projected 2007 NOx tonnage reduction may be corrected through an approved

SIP revision.

 (10) "Projected 2007 seasonal base NOx emissions" or "2007 base emissions" means the projected uncontrolled NOx emissions, in tons, for the

2007 control period as published in the NOx SIP Call Inventory. The 2007 base emissions may be recalculated through an approved SIP revision.

 (11) "Projected 2007 seasonal budget NOx emissions" or "2007 budget emissions" means the projected controlled NOx emissions in tons, for the

2007 control period as published in the NOx SIP Call Inventory. The 2007 budget emissions may be recalculated through an approved SIP revision.

 (12) "Projected 2007 Ozone Season utilization" or "2007 utilization" means the projected amount of work during the 2007 control period performed by

a NOx SIP Call Engine, calculated as the 1997 baseline utilization multiplied by the growth factor assigned to that engine in the NOx SIP Call Inventory.

 (13) "Projected NOx emission rate" means the projected emission rate in grams per brake horsepower-hour after installation of controls on an 

affected engine or the past NOx emission rate if controls are not installed on an affected engine.

 (14) "Projected operating hours" means the projected actual number of hours of operation per ozone season for an affected engine.

 (15) "Projected brake horsepower hours" means the projected actual number of brake horsepower hours per ozone season for an affected engine.

 (16) "Stationary internal combustion engine" means any internal combustion engine of the reciprocating type that is either attached to a foundation at

a facility or is designed to be capable of being carried or moved from one location to another and remains at a single site at a building, structure, facility,

or installation for more than twelve (12) consecutive months. Any engine or engines that replace an engine at a site that is intended to perform the same

or similar function as the engine replaced shall be included in calculating the consecutive time period.

 

 Section 2. Applicability. This administrative regulation shall apply to the owner or operator of any large NOx SIP call engine.

 

 Section 3. Standard for Large NOx SIP Call Engines. On and after May 1, 2007, an owner or operator of an affected engine shall not operate the

engine during a control period unless:

 (1) The NOx emission rate for a Large NOx SIP Call Engine is reduced from the Past NOx emission rate by at least eighty-two (82) percent; or

 (2) The owner or operator complies with the requirements in Section 4 of this administrative regulation.

 

 Section 4. Compliance Plan. On and after May 1, 2007, an owner or operator shall not operate a Large NOx SIP Call Engine during the control

period unless the owner or operator complies with the requirements of a compliance plan or reduces NOx emissions from that engine in accordance with

Section 3(1) of this administrative regulation.

 (1) The compliance plan shall:

 (a) Be approved by the cabinet in accordance with Sections 4 through 8 of this administrative regulation;

 (b) Include all affected engines at an individual facility, several facilities, or at all facilities located in Kentucky that are under the control of the same

owner or operator;

 (c) Be submitted to the cabinet by May 1, 2006;

 (d) Include credit for decreases in NOx emissions from Large NOx SIP Call Engines in Kentucky due to NOx control equipment. The owner or

operator shall also include credit for decreases in NOx emissions from other affected engines in Kentucky due to NOx control equipment that is not

reflected in the 2007 Ozone Season Base NOx Emissions in the NOx SIP Call Engine Inventory;

 (e) Include credit for decreases in NOx emissions due to reductions from shifting historic load capacity from an uncontrolled engine to a controlled

engine, electric motor, or turbine. The owner or operator shall demonstrate to the satisfaction of the cabinet that a quantifiable net reduction in NOx

emissions has occurred or will occur due to a direct shift of ozone season load capacity from an uncontrolled engine to a controlled engine, electric

motor, or turbine; and

 (f) Provide the following information for each affected engine:

401 KAR 51:150. NOx requirements for stationary internal combustion engines. Page 1 of 3

mhtml:file://S:\Program Planning\Eval\PM2.5 Redesignation NKY Nov 2010\FINAL Doc Appe... 11/10/2010
 1. A list of affected engines subject to the plan that includes:

 a. Engine manufacturer;

 b. Engine model number;

 c. Facility location address; and

 d. Facility identification number.

 2. The projected ozone season hours of operation and supporting documentation;

 3. A description of the NOx emissions control installed, or to be installed, and documentation to support the Projected NOx Emission Rates;

 4. The Past and Projected NOx Emission Rates in grams per brake horsepower-hour;

 5. A numerical demonstration that the emission reductions obtained from all affected engines included in the compliance plan will be equivalent to or

greater than the owner or operator’s Facility Seasonal NOx 2007 Tonnage Reduction, based on the difference between the Past NOx Emission Rate 

and the Projected NOx Emission Rate, multiplied by the Projected brake horsepower hours for each affected engine, and considering credit according to

subsection (1)(d) and (e) of this section; and

 6. Provisions for monitoring, reporting, and recordkeeping.

 (2) The Projected NOx Emission Rate in grams per brake horsepower-hour for each affected engine shall be included in a federally-enforceable 

permit.

 

 Section 5. Compliance Demonstration. (1) Pursuant to the compliance plan required in Section 4, NOx emission reductions shall be calculated

according to the following criteria:

 (a) For an affected engine to which a control device is added, a combustion modification is made, or for reductions achieved pursuant to Section 4(1)

(e) of this administrative regulation after September 30, 1997, the NOx emission reductions shall equal the difference between the past NOx emission

rate and the projected NOx emission rate, multiplied by the Projected brake horsepower hours during the control period.

 (b) For an affected engine that is removed from service after September 30, 1997, and the facility’s operating capacity, in brake horsepower-hours, 

equivalent to the removed affected engine’s projected utilization is replaced, in part or in total, during a control period:

 1. By a NOx emitting device installed after September 30, 1997, the NOx emission reductions shall be the difference, in tons, between the removed

affected engine’s projected 2007 base emissions and the replacement device’s seasonal potential to emit for the operating capacity, in brake 

horsepower-hours, equivalent to the portion of the removed affected engine’s projected utilization that the device will replace, not to exceed 100 percent;

 2. By a device that does not emit NOx installed after September 30, 1997, the NOx emission reductions shall be the removed affected engine’s 

projected 2007 base emissions, multiplied by the percentage projected from utilization of the replacement device, not to exceed 100 percent; or

 3. By a device that does not emit NOx, and a NOx emitting device is installed at the removed affected engine’s facility after the date that the device 

that does not emit NOx was installed, the NOx emission reductions shall be the difference, in tons, between the removed affected engine’s projected 

2007 base emissions, and the NOx emitting device’s seasonal potential to emit for its operating capacity, in tons, equivalent to the portion of the 

removed affected engine’s projected utilization that it will replace, not to exceed 100 percent.

 (2) The following shall not be considered NOx emission reductions for compliance with this administrative regulation:

 (a) A restriction on an affected engine’s hours of operation during a control period, including a prohibition from operating;

 (b) A NOx emission limitation enforceable by the cabinet placed upon an affected engine to which no control device was added, combustion

modification made or for reductions achieved pursuant to Section 4(1)(e) after September 30, 1997;

 (c) The removal of an affected engine from service if that affected engine is placed into service at another location within Kentucky; or

 (d) NOx emission reductions achieved at a facility that is not owned or operated by the person responsible for demonstrating compliance with this

administrative regulation.

 (3) Demonstrability and enforceability of NOx emission reductions.

 NOx emission reductions, calculated in accordance with subsection (1)(a) or (b) of this section, shall be demonstrable and enforceable if:

 (a) An hourly NOx emission limitation unit, grams per brake horsepower-hours, is included in a permit enforceable by the cabinet for the affected 

engine or replacement device that is to be operated during a control period;

 (b) The hourly NOx emission limitation is equal to the hourly emission rate used to calculate the NOx potential to emit for the affected engine or

replacement device in the compliance plan; and

 (c) A performance test conducted in accordance with Section 6 of this administrative regulation determines that the affected engine or the

replacement device is capable of complying with the hourly NOx emission limitation.

 (4) NOx emission reductions achieved to comply with this administrative regulation shall not be considered creditable for compliance with any other

applicable requirement and shall not be considered a contemporaneous emission decrease for the purposes of netting or offsets.

 

 Section 6. Monitoring Requirements. An owner or operator of an affected engine shall:

 (1) Complete an initial performance test according to the requirements codified in Appendix A to 40 C.F.R. Part 60, following the installation of

emission controls required to achieve the emissions limit in Section 3(1) of this administrative regulation.

 (2) Perform periodic monitoring to yield reliable data from the relevant time period that is representative of a source’s compliance with the emissions 

limit in Section 3(1) of this administrative regulation. Periodic monitoring shall include either:

 (a) Performance tests consistent with the requirements of Appendix A to 40 C.F.R. Part 60, or portable monitors using ASTM D6522-00,;

 (b) A parametric monitoring program that specifies operating parameters and their ranges that will provide that each affected engine’s emissions are 

consistent with the provisions of Section 3 of this administrative regulation;

 (c) A predictive emissions measurement system that relies on automated data collection from instruments; or

 (d) A continuous emission monitoring system that complies with 40 C.F.R. Part 60 or Part 75.

 

 Section 7. Recordkeeping Requirements. An owner or operator subject to this administrative regulation shall:

 (1) Maintain all records necessary to demonstrate compliance with the provisions of this administrative regulation for a period of two (2) calendar

years where the affected engine is located, and provide the records, upon request, to the cabinet and the U.S. EPA;

 (2) Maintain the following records for each affected engine:

 (a) Identification and location of each affected engine;

 (b) Calendar date of record;

 (c) Number of hours the affected engine is operated during each control period compared to the Projected Operating Hours;

 (d) Type and quantity of fuel used; and

 (e) Results of all compliance tests.

 

 Section 8. Reporting Requirements. An owner or operator subject to the provisions of this administrative regulation shall submit the required reports,

compliance plans, and compliance test results to:

 (1) Manager, Permit Review Branch, Kentucky Division for Air Quality, 803 Schenkel Lane, Frankfort, Kentucky 40601, (502) 573-3382; and

401 KAR 51:150. NOx requirements for stationary internal combustion engines. Page 2 of 3

mhtml:file://S:\Program Planning\Eval\PM2.5 Redesignation NKY Nov 2010\FINAL Doc Appe... 11/10/2010
 (2) The appropriate Regional Office of the Division for Air Quality as follows:

 (a) Ashland Regional Office, 1550 Wolohan Drive, Suite 1, Ashland, Kentucky 41102, (606) 929-5285;

 (b) Bowling Green Regional Office, 1508 Westen Avenue, Bowling Green, Kentucky 42104, (270) 746-7475;

 (c) Florence Regional Office, 8020 Veterans Memorial Drive, Suite 110, Florence, Kentucky 41042, (859) 525-4923;

 (d) Hazard Regional Office, 233 Birch Street, Suite 2, Hazard, Kentucky 41701, (606) 435-6022;

 (e) London Regional Office, 875 South Main Street, London, Kentucky 40741, (606) 878-0157;

 (f) Owensboro Regional Office, 3032 Alvey Park Drive, W., Suite 700, Owensboro, Kentucky 42303, (270) 687-7304; or

 (g) Paducah Regional Office, 130 Eagle Nest Drive, Paducah, Kentucky 42003, (270) 898-8468.

 

 Section 9. Incorporation by Reference. (1) "ASTM D6522-00, Standard Test Method for Determination of Nitrogen Oxides, Carbon Monoxide, and 

Oxygen Concentrations in Emissions from Natural Gas-Fired Reciprocating Engines, Combustion Turbines, Boilers, and process Heaters Using Portable

Analyzers, Book of ASTM Standards, February 10, 2000 and April 2000," is incorporated by reference.

 (2) This material may be inspected, copied, or obtained, subject to applicable copyright law, at the Division for Air Quality, 803 Schenkel Lane,

Frankfort, Kentucky 40601, (502) 573-3382, Monday through Friday, 8 a.m. to 4:30 p.m.

 (3) Copies are available for sale from the American Society for Testing and Materials, 100 Barr Harbor Drive, West Conshohocken, Pennsylvania,

19428-2959, telephone (610) 832-9585, facsimile (610) 832-9555, and the Internet http://www.astm.org/. (32 Ky.R. 793; 1123; 1231; eff. 2-3-2006.)

401 KAR 51:150. NOx requirements for stationary internal combustion engines. Page 3 of 3

mhtml:file://S:\Program Planning\Eval\PM2.5 Redesignation NKY Nov 2010\FINAL Doc Appe... 11/10/2010
 401 KAR 51:160. NOx requirements for large utility and industrial boilers.

 

 RELATES TO: KRS 224.10-100, 224.20-100, 224.20-110, 224.20-120, 40 C.F.R. 51.121, 51.122, 72.2, 75.1, 75.2, 75.4, 75.11-75.13, 75.17, 75.19, 

75.20, 75.24, 75.70, 75.72, 75.74, 75.75, Part 96, 42 U.S.C. 7410

 STATUTORY AUTHORITY: KRS 224.10-100(5), 224.20-110, 40 C.F.R. 51.121, 51.122, 72.2, 75.1, 75.2, 75.4, 75.11-75.13, 75.17, 75.19, 75.20, 

75.24, 75.70, 75.72, 75.74, 75.75, Part 96, 42 U.S.C. 7410

 NECESSITY, FUNCTION, AND CONFORMITY: KRS 224.10-100(5) requires the Environmental and Public Protection Cabinet to promulgate 

administrative regulations for the prevention, abatement, and control of air pollution. 42 U.S.C. 7410 requires each state to promulgate a plan which

provides for implementation, maintenance, and enforcement of the national primary and secondary ambient air quality standard in each air quality

control region within the state. This administrative regulation establishes requirements for the control of nitrogen oxides (NOx) emissions from large

boilers and turbines used in power plants and other industrial applications, pursuant to the federal mandate published under the NOx SIP Call. This

administrative regulation is not more stringent nor otherwise different than the provisions allowed under the federal mandate.

 

 Section 1. Applicability. This administrative regulation shall apply to NOx budget units that are electric generating units or industrial boilers or

turbines, except as provided in Section 2 of this administrative regulation.

 

 Section 2. Exemptions. (1) Exemptions based on permit limitations. A NOx budget unit shall be exempt from Sections 3 to 7 of this administrative

regulation if the owner or operator complies with this subsection.

 (a) The source shall have a federally-enforceable permit issued by the cabinet containing conditions for the unit that:

 1. Limit the unit’s NOx emissions during each control period beginning in 2004 to twenty-five (25) tons or less;

 2. Restrict the unit to burning only natural gas or fuel oil during a control period in 2004 and each control period thereafter;

 3. Restrict the unit's operation hours during each control period to the number calculated by dividing twenty-five (25) tons of potential NOx mass 

emissions by the unit's maximum potential hourly NOx mass emissions;

 4. Require that the unit's potential NOx mass emissions shall be calculated pursuant to 40 C.F.R. 96.4(b)(1)(iii);

 5. Require that the owner or operator of the unit shall retain at the source that includes the unit, for five (5) years, records demonstrating that the

operating hours restriction, the fuel use restriction, and the other requirements of the permit related to these restrictions were met; and

 6. Require that, by November 1 of each year for which the unit is subject to the federally-enforceable permit, the owner or operator of the unit, 

through the authorized account representative, shall:

 a. Secure and transfer to an account established pursuant to 401 KAR 51:190, NOx allowances for each control period in an amount equal to the

NOx emission limitation (in tons of NOx) under subparagraphs 1 and 3 of this paragraph upon which the unit's exemption is based; and

 b. Report to the cabinet the unit's hours of operation (treating any partial hour of operation as a whole hour of operation) and the number of NOx

allowances transferred pursuant to clause a of this subparagraph.

 (b) A unit with an exemption based on permit limitations shall become subject to all the applicable provisions of this administrative regulation and

shall be treated as commencing commercial operation on September 30 of any control period for which:

 1. The fuel use restriction in paragraph (a)2 of this subsection or the operating hours restriction in paragraph (a)3 of this subsection is removed from

the unit's federally-enforceable permit or otherwise becomes no longer applicable; or

 2. The unit does not comply with the restrictions of this subsection.

 (c) Units exempted under this subsection shall not receive a NOx allowance allocation under Section 4 of this administrative regulation.

 (d) By November 30 of each year beginning in 2004, the cabinet shall report to the U.S. EPA:

 1. The total NOx emission limitation (in tons of NOx) for all units exempted under this subsection; and

 2. The total NOx allowances reported to the cabinet pursuant to paragraph (a)6b of this subsection.

 (e) For units exempted under this subsection, the cabinet shall notify the U.S. EPA, in writing:

 1. Of permit changes that remove a limit or render it no longer applicable; and

 2. Any violation of a permit limit imposed pursuant to paragraph (a) of this subsection.

 (2) Retired unit exemption.

 (a) A NOx budget unit shall be exempt from the requirements in Sections 3 to 7 of this administrative regulation on the date that the unit is

permanently retired, if the following conditions are met:

 1. Except as provided in paragraph (b) of this subsection, the retired unit shall not emit NOx on or after the day it is retired; and

 2. Within thirty (30) days after the unit is retired, the NOx authorized account representative shall submit:

 a. A letter to the cabinet and to the U.S. EPA describing the unit, the date of retirement, and the reason for retirement; and

 b. An application for a permit revision that reflects the status of the retired unit pursuant to 401 KAR 52:020 or 401 KAR 52:030, as appropriate; and

 3. Unless the unit has been physically removed, records to demonstrate that the unit has not been operated shall be:

 a. Maintained on-site for five (5) years from the date of retirement; and

 b. Made available to the cabinet or the U.S. EPA upon request.

 (b) Operation of a retired unit shall not be resumed unless the owner or operator submits an application and receives a permit revision pursuant to

401 KAR 52:020 or 401 KAR 52:030, as appropriate, prior to commencing operation.

 (c) A retired unit shall not be allowed to opt into 401 KAR 51:190, Banking and trading NOx allowances and shall not receive a NOx allowance

allocation under Section 4 of this administrative regulation.

 (d) NOx allowances made to a unit that later retires shall:

 1. Remain with the unit until they are transferred or deducted; and

 2. Cease to be allocated to the unit at the end of the allocation period.

 (e) The cabinet shall notify the U.S. EPA, in writing, of units that are exempted under this subsection.

 (3) Category exemption. A carbon monoxide boiler that is associated with fluidized catalytic cracking units (FCCU) at petroleum refineries shall be

exempt from the requirements in Sections 3 to 7 of this administrative regulation.

 

 Section 3. Compliance Requirements. (1) NOx budget emissions limitation requirements. Commencing with the later date of May 31, 2004, or the

year the unit commences operation, the owner or operator of a NOx budget unit shall:

 (a) Beginning May 1, 2003, and May 1 of each year thereafter, monitor the total NOx emissions during each control period as specified in 40 C.F.R.

96.70 to 96.76; and

 (b) By November 30 of each year, hold NOx allowances available for compliance deductions in an amount at least equal to the total NOx emissions

during the control period as specified in 401 KAR 51:190.

 (2) NOx allowance provisions. NOx allowances shall be held in, deducted from, or transferred among the NOx compliance, overdraft, and general

accounts as specified in 401 KAR 51:190 and this subsection.

 (a) The NOx budget source shall establish a general account in the NOx allowance Tracking System (NATS) by submitting "EPA Form 7620-15, 

401 KAR 51:160. NOx requirements for large utility and industrial boilers. Page 1 of 4

mhtml:file://S:\Program Planning\Eval\PM2.5 Redesignation NKY Nov 2010\FINAL Doc Appe... 11/10/2010
General Account information".

 (b) NOx budget units shall transfer NOx allowances under the NOx Budget Trading Program from one (1) account to another in the NOx Allowance

Tracking System (NATS) by submitting "EPA Form 7620-14".

 (c) NOx allowances shall not be deducted for compliance with subsection (1) of this section for a control period prior to the year for which the NOx

allowances were allocated.

 (d) If the U.S. EPA records the allocation, transfer, or deduction of NOx allowances from the compliance or overdraft account of a NOx budget

source, this action shall:

 1. Automatically amend and become part of the NOx budget portion of the source’s permit; and

 2. Require no further review.

 (e) The owner or operator of a NOx budget unit having excess NOx emissions for each control period beginning in 2004, shall comply with 401 KAR

51:190.

 (f) Allocated NOx allowances shall not constitute a property right.

 (3) Recordkeeping and reporting requirements.

 (a) The owner or operator of a NOx budget source shall maintain the following records:

 1. The "Account Certificate of Representation" for the source’s NOx authorized account representative;

 2. Emissions monitoring information as specified in 40 C.F.R. 96.70 to 96.76;

 3. Copies of all reports, compliance certifications, and other submissions and records required by 401 KAR 51:190; and

 4. Copies of documents used to complete permit revision applications or to demonstrate compliance with 401 KAR 51:190.

 (b) These records shall be:

 1. Used to demonstrate compliance with subsection (1) of this section;

 2. Maintained on site for a period of five (5) years, unless a longer period is required by 40 C.F.R. 96.70 to 96.76 or the cabinet or the U.S. EPA

requires an extended period for cause; and

 3. Made available for inspection on request by the cabinet or the U.S. EPA.

 (4) Computation of time.

 (a) A time period scheduled to begin on the occurrence of an act or event shall begin on the day the act or event occurs.

 (b) A time period scheduled to begin before the occurrence of an act or event shall be computed so that the period ends the day before the act or

event occurs.

 (c) If the final day of a time period falls on a weekend or state or federal holiday, the time period shall be extended to the next business day.

 

 Section 4. Methodology for the Allocation and Sale of NOx Allowances. The number of NOx allowances to be allocated to each NOx budget unit by

the cabinet and to be sold by the Commonwealth of Kentucky shall be determined pursuant to this section.

 (1) The total number of NOx allowances shall be the number of NOx allowances assigned to Kentucky by the U.S. EPA and approved in Kentucky's

State Implementation Plan (SIP).

 (2) The total number of NOx allowances assigned to Kentucky shall be divided into separate pools as follows:

 (a) The number of NOx allowances specified in Kentucky's approved SIP for electric generating units with:

 1. Ninety-five (95) percent of this amount allocated for the 2004 to 2006 allocation period to units that commence commercial operation on or before 

May 1, 2001;

 2. Five (5) percent of this amount for the 2004 to 2006 allocation period sold by the Commonwealth of Kentucky with the proceeds deposited in

Kentucky's general fund;

 3. Ninety-eight (98) percent of this amount allocated for each allocation period beginning with the 2007 to 2009 allocation period to units that

commence commercial operation on or before May 1 of the year that is three (3) years before the first year of the applicable allocation period; and

 4. Two (2) percent of this amount for each allocation period beginning with the 2007 to 2009 allocation period and each allocation period thereafter

sold by the Commonwealth of Kentucky with the proceeds deposited in Kentucky's general fund; and

 (b) The number of NOx allowances specified in Kentucky's approved SIP for industrial boilers or turbines with:

 1. Ninety-eight (98) percent of this amount allocated for each allocation period to units that commence commercial operation on or before May 1 of

the year that is three (3) years before the first year of the applicable allocation period; and

 2. Two (2) percent of this amount allocated for each allocation period to NOx budget units that commence commercial operation after May 1 of the

year that is three (3) years before the first year of the applicable allocation period and on or before May 1 of the applicable control period.

 (3) The cabinet shall notify the U.S. EPA and NOx budget sources of the NOx allowances to be allocated and sold from the pools specified in

subsection (2) of this section pursuant to Section 5(4) of this administrative regulation.

 (4) For allocation of the pools specified in subsection (2)(a)1, 3 and (b) of this section, heat input, in MMBTU, of a NOx budget unit shall be

determined from:

 (a) The average of the two (2) highest amounts of the unit's heat input from the three (3) most recent control periods as determined in accordance

with 40 C.F.R. Part 75 or 96.70 to 96.76 if the unit is subject to 40 C.F.R. Part 75; or

 (b) The best available data reported to the cabinet for the unit if the unit is not otherwise subject to 40 C.F.R. Part 75.

 (5) For electric generating units included in the pools specified in subsection (2)(a)1 and 3 of this section, the cabinet shall allocate NOx allowances

to each NOx budget unit in an amount equal to the result obtained by:

 (a) Multiplying 0.15 lb/MMBTU or the permit limit, whichever is less, by the heat input determined under Section 4(4) of this administrative regulation,

rounded to the nearest whole NOx allowance as appropriate.

 (b) If the initial total number of NOx allowances allocated for an allocation period to all NOx budget units in Kentucky included in the pools specified

in subsection (2)(a)1 and 3 of this section does not equal ninety-five (95) percent for the 2004 to 2006 allocation period, or ninety-eight (98) percent for

each allocation period thereafter, of the number of tons of NOx emissions in Kentucky's trading program budget apportioned to existing electric

generating units, the cabinet shall:

 1. Adjust the total number of NOx allowances allocated to all electric generating units in the applicable pool so that the total number of NOx

allowances allocated equals ninety-five (95) percent for the 2004 to 2006 allocation period, or ninety-eight (98) percent for each allocation period 

thereafter, of the number of tons of NOx emissions in Kentucky's trading program budget apportioned to electric generating units; and

 2. Make this adjustment by multiplying each unit's allocation by ninety-five (95) percent for the 2004 to 2006 allocation period, or ninety-eight (98) 

percent thereafter, of the number of tons of NOx emissions in Kentucky's trading program budget apportioned to electric generating units divided by the

total number of NOx allowances allocated under paragraph (a) of this subsection, and rounding to the nearest whole NOx allowance as appropriate.

 (6) For industrial boilers or turbines included in the pool specified in subsection (2)(b)1 of this section, the cabinet shall allocate NOx allowances to

each NOx budget unit in an amount equal to the result obtained by:

 (a) Multiplying 0.17 lb/MMBTU or the permit limit, whichever is less, by the heat input determined under subsection (4) of this section, rounded to the

nearest whole NOx allowance as appropriate.

 (b) If the initial total number of NOx allowances allocated for an allocation period to all NOx budget units in Kentucky included in the pool specified in

subsection (2)(b)1 of this section does not equal ninety-eight (98) percent for each allocation period, of the number of tons of NOx emissions in

Kentucky's trading program budget apportioned to existing industrial boilers or turbines, the cabinet shall:

401 KAR 51:160. NOx requirements for large utility and industrial boilers. Page 2 of 4

mhtml:file://S:\Program Planning\Eval\PM2.5 Redesignation NKY Nov 2010\FINAL Doc Appe... 11/10/2010
 1. Adjust the total number of NOx allowances allocated to all industrial boilers or turbines in the applicable pool so that the total number of NOx

allowances allocated equals ninety-eight (98) percent for each allocation period, of the number of tons of NOx emissions in Kentucky's trading program 

budget apportioned to industrial boilers or turbines; and

 2. Make this adjustment by multiplying each unit's allocation by ninety-eight (98) percent, of the number of tons of NOx emissions in Kentucky's

trading program budget apportioned to industrial boilers or turbines divided by the total number of NOx allowances allocated under paragraph (a) of this

subsection, and rounding to the nearest whole NOx allowance as appropriate.

 (7)(a) The Commonwealth of Kentucky shall establish an account pursuant to 401 KAR 51:190 for the purpose of selling the NOx allowances in the

pools specified in subsection (2)(a)2 and 4 of this section. The proceeds from the sale of the NOx allowances shall be deposited in the general fund of

the Commonwealth of Kentucky.

 (b) For NOx budget units included in the pool specified in subsection (2)(b)2 of this section, the cabinet shall allocate NOx allowances to each unit

according to the following procedures:

 1. The cabinet shall establish one (1) allocation set-aside for each control period. Each allocation set-aside shall be allocated NOx allowances equal 

to two (2) percent for each control period of the tons of NOx emissions in Kentucky's trading program budget, rounded to the nearest whole NOx

allowance as appropriate.

 2. The NOx authorized account representative may submit to the cabinet a request, in writing, to be allocated NOx allowances starting with the

control period during which the NOx budget unit commences commercial operation, or is projected to commence commercial operation, and ending with

the control period preceding the control period for which it will receive an allocation under subsection (2)(b)1 of this section. The request shall be in

accordance with the following requirements:

 a. The NOx allowance allocation request shall be submitted prior to May 1 of the first control period for which the NOx allowance allocation is

requested and after the date on which the cabinet issues a permit to construct to the NOx budget unit; and

 b. For a control period, the NOx authorized account representative may request NOx allowances in an amount that does not exceed 0.17 lb/MMBTU

or the permitted limit, whichever is less, multiplied by the NOx budget unit's maximum design heat input in MMBTU/hr multiplied by the number of hours

remaining in the control period starting with the first day in the control period on which the unit operated or is projected to operate.

 3. The cabinet shall review, and allocate NOx allowances pursuant to, each NOx allowance allocation request in the order that the requests are

received by the cabinet as of the close of business each day, with each consecutive day determining the order:

 a. Upon receipt of the NOx allowance allocation request, the cabinet shall determine whether, and shall make any necessary adjustments to the

request to ensure that the control period and the number of NOx allowances specified are consistent with the requirements of this subsection.

 b. If the allocation set-aside for the control period for which NOx allowances are requested:

 (i) Has an amount of NOx allowances not less than the number requested, as adjusted by the cabinet, the cabinet shall allocate the amount of the

NOx allowances requested, as adjusted by the cabinet, to the NOx budget unit.

 (ii) Has a smaller amount of NOx allowances than the number requested, as adjusted by the cabinet, the cabinet will deny in part the request and

allocate only the remaining number of NOx allowances in the allocation set-aside to the NOx budget unit.

 (iii) Once an allocation set-aside for a control period has been depleted of all NOx allowances, the cabinet shall deny, and shall not allocate any NOx 

allowances pursuant to a NOx allowance allocation request under which NOx allowances have not already been allocated for the control period.

 4. Within sixty (60) days of receipt of a NOx allowance allocation request, the cabinet shall take appropriate action under this subsection and shall

notify the U.S. EPA of the number of NOx allowances allocated for the control period to the NOx budget unit.

 5. For a NOx budget unit that is allocated NOx allowances under this subparagraph, the U.S. EPA shall deduct NOx allowances to account for the

actual utilization of the unit during the control period, and for any NOx allowances returned to Kentucky, the cabinet shall allocate to the NOx budget

units in Kentucky using the following formula and rounding to the nearest whole NOx allowance as appropriate:

 a. Unit's share of NOx allowances remaining in allocation set-aside equals total NOx allowances remaining in allocation set-aside multiplied by the 

quantity generated by dividing the unit's NOx allowance allocation by Kentucky's trading program budget excluding allocation set-aside;

 b. If:

 (i) Total NOx allowances remaining in allocation set-aside is the total number of NOx allowances remaining in the allocation set-aside for the control 

period to which the allocation set-aside applies;

 (ii) Unit's NOx allowance allocation is the number of NOx allowances allocated under subsection (2)(b)2 of this section to the unit for the control

period to which the allocation set-aside applies; and

 (iii) State trading program budget excluding allocation set-aside is Kentucky's trading program budget for the control period to which the allocation 

set-aside applies multiplied by ninety-five (95) percent if the control period is in 2004, 2005, or 2006 or ninety-eight (98) percent if the control period is in 

any year thereafter, rounded to the nearest whole NOx allowance as appropriate.

 (8) NOx allowances created pursuant to 401 KAR 51:180 for early reduction credits or emergency compliance shall not be included in the allocation

or sale of the pools specified in this section.

 

 Section 5. Allocation of NOx Allowances. (1) The cabinet shall determine the number of NOx allowances to be allocated to eligible NOx budget units

for the allocation period beginning in 2004 and in each subsequent allocation period using the method described in Section 4 of this administrative

regulation.

 (2) A NOx budget unit that commences commercial operation on or before May 1 of the year that is three (3) years before the first year of the

applicable allocation period shall be included in the applicable allocation pool as specified in Section 4(2)(a)1, 3, or (b)1 of this administrative regulation.

 (3) If the U.S. EPA changes the number of NOx allowances assigned to Kentucky before the end of an allocation period, the cabinet shall reallocate

the NOx allowances prior to the beginning of the next control period in the same ratio as the original allocation for that period.

 (4) The cabinet shall notify the U.S. EPA and NOx budget sources of the NOx allowances to be allocated and sold by the Commonwealth of

Kentucky pursuant to this section and Section 4 of this administrative regulation:

 (a) For units that commence commercial operation on or before May 1 of the year that is three (3) years before the first year of the applicable

allocation period:

 1. Not later than sixty (60) days after the effective date of this administrative regulation for the allocation period beginning in 2004; and

 2. By April 1 of the year that is three (3) years prior to the next allocation period; and

 (b) By April 1 of each year, beginning in 2004, for units in the pool specified in Section 4(2)(b)2 of this administrative regulation that commence

commercial operation after May 1 of the year that is three (3) years before the first year of the applicable allocation period and on or before May 1 of the

applicable control period.

 (5) Excess NOx allowances may be banked and traded according to 401 KAR 51:190.

 

 Section 6. Application for NOx Budget Permit or Permit Revision. (1) The NOx authorized account representative of a NOx budget source shall

submit an application to revise the source’s permit pursuant to 401 KAR 52:020 or 401 KAR 52:030, as appropriate, and this section. For this purpose, 

the source shall use:

 (a) "Forms DEP7007A1 to DD, Permit Application to Construct or Operate an Air Contaminant Source," as applicable. Forms DEP7007A1 to DD is

incorporated by reference in 401 KAR 52:050; and

401 KAR 51:160. NOx requirements for large utility and industrial boilers. Page 3 of 4

mhtml:file://S:\Program Planning\Eval\PM2.5 Redesignation NKY Nov 2010\FINAL Doc Appe... 11/10/2010
 (b) "Form DEP7007EE, NOx Budget Permit Application".

 (2) The application shall include the following information:

 (a) The Office of Regulatory Information Systems (ORIS) or facility code assigned to the source by the Energy Information Administration;

 (b) Identification of:

 1. Each NOx budget unit at the source;

 2. Each retired unit; and

 3. Each unit exempted pursuant to Section 2(1) of this administrative regulation;

 (c) A statement that explains if the unit is:

 1. A unit described in Section 1 of this administrative regulation; or

 2. An opt-in unit pursuant to 401 KAR 51:195;

 (d) The applicable requirements of Section 3 of this administrative regulation; and

 (e) For opt-in units, the following certification statement signed by the NOx authorized account representative: "I certify that each unit for which this

permit application is submitted, pursuant to the opt-in provisions of 401 KAR 51:195, is operating; is not a NOx budget unit pursuant to 401 KAR 51:160,

Section 1; and is not covered by a retired exemption unit that is in effect pursuant to 401 KAR 51:160, Section 2(2)."

 

 Section 7. Compliance. (1) Compliance certification. On or before November 30 each year, beginning in 2004, the NOx authorized account

representative shall submit a compliance certification report to the cabinet and to the U.S. EPA pursuant to 401 KAR 51:190.

 (2) Reporting to the cabinet. Reports that are required to be submitted to the cabinet shall be mailed to:

 (a) Manager, Permit Review Branch, Kentucky Division for Air Quality, 803 Schenkel Lane, Frankfort, Kentucky 40601; and

 (b) To the appropriate Regional Office of the Division for Air Quality listed in Section 8(2) of this administrative regulation.

 

 Section 8. Incorporation by Reference. (1) The following material is incorporated by reference:

 (a) "Form DEP7007EE, NOx Budget Permit Application", May 2002;

 (b) "EPA Form 7620-14, Allowance Transfer", United States Environmental Protection Agency, OMB No. 2060-0445;

 (c) "EPA Form 7620-15, General Account Information", United States Environmental Protection Agency, OMB No. 2060-0445; and

 (d) "EPA Form 7620-16, Account Certificate of Representation", United States Environmental Protection Agency, OMB No. 2060-0445.

 (2) This material may be inspected, copied, or obtained, subject to applicable copyright law, at the following offices of the Division for Air Quality,

Monday through Friday, 8 a.m. to 4:30 p.m.:

 (a) The Division for Air Quality, 803 Schenkel Lane, Frankfort, Kentucky 40601, (502) 573-3382; and

 (b) The appropriate regional office of the Division for Air Quality as follows:

 1. Ashland Regional Office, 1550 Wolohan Drive, Suite 1,, Ashland, Kentucky 41102, (606) 929-5285;

 2. Bowling Green Regional Office, 1508 Westen Avenue, Bowling Green, Kentucky 42104, (270) 746-7475;

 3. Florence Regional Office, 8020 Veterans Memorial Drive, Suite 110, Florence, Kentucky 41042, (859) 525-4923;

 4. Hazard Regional Office, 233 Birch Street, Suite 2, Hazard, Kentucky 41701, (606) 435-6022;

 5. London Regional Office, 875 S. Main Street, London, Kentucky 40741, (606) 330-2080;

 6. Owensboro Regional Office, 3032 Alvey Park Drive, W., Suite 700, Owensboro, Kentucky 42303, (270) 687-7304; or

 7. Paducah Regional Office, 130 Eagle Nest Drive, Paducah, Kentucky 42003, (270) 898-8468.

 (3)(a) Copies of the Code of Federal Regulations (C.F.R.) and Federal Register (Fed. Reg.) are available for sale from the Superintendent of

Documents, U.S. Government Printing Office, Washington, D.C. 20402.

 (b) Copies of Forms DEP7007EE-1 to EE-3 are available on the Internet at http://www.air.ky.gov/permitting/Permit+Application+Forms.htm. (27 

Ky.R. 2606; Am. 3276; 28 Ky.R. 373; eff. 8-15-2001; 29 Ky.R. 540; 1605; eff. 12-18-02; 32 Ky.R. 724; 1233; eff. 2-3-06.)

401 KAR 51:160. NOx requirements for large utility and industrial boilers. Page 4 of 4

mhtml:file://S:\Program Planning\Eval\PM2.5 Redesignation NKY Nov 2010\FINAL Doc Appe... 11/10/2010
 401 KAR 51:170. NOx requirements for cement kilns.

 

 RELATES TO: KRS 224.10-100, 224.20-100, 224.20-110, 224.20-120, 40 C.F.R. 51.121 as amended at 65 FR 11222 (March 2, 2000), 51.122,

72.2, 75.1, 75.2, 75.4, 75.11-75.13, 75.17, 75.19, 75.20, 75.24, 75.70, 75.72, 75.74, 75.75, Part 96, 42 U.S.C. 7410

 STATUTORY AUTHORITY: KRS 224.10-100, 224.20-100, 224.20-110, 224.20-120, 40 C.F.R. 51.121 as amended at 65 FR 11222 (March 2, 2000), 

51.122, 72.2, 75.1, 75.2, 75.4, 75.11-75.13, 75.17, 75.19, 75.20, 75.24, 75.70, 75.72, 75.74, 75.75, Part 96, 42 U.S.C. 7410

 NECESSITY, FUNCTION, AND CONFORMITY: KRS 224.10-100 requires the Environmental and Public Protection Cabinet to promulgate 

administrative regulations for the prevention, abatement, and control of air pollution. This administrative regulation provides for the regional control of

nitrogen oxides (NOx) emissions from portland cement manufacturing plants pursuant to the federal mandate published under the NOx SIP Call. This

administrative regulation is not more stringent nor otherwise different than the provisions allowed under the federal mandate.

 

 Section 1. Applicability. This administrative regulation shall apply to a portland cement manufacturing plant with process rates, on or after January 1,

1995, equal to or greater than:

 (1) Twelve (12) tons of clinker per hour for a long dry kiln;

 (2) Ten (10) tons of clinker per hour for a long wet kiln;

 (3) Sixteen (16) tons of clinker per hour for a preheater kiln; or

 (4) Twenty-two (22) tons of clinker per hour for a precalciner or preheater/precalciner kiln.

 

 Section 2. Standard for Kilns. (1) On and after May 31, 2004, the owner or operator of a kiln specified in Section 1 of this administrative regulation

shall, during a control period, operate the kiln so that NOx emissions do not exceed six and six-tenths (6.6) lbs per ton of clinker averaged over a thirty 

(30) day rolling period.

 (2) The requirements in subsection (1) of this section shall not apply during:

 (a) Periods of start-up, shutdown, or malfunction that do not exceed thirty-six (36) consecutive hours; and

 (b) Regularly scheduled maintenance activities.

 

 Section 3. Reporting, Monitoring, and Recordkeeping for Kilns. (1) Reporting requirements. The owner or operator of a kiln specified in Section 1 of

this administrative regulation shall submit the following reports to the cabinet at the locations specified in Section 4 of this administrative regulation:

 (a) By May 31, 2004, a report that includes:

 1. The number and types of kilns;

 2. The name and address of the plant where the kilns are located; and

 3. The name and telephone number of the person responsible for demonstrating that the kiln is in compliance.

 (b) By October 31 each year, beginning in 2004, a report that documents the total NOx emissions from the kiln during the control period.

 (2) Monitoring requirements. Beginning April 1, 2004, the owner or operator of a kiln specified in Section 1 of this administrative regulation shall

monitor NOx emissions during each control period in accordance with provisions in 40 CFR 96.70 to 96.76.

 (3) Recordkeeping requirements. An owner or operator of a kiln specified in Section 1 of this administrative regulation shall maintain all records

necessary to demonstrate compliance with the standards in Section 2 of this administrative regulation for a period of two (2) years. These records shall:

 (a) Be kept at the facility where the kiln is located;

 (b) Be made available to the cabinet or the U.S. EPA upon request; and

 (c) Contain the following information:

 1. Emissions, in pounds of NOx per ton of clinker, from the kiln;

 2. The results of all performance tests;

 3. Daily production records; and

 4. The date, time, and duration of all startups, shutdowns, or malfunctions in the operation of the kiln or emissions monitoring equipment.

 

 Section 4. Reporting to the Cabinet. Reports required to be submitted to the cabinet shall be mailed to:

 (1) Manager, Permit Review Branch, Kentucky Division for Air Quality, 803 Schenkel Lane, Frankfort, Kentucky 40601; and

 (2) To the appropriate Regional Office of the Division for Air Quality as follows:

 (a) Ashland Regional Office, 3700 Thirteenth Street, Ashland, Kentucky 41105, (606) 920-2067;

 (b) Bowling Green Regional Office, 1508 Westen Avenue, Bowling Green, Kentucky 42104, (270) 746-7475;

 (c) Florence Regional Office, 8020 Veterans Memorial Drive, Suite 110, Florence, Kentucky 41042, (859) 525-4923;

 (d) Hazard Regional Office, 233 Birch Street, Suite 2, Hazard, Kentucky 41701, (606) 435-6022;

 (e) London Regional Office, 875 S. Main Street, London, Kentucky 40741, (606) 330-2080;

 (f) Owensboro Regional Office, 3032 Alvey Park Drive, W., Suite 700, Owensboro, Kentucky 42303, (270) 687-7304; and

 (g) Paducah Regional Office, 130 Eagle Nest Drive, Paducah, Kentucky 42003, (270) 898-8468. (27 Ky.R. 2609; Am. 3281; eff. 8-15-2001; TAm eff. 

8-9-2007.)

401 KAR 51:170. NOx requirements for cement kilns. Page 1 of 1

mhtml:file://S:\Program Planning\Eval\PM2.5 Redesignation NKY Nov 2010\FINAL Doc Appe... 11/10/2010
 401 KAR 51:180. NOx credits for early reduction and emergency.

 

 RELATES TO: KRS 224.10-100, 224.20-100, 224.20-110, 224.20-120, 40 C.F.R. 51.121 as amended at 65 FR 11222 (March 2, 2000), 51.122,

72.2, 75.1, 75.2, 75.4, 75.11-75.13, 75.17, 75.19, 75.20, 75.24, 75.70, 75.72, 75.74, 75.75, Part 96, 42 U.S.C. 7410

 STATUTORY AUTHORITY: KRS 224.10-100, 224.20-100, 224.20-110, 224.20-120, 40 C.F.R. 51.121 as amended at 65 FR 11222 (March 2, 2000), 

51.122, 72.2, 75.1, 75.2, 75.4, 75.11-75.13, 75.17, 75.19, 75.20, 75.24, 75.70, 75.72, 75.74, 75.75, Part 96, 42 U.S.C. 7410

 NECESSITY, FUNCTION, AND CONFORMITY: KRS 224.10-100 requires the Environmental and Public Protection Cabinet to promulgate 

administrative regulations for the prevention, abatement, and control of air pollution. This administrative regulation provides for the distribution of NOx

allowances from a compliance supplement pool allocated to Kentucky by the U.S. EPA for sources that reduce nitrogen oxides (NOx) emissions before

the compliance deadline of the federal mandate published under the NOx SIP Call. It also provides for setting aside unused credits to assist sources that

are unable to meet the compliance deadline. This administrative regulation is not more stringent nor otherwise different than the provisions allowed

under the federal mandate.

 

 Section 1. Applicability. This administrative regulation shall apply to a NOx budget unit in Kentucky.

 

 Section 2. Procurement and Use of Early Reduction Credits (ERCs). (1) ERCs may be earned for reductions in NOx emissions achieved during the

2001, 2002, and 2003 control periods.

 (2) NOx allowances given for earned ERCs may be deducted for compliance with NOx emission standards in 401 KAR 51:160 only during the 2004

and 2005 control periods.

 (3) ERCs shall not be earned for emission reductions made to satisfy requirements under the Clean Air Act.

 

 Section 3. The Compliance Supplement Pool. (1) The compliance supplement pool shall be divided into separate pools (utility and industry) based

on the ratio of the NOx emission reductions required from each group to the total reductions required from both groups multiplied by the number of ERCs

in the compliance supplement pool as specified in the Kentucky State Implementation Plan (SIP).

 (2) The utility pool shall be further divided into separate annual allocations as follows:

 (a) Twenty (20) percent of the utility pool to be allocated for NOx emission reductions achieved in 2001;

 (b) Thirty (30) percent of the utility pool to be allocated for NOx emission reductions achieved in 2002; and

 (c) Fifty (50) percent of the utility pool to be allocated for NOx emission reductions achieved in 2003.

 (3) The entire industry pool shall be available for distribution beginning in 2002 and shall be allocated annually through 2004 for NOx emission

reductions achieved in 2001, 2002, and 2003 or until all available NOx allowances are allocated.

 (4) Unrequested NOx allowances from the previous year shall be made available in the applicable pool for the next annual allocation.

 

 Section 4. Methodology for Determining Allocation of ERCs. (1) The annual allocation of ERCs shall be made based on the actual NOx emission

reductions achieved for each NOx budget unit during the 2001, 2002, and 2003 control periods compared to the unit’s baseline NOx emission rate 

during the 2000 control period.

 (2) Baseline emissions shall be determined using the procedures in 40 CFR 96.70 to 96.76.

 (3) ERCs shall be granted only for NOx emission reductions that are monitored pursuant to Section 6 of this administrative regulation and reported

pursuant to Section 7 of this administrative regulation.

 (4) An ERC shall be granted for each ton of NOx emission reduction achieved below 0.45 lbs/MMBTU or the average NOx emission rate (in

lbs/MMBTU) from the baseline control period in 2000, whichever is less.

 (5) ERCs shall be rounded to the nearest whole number and distributed in the form of one (1) NOx allowance for one (1) ton of NOx emission

reduction.

 (6) If the requests for ERCs exceeds the maximum NOx allowances available for distribution in the applicable pool for an annual allocation, the

cabinet shall distribute the ERCs on a proportional basis using the following calculation: the NOx budget unit's allocated ERCs shall equal the unit's NOx

emission reductions determined pursuant to subsection (3) of this section divided by the total NOx emission reductions from all units in the applicable

pool multiplied by the ERCs available for distribution in that pool.

 (7) NOx allowances shall be distributed annually on or before May 1 of each year for the previous year's NOx emission reductions beginning in 2002

and ending in 2004.

 (8) The cabinet shall notify the U.S. EPA of the final allocation on or before May 31, 2004.

 

 Section 5. NOx Credits for Emergency Use. After allocations are made pursuant to Section 4 of this administrative regulation for 2001, 2002, and

2003, credits that remain in the compliance supplement pools shall be used by the cabinet to assist sources that are unable to meet the compliance

deadline in 401 KAR 51:160 according to the following restrictions:

 (1) ERCs remaining in the utility pool shall only be used to assist electric generating units and ERCs remaining in the industry pool shall only be used

to assist industrial boilers or turbines.

 (2) Credits shall be issued by the cabinet to extend the compliance deadline only for sources that meet the following conditions:

 (a) Electric generating units for which meeting the compliance deadline would seriously jeopardize the reliability of the electric supply, and for which

it was not feasible to import electricity from other sources in order to meet the deadline;

 (b) Industrial boilers and turbines for which meeting the compliance deadline would create an undue risk comparable to that for utility sources in

paragraph (a) of this subsection; and

 (c) Sources able to demonstrate that it was not possible to acquire sufficient NOx allowances to meet the compliance deadline by:

 1. Generating ERCs;

 2. Acquiring ERCs from other sources; or

 3. Acquiring NOx allowances from the NOx Budget Trading Program.

 (3) Allowances shall be allocated, based upon need, in 2004 and 2005.

 (4) A public hearing shall take place before allowances are allocated.

 

 Section 6. Monitoring Requirements. (1) Monitoring shall be performed on a NOx budget unit for which early reduction credit is to be obtained during

the 2000 control period and each subsequent control period during which NOx emission reductions will occur.

 (2) Units shall be monitored in accordance with 40 CFR 96.70 to 96.76.

 

 Section 7. Reporting Requirements. (1) The owner or operator of a NOx budget source that achieves early reductions pursuant to this administrative

401 KAR 51:180. NOx credits for early reduction and emergency. Page 1 of 2

mhtml:file://S:\Program Planning\Eval\PM2.5 Redesignation NKY Nov 2010\FINAL Doc Appe... 11/10/2010
regulation shall submit a report to the cabinet on or before January 30 of each year following the year in which reductions were achieved for the years of

2001, 2002, and 2003, documenting the actual NOx emission reductions achieved by each NOx budget unit during each control period compared to the

unit’s actual emissions during the 2000 control period. These reports shall contain the following information, for each NOx budget unit:

 (a) Identification and location of the unit that achieved NOx emission reductions;

 (b) The maximum design heat input for the unit, expressed in MMBTU/hr;

 (c) For the 2000 control period and each control period during which NOx emission reductions are achieved:

 1. The total hours of operation;

 2. The total NOx emissions, in tons;

 3. The average NOx emission rate, in lbs/MMBTU;

 4. The maximum allowable NOx emission rate, based on the most stringent applicable requirement, in lbs/MMBTU; and

 5. Calculations showing the tons of NOx emission reductions below 0.45 lbs/MMBTU or the average NOx emission rate (in lbs/MMBTU) from the

baseline season, whichever is less.

 (2) The report required in subsection (1) of this section shall be signed by the owner or operator of the NOx budget source and submitted to:

 (a) Manager, Permit Review Branch, Kentucky Division for Air Quality, 803 Schenkel Lane, Frankfort, Kentucky 40601; and

 (b) The appropriate regional office of the Division for Air Quality as follows:

 1. Ashland Regional Office, 3700 Thirteenth Street, Ashland, Kentucky 41105, (606) 920-2067;

 2. Bowling Green Regional Office, 1508 Westen Avenue, Bowling Green, Kentucky 42104, (270) 746-7475;

 3. Florence Regional Office, 8020 Veterans Memorial Drive, Suite 110, Florence, Kentucky 41042, (859) 525-4923;

 4. Hazard Regional Office, 233 Birch Street, Suite 2, Hazard, Kentucky 41701, (606) 435-6022;

 5. London Regional Office, 875 S. Main Street, London, Kentucky 40741, (606) 330-2080;

 6. Owensboro Regional Office, 3032 Alvey Park Drive, W., Suite 700, Owensboro, Kentucky 42303, (270) 687-7304; or

 7. Paducah Regional Office, 130 Eagle Nest Drive, Paducah, Kentucky 42003, (270) 898-8468. (27 Ky.R. 2611; Am. 3283; 28 Ky.R. 377; eff. 

8-15-2001; TAm eff. 8-9-2007.)

401 KAR 51:180. NOx credits for early reduction and emergency. Page 2 of 2

mhtml:file://S:\Program Planning\Eval\PM2.5 Redesignation NKY Nov 2010\FINAL Doc Appe... 11/10/2010
 401 KAR 51:190. Banking and trading NOx allowances.

 

 RELATES TO: KRS 224.10-100, 224.20-100, 224.20-110, 224.20-120, 40 C.F.R. 51.121 as amended at 65 FR 11222 (March 2, 2000), 51.122,

72.2, 75.1, 75.2, 75.4, 75.11-75.13, 75.17, 75.19, 75.20, 75.24, 75.70, 75.72, 75.74, 75.75, Part 96, 42 U.S.C. 7410

 STATUTORY AUTHORITY: KRS 224.10-100, 224.20-100, 224.20.110, 224.20-120, 40 C.F.R. 51.121 as amended at 65 FR 11222 (March 2, 2000), 

51.122, 72.2, 75.1, 75.2, 75.4, 75.11-75.13, 75.17, 75.19, 75.20, 75.24, 75.70, 75.72, 75.74, 75.75, Part 96, 42 U.S.C. 7410

 NECESSITY, FUNCTION, AND CONFORMITY: KRS 224.10-100 requires the Environmental and Public Protection Cabinet to promulgate 

administrative regulations for the prevention, abatement, and control of air pollution. This administrative regulation incorporates by reference the federal

regulation that establishes a program for banking and trading of emission allowances to reduce nitrogen oxides (NOx) emissions under the federal NOx

SIP Call. This administrative regulation is not more stringent nor otherwise different than the provisions of the federal mandate.

 

 Section 1. For purposes of 40 CFR 96.10 to 96.14, 96.30, 96.31, 96.50 to 96.55 (b), 96.56 to 96.57, 96.60 to 96.62:

 (1) The administrator shall be the Administrator of the U.S. EPA;

 (2) The permitting authority shall be the cabinet;

 (3) The citations, Subpart E and 40 CFR 96.42(e) shall be 401 KAR 51:160, NOx requirements for large utility and industrial boilers; and

 (4) The citation Subpart I shall be 401 KAR 51:195, NOx opt-in provisions.

 

 Section 2. Applicability. NOx budget units shall comply with the following requirements, which are incorporated by reference in Section 3 of this

administrative regulation:

 (1) 40 CFR 96.10 to 96.14;

 (2) 40 CFR 96.30 to 96.31;

 (3) 40 CFR 96.50 to 96.55(b) and 96.56 to 96.57; and

 (4) 40 CFR 96.60 to 96.62.

 

 Section 3. Incorporation by Reference. (1) The following material is incorporated by reference:

 (a) 40 CFR 96.10 to 96.14, "NOx Authorized Account Representative for NOx Budget Sources," as published in the Code of Federal Regulations, 40

CFR Part 96, July 1, 1999;

 (b) 40 CFR 96.30 to 96.31, "Compliance Certification," as published in the Code of Federal Regulations, 40 CFR Part 96, July 1, 1999;

 (c) 40 CFR 96.50 to 96.55(b) and 96.56 to 96.57, "NOx Allowance Tracking System," as published in the Code of Federal Regulations, 40 CFR Part

96, July 1, 1999; and

 (d) 40 CFR 96.60 to 96.62, "NOx Allowance Transfers," as published in the Code of Federal Regulations, 40 CFR Part 96, July 1, 1999.

 (2) This material may be inspected, copied, or obtained at the following offices of the Division for Air Quality, Monday through Friday, 8 a.m. to 4:30

p.m.:

 (a) The Division for Air Quality, 803 Schenkel Lane, Frankfort, Kentucky 40601, (502) 573-3382;

 (b) Ashland Regional Office, 3700 Thirteenth Street, Ashland, Kentucky 41105, (606) 920-2067;

 (c) Bowling Green Regional Office, 1508 Westen Avenue, Bowling Green, Kentucky 42104, (270) 746-7475;

 (d) Florence Regional Office, 8020 Veterans Memorial Drive, Suite 110, Florence, Kentucky 41042, (859) 525-4923;

 (e) Hazard Regional Office, 233 Birch Street, Suite 2, Hazard, Kentucky 41701, (606) 435-6022;

 (f) London Regional Office, 875 S. Main Street, London, Kentucky 40741, (606) 330-2080;

 (g) Owensboro Regional Office, 3032 Alvey Park Drive, W., Suite 700, Owensboro, Kentucky 42303, (270) 687-7304; and

 (h) Paducah Regional Office, 130 Eagle Nest Drive, Paducah, Kentucky, 42003 (270) 898-8468.

 (3) Copies of the Code of Federal Regulations (CFR) and the Federal Register (Fed. Reg.) are available for sale from the Superintendent of 

Documents, U.S. Government Printing Office, Washington, D.C. 20402. (27 Ky.R. 2611; Am. 3285; eff. 8-15-2001; TAm eff. 8-9-2007.)

401 KAR 51:190. Banking and trading NOx allowances. Page 1 of 1

mhtml:file://S:\Program Planning\Eval\PM2.5 Redesignation NKY Nov 2010\FINAL Doc Appe... 11/10/2010
 401 KAR 51:195. NOx opt-in provisions.

 

 RELATES TO: KRS 224.10-100, 224.20-100, 224.20-110, 224.20-120, 40 C.F.R. 51.121 as amended at 65 FR 11222 (March 2, 2000), 51.122,

72.2, 75.1, 75.2, 75.4, 75.11-75.13, 75.17, 75.19, 75.20, 75.24, 75.70, 75.72, 75.74, 75.75, Part 96, 42 U.S.C. 7410, 7661

 STATUTORY AUTHORITY: KRS 224.10-100, 224.20-100, 224.20.110, 224.20-120, 40 C.F.R. 51.121 as amended at 65 FR 11222 (March 2, 2000), 

51.122, 72.2, 75.1, 75.2, 75.4, 75.11-75.13, 75.17, 75.19, 75.20, 75.24, 75.70, 75.72, 75.74, 75.75, Part 96, 42 U.S.C. 7410, 7661

 NECESSITY, FUNCTION, AND CONFORMITY: KRS 224.10-100 requires the Environmental and Public Protection Cabinet to promulgate 

administrative regulations for the prevention, abatement, and control of air pollution. The federal regulation incorporated by reference in this

administrative regulation establishes provisions for individual sources to opt into the NOx Budget Trading Program. This administrative regulation is not

more stringent nor otherwise different than the provisions of the federal mandate.

 

 Section 1. For purposes of 40 CFR 96.80 to 96.88:

 (1) The administrator shall be the Administrator of the U.S. EPA;

 (2) The permitting authority shall be the cabinet;

 (3) The citations Subpart E, 96.4, 96.5, and 96.42, shall be 401 KAR 51:160;

 (4) The citations 96.20, 96.21(c), 96.22, and 96.23, shall be 401 KAR Chapter 52; and

 (5) The citation Subparts A through H shall be 401 KAR 51:001, 51:160, 51:170, 51:180, and 51:190.

 

 Section 2. Applicability. Units that opt into the NOx Budget Trading Program shall comply with the requirements of 40 CFR 96.80 to 96.88, which is

incorporated by reference in Section 3 of this administrative regulation.

 

 Section 3. Incorporation by Reference. (1) 40 CFR 96.80 to 96.88, "Individual Unit Opt-ins," as published in the Code of Federal Regulations, 40 

CFR Part 96, July 1, 1999, is incorporated by reference.

 (2) This material may be inspected, copied, or obtained at the following offices of the Division for Air Quality, Monday through Friday, 8 a.m. to 4:30

p.m.:

 (a) The Division for Air Quality, 803 Schenkel Lane, Frankfort, Kentucky, 40601, (502) 573-3382;

 (b) Ashland Regional Office, 3700 Thirteenth Street, Ashland, Kentucky, 41105, (606) 920-2067;

 (c) Bowling Green Regional Office, 1508 Westen Avenue, Bowling Green, Kentucky, 42104, (270) 746-7475;

 (d) Florence Regional Office, 8020 Veterans Memorial Drive, Suite 110, Florence, Kentucky, 41042, (859) 525-4923;

 (e) Hazard Regional Office, 233 Birch Street, Suite 2, Hazard, Kentucky, 41701, (606) 435-6022;

 (f) London Regional Office, 875 S. Main Street, London, Kentucky, 40741, (606) 330-2080;

 (g) Owensboro Regional Office, 3032 Alvey Park Drive, W., Suite 700, Owensboro, Kentucky, 42303, (270) 687-7304; and

 (h) Paducah Regional Office, 130 Eagle Nest Drive, Paducah, Kentucky, 42003, (270) 898-8468.

 (3) Copies of the Code of Federal Regulations (CFR) and the Federal Register (Fed. Reg) are available for sale from the Superintendent of

Documents, U.S. Government Printing Office, Washington, D.C. 20402. (27 Ky.R. 2614; Am. 3286; eff. 8-15-2001; TAm eff. 8-9-2007.)

401 KAR 51:195. NOx opt-in provisions. Page 1 of 1

mhtml:file://S:\Program Planning\Eval\PM2.5 Redesignation NKY Nov 2010\FINAL Doc Appe... 11/10/2010
224.10-100 Powers and duties of cabinet.

In addition to any other powers and duties vested in it by law, the cabinet shall have the 

authority, power, and duty to:

(1) Exercise general supervision of the administration and enforcement of this chapter, 

and all rules, regulations, and orders promulgated thereunder;

(2) Prepare and develop a comprehensive plan or plans related to the environment of 

the Commonwealth;

(3) Encourage industrial, commercial, residential, and community development which 

provides the best usage of land areas, maximizes environmental benefits, and 

minimizes the effects of less desirable environmental conditions;

(4) Develop and conduct a comprehensive program for the management of water, land, 

and air resources to assure their protection and balance utilization consistent with 

the environmental policy of the Commonwealth;

(5) Provide for the prevention, abatement, and control of all water, land, and air 

pollution, including but not limited to that related to particulates, pesticides, gases, 

dust, vapors, noise, radiation, odor, nutrients, heated liquid, or other contaminants;

(6) Provide for the control and regulation of surface coal mining and reclamation in a 

manner to accomplish the purposes of KRS Chapter 350;

(7) Secure necessary scientific, technical, administrative, and operational services, 

including laboratory facilities, by contract or otherwise;

(8) Collect and disseminate information and conduct educational and training programs 

relating to the protection of the environment;

(9) Appear and participate in proceedings before any federal regulatory agency 

involving or affecting the purposes of the cabinet;

(10) Enter and inspect any property or premises for the purpose of investigating either 

actual or suspected sources of pollution or contamination or for the purpose of 

ascertaining compliance or noncompliance with this chapter, or any regulation 

which may be promulgated thereunder;

(11) Conduct investigations and hold hearings and compel the attendance of witnesses 

and the production of accounts, books, and records by the issuance of subpoenas;

(12) Accept, receive, and administer grants or other funds or gifts from public and 

private agencies including the federal government for the purpose of carrying out 

any of the functions of the cabinet. The funds received by the cabinet shall be 

deposited in the State Treasury to the account of the cabinet;

(13) Request and receive the assistance of any state or municipal educational institution, 

experiment station, laboratory, or other agency when it is deemed necessary or 

beneficial by the cabinet in the performance of its duties;

(14) Advise, consult, and cooperate with other agencies of the Commonwealth, other 

states, the federal government, and interstate and interlocal agencies, and affected 

persons, groups, and industries;
(15) Formulate guides for measuring presently unidentified environmental values and 

relationships so they can be given appropriate consideration along with social, 

economic, and technical considerations in decision making;

(16) Monitor the environment to afford more effective and efficient control practices, to 

identify changes and conditions in ecological systems, and to warn of emergency 

conditions;

(17) Adopt, modify, or repeal with the recommendation of the commission any standard, 

regulation, or plan specified in KRS 224.01-110 (5) and (6);

(18) Issue, after hearing, orders abating activities in violation of this chapter, or the 

provisions of this chapter, or the regulations promulgated pursuant thereto and 

requiring the adoption of the remedial measures the cabinet deems necessary;

(19) Issue, continue in effect, revoke, modify, suspend, or deny under such conditions as 

the cabinet may prescribe and require that applications be accompanied by plans, 

specifications, and other information the cabinet deems necessary for the following 

permits:

(a) Permits to discharge into any waters of the Commonwealth, and for the 

installation, alteration, expansion, or operation of any sewage system; 

however, the cabinet may refuse to issue the permits to any person, or any 

partnership, corporation, etc., of which the person owns more than ten percent 

(10%) interest, who has improperly constructed, operated, or maintained a 

sewage system willfully, through negligence, or because of lack of proper 

knowledge or qualifications until the time that person demonstrates proper 

qualifications to the cabinet and provides the cabinet with a performance 

bond;

(b) Permits for the installation, alteration, or use of any machine, equipment, 

device, or other article that may cause or contribute to air pollution or is 

intended primarily to prevent or control the emission of air pollution; or

(c) Permits for the establishment or construction and the operation or 

maintenance of waste disposal sites and facilities;

(20) May establish, by regulation, a fee or schedule of fees for the cost of processing 

applications for permits authorized by this chapter, and for the cost of processing 

applications for exemptions or partial exemptions which may include but not be 

limited to the administrative costs of a hearing held as a result of the exemption 

application, except that applicants for existing or proposed publicly owned facilities 

shall be exempt from any charge, other than emissions fees assessed pursuant to 

KRS 224.20-050, and that certain nonprofit organizations shall be charged lower 

fees to process water discharge permits under KRS 224.16-050(5);

(21) May require for persons discharging into the waters or onto the land of the 

Commonwealth, by regulation, order, or permit, technological levels of treatment 

and effluent limitations;

(22) Require, by regulation, that any person engaged in any operation regulated pursuant 

to this chapter install, maintain, and use at such locations and intervals as the 

cabinet may prescribe any equipment, device, or test and the methodologies and 
procedures for the use of the equipment, device, or test to monitor the nature and 

amount of any substance emitted or discharged into the ambient air or waters or 

land of the Commonwealth and to provide any information concerning the 

monitoring to the cabinet in accordance with the provisions of subsection (23) of 

this section;

(23) Require by regulation that any person engaged in any operation regulated pursuant 

to this chapter file with the cabinet reports containing information as to location, 

size, height, rate of emission or discharge, and composition of any substance 

discharged or emitted into the ambient air or into the waters or onto the land of the 

Commonwealth, and such other information the cabinet may require;

(24) Promulgate regulations, guidelines, and standards for waste planning and 

management activities, approve waste management facilities, develop and publish a 

comprehensive statewide plan for nonhazardous waste management which shall 

contain but not be limited to the provisions set forth in KRS 224.43-345, and 

develop and publish a comprehensive statewide plan for hazardous waste 

management which shall contain but not be limited to the following:

(a) A description of current hazardous waste management practices and costs, 

including treatment and disposal, within the Commonwealth;

(b) An inventory and description of all existing facilities where hazardous waste 

is being generated, treated, recycled, stored, or disposed of, including an 

inventory of the deficiencies of present facilities in meeting current hazardous 

waste management needs and a statement of the ability of present hazardous 

waste management facilities to comply with state and federal laws relating to 

hazardous waste;

(c) A description of the sources of hazardous waste affecting the Commonwealth 

including the types and quantities of hazardous waste currently being 

generated and a projection of such activities as can be expected to continue for 

not less than twenty (20) years into the future; and

(d) An identification and continuing evaluation of those locations within the 

Commonwealth which are naturally or may be engineered to be suitable for 

the establishment of hazardous waste management facilities, and an 

identification of those general characteristics, values, and attributes which 

would render a particular location unsuitable, consistent with the policy of 

minimizing land disposal and encouraging the treatment and recycling of the 

wastes.

The statewide waste management plans shall be developed consistent with state and 

federal laws relating to waste;

(25) Perform other acts necessary to carry out the duties and responsibilities described in 

this section;

(26) Preserve existing clean air resources while ensuring economic growth by issuing 

regulations, which shall be no more stringent than federal requirements, setting 

maximum allowable increases from stationary sources over baseline concentrations 
of air contaminants to prevent significant deterioration in areas meeting the state 

and national ambient air quality standards;

(27) Promulgate regulations concerning the bonding provisions of subsection (19)(a) of 

this section, setting forth bonding requirements, including but not limited to 

requirements for the amount, duration, release, and forfeiture of the bonds. All 

funds from the forfeiture of bonds required pursuant to this section shall be placed 

in the State Treasury and credited to a special trust and agency account which shall 

not lapse. The account shall be known as the "sewage treatment system 

rehabilitation fund" and all moneys placed in the fund shall be used for the 

elimination of nuisances and hazards created by sewage systems which were 

improperly built, operated, or maintained, and insofar as practicable be used to 

correct the problems at the same site for which the bond or other sureties were 

originally provided; and

(28) Promulgate administrative regulations not inconsistent with the provisions of law 

administered by the cabinet.

Effective: August 30, 2007

History: Amended 2007 (2d Extra. Sess.) Ky. Acts ch. 1, sec. 42, effective August 30, 

2007. -- Amended 1994 Ky. Acts ch. 162, sec. 3, effective July 15, 1994. -- Amended

1990 Ky. Acts ch. 325, sec. 15, effective July 13, 1990; and ch. 412, sec. 1, effective 

July 13, 1990. -- Amended 1986 Ky. Acts ch. 455, sec. 1, effective July 15, 1986. --

Amended 1984 Ky. Acts ch. 111, sec. 109, effective July 13, 1984. -- Amended 1980 

Ky. Acts ch. 264, sec. 2; and ch. 377, sec. 10, effective July 15, 1980. -- Amended 

1978 Ky. Acts ch. 113, sec. 3, effective June 17, 1978; and ch. 266, sec. 2, effective 

June 17, 1978. -- Amended 1974 Ky. Acts ch. 355, sec. 2, effective June 21, 1974. --

Created 1972 (1st Extra. Sess.) Ky. Acts ch. 3, sec. 3, effective January 1, 1973.

Formerly codified as KRS 224.033

Legislative Research Commission Note (9/28/93). The Division of Energy within the 

Department for Natural Resources of the Natural Resources and Environmental 

Protection Cabinet was made "responsible for subsections (28) and (29)" of this 

statute by 1990 Ky. Acts, ch. 325, sec. 14.

Legislative Research Commission Note (6/20/2005). 2005 Ky. Acts ch. 123, sec. 5, 

codified at KRS 224.10-103, provides that the Division of Energy and all "personnel, 

functions, powers, and duties of the Division of Energy shall be transferred to the 

Tourism Development Cabinet." The abolition of the Tourism Development Cabinet 

and creation of the Commerce Cabinet under Executive Order 2004-729 were 

confirmed by 2005 Ky. Acts ch. 95, in which the Office of Energy Policy is 

established and statutory references to the "Division of Energy" are changed to the 

"Office of Energy Policy."
 401 KAR 50:012. General application.

 

 RELATES TO: KRS 224.10-100, 224.20-120, 40 C.F.R. 60.14, 42 U.S.C. 7401 et seq., 7408, 7410

 STATUTORY AUTHORITY: KRS 224.10-100

 NECESSITY, FUNCTION, AND CONFORMITY: KRS 224.10-100 requires the Environmental and Public Protection Cabinet to prescribe

administrative regulations for the prevention, abatement, and control of air pollution. 42 USC 7410 likewise requires the state to implement standards for

national primary and secondary ambient air quality. This administrative regulation provides guidelines by which all administrative regulations of 401 KAR

Chapters 50 to 65, are to be understood.

 

 Section 1. General Application of Administrative Regulations and Standards. Administrative Regulations of the cabinet shall be construed and

applied according to subsections (1) through (6) of this section, which shall guide the cabinet in the issuance, modification, and revocation of permits.

 (1) All major sources of VOCs located in a county or portion of a county which is designated ozone nonattainment, for any nonattainment

classification except marginal, under 401 KAR 51:010, shall install and use control technology which is reasonable and available.

 (a) The determination of reasonably available control technology shall be approved by the cabinet and shall be based upon:

 1. A Control Techniques Guidelines Document issued by the U.S. EPA and promulgated in regulatory form by the cabinet; or

 2. If no Control Techniques Guidelines Document is appropriate, the lowest emission limit that a particular source is capable of meeting by the

application of control technology that is reasonably available considering technological and economic feasibility. The cabinet may require technology that

has been applied to similar, but not necessarily identical source categories.

 (b) For those reasonably available control technology determinations not based on a control techniques guidelines document, the cabinet shall:

 1. Hold a public hearing on the determination.

 2. Submit the determination to the U.S. EPA for approval.

 (c) For these determinations, that portion of a source with facilities uncontrolled by reasonably available control technology which emit VOCs that

sum to 100 tpy or greater shall be considered a major source.

 (2) In the absence of a standard specified in these administrative regulations, all major air contaminant sources shall as a minimum apply control

procedures that are reasonable, available, and practical.

 (3) Nothing in these administrative regulations is intended to permit a practice which is in violation of a statute, ordinance, or administrative

regulation.

 (4) These administrative regulations shall be complementary to each other, and to other administrative regulations adopted by the cabinet. If a

provision of these administrative regulations or the application thereof to a person or circumstance is held to be invalid, the invalidity shall not affect other

provisions or application of another part of these administrative regulations and to this end each provision of these administrative regulations and the

various applications thereof are declared to be severable.

 (5) Except as provided by 401 KAR 50:055, nothing in these administrative regulations shall allow a source to remove control equipment or

discontinue procedures previously required in a nonattainment area to achieve the national ambient air quality standards until a state implementation

plan containing different requirements has been approved by the U.S. EPA.

 (6) For the purpose of applying the definition of modification, an increase in the amount of an air pollutant shall be determined as in 40 CFR 60.14. (5

Ky.R. 352; eff. 6-6-79; Recodified from 401 KAR 50:005, 7-31-90; Am. 18 Ky.R. 2604; 2929; 3333; eff. 6-24-92; 24 Ky.R. 648; eff. 11-12-97; TAm eff. 8-

9-2007.)

401 KAR 50:012. General application. Page 1 of 1

mhtml:file://S:\Program Planning\Eval\PM2.5 Redesignation NKY Nov 2010\FINAL Doc Appe... 11/10/2010
 401 KAR 63:005. Open burning.

 

 RELATES TO: KRS 149.400, 224.10-100, 224.20-100, 224.20-110, 224.20-120, 42 U.S.C. 7401-7671q 

 STATUTORY AUTHORITY: KRS 224.10-100, 224.20-110 

 NECESSITY, FUNCTION, AND CONFORMITY: KRS 224.10-100 requires the Environmental and Public Protection Cabinet to promulgate 

administrative regulations for the prevention, abatement, and control of air pollution. KRS 224.20-110 prohibits any person from directly or indirectly, 

emitting into or discharging into the air under the jurisdiction of the commonwealth, or causing, permitting, or allowing to be emitted or discharged into

the air, any contaminants as provided for in subsection (1) of KRS 224.01-010 that shall cause or contribute to the pollution of the air of the 

commonwealth in contravention of any of the rules, administrative regulations, or orders of the cabinet. This administrative regulation establishes

requirements for the control of open burning. 

 

 Section 1. Definitions. 

 (1) "Clean lumber" means wood or wood products that have been cut or shaped and includes wet, air-dried, and kiln-dried wood products and does 

not include commercial or industrial waste or wood products that have been painted, pigment-stained, or pressure-treated using any hazardous or toxic 

compounds. 

 (2) "Fire training" means the instruction of industrial, public and private firefighters conducted in accordance with safety standards and procedures as

accepted by the Kentucky State Fire Marshal, the Kentucky Fire Commission or the National Wildfire Coordinating Group. 

 (3) "Garbage" means putrescible animal and vegetable matter accumulated in the course of ordinary day-to-day living. 

 (4) "Household rubbish" means waste material and trash normally accumulated by a family in a residence in the course of ordinary day-to-day living, 

except for garbage, cans, glass, plastic, or other potentially hazardous waste materials. 

 (5) "Land clearing" means clearing of land for agricultural, residential, industrial, or commercial development purposes, including the construction of

roads. 

 (6) "Open burning" means the burning of any matter without a burn chamber approved by the Kentucky Division for Air Quality, or without a stack or

chimney with control devices approved by the Kentucky Division for Air Quality. 

 (7) "Priority I Region" means a region classified as Priority I in 401 KAR 50:020, Appendix A. 

 (8) "Recognized agricultural, silvicultural, range, ecological, or wildlife management practices" means burning recognized by the Kentucky

Department of Agriculture, the United States Department of Agriculture, the Kentucky Division of Forestry, the United States Forest Service, the

Kentucky Department of Fish and Wildlife, the Kentucky State Nature Preserves Commission, or the United States Fish and Wildlife Service as

necessary to promote cultivation of crops, range, and forest lands, weed and understory abatement and pest control and prevention. 

 (9) "Wood waste" means untreated wood and untreated wood products, including tree stumps (whole or chipped), felled trees, tree limbs (whole or

chipped), bark, sawdust, chips, scraps, slabs, millings and shavings. Wood waste does not include: 

 (a) Yard waste; 

 (b) Construction, renovation, or demolition wastes; or 

 (c) Clean lumber. 

 (10) "Yard waste" means grass, grass clippings, bushes, shrubs, and clippings from bushes and shrubs, which come from residential, commercial,

retail, institutional, or industrial sources as part of maintaining yards or other private or public lands. Yard waste does not include: 

 (a) Construction, renovation, and demolition wastes; or 

 (b) Clean lumber. 

 

 Section 2. Applicability. This administrative regulation shall apply to all open burning that is not subject to another administrative regulation in 401

KAR Chapters 50 to 65. 

 

 Section 3. Prohibition of Open Burning. Except as provided in Sections 4 and 5 of this administrative regulation, open burning shall be prohibited. 

 

 Section 4. Allowable Open Burning. Subject to the limitations contained in this section and the restrictions contained in Section 5 of this

administrative regulation, open burning shall be allowed for: 

 (1) Fires set for the cooking of food for human consumption; 

 (2) Fires set for recreational or ceremonial purposes; 

 (3) Small fires set by construction and other workers for comfort heating purposes if: 

 (a) The ambient temperature is below fifty (50) degrees Fahrenheit;

 (b) Excessive or unusual smoke is not created; 

 (c) Only clean lumber or vegetative matter is burned; and 

 (d) The fire is burned in a container not exceeding fifty-five (55) gallons in size; 

 (4) Fires set for the purpose of weed abatement, disease, and pest prevention; 

 (5) Fires set for prevention of a fire hazard, including the disposal of dangerous materials if no safe alternative is available; 

 (6) Fires set for the purpose of instruction and training of public and industrial employees in the methods of fighting fires as set forth in Section 6 of

this administrative regulation; 

 (7) Fires set for recognized agricultural, silvicultural, range, ecological, and wildlife management practices; 

 (8) Fires set by individual homeowners for burning of leaves except in cities greater than 8,000 population located in a Priority I Region; 

 (9) Fires for disposal of household rubbish, which shall not include garbage, originating at dwellings of five (5) family units or less, if the fires are

maintained by an occupant of the dwelling at the dwelling, except in cities greater than 8,000 population located in a Priority I Region; 

 (10) Fires set for the purpose of disposing of accidental spills or leaks of crude oil, petroleum products or other organic materials, and the disposal of

absorbent material used in their removal, if no other economically feasible means of disposal is available and practical. Permission shall be obtained

from the cabinet prior to burning; 

 (11) Fires set for disposal of natural growth for land clearing and maintenance, and trees and tree limbs felled by storms if no extraneous materials,

such as tires or heavy oil which tend to produce dense smoke, are used to cause ignition or aid combustion and the burning is done on days when

conditions do not pose a threat of igniting a forest fire. In regions classified Priority I, with respect to particulate matter pursuant to 401 KAR 50:020,

Appendix A, the emissions from these fires shall not be equal to or greater than forty (40) percent opacity; 

 (12) Heating ropes that are set on fire to repair steel rails during cold weather; and 

 (13) Fires set by county or municipal governments to dispose of wood waste or clean lumber. This activity shall not be considered in violation of 401

KAR 47:030, Section 10. 

 

 Section 5. Restrictions to Open Burning. (1) For those counties, or portions of counties, which are, or were previously, designated moderate

nonattainment for the one (1) hour ozone or nonattainment for the National Ambient Air Quality Standards (NAAQS) PM10 or those counties, or portions 

of counties, which are, or were designated nonattainment for the eight (8) hour ozone or PM2.5 national ambient air quality standards, pursuant to 401 

401 KAR 63:005. Open burning. Page 1 of 2

mhtml:file://S:\Program Planning\Eval\PM2.5 Redesignation NKY Nov 2010\FINAL Doc Appe... 11/10/2010
KAR 51:010, fires may be set in accordance with this administrative regulation except during the months of May, June, July, August, and September.

During these months, the only open burning activities allowed shall be: 

 (a) Fires set for the cooking of food for human consumption; 

 (b) Fires set for prevention of a fire hazard, including disposal of dangerous materials if no safe alternative is available; 

 (c) Fires set for the purpose of bona fide instruction and training of public and industrial employees in the methods of fighting fires; 

 (d) Fires set for recognized agricultural, silvicultural, range, ecological, and wildlife management practices; 

 (e) Fires set for the purpose of disposing of accidental spills or leaks of crude oil, petroleum products or other organic materials, and the disposal of

absorbent material used in their removal, if no other economically feasible means of disposal is available and practical. Permission shall be obtained

from the cabinet prior to burning; and 

 (f) Fires set for recreational or ceremonial purposes. 

 (2) Open burning shall comply with the fire hazard season requirements of KRS 149.400. 

 (3) Open burning for land clearing purposes associated with residential, commercial, or industrial development shall be limited to a maximum of two

(2) contiguous acres at any one (1) time. 

 (4) This administrative regulation shall not authorize open burning that is prohibited by any local ordinance. 

 

 Section 6. Procedures for Fire Training. Burning conducted in conjunction with training for public, private and industrial firefighters shall be subject to

the following criteria: 

 (1) Excluding fire training that has been approved by the Kentucky State Fire Marshal, or which has been certified by the Kentucky State Fire

Commission, or which is conducted in accordance with standards adopted by the National Wildfire Coordinating Group, any entity intending to conduct

fire training shall submit written notification to the local Division for Air Quality regional office a minimum of fifteen (15) days prior to the scheduled

training. The written notification shall state the location and the date of the proposed fire training, the name and contact information for the on-site 

training coordinator, the number of firefighters to be trained, the goals and the objectives of the training, and a brief summary of what is to be taught. 

 (2) Any materials that contain asbestos shall not be burned. 

 (3) Materials likely to produce hazardous or toxic emissions shall be removed prior to the fire training burning event, to the extent practicable, and

properly disposed. 

 (4) Excluding fire training approved by the Kentucky Division of Forestry or the Kentucky State Fire Marshal, or which has been certified by the

Kentucky State Fire Commission, or which is conducted in accordance with standards adopted by the National Wildfire Coordinating Group, entities

conducting fire training shall be limited to one burning event related to training per year for every ten firefighters under their supervision. 

 (5) Excluding fire training approved by the Kentucky Division of Forestry or the Kentucky State Fire Marshal, or which has been certified by the

Kentucky State Fire Commission, or which is conducted in accordance with standards adopted by the National Wildfire Coordinating Group, between

May 1 and September 30, fire training shall not be conducted in any counties, or portions of counties, which are, or were previously, designated

moderate nonattainment for ozone, or designated, or previously designated, nonattainment for the eight (8) hour ozone or PM2.5 (particulate matter) 

national ambient air quality standard, pursuant to 401 KAR 51:010. (5 Ky.R. 510; eff. 6-6-79; Am. 10 Ky.R. 634; eff. 3-1-84; 24 Ky.R. 654; 1299; eff. 1-

12-98; 31 Ky.R. 1354; 32 Ky.R. 63; eff. 7-13-2005.)

401 KAR 63:005. Open burning. Page 2 of 2

mhtml:file://S:\Program Planning\Eval\PM2.5 Redesignation NKY Nov 2010\FINAL Doc Appe... 11/10/2010
 401 KAR 63:010. Fugitive emissions.

 

 RELATES TO: KRS Chapter 224

 STATUTORY AUTHORITY: KRS 224.10-100

 NECESSITY, FUNCTION, AND CONFORMITY: KRS 224.10-100 requires the Environmental and Public Protection Cabinet to prescribe

administrative regulations for the prevention, abatement, and control of air pollution. This administrative regulation provides for the control of fugitive

emissions.

 

 Section 1. Applicability. The provisions of this administrative regulation are applicable to each affected facility as defined in Section 2 of this

administrative regulation.

 

 Section 2. Definitions. Terms used in this administrative regulation not defined herein shall have the meaning given to them in 401 KAR 50:010.

 (1) "Affected facility" means an apparatus, operation, or road which emits or may emit fugitive emissions provided that the fugitive emissions from

such facility are not elsewhere subject to an opacity standard within the administrative regulations of the Division for Air Quality.

 (2) "Fugitive emissions" means the emissions of any air contaminant into the open air other than from a stack or air pollution control equipment

exhaust.

 (3) "Open air" means the air outside buildings, structures, and equipment.

 (4) "Classification date" means the effective date of this administrative regulation.

 

 Section 3. Standards for Fugitive Emissions. (1) No person shall cause, suffer, or allow any material to be handled, processed, transported, or

stored; a building or its appurtenances to be constructed, altered, repaired, or demolished, or a road to be used without taking reasonable precaution to

prevent particulate matter from becoming airborne. Such reasonable precautions shall include, when applicable, but not be limited to the following:

 (a) Use, where possible, of water or chemicals for control of dust in the demolition of existing buildings or structures, construction operations, the

grading of roads or the clearing of land;

 (b) Application and maintenance of asphalt, oil, water, or suitable chemicals on roads, materials stockpiles, and other surfaces which can create

airborne dusts;

 (c) Installation and use of hoods, fans, and fabric filters to enclose and vent the handling of dusty materials, or the use of water sprays or other

measures to suppress the dust emissions during handling. Adequate containment methods shall be employed during sandblasting or other similar

operations;

 (d) Covering, at all times when in motion, open bodied trucks transporting materials likely to become airborne;

 (e) The maintenance of paved roadways in a clean condition;

 (f) The prompt removal of earth or other material from a paved street which earth or other material has been transported thereto by trucking or earth

moving equipment or erosion by water.

 (2) No person shall cause or permit the discharge of visible fugitive dust emissions beyond the lot line of the property on which the emissions

originate.

 (3) When dust, fumes, gases, mist, odorous matter, vapors, or any combination thereof escape from a building or equipment in such a manner and

amount as to cause a nuisance or to violate any administrative regulation, the secretary may order that the building or equipment in which processing,

handling and storage are done be tightly closed and ventilated in such a way that all air and gases and air or gas-borne material leaving the building or

equipment are treated by removal or destruction of air contaminants before discharge to the open air.

 (4) The provisions of this administrative regulation shall not apply to agricultural practices, such as tilling of land or application of fertilizers, which

take place on a farm.

 

 Section 4. Additional Requirements. In addition to the requirements of Section 3 of this administrative regulation, the following shall apply:

 (1) At all times when in motion, open bodied trucks, operating outside company property, transporting materials likely to become airborne shall be 

covered.

 (2) Agricultural practices, such as tilling of land or application of fertilizers, which take place on a farm shall be conducted in such a manner as to not

create a nuisance to others residing in the area. Agricultural practices are not subject to the opacity standard.

 (3) The provisions of Section 3(1) and (2) of this administrative regulation shall not be applicable to temporary blasting or construction operations.

 (4) No one shall allow earth or other material being transported by truck or earth moving equipment to be deposited onto a paved street or roadway.

(5 Ky.R. 511; Am. 6 Ky.R. 50; eff. 6-29-1979; TAm eff. 8-9-2007.)

401 KAR 63:010. Fugitive emissions. Page 1 of 1

mhtml:file://S:\Program Planning\Eval\PM2.5 Redesignation NKY Nov 2010\FINAL Doc Appe... 11/10/2010
Appendix H

Ohio and Indiana

Redesignation to Attainment

Request  

Submittal
I Environmental 

Protection Agency 

Ted Strickland, Governor 

Lee Fisher, Lt. Governor 

Chris Korieski. Director 

Ms. Susan Hedman 

Regional Administrator 

US. EPA Region V 

77 W. Jackson Blvd. 

Chicago, 1L 60604 

Re: PM2.5 redesignation request for the 1997 PM2.5 Annual Standard for the CincinnatiHamilton Area 

Dear Administrator Hedman: 

I am writing to formally request a redesignation to attainment of the Ohio portion of the 

Cincinnati-Hamilton, OH-IN-KY area (Butler, Clermont, Hamilton, and Warren Counties 

in Ohio; Dearborn Township in Indiana; and Boone, Campbell, and Kenton Counties in 

Kentucky) with respect to the 1997 PMz.~ annual standard. The enclosed submittal 

combines the redesignation request and the required maintenance plan for this area. 

Monitoring of existing air quality indicates that the 1997 National Ambient Air Quality 

Standard (NAAQS) for PM2.5 has been attained throughout this area based on 2007- 

2009 air quality data. Emissions projections indicate that current controls, existing State 

rules, existing federal rules, and Ohio's PSD program will be more than sufficient to 

maintain the NAAQS indefinitely into the future. These programs will, therefore, 

constitute the attainment and maintenance plan for Ohio's portion of the CincinnatiHamilton area. 

The enclosed information, compiled by the Ohio Environmental Protection Agency (Ohio 

EPA), Ohio Department of Transportation, and the Ohio, Indiana, and Kentucky 

Regional Council of Governments (associated planning organization), shows significant 

emission reductions in point and mobile sources since ambient violations have 

occurred. A significant portion of the improved air quality can be attributed to federal 

programs for the mobile source sector, the regional reductions associated with the NOx 

Trading Program, and control strategies implemented by Ohio, such as Low Reid Vapor 

Pressure Fuel requirements. 

The public hearing for this package was held on November 29, 2010, in Cincinnati, Ohio 

and public comments were accepted through November 30, 2010. 

50 West Town Street, Suhe 700 

PO. Box 1049 

Columbus, OH 43216-1049 

614 / 644 3020 

614 1644 3184 (fax) 

www.epa.ohio.gov 
If you have questions, please contact Jennifer Hunter in our Division of Air Pollution 

Control at (614) 644-3696. 

Sincerely, 

Chris Korleski 

Director 
 

REDESIGNATION REQUEST AND 

MAINTENANCE PLAN FOR 

THE OHIO PORTION OF THE 

CINCINNATI-HAMILTON, OH-KY-IN 

ANNUAL PM2.5

NONATTAINMENT AREA 

Butler, Clermont, Hamilton, 

and Warren Counties, Ohio 

Prepared by: 

Ohio Environmental Protection Agency 

Division of Air Pollution Control 

December 2010 
 

This page left intentionally blank
 i 

TABLE OF CONTENTS 

Chapter One 

Introduction ................................................................................................................................... 1 

Geographical description .............................................................................................................. 2 

Status of air quality ....................................................................................................................... 3 

Chapter Two 

Requirements for redesignation .................................................................................................... 4 

Chapter Three 

PM2.5 monitoring ............................................................................................................................ 8 

Annual PM2.5 NAAQS .................................................................................................................... 8 

Ambient data quality assured ........................................................................................................ 9 

Three complete years of data ....................................................................................................... 9 

Commitment to continue monitoring ........................................................................................... 13 

Chapter Four 

Emission inventory ...................................................................................................................... 14 

Base year inventory .................................................................................................................... 14 

Emission projections ................................................................................................................... 15 

Demonstration of maintenance ................................................................................................... 24 

Permanent and enforceable emissions reductions ..................................................................... 39 

Provisions for future updates ...................................................................................................... 40 

Chapter Five 

Control measures and regulations .............................................................................................. 41 

Marginal nonattainment areas to implement RACM and RACT .................................................. 41 

Show Reasonable Further Progress (RFP) ................................................................................ 43 

Emission inventories ................................................................................................................... 43 

Implementation of past SIP revisions .......................................................................................... 44 

New source review provisions ................................................................................................... 46 

Assurance of continued controls ................................................................................................. 46 

Chapter Six 

Contingency measures ............................................................................................................... 48 

Commitment to revise plan ......................................................................................................... 48 

Commitment for contingency measures ..................................................................................... 48 

Potential contingency measures ................................................................................................. 49 

List of PM2.5, SO2, and NOx sources ........................................................................................... 50 

Chapter Seven 

Public participation ...................................................................................................................... 51 

Chapter Eight 

Conclusions ................................................................................................................................ 52 
 ii 

FIGURES 

Figure 1 Map of the Cincinnati-Hamilton, OH-KY-IN nonattainment area and monitor 

locations ................................................................................................................ 9 

Figure 2 PM2.5 Annual Mean Trends LADCO States ......................................................... 12 

Figure 3 PM2.5 Annual Mean Trends Midwest States ........................................................ 12 

Figure 4 PM2.5 Annual Mean National Trends .................................................................. 13 

TABLES 

Table 1 Monitoring Data for Cincinnati-Hamilton, OH-KY-IN area for 2007 – 2009 ......... 11 

Table 2 Butler County, Ohio Emission Estimations for On-road Mobile Sources ............. 20 

Table 3 Clermont County, Ohio Emission Estimations for On-road Mobile Sources ........ 20 

Table 4 Hamilton County, Ohio Emission Estimations for On-road Mobile Sources ........ 21 

Table 5 Warren County, Ohio Emission Estimations for On-road Mobile Sources .......... 21 

Table 6 Dearborn County, Indiana Emission Estimations for On-road Mobile Sources ... 21 

Table 7 Summary of Ohio and Indiana Emissions Estimations for On-road Mobile 

 Sources ............................................................................................................... 21 

Table 8 Boone County, Kentucky Emission Estimations for On-road Mobile Sources ..... 21 

Table 9 Campbell County, Kentucky Emission Estimations for On-road Mobile Sources 21 

Table 10 Kenton County, Kentucky Emission Estimations for On-road Mobile Sources .... 22 

Table 11 Summary of Kentucky Emission Estimations for On-Road Mobile Sources ........ 22 

Table 12 Emission Estimations Totals for On-road Mobile Sources for the CincinnatiHamilton Area ...................................................................................................... 22 

Table 13 Mobile Vehicle Emission Budget for Ohio and Indiana ....................................... 22 

Table 14 Mobile Vehicle Emission Budget for Kentucky .................................................... 22 

Table 15 Reductions in SO2 and NOx EGU Emissions Between 2008 and 2009. ............. 26 

Table 16 Reductions in SO2 and NOx EGU Emissions Between the First Half of 2008 

 and 2010.... ......................................................................................................... 27 

Table 17 Butler County, Ohio PM2.5 Emission Inventory Total for Base Year 2005, 

Estimated 2008, and Projected 2015 and 2021 (tpy) – Without CAIR. ............... 29 

Table 18 Clermont County, Ohio PM2.5 Emission Inventory Total for Base Year 2005, 

Estimated 2008, and Projected 2015 and 2021 (tpy) – Without CAIR. ............... 29 

Table 19 Hamilton County, Ohio PM2.5 Emission Inventory Total for Base Year 2005, 

Estimated 2008, and Projected 2015 and 2021 (tpy) – Without CAIR. ............... 29 

Table 20 Warren County, Ohio PM2.5 Emission Inventory Total for Base Year 2005, 

Estimated 2008, and Projected 2015 and 2021 (tpy) – Without CAIR. ............... 30 

Table 21 Dearborn County, Indiana PM2.5 Emission Inventory Total for Base Year 2005, 

Estimated 2008, and Projected 2015 and 2021 (tpy) – Without CAIR ................ 30 

Table 22 Boone County, Kentucky PM2.5 Emission Inventory Total for Base Year 2005, 

Estimated 2008, and Projected 2015 and 2021 (tpy) – Without CAIR. ............... 30 

Table 23 Campbell County, Kentucky PM2.5 Emission Inventory Total for Base Year 2005, 

Estimated 2008, and Projected 2015 and 2021 (tpy) – Without CAIR. ............... 31 

Table 24 Kenton County, Kentucky PM2.5 Emission Inventory Total for Base Year 2005, 

Estimated 2008, and Projected 2015 and 2021 (tpy) – Without CAIR ................ 31 

Table 25 Cincinnati-Hamilton Area PM2.5 Emission Inventory Total for Base Year 2005, 

Estimated 2008, and Projected 2015 and 2021 (tpy) – Without CAIR. ............... 31 

Table 26 Butler County, Ohio NOx Emission Inventory Total for Base Year 2005, Estimated 

2008, and Projected 2015 and 2021 (tpy) – With CAIR ...................................... 32 
 iii 

Table 27 Clermont County, Ohio NOx Emission Inventory Total for Base Year 2005, 

Estimated 2008, and Projected 2015 and 2021 (tpy) – With CAIR ..................... 32 

Table 28 Hamilton County, Ohio NOx Emission Inventory Total for Base Year 2005, 

Estimated 2008, and Projected 2015 and 2021 (tpy) – With CAIR. .................... 32 

Table 29 Warren County, Ohio NOx Emission Inventory Total for Base Year 2005, 

Estimated 2008, and Projected 2015 and 2021 (tpy) – With CAIR. .................... 33 

Table 30 Dearborn County, Indiana NOx Emission Inventory Total for Base Year 2005, 

Estimated 2008, and Projected 2015 and 2021 (tpy) – With CAIR. .................... 33 

Table 31 Boone County, Kentucky NOx Emission Inventory Total for Base Year 2005, 

Estimated 2008, and Projected 2015 and 2021 (tpy) – With CAIR. .................... 33 

Table 32 Campbell County, Kentucky NOx Emission Inventory Total for Base Year 2005, 

Estimated 2008, and Projected 2015 and 2021 (tpy) – With CAIR ..................... 34 

Table 33 Kenton County, Kentucky NOx Emission Inventory Total for Base Year 2005, 

Estimated 2008, and Projected 2015 and 2021 (tpy) – With CAIR. .................... 34 

Table 34 Cincinnati-Hamilton Area NOx Emission Inventory Total for Base Year 2005, 

Estimated 2008, and Projected 2015 and 2021 (tpy) – With CAIR. .................... 34 

Table 35 Butler County, Ohio SO2 Emission Inventory Total for Base Year 2005, 

 Estimated 2008, and Projected 2015 and 2021 (tpy) – With CAIR ..................... 35 

Table 36 Clermont County, Ohio SO2 Emission Inventory Total for Base Year 2005, 

Estimated 2008, and Projected 2015 and 2021 (tpy) – With CAIR ..................... 35 

Table 37 Hamilton County, Ohio SO2 Emission Inventory Total for Base Year 2005, 

Estimated 2008, and Projected 2015 and 2021 (tpy) – With CAIR ..................... 35 

Table 38 Warren County, Ohio SO2 Emission Inventory Total for Base Year 2005, 

Estimated 2008, and Projected 2015 and 2021 (tpy) – With CAIR ..................... 36 

Table 39 Dearborn County, Indiana SO2 Emission Inventory Total for Base Year 2005, 

Estimated 2008, and Projected 2015 and 2021 (tpy) – With CAIR. .................... 36 

Table 40 Boone County, Kentucky SO2 Emission Inventory Total for Base Year 2005, 

Estimated 2008, and Projected 2015 and 2021 (tpy) – With CAIR. .................... 36 

Table 41 Campbell County, Kentucky SO2 Emission Inventory Total for Base Year 2005, 

Estimated 2008, and Projected 2015 and 2021 (tpy) – With CAIR ..................... 37 

Table 42 Kenton County, Kentucky SO2 Emission Inventory Total for Base Year 2005, 

Estimated 2008, and Projected 2015 and 2021 (tpy) – With CAIR ..................... 37 

Table 43 Cincinnati-Hamilton Area SO2 Emission Inventory Total for Base Year 2005, 

Estimated 2008, and Projected 2015 and 2021 (tpy) – With CAIR ..................... 37 

Table 44 Cincinnati-Hamilton Area Comparison of 2008 attainment year and 2015 and 

2021 projected emission estimates (tpy) ............................................................. 38 

Table 45 Miami Fort Station, Hamilton County , Emission Reductions (tpy) as Reported 

 by Clean Air Markets Division.............................................................................. 39 

Table 46 Cincinnati-Hamilton Area Combined Comparison of 2005 base year and 2008 

attainment year on-road and EGU reductions ..................................................... 39 

APPENDICES 

A Air Quality System (AQS) Data 

B Ohio 2005 SIP Base Year Inventory Discussion 

C “Mobile Source Emissions Inventory for the Cincinnati Ozone Nonattainment Area” 

D LADCO Technical Support Document 

E Public Participation Documentation 
 iv 

This page left intentionally blank 
REDESIGNATION REQUEST AND MAINTENANCE PLAN FOR THE OHIO 

PORTION OF THE CINCINNATI-HAMILTON, OH-KY-IN 

ANNUAL PM2.5 NONATTAINMENT AREA 

Butler, Clermont, Hamilton, and Warren Counties, Ohio 

CHAPTER ONE 

Introduction

The Clean Air Act (CAA) requires areas failing to meet the National Ambient Air 

Quality Standard (NAAQS) for the annual PM2.5 to develop State Implementation 

Plans (SIP’s) to expeditiously attain and maintain the standard. The United 

States Environmental Protection Agency (U.S. EPA) revised the NAAQS for 

particulate matter in July 1997. It replaced the existing PM10 standard with a 

health based PM2.5 standard and retained the PM10 standard as a “coarse” 

standard protecting welfare. The standards include an annual standard set at 

15.0 micrograms per cubic meter (μg/m3

), based on the 3-year average of 

annual mean PM2.5 concentrations and a 24-hour standard of 65 μg/m3

, based 

on the 3-year average of the 98th percentile of 24-hour concentrations. 

The revised NAAQS were legally challenged in the U.S. Court of Appeals for the 

District of Columbia Circuit (The D.C. Circuit). On May 14, 1999, the D.C. Circuit 

remanded, without vacatur, the standard back to U.S. EPA. The remand did not 

question the level at which U.S. EPA set the standards but rather the 

constitutionality of the CAA provision that authorizes U.S. EPA to set national air 

quality standards. U.S. EPA requested a rehearing which the D.C. Circuit denied. 

Therefore, in December 1999, U.S. EPA appealed the D.C. Circuit decision to 

the U.S. Supreme Court. The U.S. Supreme Court issued a decision on 

February 27, 2001 that unanimously affirmed the constitutionality of the CAA 

provision but did remand several other issues back to the D.C. Circuit, including 

the issue of whether U.S. EPA acted arbitrarily and capriciously in establishing 

the specific levels of the standards. 

The D.C. Circuit heard arguments in this remanded case in December 2001, and 

issued its decision on March 26, 2002. The D.C. Circuit rejected the claims that 

the U.S. EPA had acted arbitrarily and capriciously in setting the levels of the 

standards. 

On December 17, 2004, U.S. EPA promulgated the initial PM2.5 nonattainment 

areas designations for the PM2.5 standards across the country. Modifications to 

those designations were made and an effective date was set at April 5, 2005. 

Unlike Subpart 2 of the CAA Amendments of 1990 which defined five ozone 

nonattainment classifications for the areas that exceed the NAAQS based on the 
 2 

severity of the ozone levels, PM2.5 nonattainment designations are simply 

labeled “nonattainment.” The CAA Amendments require states with PM2.5

nonattainment areas to submit a plan within three years of the effective date of 

the designations (April 5, 2008) detailing how the PM2.5 standards will be 

attained by April 5, 2010. Ohio EPA submitted its attainment demonstration for 

the entire State of Ohio on July 16, 2008. 

Section 107(d)(3)(E) of the CAA allows states to request nonattainment areas to 

be redesignated to attainment provided certain criteria are met. The following are 

the criteria that must be met in order for an area to be redesignated from 

nonattainment to attainment: 

i) A determination that the area has attained the PM2.5 standard.

ii) An approved State Implementation Plan (SIP) for the area under 

Section 110(k).

iii) A determination that the improvement in air quality is due to 

permanent and enforceable reductions in emissions resulting from 

implementation of the SIP and other federal requirements.

iv) A fully approved maintenance plan under Section 175(A).

v) A determination that all Section 110 and Part D requirements have 

been met. 

This document addresses each of these requirements, and provides additional 

information to support continued compliance with the annual PM2.5 standard. 

 

Geographical Description and Background

The current Cincinnati-Hamilton nonattainment area is located in southwest Ohio 

and includes the following counties: Butler, Clermont, Hamilton, and Warren in 

Ohio; Dearborn (partial nonattainment of Lawrenceburg Township only) in 

Indiana; and Boone, Campbell, and Kenton in Kentucky. This area is shown in 

Figure 1 under Chapter Three. 

The Cincinnati-Hamilton area has not previously been subject to nonattainment 

area rulemakings for fine particles. 

As a result of the 2005 PM2.5 designations, U.S. EPA designated the CincinnatiHamilton area nonattainment for the 15.0 μg/m3 annual standard1

, and Ohio EPA 

was required to develop a plan to reduce oxides of nitrogen (NOx), sulfur dioxide 

(SO2) and direct PM2.5 emissions and to demonstrate that the area will meet the 

federal annual air quality standard by April 5, 2010. Ohio’s main PM2.5

components are primary particles (organic carbon, crustal material, and 

elemental carbon), SO2 and NOx, which were included in the attainment 

demonstration analysis. Volatile organic compounds (VOCs) and ammonia 

(NH3) were not included in the analysis since they were not part of Ohio’s 

 

1 There were no monitors in Ohio that violated the 1997 24-hour PM2.5 standard of 65μg/m3. 
 3 

current attainment strategy for PM2.5 (although controls for VOCs have been 

implemented for ozone nonattainment). This is consistent with U.S. EPA’s “Clean 

Air Particle Implementation Rule” [74FR 20856] (hereafter referred to as 

“Implementation Rule”). In the Implementation Rule U.S. EPA presumes NH3 

emissions are not a PM2.5 attainment plan precursor and that States are not 

required to address VOC unless the State or U.S. EPA makes technical 

demonstration that emissions of VOCs significantly contribute to nonattainment. 

This document is intended to support Ohio’s request that the Ohio portions of the 

Cincinnati-Hamilton area be redesignated from nonattainment to attainment for 

the annual PM2.5 standard. In addition, the States of Kentucky and Indiana also 

intend to submit requests for their respective portions of the Cincinnati-Hamilton 

area.

Status of Air Quality

PM2.5 complete quality-assured ambient air quality monitoring data for the most 

recent three (3) years, 2007 through 2009, demonstrate that the air quality has 

met the NAAQS for annual PM2.5 in this nonattainment area. The NAAQS 

attainment, accompanied by decreases in emission levels discussed in Chapter 

Four, supports a redesignation to attainment for the Cincinnati-Hamilton area 

based on the requirements in Section 107(d)(3)(E) of the CAA. 
 4 

CHAPTER TWO 

Requirements for Redesignation

U.S. EPA has published detailed guidance in a document entitled Procedures for 

Processing Requests to Redesignate Areas to Attainment (redesignation 

guidance), issued September 4, 1992, to Regional Air Directors. The 

redesignation request and maintenance plan are based on the redesignation 

guidance, supplemented with additional guidance received from staff of U.S. 

EPA Region V. 

Below is a summary of each redesignation criterion as it applies to the 

Cincinnati-Hamilton area. 

i.) Attainment of the standard (CAA Section 107(d)(3)(E)(i)) 

There are two components involved in making this demonstration. 

The first component relies on ambient air quality data. The data 

that are used to demonstrate attainment should be the product of 

ambient monitoring that is representative of the area of highest 

concentration. The data should be collected and quality-assured in 

accordance with 40 CFR 58 and recorded in the Air Quality 

System (AQS)in order for it to be available to the public for review. 

The second component relies upon supplemental U.S. EPAapproved air quality modeling. While no modeling is required for 

redesignating nonattainment areas, the redesignation guidance 

states it is “generally necessary” for particulate matter 

redesignations. Appendix C and Appendix D contains the most 

recent modeling results showing future attainment and 

maintenance are provided. Chapter Three discusses this 

requirement in more detail and provides the attainment 

demonstration. 

ii.) Permanent and enforceable improvement in air quality (CAA 

Section 107(d)(3)(E)(iii))

The state must be able to reasonably attribute the improvement in 

air quality to emission reductions which are permanent and 

enforceable. The state should estimate the percent reduction 

achieved from federal measures as well as control measures that 

have been adopted and implemented by the state. 

It was not necessary for Ohio to adopt or implement control 

measures for these counties beyond the federal measures. 

Ohio EPA has adopted several rules recently that will have an 

impact Statewide on PM2.5 emissions in the future: 
 5 

• Clean Air Interstate Rule (CAIR) 

• NOx SIP Call Rules 

In addition, since the initial designations were made federally 

enforceable consent decrees have resulted in reductions in 

emissions from utilities across the state, including this area. 

Chapters Four and Five discuss this requirement in more detail. 

iv.) Section 110 and Part D requirements (CAA Section 

107(d)(3)(E)(v))

For purposes of redesignation, a state must meet all requirements 

of Section 110 and Part D that were applicable prior to submittal of 

the complete redesignation request. 

Subpart 1 of Part D consists of general requirements applicable to 

all areas which are designated nonattainment based on a violation 

of the NAAQS. Subpart 4 of Part D consists of more specific 

requirements applicable to particulate matter (specifically to 

address PM10). However, for the purpose of implementing the 

1997 PM2.5 standard, U.S. EPA’s Implementation Rule stated 

Subpart 1, rather than Subpart 4, is appropriate for the purpose of 

implementing PM2.5.[72 FR 20589] 

i.) Section 110(a) requirements

Section 110(a) of Title I of the CAA contains the general 

requirements for a SIP. Section 110(a)(2) provides that the 

implementation plan submitted by a state must have been 

adopted by the state after reasonable public notice and 

hearing, and that, among other things, it must include 

enforceable emission limitations and other control 

measures, means or techniques necessary to meet the 

requirements of the CAA; provide for establishment and 

operation of appropriate devices, methods, systems and 

procedures necessary to monitor ambient air quality; 

provide for implementation of a source permit program to 

regulate the modification and construction of any stationary 

source within the areas covered by the plan; include 

provisions for the implementation of Part C, prevention of 

significant deterioration (PSD) and Part D, NSR permit 

programs; include criteria for stationary source emission 

control measures, monitoring, and reporting; include 

provisions for air quality modeling; and provides for public 

and local agency participation in planning and emission 

control rule development. In Ohio’s December 5, 2007 and 

September 4, 2009 infrastructure SIP submissions, Ohio 
 6 

verified that the State fulfills the requirements of Section 

110(a)(2) of the Act. 

Section 110(a)(2)(D) also requires State plans to prohibit 

emissions from within the State which contribute 

significantly to nonattainment or maintenance areas in any 

other State, or which interfere with programs under Part C 

to prevent significant deterioration of air quality or to 

achieve reasonable progress toward the national visibility 

goal for Federal class I areas (national parks and 

wilderness areas). In order to assist States in addressing 

their obligations regarding regionally transported pollution, 

U.S. EPA finalized CAIR to reduce SO2 and NOx emissions 

from large electric generating units (EGU). Ohio has met 

the requirements of the federal CAIR to reduce NOx and 

SO2 emissions contributing to downwind states. On 

February 1, 2008, U.S. EPA approved Ohio’s CAIR 

program, which can be found in Ohio Administrative Code 

(OAC) Chapter 3745-1092. On July 6, 2010, U.S. EPA 

proposed a replacement to the CAIR program, the 

Transport Rule. [75 FR 45210] Upon finalization, it will 

further assist States in addressing their obligations 

regarding regionally transported pollution by providing 

reductions in NOx and SO2 emissions in 2012 and 2014. 

ii.) Section 172(c) requirements

 This Section contains general requirements for 

nonattainment plans. The requirements for reasonable 

further progress, identification of certain emissions 

increases, and other measures needed for attainment will 

not apply for redesignations because they only have 

meaning for areas not attaining the standard. The 

requirements for an emission inventory will be satisfied by 

the inventory requirements of the maintenance plan. 

Chapters Four and Five discuss this requirement in more 

detail. 

iii.) Conformity

The state must work with U.S. EPA to show that its SIP 

provisions are consistent with the Section 176(c)(4) 

conformity requirements. The redesignation request should 

include conformity procedures, if the state already has 

these procedures in place. If a state does not have 

conformity procedures in place at the time that it submits a 

 

2 http://www.epa.ohio.gov/dapc/regs/regs.aspx#3745-109 
 7 

redesignation request, the state must commit to follow U.S. 

EPA’s conformity regulation upon issuance, as applicable. 

v.) Maintenance plans (CAA Section 107(d)(3)(E)(iv))

Section 107(d)(3)(E) stipulates that for an area to be redesignated, 

U.S. EPA must fully approve a maintenance plan that meets the 

requirements of Section 175(A). The maintenance plan will 

constitute a SIP revision and must provide for maintenance of the 

relevant NAAQS in the area for at least 10 years after 

redesignation. Section 175 (A) further states that the plan shall 

contain such additional measures, if any, as may be necessary to 

ensure such maintenance. 

In addition, the maintenance plan shall contain such contingency 

measures as the Administrator deems necessary to ensure prompt 

correction of any violation of the NAAQS. At a minimum, the 

contingency measures must include a requirement that the state 

will implement all measures contained in the nonattainment SIP 

prior to redesignation. 

States seeking redesignation of a nonattainment area should 

consider the following provisions: 

a.) attainment inventory; 

b.) maintenance demonstration; 

c.) monitoring network; 

d.) verification of continued attainment; and 

e.) contingency plan. 

Chapter Six discusses this requirement in more detail. 
 8 

CHAPTER THREE 

PM2.5 MONITORING 

CAA Section 107(d)(3)(E)(i) 

Requirement 1 of 4 

A demonstration that the NAAQS for annual PM2.5, as published in 40 CFR 50.7, 

has been attained. 

Background

There are sixteen monitors measuring PM2.5 concentrations in this 

nonattainment area. Twelve of the sixteen monitors are located in 

Ohio3

 and are operated by Ohio EPA Division of Air Pollution 

Control, Southwest District Office and the Hamilton County Division 

of Environmental Services. A listing of the design values based on 

the three-year average of the annual mean concentrations from 

2007 through 2009 is shown in Table 1. The locations of the 

monitoring sites for this nonattainment area are shown on Figure 1. 

 

3 The four remaining PM2.5 monitors are located in Kentucky. 
 9 

Demonstration

 

Figure 1 - Map of the Cincinnati-Hamilton, OH-KY-IN nonattainment area 

and monitor locations 

Requirement 2 of 4 

Ambient monitoring data quality assured in accordance with 40 CFR 58.10, 

recorded in the U.S. EPA air quality system (AQS) database, and available for 

public view. 

Demonstration

The Ohio EPA has quality assured all data shown in Appendix A in 

accordance with 40 CFR 58.10 and all other federal requirements. Ohio 

EPA has recorded the data in the AQS database and, therefore, the data 

are available to the public. 

Requirement 3 of 4 

A showing that the three-year average of the annual mean values, based on 

data from all monitoring sites in the area or its affected downwind environs, are 

below 15.0 μg/m3

. (This showing must rely on three complete, consecutive 

calendar years of quality assured data.) 

 
 10 

Background

The following information is taken from U.S. EPA's "Guideline on 

Data Handling Conventions for the PM NAAQS," U.S. EPA-454/R99-008, April 1999. 

In accordance with the CAA Amendments, three complete years of 

monitoring data are required to demonstrate attainment at a 

monitoring site. The annual PM2.5 primary and secondary ambient air 

quality standards are met at an ambient air quality monitoring site 

when the three-year average of the annual average is less than 15.0 

μg/m3. While calculating design values, three significant digits must 

be carried in the computations, with final values rounded to the 

nearest 0.1 μg/m3. Decimals 0.05 or greater are rounded up, and 

those less than 0.05 are rounded down, so that 15.049 μg/m3 is the 

largest concentration that is less than, or equal to 15.0 μg/m3

. 

Values at or below 15.0 μg/m3 meet the standard; values equal to or 

greater than 15.1 μg/m3 exceed the standard. An area is in 

compliance with the annual PM2.5 NAAQS only if every monitoring 

site in the area meets the NAAQS. An individual site's 3-year 

average of the annual average concentrations is also called the 

site's design value. The air quality design value for the area is the 

highest design value among all sites in the area. 

Table 1 shows the monitoring data for 2007 – 2009 that were 

retrieved from the U.S. EPA AQS. The air quality design value for 

the area is the highest design value among all sites in the area. 
 11 

Demonstration

Table 1 - Monitoring Data for the Cincinnati-Hamilton, OH-KY-IN area 

for 2007 – 2009 

Average

2007 2008 2009 2007-2009

39-017-0003 15.4 13.8 12.8 14.0

39-017-0016 14.9 13.8 13.1 13.9

39-017-1004 [a] 14.6

39-025-0022 Clermont, OH 14.0 11.7 11.0 12.2

39-061-0006 14.6 12.5 12.1 13.1

39-061-0014 16.6 15.1 13.4 15.0

39-061-0040 15.1 12.6 12.7 13.5

39-061-0042 15.9 14.4 13.7 14.7

39-061-0043 [b] 14.8 13.3

39-061-7001 15.1 13.7 13.0 13.9

39-061-8001 16.1 14.4 13.4 14.6

39-165-0007 Warren, OH 14.0 11.9 11.7 12.5

21-037-3002 [c] Campbell, KY 14.4 11.8 11.3 12.5

21-117-0007 Kenton, KY 14.2 12.0 11.0 12.4

Less than 75% capture in at least one quarter

[a] This site was terminated at the end of 2007. Based on data from available previous years,

 the site incidcates attainment for the PM2.5 annual standard.

 2004-2006 average: 14.6ug/m3; 2005-2007 average: 15.0 ug/m3

[b] This site was discontinued at the end of 2008. Based on data from available previous

 years, the site indicates attainment for the PM2.5 annual standard 

 2006-2008 average: 14.2ug/m3

[c] This site did not start operating until 8/1/2007. All available data indicates attainment of

 the PM2.5 annual standard.

Year Site County

Hamilton, OH

Butler, OH

Annual Standard

Source: U.S. EPA Air Quality System (AQS); http://www.epa.gov/ttn/airs/airsaqs/index.htm 

The design values calculated for the Cincinnati-Hamilton area 

demonstrates that the annual PM2.5 NAAQS has been attained. The area's 

design values have trended downward as emissions have declined due to 

such factors as cleaner automobiles and fuels, and controls for EGUs, at 

the national, regional and local level. 

National monitoring for PM2.5 began in 1999. With respect to each of the 

Lake Michigan Air Directors Consortium (LADCO) states, there has been a 

clear downward trend in design values: 
 12 

Figure 2 - PM2.5 Annual Mean Trends LADCO States 

Source: LADCO; Recent Ozone and PM2.5 Trends – Aug 26 2010.pptx

The same trend can be seen within the Midwest States as a whole: 

Figure 3 - PM2.5 Annual Mean Trends Midwest States 

Source: LADCO; Recent Ozone and PM25 Trends - Aug 26 2010.pptx 
 13 

Design values have also trended downward nationally: 

Figure 4 - PM2.5 Annual Mean National Trends 

Source: http://www.epa.gov/airtrends/pm.html 

Requirement 4 of 4 

A commitment that once redesignated, the state will continue to operate an 

appropriate monitoring network to verify the maintenance of the attainment 

status. 

Demonstration

Ohio EPA commits to continue monitoring PM2.5 levels at the Ohio 

sites indicated in Figure 1 and Table 1. Ohio EPA will consult with 

U.S. EPA Region V prior to making changes to the existing 

monitoring network, should changes become necessary in the 

future. Ohio EPA will continue to quality assure the monitoring data 

to meet the requirements of 40 CFR 58 and all other federal 

requirements. Connection to a central station and updates to the 

Ohio EPA web site4

 will provide real time availability of the data and 

knowledge of any exceedances. Ohio EPA will enter all data into 

AQS on a timely basis in accordance with federal guidelines. 

 

4 www.epa.ohio.gov/dapc 
 14 

CHAPTER FOUR 

EMISSION INVENTORY

CAA Section 107(d)(3)(E)(iii) 

U.S. EPA’s redesignation guidance requires the submittal of a comprehensive 

inventory of PM2.5 precursor emissions (primary particles (organic carbon, crustal 

matter, and elemental carbon), SO2 and NOx

5

) representative of the year when 

the area achieves attainment of the annual PM2.5 air quality standard. Ohio also 

must demonstrate that the improvement in air quality between the year that 

violations occurred and the year that attainment was achieved is based on 

permanent and enforceable emission reductions. Other emission inventory 

related requirements include a projection of the emission inventory to a year at 

least 10 years following redesignation; a demonstration that the projected level 

of emissions is sufficient to maintain the annual PM2.5 standard; and a 

commitment to provide future updates of the inventory to enable tracking of 

emission levels during the 10-year maintenance period. 

The emissions inventory development and emissions projection discussion 

below, with the exception of the mobile (on-road) emissions inventory and 

projections, identifies procedures used by Ohio EPA and the LADCO regarding 

emissions from Ohio’s portion of the counties in the Cincinnati-Hamilton area. 

Specific emissions data are provided for all counties, including those in Ohio, 

Kentucky and Indiana. Indiana and Kentucky emissions data were also obtained 

though the LADCO emissions inventory and projections. All of these inventories 

and emissions projections were prepared using similar methodologies. Ohio 

recognizes that revisions to the emissions data below may be necessary once 

Kentucky and Indiana prepare a redesignation request and maintenance plan for 

their portion of the nonattainment area. Mobile emissions inventories and 

projections for all counties were prepared by the Ohio, Kentucky, Indiana Council 

of Governments (OKI). 

Requirement 1 of 5 

A comprehensive emission inventory of PM2.5, SO2 and NOx completed for the 

base year. 

Background

The point source data are taken from Ohio's annual emissions 

reporting program. The 2005 periodic inventory has been identified 

as one of the preferred databases for SIP development and 

coincides with nonattainment air quality in the Cincinnati-Hamilton 

area. 

 

5 VOC and NH3 are not addressed. 
 15 

Periodic inventories, which include emissions from all sectors - 

mobile, area, non-road, and point sources - are prepared every 

three years. 

Demonstration

The 2005 inventory is used as the base year for the purpose of this 

submittal and was submitted to U.S. EPA with Ohio’s PM2.5

attainment demonstration SIP submitted on July 18, 2008 and 

revised on June 7, 2010. The detailed emission inventory 

information for the Ohio portion of the Cincinnati-Hamilton area is 

provided in Appendix B. Emissions of PM2.5, SO2 and NOx for 2005 

are identified under Requirement Three of this Chapter. 

Requirement 2 of 5 

A projection of the emission inventory to a year at least 10 years following 

redesignation. 

Background

Ohio EPA prepared a comprehensive inventory for the Ohio portion of the 

Cincinnati-Hamilton area including area, mobile, and point sources for 

PM2.5, S02 and NOx for base year 2005. The 2005 inventory was submitted 

to U.S. EPA on July 18, 2008 as part of Ohio’s PM2.5 attainment 

demonstration SIP for this area. The information below describes the 

procedures Ohio EPA used to generate the 2005 base year inventory and 

to develop SIP-ready modeling inventories and future year projections 

(Pechan Report6) based on a 2005 base year inventory. The report by 

Pechan generated future year estimates of annual emissions for each 

source sector using accepted growth surrogates. These inventories were 

provided to the LADCO and have been processed to develop average daily 

emissions for use in the air quality analyses. These processed modeling 

inventories have been identified as the correct iteration of the inventory for 

use in the redesignation. In this document, references to LADCO include 

the Midwest Regional Planning Organization. Note, the on-road mobile 

source sector was addressed by specific PM2.5 and NOx modeling as 

discussed below. 

• Area sources were taken from the Ohio 2005 periodic 

inventory submitted to U.S. EPA. These projections were 

made from the U.S. Department of Commerce Bureau of 

Economic Analysis (BEA) growth factors, with some updated 

local information. 

 

6 

http://www.ladco.org/tech/emis/r5/reports/LADCO%202005%20Base%20Yr%20Growth%20and%20Con

trols%20Report_Final.pdf 
 16 

• Mobile source emissions were calculated from MOVES2010 -

produced emission factors. Only PM2.5 and NOx necessitate 

emissions inventory analysis. As documented in Ohio EPA’s 

attainment demonstration SIP, Ohio EPA in consultation with 

U.S. EPA determined mobile sources are insignificant 

contributors for SO2. Consistent with Ohio EPA’s attainment 

demonstration, Ohio EPA continues to consider mobile 

source SO2 to be an insignificant contributor to fine particles 

for this nonattainment area. Based on the demonstration 

below, SO2 constitutes less than one percent (<1%) of the 

area’s total SO2 emissions in 2005, 2008, 2015 and 2021 

(ranging between 0.09% and 0.31%). 

• Point source information was compiled from Ohio EPA’s 

2005 annual emissions inventory database and the 2005 

U.S. EPA Air Markets acid rain database7

. 

• Biogenic emissions are not included in these summaries. 

• Non-road emissions were generated using U.S. EPA’s 

National Mobile Inventory Model (NMIM) 2002 application. 

To address concerns about the accuracy of some of the 

categories in U.S. EPA’s non-road emissions model, LADCO 

contracted with two (2) companies to review the base data 

and make recommendations. One of the contractors also 

estimated emissions for three (3) non-road categories not 

included in U.S. EPA’s non-road model. Emissions were 

estimated for aircraft, commercial marine vessels, and 

railroads. Recreational motorboat population and spatial 

surrogates (used to assign emissions to each county) were 

significantly updated. The populations for the construction 

equipment category were reviewed and updated based upon 

surveys completed in the Midwest, and the temporal 

allocation for agricultural sources also was updated. 

 

Demonstration

On-Road Emission Estimations

In coordination with the Ohio Department of Transportation (Ohio 

DOT), OKI utilizes a regional travel demand forecast model to 

simulate traffic in the area and to forecast traffic flows for given 

growth expectations. The model has been validated to observed 

traffic volumes for the model base year 2005. The model is primarily 

used as a long range planning tool to evaluate the transportation 

system including determination of locations where additional travel 

capacity may be needed and to determine the infrastructure 

requirements necessary to meet that need. It is also used as a tool 

 

7 http://www.epa.gov/airmarkets/acidrain 
 17 

for air quality purposes to estimate the total emissions of pollution 

caused by vehicles in the area. The travel demand forecasting 

model is used to predict traffic volumes vehicle miles traveled 

(VMT), travel speeds, and a U.S. EPA computer program called 

MOVES is used to calculate emissions per mile. The product of 

these is the total amount of pollution emitted by the on-road vehicles 

for the area. 

Overview 

U.S.EPA published a Federal Register notice8 of availability on 

March 2, 2010, to approve MOVES2010 (Motor Vehicle Emissions 

Simulator), hereafter referred to as MOVES. Upon publication of the 

Federal Register notice, MOVES became U.S. EPA’s approved 

motor vehicle emission factor model for estimating VOCs, NOx, CO, 

PM10 and PM2.5 and other pollutants and precursors from cars, 

trucks, motorcycles, and buses by state and local agencies. MOVES 

is a computer program designed by the U.S. EPA to estimate air 

pollution emissions from mobile sources. MOVES replaces U.S. 

EPA’s previous emissions model for on-road mobile sources, 

MOBILE6.2. MOVES can be used to estimate exhaust and 

evaporative emissions as well as brake and tire wear emissions 

from all types of on-road vehicles. 

The CAA requires U.S. EPA to regularly update its mobile source 

emission models. U.S. EPA continuously collects data and 

measures vehicle emissions to make sure the Agency has the best 

possible understanding of mobile source emissions. This 

assessment, in turn, informs the development of U.S. EPA’s mobile 

source emission models. MOVES represents the Agency’s most upto-date assessment of on-road mobile source emissions. MOVES 

also incorporates several changes to the U.S. EPA’s approach to 

mobile source emission modeling based upon recommendations 

made to the Agency by the National Academy of Sciences. 

U.S.EPA believes that MOVES should be used in ozone, CO, PM, 

and nitrogen dioxide SIP development as expeditiously as possible. 

The CAA requires that SIP inventories and control measures be 

based on the most current information and applicable models that 

are available when a SIP is developed. 

Regarding transportation conformity, U.S. EPA and U.S. DOT intend 

to establish a two-year grace period before MOVES is required for 

new transportation conformity analyses. 

 

8 http://www.regulations.gov/search/Regs/home.html#documentDetail?R=0900006480ab1f98 
 18 

The MOVES more detailed approach (when compared with the 

previous MOBILE model) to modeling allows U.S. EPA to easily 

incorporate large amounts of in-use data from a wide variety of 

sources, such as data from vehicle inspection and maintenance 

(I/M) programs, remote sensing device (RSD) testing, certification 

testing, portable emission measurement systems (PEMS), etc. This 

approach also allows users to incorporate a variety of activity data to 

better estimate emission differences such as those resulting from 

changes to vehicle speed and acceleration patterns. MOVES has a 

graphical user interface which allows users to more easily set up 

and run the model. MOVES database-centered design provides 

users much greater flexibility regarding output choices. Unlike earlier 

models which provided emission factors in grams-per-mile in fixed 

output formats, MOVES output can be expressed as total mass (in 

tons, pounds, kilograms, or grams) or as emission factors (gramsper-mile and in some cases grams-per-vehicle). Output can be 

easily aggregated or disaggregated to examine emissions in a range 

of scales, from national emissions impacts down to the emissions 

impacts of individual transportation projects. The database-centered 

design also allows U.S. EPA to update emissions data incorporated 

in MOVES more easily and will allow users to incorporate a much 

wider array of activity data to improve estimation of local emissions. 

For example, the improvements in MOVES will allow project-level 

PM2.5 emissions to be estimated. 

OKI’s utilized U.S.EPA’s emissions model MOVES to develop 

emissions factors for SO2, NOx and PM2.5. Further details on the use 

of MOVES are found on Appendix C. Transportation system 

performance was estimated using the OKI Travel Demand Model 

Version 7.6. The model uses demographic and land use data and 

capacity and free-flow speed characteristics for each roadway 

segment in the network to produce a “loaded” highway network with 

forecasted traffic volumes with revised speeds based on specified 

speed/capacity relationships. 

Travel analysis zones are the basic geographic unit for estimating 

travel in the OKI model. The OKI region is subdivided into 1608 

traffic analysis zones to permit detail as well as manageability. A 

variety of socioeconomic data items are used in the OKI 

transportation planning process. These data are used primarily to 

forecast future travel patterns by serving as independent variables in 

OKI trip generation equations. The following categories of planning 

data are utilized: 

- Population. 

- Households. 
 19 

- Household vehicles. 

- Employment. 

- Labor force participation. 

- Area type. 

The principal data requirements of the OKI travel demand 

forecasting model are population and employment, from these 

variables other characteristics including household, labor force, and 

personal vehicles may be derived (OKI 2030 Regional 

Transportation Plan 2008 Update provides a complete demographic 

overview of the region). 

OKI utilizes both base year (2005) and future year data (2010, 2020 

and 2030) in the planning process. Planning data are maintained at 

the Traffic Analysis Zone (TAZ) level, and originate in the 2000 

Census of Population and Housing. Base year 2005 and future yare 

data for each variable are developed through various methods. 

OKI’s Travel Demand Model has been validated to observed traffic 

volumes for the model base year 2005. The modeling network 

encompasses the entire PM2.5 nonattainment area. The modeling 

network also includes Greene, Miami and Montgomery counties in 

Ohio and the remainder of Dearborn County, Indiana. The 

differences between estimated vehicle miles traveled (VMT) and 

2005 observed VMT is less than 1%. A highway screenline analysis 

compares the screenline observed and simulated traffic volume 

discrepancies with the Ohio Department of Transportation (ODOT) 

standard of maximum desirable deviation. The comparison shows 

that the model performs at a satisfactory level and all the errors 

were under the ODOT curve (OKI’s 2007 report, “OKI/MVRPC 

Travel Demand Model Methodology/Validation Report”). For the 

calibration, OKI used over 3000 traffic counts collected through 2006 

by the ODOT, the Kentucky Transportation Cabinet, many county 

and local governments, transportation engineering consultants, and 

OKI. These traffic counts cover nearly 50% of the links in the OKI 

portion of the modeling network. The methodology provides 

consistency with past emission inventory and conformity analysis 

work performed by OKI. 

OKI incorporates a variety of sources of local data to both improve 

and confirm the accuracy of VMT, as well as other travel-related 

parameters. Free flow speeds used on the highway and transit 

networks are based on travel time studies performed locally. An 

OKI post-processing program uses the loaded highway network to 

generate VMT by hour, VMT by speed distribution, and VMT by 

facility type. These tables are then included as input into MOVES. 
 20 

The VMT by hour tables utilize hourly traffic distribution and 

directional split factors for different roadway types as developed by 

OKI. The main source of the data was the permanent traffic counting 

stations located throughout the OKI region for the years of 1998-

2002. These data were supplemented with data collected at 

coverage count stations (locations with counts taken on only onetwo days). The stations were classified by area type (urban and 

rural) and functional classification (freeway, arterial and collector). 

Speeds representing various “loaded” conditions (with traffic 

volumes) are estimated using techniques from the 1997 Highway 

Capacity Manual. This permits the estimation of speeds as 

conditions vary from hour to hour on the different facility types 

throughout the region. The post-processing program performs the 

appropriate summation by area and roadway type as well as 

regional totals. OKI has also developed seasonal conversion factors 

to adjust traffic volumes to summer conditions. The factors were 

derived from local data collected at permanent traffic counting 

stations during 1994-1997 utilizing the average daily traffic monthly 

conversion factors for June, July and August. 

On-Road Mobile Emission Estimations

Tables 2 through 12 contain the results of the emissions analysis for the 

appropriate years. All emissions estimations are expressed in tons per year 

(tpy). 

Table 2 - Butler County, Ohio Emissions Estimations for On-Road 

Mobile Sources 

2005 2008 2015 2021 

PM2.5 (tpy) 413.970 377.640 301.16 215.76 

NOx (tpy) 10,910.37 9,803.70 6,064.61 3,757.91 

SO2 (tpy) 30.01 34.25 34.28 37.90 

Annual VMT 2,469,168,490 2,598,061,793 2,792,190,918 2,966,040,396 

Table 3 – Clermont County, Ohio Emissions Estimations for On-Road 

Mobile Sources 

 2005 2008 2015 2021 

PM2.5 (tpy) 281.790 256.600 204.32 145.39 

NOx (tpy) 7,295.87 6,516.40 3,993.63 2,449.31 

SO2 (tpy) 20.51 23.32 23.34 25.66 

Annual VMT 1,684,261,582 1,765,146,867 1,899,319,930 2,005,373,961 

 

 
 21 

Table 4 – Hamilton County, Ohio Emissions Estimations for On-Road 

Mobile Sources 

 2005 2008 2015 2021 

PM2.5 (tpy) 1,222.020 1,080.540 826.00 571.48 

NOx (tpy) 31,127.09 27,020.93 15,925.19 9,530.16 

SO2 (tpy) 88.85 98.30 94.43 100.82 

Annual VMT 7,241,536,812 7,421,012,594 7,630,239,650 7,811,745,310 

Table 5 – Warren County, Ohio Emissions Estimations for On-Road 

Mobile Sources 

 2005 2008 2015 2021 

PM2.5 (tpy) 320.740 289.560 242.05 177.61 

NOx (tpy) 8,224.57 7,267.18 4,598.44 2,875.72 

SO2 (tpy) 23.54 26.57 27.77 31.58 

Annual VMT 1,949,619,088 2,031,755,542 2,285,057,933 2,498,434,852 

Table 6 – Dearborn County, Ohio Emissions Estimations for On-Road 

Mobile Sources 

 2005 2008 2015 2021 

PM2.5 (tpy) 33.980 29.890 25.14 18.11 

NOx (tpy) 865.46 748.81 482.33 297.95 

SO2 (tpy) 2.45 2.69 2.87 3.19 

Annual VMT 196,738,031 199,778,078 223,644,622 240,321,759 

Table 7 – Summary of Ohio and Indiana Emissions Estimations for 

On-Road Mobile Sources 

 2005 2008 2015 2021 

PM2.5 (tpy) 2,272.50 2,034.23 1,598.67 1,128.35 

NOx (tpy) 58,423.36 51,357.02 31,064.20 18,911.05 

SO2 (tpy) 165.36 185.13 182.69 199.15 

Annual VMT 13,541,324,003 14,015,754,874 14,830,453,053 15,521,916,278 

Table 8 – Boone County, Kentucky Emissions Estimations for OnRoad Mobile Sources 

 2005 2008 2015 2021 

PM2.5 (tpy) 205.210 251.850 151.35 114.05 

NOx (tpy) 5,126.88 5,067.94 2,788.45 1,772.72 

SO2 (tpy) 15.91 16.71 20.67 24.37 

Annual VMT 1,273,226,967 1,350,001,539 1,628,041,282 1,800,571,684 

Table 9 – Campbell County, Kentucky Emissions Estimations for OnRoad Mobile Sources 

 2005 2008 2015 2021 

PM2.5 (tpy) 120.300 146.460 82.36 60.09 

NOx (tpy) 3,041.21 2,988.33 1,570.14 985.28 

SO2 (tpy) 9.30 9.69 11.21 12.77 

Annual VMT 741,790,595 774,762,718 875,774,487 936,445,352 
 22 

Table 10 – Kenton County, Kentucky Emissions Estimations for OnRoad Mobile Sources 

 2005 2008 2015 2021 

PM2.5 (tpy) 212.290 29.890 137.40 101.24 

NOx (tpy) 5,328.44 5,057.93 2,637.63 1,677.96 

SO2 (tpy) 16.24 16.34 18.62 21.48 

Annual VMT 1,274,091,641 1,300,575,248 1,427,569,972 1,549,817,325 

Table 11 – Summary of Kentucky Emissions Estimations for On-Road 

Mobile Sources 

 2005 2008 2015 2021 

PM2.5 (tpy) 537.8 645.62 371.11 275.38

NOx (tpy) 13,496.53 13,114.20 6,996.22 6,421.15

SO2 (tpy) 41.45 42.74 50.50 72.15

Annual VMT 3,289,109,203.00 3,425,339,505.00 3,931,385,741.00 5,452,303,073.00

Table 12 – Emissions Estimations Totals for On-Road Mobile Sources 

for the Cincinnati-Hamilton Area 

 2005 2008 2015 2021 

PM2.5 (tpy) 2,810.30 2,679.85 1,969.78 1,403.73

NOx (tpy) 71,919.89 64,471.22 38,060.42 25,332.20

SO2 (tpy) 206.81 227.87 233.19 271.30

Annual VMT 16,830,433,206.00 17,441,094,379.00 18,761,838,794.00 20,974,219,351.00

Motor Vehicle Emission Budget

Table 13 and Table 14 contain the motor vehicle emissions budgets 

for the Cincinnati-Hamilton area. For planning purposes, budgets are 

established for the combined Ohio and Indiana portions and for the 

separate Kentucky portion. 

Table 13 - Mobile Vehicle Emissions Budget for Ohio and Indiana 

 2015 Estimated 

Emissions 

2015 Mobile 

Safety Margin 

Allocation* 

2015 Total 

Mobile 

Budget 

2021 Estimated 

Emissions 

2021 Mobile 

Safety Margin 

Allocation* 

2021 Total 

Mobile 

Budget 

PM2.5 (tpy) 1598.67 79.93 1678.60 1128.35 112.84 1241.19

NOx (tpy) 31,064.20 4659.63 35,723.83 18,911.05 2836.65 21,747.71

Annual VMT 14,830,453,053 - - 15,521,916,278 - - 

*The 5 to15 percent margin of safety was calculated by taking 5 to15 percent of the mobile source emission estimates 

Table 14 - Mobile Vehicle Emissions Budget for Kentucky 

 2015 

Estimated 

Emissions 

2015 Mobile 

Safety Margin 

Allocation* 

2015 Total 

Mobile 

Budget 

2021 

Estimated 

Emissions 

2021 Mobile 

Safety Margin 

Allocation* 

2021 Total 

Mobile 

Budget 

PM2.5 (tpy) 371.11 18.56 389.67 275.38 27.54 302.92 

NOx (tpy) 6,996.22 1049.43 8,045.65 6,421.15 963.17 7,384.32

Annual VMT 3,931,385,741 5,452,303,073 

*The 5 to15 percent margin of safety was calculated by taking 5 to15 percent of the mobile source emission estimates 
 23 

The above budgets for the Ohio and Indiana portion and for the 

Kentucky portion of the area, agreed upon as part of the interagency 

consultation process, include the emission estimates calculated for 

2015 and 2021 (from Table 7 and Table 11) with an additional 5 

percent margin of safety allocated for PM2.5 in 2015, 10 percent 

margin of safety allocated to PM2.5 in 2021 and 15 percent margin of 

safety allocated to NOx in 2015 and 2021. 

In an effort to accommodate future variations in travel demand 

models and VMT forecast when no change to the network is 

planned, Ohio EPA consulted with U.S. EPA to determine a 

reasonable approach to address this variation. Based on this 

discussion, a 5 to15 percent margin of safety allocation was agreed 

upon and has been added to the emissions estimates for the Ohio 

and Indiana portions of this nonattainment area. 

All methodologies, the latest planning assumptions, and the safety 

margins allocations were determined through the interagency 

consultation process described in the Transportation Conformity 

Memorandum of Understanding (MOU) among OKI, Ohio DOT, and 

Ohio EPA. 

A 5 to15 percent margin of safety is appropriate because: 1) there is 

an acknowledged potential variation in VMT forecast and potential 

estimated mobile source emissions due to expected modifications to 

TDM and mobile emissions models; and 2) the total decrease in 

emissions from all sources is sufficient to accommodate this 5 to15 

percent allocation of safety margin (as defined in 40 CFR93.1019

) to 

mobile sources while still continuing to maintain the total emissions 

in the Cincinnati-Hamilton area well below the 2008 attainment level 

of emissions. 

 

The 5 to 15 percent margin of safety was calculated by taking 5 to 

15 percent of the mobile source emission estimates. Safety margin, 

as defined by the conformity rule, looks at the total emissions from 

all sources in the nonattainment area. The actual allocation is less 

than 5 to 15 percent of the total emission reduction from all sources 

as can be seen from Table 44. 

In summary, for all three states combined, the mobile budget safety 

margin allocation translates into an additional 98.49 tpy for PM2.5

and 5,709.06 tpy for NOx for 2015 and an additional 140.38 tpy for 

PM2.5 and 3,799.82 tpy for NOx for 2021. 

 

9 "Safety margin" means the amount by which the total projected emissions from all sources of a given 

pollutant are less than the total emissions that would satisfy the applicable requirement for reasonable 

further progress, attainment, or maintenance.
 24 

When compared to the overall safety margin, as defined in 40 CFR 

93.101, discussed under “Requirement 3 of 5” below, it is evident 

this allocation is significantly below the total safety margin for this 

area. 

The current PM2.5 and NOx mobile budgets for the fine particle 

NAAQS will no longer be applicable either after the effective date of 

the approved redesignation or after the effective date of any U.S. 

EPA action approving a finding that the PM2.5 and NOx conformity 

budgets included in this submittal are adequate for transportation 

conformity purposes, whichever date comes first. 

Finally, it is important to underline that all motor vehicle emission 

budgets in this Redesignation submittal, which are based on 

MOVES2010, will replace previous motor vehicle emission budgets 

on Attainment Demonstration submittals based on MOBILE6.2. 

Requirement 3 of 5 

A demonstration that the projected level of emissions is sufficient to maintain the 

PM2.5 standard. 

Background

In consultation with U.S. EPA, Ohio EPA selected the year 2021 as 

the maintenance year for this redesignation request. This document 

contains projected emissions inventories for 2015 and 2021. 

Emission projections for the Cincinnati-Hamilton area were 

performed using the following approaches: 

• As performed by OKI, mobile source emission projections are 

based on the U.S. EPA MOVES model. The analysis is 

described in more detail in Appendix C. All projections were 

made in accordance with “Procedures for Preparing Emissions 

Projections” U.S. EPA-45/4-91-019. 

• Emissions inventories are required to be projected to future 

dates to assess the influence growth and future controls will 

have. LADCO has developed growth and control files for point, 

area, and non-road categories. These files were used to develop 

the future-year emissions estimates used in this document. This 

was done so the inventories used for redesignation are 

consistent with modeling performed in the future. Appendix D 
 25 

contains LADCO’s technical support document detailing the 

analysis used to project emissions (Base M10). 

• For the Ohio portion of the Cincinnati-Hamilton area, for the 2008 

attainment year, emissions were grown from the 2005 LADCO 

modeling inventory, using LADCO’s growth factors, for all 

sectors except point sources (electrical generating units and 

non-electrical generating units). Point source emissions for 2008 

were compiled from Ohio EPA’s 2008 annual emissions 

inventory database. The 2015 interim year emissions were 

estimated based on the 2009 and 2018 LADCO modeling 

inventory, using LADCO’s growth factors, for all sectors. The 

2021 maintenance year is based on emissions estimates from 

the 2018 LADCO modeling. 

The detailed inventory information for the Ohio portion of the 

Cincinnati-Hamilton area for 2005 is in Appendix B. Emission trends 

are an important gauge for continued compliance with the PM2.5

standard. Therefore, Ohio EPA performed an initial comparison of 

the inventories for the base year and maintenance years. Mobile 

source emission inventories are described in Section 5 of Appendix 

B. 

Sectors included in the following tables are: Electrical Generating 

Unit (EGU-Point); Non-Electrical Generating Unit (Non-EGU); Nonroad Mobile (Non-road); Other Area (Other); Marine; Aircraft; Rail 

(MAR); and On-road Mobile (On-road). 

Ohio EPA is identifying emissions projections for 2015 and 2021 for 

EGUs with implementation of the CAIR program. U.S. EPA has 

raised concerns regarding the CAIR program and its remand. 

However, as discussed below, with the proposed CAIR replacement, 

the Transport Rule, Ohio EPA believes these are the most 

appropriate and accurate future projections. 

On March 10, 2004, the U.S. EPA promulgated the CAIR. 

Beginning in 2009, U.S. EPA’s CAIR rule requires EGUs in 28 

eastern states and the District of Columbia to significantly reduce 

emissions of NOx and SO2. CAIR replaced the NOx SIP Call for 

EGUs. The intent of the CAIR program is for national NOx emissions 

to be cut from 4.5 million tons in 2004, to a cap of 1.5 million tons by 

2009, and 1.3 million tons in 2018 in 28 states. States were required 

to submit a CAIR SIP as part of this effort. Ohio submitted a CAIR 

SIP which was approved by U.S. EPA on February 1, 2007. 

 

10 http://www.ladco.org/tech/emis/current/index.php 
 26 

Revisions to the CAIR SIP were again submitted on July 15, 2009. 

The revised CAIR SIP was approved as a direct final action on 

September 25, 2009 (74 FR 48857). As a result of CAIR, U.S. EPA 

projects that in 2009 emissions of NOx will decrease from a baseline 

of 264,000 tons per year to 93,000 tons per year while in 2010 

emissions of SO2 will decrease from a baseline of 1,373,000 tons 

per year to 298,000 tons per year, within Ohio. And by 2015 U.S. 

EPA projects emissions of NOx will decrease to 83,000 tons per year 

while emissions of SO2 will decrease to 208,000 tons per year, 

within Ohio11. 

On December 23, 2008, U.S. EPA’s CAIR program was remanded 

without vacatur by the D.C. Circuit Court. As mentioned above, Ohio 

EPA has not incorporated these expected CAIR reductions into this 

redesignation request. It should also be noted that Ohio’s SIPapproved NOx SIP Call program and regulations are still in place. 

Ohio EPA is currently in the process of revising these regulations to 

provide a “back stop” for the reinstatement of the NOx SIP Call 

program in the event the CAIR program, or an equivalent, is no 

longer implemented by U.S. EPA. 

As can be seen in Table 15 below, Ohio has seen a significant 

decline in the 264,000 tons of NOx and 1,373,000 tons of SO2

emitted in 2005. In 2008 and 2009 facilities began preparing for and 

implementing control programs to address CAIR12 and consent 

decrees. 

Table 15 - Reductions in SO2 and NOx EGU Emissions Between 

2008 and 2009 

SO2 NOx

 2008 2009 Change 2008 2009 Change 

Ohio 709,444 601,101 15% 235,018 96,351 59% 

LADCO States 2,019,036 1,620,071 20% 702,384 393,930 44% 

National 7,616,262 5,747,353 25% 2,996,287 1,990,385 34% 

Source: Clean Air Markets Quarterly Emissions Tracking13

Significant reductions also occurred regionally and nationally as can 

be seen from the above. Data is also available for the first two 

quarters of 2010, the year SO2 reductions are to be implemented 

under CAIR: 

 

11 http://www.epa.gov/CAIR/oh.html 

12 Under CAIR, NOx reductions are to occur beginning in 2009 while SO2 reductions are to occur 

beginning in 2010.

13 http://www.epa.gov/airmarkets/quarterlytracking.html
 27 

Table 16 – Reductions in SO2 and NOx EGU Emissions 

Between the First Half of 2008 and 2010 

SO2 NOx

 2008 

(1st half) 

2010 

(1st half) Change 2008 

(1st half) 

2010 

(1st half) Change 

Ohio 373,798 279,854 25% 130,598 53,187 59% 

LADCO States 1,190,497 854,282 28% 419,114 220,907 47% 

National 3,895,472 2,502,965 36% 1,487,179 930,148 37% 

Source: Clean Air Markets Quarterly Emissions Tracking14

The following was reported by U.S. EPA’s Clean Markets Division: 

“Based on emissions monitoring data, EPA has observed substantial 

reductions in SO2 emissions from 2005 to 2009 and in the first two 

quarters of 2010 as companies installed more controls, electric 

demand declined, and low natural gas prices made combined-cycle 

gas-fired units more competitive in several parts of the country. 

Thus, even after CAIR's vacatur and subsequent remand in late 

2008, the controls in place generally have continued to operate, 

helping to drive continued progress in reducing emissions.15” 

On July 6, 2010, U.S. EPA proposed a replacement to the CAIR 

program, the Transport Rule. [75 FR 45210] U.S. EPA intends to 

finalize the Transport Rule in time for reductions to begin in 2012. 

As proposed, the Transport Rule will preserve those initial 

reductions achieved under CAIR and provide more reductions in 

NOx and SO2 emissions in 2012 and 2014, ahead of the 2015 CAIR 

Phase 2. 

Ohio EPA is in agreement with the analysis by U.S.EPA that the 

CAIR program is providing real reductions at this time, Ohio believes 

these reductions have assisted with PM2.5 attainment in this 

nonattainment area and throughout Ohio. It is also Ohio EPA’s 

belief that the Transport Rule, when finalized, will continue to 

provide the necessary reductions, and likely even greater 

reductions, that will be necessary for maintenance of the annual 

PM2.5 standard to occur. As stated by U.S. EPA regarding the 

proposed Transport Rule, “the results of the air quality modeling 

indicate that all but one site16 is projected to be in attainment and 

only one site17 is projected to have a maintenance problem for 

annual PM2.5 in 2014 with the emissions reductions expected from 

this proposal.” [75 FR 45345] Therefore, it is Ohio EPA’s belief it is 

most appropriate to evaluate Ohio EPA’s demonstration that the 

 

14 http://www.epa.gov/airmarkets/quarterlytracking.html

15 http://www.epa.gov/airmarkets/background.htm

16 Allegheny, PA

17 Birmingham, AL
 28 

projected level of emissions is sufficient to maintain the annual PM2.5

standard by assessing future year emissions that include the CAIR 

program. 

Maintenance is demonstrated when the future-year (2021) projected 

emission totals are below the 2008 attainment year totals. 

The Ohio emissions data in the tables below are based on the 

following data sources: 

- All On-Road data source: OKI Transportation Modeling 

Department. 

- 2008 EGU and non-EGU: Ohio EPA’s 2008 annual emissions 

inventory database. 

- All other data source: Lake Michigan Air Directors Consortium 

(LADCO). 

Demonstration

PM2.5

The 2005 and 2008 actual PM2.5 emissions data below generally contains 

particulate fraction emissions only and not the condensable fractions as 

Ohio EPA did not have a consistent reporting requirement at those years. 

U.S. EPA Integrated Planning Model (IPM) modeling was used to generate 

future year EGU emissions with the CAIR program. The IPM modeling 

added additional PM2.5 condensable emissions into future years. Therefore, 

comparing base and attainment year emissions with the future year 

predictions is not accurate in the IPM CAIR modeling. This step leads to a 

false perception of significant PM2.5 emissions growth. Modeling performed 

by LADCO, without CAIR, did not incorporate added condensable fraction 

emissions. Although Ohio EPA has stated that it is most appropriate to 

evaluate future year emissions that include the CAIR program, because of 

this flaw it will be more accurate and appropriate for the purposes of PM2.5 

to evaluate future year emissions without the CAIR program. 

Table 17 - Butler County18, Ohio PM2.5 Emission Inventory Totals for 

Base Year 2005, Estimated 2008, and Projected 2015 and 

2021 (tpy) – Without CAIR

 

18 Ohio EPA has revised the Butler County, Ohio PM2.5, NOx and SO2 Emissions Inventory (non-EGU) to 

incorporate the total emissions reduction credits available and used to offset the allowed emissions of a 
 29 

Sector 2005 

Base 

2008 

Attainment 

2015 

Interim 

2021 

Maintenance 

Safety 

Margin 

EGU Point 15.27 16.78 15.86 15.59 1.19 

Non-EGU 944.29 1045.15 1254.70 1337.03 -291.88 

Non-road 185.28 158.41 109.75 66.98 91.43 

Other 173.24 180.43 180.86 182.45 -2.02 

MAR 31.19 27.40 16.01 6.43 20.97 

On-road 413.97 377.64 301.16 215.76 161.88 

TOTAL 1763.24 1805.81 1878.34 1824.24 -18.43 

Table 18 - Clermont County, Ohio PM2.5 Emission Inventory Totals for 

Base Year 2005, Estimated 2008, and Projected 2015 and 

2021 (tpy) – Without CAIR 

Sector 2005 

Base 

2008 

Attainment 

2015 

Interim 

2021 

Maintenance 

Safety 

Margin 

EGU Point 648.21 532.61 651.88 711.22 -178.61 

Non-EGU 7.93 3.86 6.42 7.33 -3.47 

Non-road 104.54 89.84 62.51 38.56 51.28 

Other 193.70 196.15 193.49 191.83 4.32 

MAR 6.11 5.64 3.54 1.81 3.83 

On-road 281.79 256.60 204.32 145.39 111.21 

TOTAL 1242.28 1084.70 1122.16 1096.14 -11.44 

 

Table 19 - Hamilton County, Ohio PM2.5 Emission Inventory Totals for 

Base Year 2005, Estimated 2008, and Projected 2015 and 

2021 (tpy) – Without CAIR

Sector 2005 

Base 

2008 

Attainment 

2015 

Interim 

2021 

Maintenance 

Safety 

Margin 

EGU Point 648.64 202.88 554.65 708.74 -505.86 

Non-EGU 161.88 158.14 171.28 179.45 -21.31 

Non-road 355.97 307.30 218.86 141.16 166.14 

Other 303.61 323.94 330.03 338.37 -14.43 

MAR 42.04 37.82 23.54 11.64 26.18 

On-road 1222.02 1080.54 826.00 571.48 509.06 

TOTAL 2734.16 2110.62 2124.36 1950.84 159.78 

 

 

Table 20 - Warren County, Ohio PM2.5 Emission Inventory Totals for 

Base Year 2005, Estimated 2008, and Projected 2015 and 

2021 (tpy) – Without CAIR 

 major source modified within the maintenance area that will begin operating during the maintenance period. 

The total emissions included in the inventory, and in all the Butler County tables below for this facility in 

2015 and 2021, are 117.81 tpy PM2.5, 479.57 tpy NOx and 1209.92 tpy SO2. The emissions increase does 

not significantly impact the safety margin for this area or prevent the area from maintaining the standard in 

future years. 
 30 

Sector 2005 

Base 

2008 

Attainment 

2015 

Interim 

2021 

Maintenance 

Safety 

Margin 

EGU Point 0.00 0.00 0.00 0.00 0.00 

Non-EGU 18.75 19.91 19.01 18.60 1.31 

Non-road 143.72 122.20 79.69 42.68 79.52 

Other 236.92 238.33 233.88 230.65 7.68 

MAR 2.95 2.58 1.53 0.64 1.94 

On-road 320.74 289.56 242.05 177.61 111.95 

TOTAL 723.08 672.58 576.16 470.18 202.40 

Table 21 - Dearborn County, Indiana PM2.5 Emission Inventory Totals 

for Base Year 2005, Estimated 2008, and Projected 2015 

and 2021 (tpy) – Without CAIR 

Sector 2005 

Base 

2008 

Attainment 

2015 

Interim

2021 

Maintenance 

Safety 

Margin 

EGU Point 673.94 804.18 847.16 922.81 -118.63 

Non-EGU 67.38 62.02 60.00 57.32 4.70 

Non-road 23.96 19.91 13.34 9.07 10.84 

Other 4.29 4.29 4.11 3.98 0.31 

MAR 

On-road 33.98 29.89 25.14 18.11 11.78 

TOTAL 803.55 920.29 949.75 1011.29 -91.00 

*MAR emissions are included in Non-road emissions 

Table 22 - Boone County, Kentucky PM2.5 Emission Inventory Totals 

for Base Year 2005, Estimated 2008, and Projected 2015 

and 2021 (tpy) – Without CAIR 

Sector 2005 

Base 

2008 

Attainment 19

2015 

Interim

2021 

Maintenance

Safety 

Margin 

EGU Point 76.85 76.70 80.70 83.42 -6.72 

Non-EGU 58.77 68.81 84.35 98.94 -30.13 

Non-road 89.15 82.90 62.42 45.30 37.60 

Other 351.27 353.71 359.57 364.58 -10.87 

MAR 215.61 227.62 206.01 191.23 36.39 

On-road 205.21 251.85 151.35 114.05 137.80 

TOTAL 996.86 1061.59 944.40 897.52 164.07 

Table 23 - Campbell County, Kentucky PM2.5 Emission Inventory Total 

for Base Year 2005, Estimated 2008, and Projected 2015 

and 2021 (tpy) – Without CAIR 

Sector 2005 

Base 

2008 

Attainment 

2015 

Interim

2021 

Maintenance

Safety 

Margin 

 

19 Kentucky 2008 data is grown from the 2005 LADCO modeling inventory, using LADCO’s growth 

factors, for all sectors, including EGUs.
 31 

EGU Point 0.00 0.00 0.00 0.00 0.00 

Non-EGU 84.26 89.52 101.84 112.39 -22.87 

Non-road 25.29 22.35 16.18 10.84 11.51 

Other 200.08 201.26 200.05 199.32 1.94 

MAR 55.66 53.74 41.25 31.15 22.59 

On-road 120.30 146.46 82.36 60.09 86.37 

TOTAL 485.59 513.33 441.68 413.79 99.54 

Table 24 - Kenton County, Kentucky PM2.5 Emission Inventory Totals 

for Base Year 2005, Estimated 2008, and Projected 2015 

and 2021 (tpy) – Without CAIR 

Sector 2005 

Base 

2008 

Attainment 

2015 

Interim

2021 

Maintenance

Safety 

Margin 

EGU Point 0.00 0.00 0.00 0.00 0.00 

Non-EGU 9.53 11.11 13.50 15.76 -4.65 

Non-road 56.44 50.98 38.18 27.22 23.76 

Other 365.74 366.69 363.77 361.65 5.04 

MAR 62.64 59.63 44.85 32.76 26.87 

On-road 212.29 247.31 137.40 101.24 146.07 

TOTAL 706.64 735.72 597.70 538.63 197.09 

Table 25 – Cincinnati-Hamilton Area PM2.5 Emission Inventory Totals 

for Base Year 2005, Estimated 2008, and projected 2015 

and 2021 (tpy) – Without CAIR 

PM2.5

2005 

Base 

2008 

Attainment 

2015 

Interim 

2021 

Maintenance 

Safety 

Margin 

Butler 1763.24 1805.81 1878.34 1824.24 -18.43 

Clermont 1242.28 1084.70 1122.16 1096.14 -11.44 

Hamilton 2734.16 2110.62 2124.36 1950.84 159.78 

Warren 723.08 672.58 576.16 470.18 202.40 

Dearborn 803.55 920.29 949.75 1011.29 -91.00 

Boone 996.86 1061.59 944.40 897.52 164.07 

Campbell 485.59 513.33 441.68 413.79 99.54 

Kenton 706.64 735.72 597.70 538.63 197.09 

COMBINED 

PM2.5 TOTAL 9455.40 8904.64 8634.55 8202.63 702.01 

 

NOx
 32 

Table 26 - Butler County, Ohio NOx Emission Inventory Totals for 

Base Year 2005, Estimated 2008, and Projected 2015 and 

2021 (tpy) – With CAIR 

Sector 2005 

Base 

2008 

Attainment

2015 

Interim 

2021 

Maintenanc

e 

Safety 

Margin 

EGU Point 743.27 856.92 343.95 124.10 732.82 

Non-EGU 4367.15 3940.28 4626.45 4686.11 -745.83 

Non-road 2348.42 1986.81 1228.83 572.69 1414.12 

Other 796.34 807.64 811.94 817.28 -9.64 

MAR 919.91 847.08 545.76 297.37 549.71 

On-road 10910.37 9803.70 6064.61 3757.91 6045.79 

TOTAL 20085.46 18242.43 13621.54 10255.46 7986.97 

Table 27 - Clermont County, Ohio NOx Emission Inventory Totals for 

Base Year 2005, Estimated 2008, and Projected 2015 and 

2021 (tpy) – With CAIR 

Sector 2005 

Base 

2008 

Attainment

2015 

Interim 

2021 

Maintenanc

e 

Safety 

Margin 

EGU Point 28063.56 24233.18 16491.26 10451.28 13781.90 

Non-EGU 67.50 42.71 60.83 68.68 -25.97 

Non-road 1218.23 1039.67 655.01 322.89 716.78 

Other 612.97 619.27 620.94 623.36 -4.09 

MAR 259.07 245.25 159.04 89.20 156.05 

On-road 7295.87 6516.40 3993.63 2449.31 4067.09 

TOTAL 37517.20 32696.48 21980.71 14004.72 18691.76 

 

Table 28 - Hamilton County, Ohio NOx Emission Inventory Totals for 

Base Year 2005, Estimated 2008, and Projected 2015 and 

2021 (tpy) – With CAIR 

Sector 2005 

Base 

2008 

Attainment

2015 

Interim 

2021 

Maintenanc

e 

Safety 

Margin 

EGU Point 15236.04 12372.00 7236.90 5036.15 7335.85 

Non-EGU 2756.21 2652.79 2943.73 3139.37 -486.58 

Non-road 4845.98 4029.63 2464.90 1098.14 2931.49 

Other 1923.27 1955.47 1974.77 1995.51 -40.04 

MAR 1463.80 1372.41 909.89 532.19 840.22 

On-road 31127.09 27020.93 15925.19 9530.16 17490.77 

TOTAL 57352.39 49403.23 31455.38 21331.52 28071.71 

 
 33 

Table 29 - Warren County, Ohio NOx Emission Inventory Totals for 

Base Year 2005, Estimated 2008, and Projected 2015 and 

2021 (tpy) – With CAIR 

Sector 2005 

Base 

2008 

Attainment 

2015 

Interim 

2021 

Maintenance 

Safety 

Margin 

EGU Point 0.00 0.00 0.00 0.00 0.00 

Non-EGU 1024.95 1043.27 1035.29 1034.26 9.01 

Non-road 1789.97 1517.53 919.21 403.56 1113.97 

Other 426.57 432.28 434.26 436.82 -4.54 

MAR 96.07 89.92 60.22 35.92 54.00 

On-road 8224.57 7267.18 4598.44 2875.72 4391.46 

TOTAL 11562.13 10350.18 7047.42 4786.28 5563.90 

Table 30 - Dearborn County, Indiana NOx Emission Inventory Totals 

for Base Year 2005, Estimated 2008, and Projected 2015 

and 2021 (tpy) – With CAIR 

Sector 2005 

Base 

2008 

Attainment 

2015 

Interim 

2021 

Maintenance 

Safety 

Margin 

EGU Point 7961.30 7429.20 9862.76 11229.31 -3800.11 

Non-EGU 2024.68 1979.83 1965.19 1943.22 36.61 

Non-road 382.53 318.09 219.83 154.18 163.91 

Other 141.37 145.42 143.39 142.90 2.52 

MAR* 

On-road 865.46 748.81 482.33 297.95 450.86 

TOTAL 11375.34 10621.35 12673.50 13767.56 -3146.21 

*MAR emissions are included in Non-road emissions

Table 31 - Boone County, Kentucky NOx Emission Inventory Totals for 

Base Year 2005, Estimated 2008, and Projected 2015 and 

2021 (tpy) – With CAIR 

Sector 2005 

Base 

2008 

Attainment

2015 

Interim 

2021 

Maintenance

Safety 

Margin 

EGU Point 3926.27 1962.59 1504.39 1308.03 654.56 

Non-EGU 58.03 61.66 66.48 71.21 -9.55 

Non-road 931.11 845.72 582.34 361.41 484.31 

Other 1844.50 1897.28 1985.25 2063.30 -166.02 

MAR 2927.85 2926.70 2310.38 1828.25 1098.45 

On-road 5126.88 5067.94 2788.45 1772.72 3295.22 

TOTAL 14814.64 12761.89 9237.29 7404.92 5356.97 

Table 32 – Campbell County, Kentucky NOx Emission Inventory Total 

for Base Year 2005, Estimated 2008, and Projected 2015 
 34 

and 2021 (tpy) – With CAIR 

Sector 2005 

Base 

2008 

Attainment 

2015 

Interim 

2021 

Maintenance

Safety 

Margin 

EGU Point 0.00 0.00 0.00 0.00 0.00 

Non-EGU 53.68 49.52 53.81 55.21 -5.69 

Non-road 284.66 261.59 189.27 128.67 132.92 

Other 523.45 536.71 563.83 587.37 -50.66 

MAR 1617.89 1571.87 1156.10 822.91 748.96 

On-road 3041.21 2988.33 1570.14 985.28 2003.05 

TOTAL 5520.89 5408.02 3533.15 2579.44 2828.58 

Table 33 – Kenton County, Kentucky NOx Emission Inventory Totals 

for Base Year 2005, Estimated 2008, and Projected 2015 

and 2021 (tpy) – With CAIR 

Sector 2005 

Base 

2008 

Attainment 

2015 

Interim 

2021 

Maintenance

Safety 

Margin 

EGU Point 0.00 0.00 0.00 0.00 0.00 

Non-EGU 19.50 20.44 21.79 23.09 -2.65 

Non-road 616.67 562.88 395.18 254.61 308.27 

Other 1542.27 1581.60 1654.75 1718.86 -137.26 

MAR 2068.01 1999.72 1453.68 1014.71 985.01 

On-road 5328.44 5057.93 2637.63 1677.96 3379.97 

TOTAL 9574.89 9222.57 6163.03 4689.23 4533.34 

Table 34 - Cincinnati-Hamilton Area NOx Emission Inventory Totals 

for Base Year 2005, Estimated 2008, and Projected 2015 

and 2021 (tpy) – With CAIR 

NOx 2005 

Base 

2008 

Attainment 

2015 

Interim 

2021 

Maintenance 

Safety 

Margin 

Butler 20085.46 18242.43 13621.54 10255.46 7986.97 

Clermont 37517.20 32696.48 21980.71 14004.72 18691.76 

Hamilton 57352.39 49403.23 31455.38 21331.52 28071.71 

Warren 11562.13 10350.18 7047.42 4786.28 5563.90 

Dearborn 11375.34 10621.35 12673.50 13767.56 -3146.21 

Boone 14814.64 12761.89 9237.29 7404.92 5356.97 

Campbell 5520.89 5408.02 3533.15 2579.44 2828.58 

Kenton 9574.89 9222.57 6163.03 4689.23 4533.34 

COMBINED 

NOx TOTAL 167802.94 148706.15 105712.02 78819.13 69887.02 

SO2
 35 

Table 35 - Butler County, Ohio SO2 Emission Inventory Totals for 

Base Year 2005, Estimated 2008, and Projected 2015 and 

2021 (tpy) – With CAIR

Sector 2005 

Base 

2008 

Attainment 

2015 

Interim 

2021 

Maintenanc

e 

Safety 

Margin 

EGU Point 1959.10 2181.63 654.49 0.00 2181.63 

Non-EGU 6185.26 5442.54 6847.48 6828.13 -1385.59 

Non-road 260.36 95.29 15.09 0.80 94.49 

Other 224.54 221.09 209.01 198.96 22.13 

MAR 80.84 79.05 62.61 49.44 29.61 

On-road 30.01 34.25 34.28 37.90 -3.65 

TOTAL 8740.11 8053.85 7822.96 7115.23 938.62 

Table 36 - Clermont County, Ohio SO2 Emission Inventory Totals for 

Base Year 2005, Estimated 2008, and Projected 2015 and 

2021 (tpy) – With CAIR 

Sector 2005 

Base 

2008 

Attainment

2015 

Interim 

2021 

Maintenanc

e 

Safety 

Margin 

EGU Point 88876.65 42918.28 32590.92 20589.16 22329.12 

Non-EGU 162.19 118.05 148.28 160.98 -42.93 

Non-road 138.93 50.86 8.05 0.43 50.43 

Other 164.72 162.20 151.29 142.32 19.88 

MAR 22.73 15.39 5.26 0.78 14.61 

On-road 20.51 23.32 23.34 25.66 -2.34 

TOTAL 89385.73 43288.10 32927.14 20919.33 22368.77 

Table 37 - Hamilton County, Ohio SO2 Emission Inventory Totals for 

Base Year 2005, Estimated 2008, and Projected 2015 and 

2021 (tpy) – With CAIR 

Sector 2005 

Base 

2008 

Attainment

2015 

Interim 

2021 

Maintenanc

e 

Safety 

Margin 

EGU Point 77381.13 24693.00 16390.65 7508.46 17184.54 

Non-EGU 7819.40 6552.65 7739.34 8309.88 -1757.23 

Non-road 474.85 174.16 28.47 1.93 172.23 

Other 163.45 161.80 151.81 143.71 18.09 

MAR 117.60 100.46 64.96 34.20 66.26 

On-road 88.85 98.30 94.43 100.82 -2.52 

TOTAL 86045.28 31780.37 24469.66 16099.00 15681.37 

 

 
 36 

Table 38 - Warren County, Ohio SO2 Emission Inventory Totals for 

Base Year 2005, Estimated 2008, and Projected 2015 and 

2021 (tpy) – With CAIR 

Sector 2005 

Base 

2008 

Attainment 

2015 

Interim 

2021 

Maintenance 

Safety 

Margin 

EGU Point 0.00 0.00 0.00 0.00 0.00 

Non-EGU 3.39 3.53 3.45 3.42 0.11 

Non-road 23.54 26.57 27.77 31.58 -5.01 

Other 140.25 138.31 131.36 125.59 12.72 

MAR 8.13 7.99 6.34 5.03 2.96 

On-road 208.73 76.29 11.87 1.73 74.56 

TOTAL 384.4 252.69 180.79 167.35 85.34 

Table 39 - Dearborn County, Indiana SO2 Emission Inventory Totals 

for Base Year 2005, Estimated 2008, and Projected 2015 

and 2021 (tpy) – With CAIR 

Sector 2005 

Base 

2008 

Attainment

2015 

Interim 

2021 

Maintenanc

e 

Safety 

Margin 

EGU Point 46533.70 25729.10 39295.70 36843.66 -11114.56 

Non-EGU 1331.15 1334.33 1335.94 1337.95 -3.62 

Non-road 40.16 17.38 4.73 1.14 16.24 

Other 78.72 81.02 77.64 75.69 5.33 

MAR* 

On-road 2.45 2.69 2.87 3.19 -0.50 

TOTAL 47986.18 27164.52 40716.88 38261.63 -111097.11 

*MAR emissions are included in Non-road emissions

 

Table 40 - Boone County, Kentucky SO2 Emission Inventory Totals for 

Base Year 2005, Estimated 2008, and Projected 2015 and 

2021 (tpy) – With CAIR 

Sector 2005 

Base 

2008 

Attainment 

2015 

Interim 

2021 

Maintenance

Safety 

Margin 

EGU Point 3644.98 2812.16 2617.84 2534.56 277.60 

Non-EGU 16.82 17.97 19.50 21.01 -3.04 

Non-road 59.56 26.45 5.98 0.51 25.94 

Other 1054.33 1066.79 1093.47 1116.53 -49.74 

MAR 434.71 409.48 322.39 249.85 159.63 

On-road 15.91 16.71 20.67 24.37 -7.66 

TOTAL 5226.31 4349.56 4079.85 3946.83 402.73 
 37 

Table 41 - Campbell County, Kentucky SO2 Emission Inventory Total 

for Base Year 2005, Estimated 2008, and Projected 2015 

and 2021 (tpy) – With CAIR 

Sector 2005 

Base 

2008 

Attainment 

2015 

Interim

2021 

Maintenance

Safety 

Margin 

EGU Point 0.00 0.00 0.00 0.00 0.00 

Non-EGU 0.97 0.96 1.04 1.09 -0.13 

Non-road 18.01 7.89 1.78 0.17 7.72 

Other 471.77 479.14 491.66 502.75 -23.61 

MAR 221.98 198.32 147.50 103.61 94.71 

On-road 9.30 9.69 11.21 12.77 -3.08 

TOTAL 722.03 696.00 653.19 620.39 75.61 

Table 42 - Kenton County, Kentucky SO2 Emission Inventory Totals 

for Base Year 2005, Estimated 2008, and Projected 2015 

and 2021 (tpy) – With CAIR 

Sector 2005 

Base 

2008 

Attainment 

2015 

Interim 

2021 

Maintenance

Safety 

Margin 

EGU Point 0.00 0.00 0.00 0.00 0.00 

Non-EGU 12.91 13.89 15.16 16.41 -2.52 

Non-road 41.75 18.27 4.01 0.31 17.96 

Other 1196.61 1210.42 1238.92 1263.63 -53.21 

MAR 206.59 172.13 123.08 78.68 93.45 

On-road 16.24 16.34 18.62 21.48 -5.14 

TOTAL 1474.10 1431.05 1399.79 1380.51 50.54 

Table 43 - Cincinnati-Hamilton Area SO2 Emission Inventory Totals for 

Base Year 2005, Estimated 2008, and Projected 2015 and 

2021 (tpy) – With CAIR 

SO2

2005 

Base 

2008 

Attainment 

2015 

Interim 

2021 

Maintenance 

Safety 

Margin 

Butler 8740.11 8053.85 7822.96 7115.23 938.62 

Clermont 89385.73 43288.10 32927.14 20919.33 22368.77 

Hamilton 86045.28 31780.37 24469.66 16099.00 15681.37 

Warren 384.04 252.69 180.79 167.35 85.34 

Dearborn 47986.18 27164.52 40716.88 38261.63 -11097.11 

Boone 5226.31 4349.56 4079.85 3946.83 402.73 

Campbell 722.03 696.00 653.19 620.39 75.61 

Kenton 1474.10 1431.05 1399.79 1380.51 50.54 

COMBINED 

SO2 TOTAL 239963.78 117016.14 112250.26 88510.27 28505.87 
 38 

PM2.5, NOx, and SO2

Table 44 - Cincinnati-Hamilton Area Comparison of 2008 attainment 

year and 2015 and 2021 projected emission estimates 

(tpy) 

 

2008 Base 2015 

Interim 

2015 

Projected 

Decrease 

2021 

Maintenance

2021 

Projected 

Decrease 

PM2.5 8,904.64 8,634.55 270.09 8,202.63 702.01 

NOx 148,706.15 105,712.02 42,994.13 78,819.13 69,887.02 

SO2 117,016.14 112,250.26 4,765.88 88,510.27 28,505.87 

 

As shown in the table above (Table 44), PM2.5 emissions in the 

nonattainment area are projected to decrease by 270.09 tpy in 2015 

and 702.01 tpy in 2021. NOx emissions in the nonattainment area 

are projected to decrease by 42,994.13 tpy in 2015 and 69,887.02 

tpy in 2021. SO2 emissions in the nonattainment area are projected 

to decline by 4,765.88 tpy in 2015 and 28,505.87 in 2021. 

Area source emissions and, to a lesser extent, point sources show 

an increase due to expectations that the population will grow in this 

area; however, cleaner vehicles and fuels are expected to be in 

place in 2009 and 2018, and the Transport Rule will be implemented 

in 2012 and 2014 and these programs should cause an overall drop 

in all three pollutants emissions. Decreases from U.S. EPA rules 

covering Tier 2 Motor Vehicle Emissions Standards and Gasoline 

Sulfur Control Requirements20, Highway Heavy-Duty Engine Rule21, 

and the Non-Road Diesel Engine Rule22 are factored into the 

changes. 

In addition to the above, the Miami Fort Station in Hamilton County 

implemented important changes in 2007. Two units, B005 (# 5-1) 

and B006 (# 5-2) permanently shut down effective December 31, 

2007. Each were 50 megawatt coal fired boilers. In addition, units 

B015 (# 7) and B017 (# 8) were issued a new source review permitto-install scrubbers, accepting a restricted SO2 allowable emissions 

rate that will not cause or contribute to a violation of a National 

Ambient Air Quality Standard (NAAQS) and/or Prevention of 

Significant Deterioration (PSD) increment violation based upon air 

dispersion modeling. These scrubbers began operating in April 2007 

and December 2007.23 The following summarizes Miami Fort’s 

 

20 http://www.epa.gov/fedrgstr/EPA-AIR/2000/February/Day-10/a19a.htm 

21 http://www.epa.gov/fedrgstr/EPA-AIR/1997/October/Day-21/a27494.htm 

22 http://www.epa.gov/fedrgstr/EPA-AIR/1998/October/Day-23/a24836.htm 

23 The lower rates will be incorporated into the facility’s Title V operating permit at renewal. 
 39 

emissions changes from the base year (2005), to the attainment 

year (2008), and for 2009: 

Table 45 - Miami Fort Station, Hamilton County, Emission Reductions 

(tpy) as Reported by Clean Air Markets Division 

SO2 NOx 

2005 77,583 12,264 

2008 24,693 12,371 

2009 25,340 4,338 

Requirement 4 of 5

A demonstration that improvement in air quality between the year violations 

occurred and the year attainment was achieved is based on permanent and 

enforceable emission reductions and not on temporary adverse economic 

conditions or unusually favorable meteorology. 

Background

Ambient air quality data from all monitoring sites indicate that air quality met 

the NAAQS for PM2.5 in 2007-2009. U.S. EPA’s redesignation guidance (p 

9) states: “A state may generally demonstrate maintenance of the NAAQS 

by either showing that future emissions of a pollutant or its precursors will 

not exceed the level of the attainment inventory, or by modeling to show 

that the future mix of sources and emissions rates will not cause a violation 

of the NAAQS.” 

Demonstration

Permanent and enforceable reductions of PM2.5, NOx, and SO2 emissions 

have contributed to the attainment of the annual PM2.5 standard. Some of 

these reductions were due to the application of tighter federal standards on 

new vehicles. Also Title IV of the CAA, the NOx SIP Call, CAIR, and federal 

consent decrees required the reductions of SO2 and NOx emissions from 

utility sources. Reductions achieved are discussed in greater detail under 

Chapter Five. 

Table 46 - Cincinnati-Hamilton Area Combined Comparison of 2005 

base year and 2008 attainment year on-road and EGU 

reductions 

2005 2008 

On-road PM2.5 2810.30 2679.85 

On-road NOx 71919.89 64471.22 

On-road SO2 392.00 277.59 

EGU PM2.5 2062.91 1633.15 

EGU NOx 55930.44 46853.89 

EGU SO2 218395.56 98334.17 
 40 

Requirement 5 of 5 

Provisions for future annual updates of the inventory to enable tracking of the 

emission levels, including an annual emission statement from major sources. 

Demonstration

In Ohio, major point sources in all counties are required to submit air 

emissions information annually, in accordance with U.S. EPA’s 

Consolidated Emissions Reporting Rule (CERR). Ohio EPA 

prepares a new periodic inventory for all PM2.5 precursor emission 

sectors every three years. These PM2.5 precursor inventories will be 

prepared for future years as necessary to comply with the inventory 

reporting requirements established in the CFR. Emissions 

information will be compared to the 2005 base year and the 2021 

projected maintenance year inventories to assess emission trends, 

as necessary, and to assure continued compliance with the annual 

PM2.5 standard. 
 41 

CHAPTER FIVE 

CONTROL MEASURES AND REGULATIONS

CAA Section107 (d)(3)(E)(ii), 107(d)(3)(iv), and 107(d)(3)(E)(v) 

Requirement 1 of 6

Section 172(c)(1) of the 1990 Clean Air Act Amendments requires states with 

nonattainment areas to implement RACM and RACT. 

Background

Section 172(c)(1) of the 1990 Clean Air Act Amendments requires 

states with nonattainment areas to submit a SIP providing for 

implementation of all reasonably available control measures and 

expeditiously as practicable (including such reductions in emissions 

from existing sources in the area as may be obtained through the 

adoption, at a minimum, of reasonable available control technology). 

U.S. EPA’s Implementation Rule interprets this requirement in great 

detail. Under U.S. EPA’s approach, RACT is determined as part of 

the broader RACM analysis and identification of all measures (for 

stationary, mobile, and area sources) that are technically and 

economically feasible, and that would collectively contribute to 

advancing the attainment date (i.e. by one year or more). States are 

required to use a combined approach to RACT and RACM, that (1) 

identifies potential measures that are reasonable, (2) uses modeling 

to identify the attainment date that is as expeditious as practicable, 

and (3) selects the appropriate RACT and RACM. 

The Implementation Rule also provides for a presumption that in 

States that fulfill their CAIR emission reduction requirements, EGU 

compliance with CAIR is equivalent to RACM/RACT. 

Demonstration

In 1972, 1980, and 1991, Ohio promulgated rules requiring 

reasonably available controls measures for particulate emissions 

from stationary sources. 

Statewide RACT rules have been applied to all new sources locating 

in Ohio since that time. RACT requirements are incorporated into 

permits along with monitoring, recordkeeping, and reporting 

necessary to ensure ongoing compliance. Ohio EPA also has an 

active enforcement program to address violations discovered by 

field office staff. The Ohio RACT rules are found in OAC Chapter 

3745-1724. 

 

24 http://www.epa.ohio.gov/dapc/regs/3745_17.aspx 
 42 

In addition, Ohio EPA promulgated NOx SIP Call rules (OAC 

Chapter 3745-1425), CAIR (OAC Chapter 3745-10926), and NOx

Reasonably Available Control Technology rules (OAC Chapter 

3745-11027) over the past five years. Emissions from EGUs make up 

a significant contribution to Ohio’s inventory. Beginning in 2009, 

Ohio implemented CAIR which has, and will, provide for significant 

reductions in NOx, PM2.5, and SO2 until such time it is replaced by 

U.S. EPA’s proposed Transport Rule. Then the Transport Rule will 

provide for even greater reductions. 

As part of a larger initiative, LADCO, in consultation with two 

contractors, performed a series of studies exploring control 

measures for reducing both ozone precursors and PM2.5 precursors 

in Ohio, Illinois, Indiana, Michigan, and Wisconsin area. The first 

consultant, MACTEC, prepared a series of white papers28

researching different stationary source categories. The results were 

compiled into two reports29. The second consultant, Environ, 

investigated control options for mobile sources. The results were 

compiled into two reports30. The stationary and mobile source 

sectors (and associated control measures) were selected by the 

LADCO States based on several factors presented in the report 

(See Chapter 2). 

Photochemical modeling was then conducted (as part of LADCO 

Round 4 modeling) to assess the air quality benefit of the candidate 

control measures and a modeling report was developed31. Based on 

the results, the LADCO project team felt it would not be possible to 

advance the attainment date for PM2.5. Ohio EPA, in its attainment 

demonstration submitted on July 18, 2008, demonstrated (using a 

weight of evidence approach) that attainment would be achieved in 

this area by 2009. Because of a projected 2009 attainment date, it 

would not have been reasonably possible or practicable for Ohio to 

 

25 http://www.epa.ohio.gov/dapc/regs/3745_14.aspx 

26 http://www.epa.ohio.gov/dapc/regs/3745_109.aspx 

27 http://www.epa.ohio.gov/dapc/regs/3745_110.aspx

28 http://www.ladco.org/reports/control/white_papers 

29 

http://www.ladco.org/reports/control/final_reports/identification_and_evaluation_of_candidate_control_measures_i_

april_2005.pdf; 

http://www.ladco.org/reports/control/final_reports/identification_and_evaluation_of_candidate_control_measures_ii_

june_2006.pdf 

30

http://www.ladco.org/reports/control/final_reports/final_report_evaluation_of_candidate_mobile_source_control_me

asures_february_2006.pdf; 

http://www.ladco.org/reports/control/final_reports/final_report_evaluation_of_candidate_mobile_source_control_me

asures_for_ladco_states_in_2009_and_2012_march_2007.pdf

31 http://www.ladco.org/reports/control/modeling/round4_modeling.pdf
 43 

develop RACT/RACM requirements, promulgate regulations and 

implement a control program prior to the projected attainment date. 

Requirement 2 of 6

Section 172(c)(2) of the 1990 CAA Amendments requires attainment 

demonstration SIPs for nonattainment areas to show reasonable further 

progress (RFP). 

Background

U.S. EPA’s Implementation Rule requires RFP only for any area 

which a State projects an attainment date beyond 2010. The RFP 

would provide emission reductions showing linear progress between 

2002 and 2009. If a State demonstrates attainment will occur by 

2010 or earlier, U.S. EPA considers the attainment demonstration to 

demonstrate achievement of RFP. 

Demonstration

In Ohio’s attainment demonstration submitted on July 18, 2008, 

Ohio demonstrated (using a weight of evidence approach) that 

attainment would be achieved in this area by 2009; and therefore, it 

was not necessary to submit a separate RFP plan. 

Requirement 3 of 6

Section 172(c)(3) requires states to submit a comprehensive inventory of actual 

emissions. 

Background

Section 172(c)(3) requires states to submit a comprehensive 

inventory of actual emissions in the area, including the requirement 

for periodic revisions as determined necessary. 40 CFR 51.1008 

requires such inventory to be submitted within three years of 

designation and requires a baseline emission inventory for calendar 

year 2002 or other suitable year to be used for attainment planning. 

Demonstration

The 2005 comprehensive inventory was submitted to U.S. EPA with 

Ohio’s PM2.5 attainment demonstration SIP submitted on July 18, 

2008. It was then subsequently revised and resubmitted on June 7, 

2010. 

Ohio also updates its inventory in accordance with U.S. EPA’s 

CERR rule (i.e. emissions statements). Ohio EPA submitted its 

emissions statement SIP on March 18, 1994 which was approved by 

U.S. EPA on October 13, 1995 (59 FR 51863). As discussed in 

Chapter 4 (Requirement 4), Ohio EPA submits, and commits to 

submit, emission inventories (statements) every three years. 
 44 

Requirement 4 of 6

Evidence that control measures required in past PM2.5 SIP revisions have been 

fully implemented. 

Background

In addition to the historic RACT requirements for PM, the U.S. EPA 

NOx SIP Call required 22 states to pass rules that would result in 

significant emission reductions from large EGUs, industrial boilers, 

and cement kilns in the eastern United States. Ohio passed this rule 

in 2001. NOx SIP Call requirements are incorporated into permits 

along with monitoring, recordkeeping, and reporting necessary to 

ensure ongoing compliance. Ohio EPA also has an active 

enforcement program to address violations discovered by field office 

staff. Compliance is tracked through the Clean Air Markets data 

monitoring program. Beginning in 2004, this rule accounts for a 

reduction of approximately 31 percent of all NOx emissions 

statewide compared to previous uncontrolled years. The other 21 

states also have adopted these rules. 

On March 10, 2004, the U.S. EPA promulgated the CAIR. 

Beginning in 2009, U.S. EPA’s CAIR rule requires EGUs in 28 

eastern states and the District of Columbia to significantly reduce 

emissions of NOx and SO2. CAIR replaced the NOx SIP Call for 

EGUs. National NOx emissions will be cut from 4.5 million tons in 

2004, to a cap of 1.5 million tons by 2009, and 1.3 million tons in 

2018 in 28 states. States were required to submit a CAIR SIP as 

part of this effort. Ohio submitted a CAIR SIP which was approved 

by U.S. EPA on February 1, 2007. Revisions to the CAIR SIP were 

again submitted on July 15, 2009. The revised CAIR SIP was 

approved as a direct final action on September 25, 2009 (74 FR 

48857). 

Demonstration

Controls for EGUs under the NOx SIP Call formally commenced May 

31, 2004. Emissions covered by this program have been generally 

trending downward since 1998 with larger reductions occurring in 

2002 and 2003. Data taken from the U.S. EPA Clean Air Markets 

web site, quantify the gradual NOx reductions that have occurred in 

Ohio as a result of Title IV of the 1990 CAA Amendments and the 

beginning of the NOx SIP Call Rule. Ohio developed the NOx Budget 

Trading Program rules in OAC Chapter 3745-1432 in response to the 

SIP Call. OAC Chapter 3745-14 regulates EGUs and certain nonEGUs under a cap and trade program based on an 85 percent 

 

32 http://www.epa.ohio.gov/dapc/regs/3745_14.aspx 
 45 

reduction of NOx emissions from EGUs and a 60 percent reduction 

of NOx emissions from non-EGUs, compared to historical levels. 

This cap was in place through 2008, at which time the CAIR 

program superseded it as discussed above. Requirement 3 of 5 

under Chapter 4 above discussed the reductions Ohio has seen as 

a result of CAIR. 

On April 21, 2004, U.S. EPA published Phase II of the NOx SIP Call 

that establishes a budget for large (greater than 1 ton per day 

emissions) stationary internal combustion engines. Ohio EPA’s OAC 

rule 3745-14-12 addresses stationary internal combustion engines, 

all used in natural gas pipeline transmissions. U.S. EPA approved 

this revision to the SIP on April 4, 2008. An 82 percent NOx 

reduction from 1995 levels is anticipated. Completion of the 

compliance plan occurred by May 1, 2006, and the compliance 

demonstration began May 1, 2007. 

Tier II Emission Standards for Vehicles and Gasoline Sulfur 

Standards

In February 2000, U.S. EPA finalized a federal rule to significantly 

reduce emissions from cars and light trucks, including sport utility 

vehicles (SUVs). Under this proposal, automakers will be required 

to sell cleaner cars, and refineries will be required to make cleaner, 

lower sulfur gasoline. This rule will apply nationwide. The federal 

rules will phase in between 2004 and 2009. U.S. EPA has 

estimated that NOx emission reductions will be approximately 77 

percent for passenger cars, 86 percent for smaller SUVs, light 

trucks, and minivans, and 65 to 95 percent reductions for larger 

SUVs, vans, and heavier trucks. The sulfur content of gasoline is 

estimated to be reduced by up to 90 percent. VOC emission 

reductions will be approximately 12 percent for passenger cars, 18 

percent for smaller SUVs, light trucks, and minivans, and 15 percent 

for larger SUVs, vans, and heavier trucks. 

Heavy-Duty Diesel Engines

In July 2000, U.S. EPA issued a final rule for Highway Heavy Duty 

Engines, a program which includes low-sulfur diesel fuel standards, 

which will be phased in from 2004 through 2007. This rule applies to 

heavy-duty gasoline and diesel trucks and buses. This rule will 

result in a 40 percent reduction in NOx from diesel trucks and buses, 

a large sector of the mobile sources NOx inventory. It also estimated 

the level of sulfur in highway diesel fuel will be reduced by 97 

percent by mid-2006. 
 46 

Clean Air Non-road Diesel Rule

In May 2004, U.S. EPA issued the Clean Air Non-road Diesel Rule. 

This rule applies to diesel engines used in industries such as 

construction, agriculture, and mining. It also contains a cleaner fuel 

standard similar to the highway diesel program. The new standards 

will cut emissions from non-road diesel engines by more than 90 

percent. Non-road diesel equipment, as described in this rule, 

currently accounts for 47 percent of diesel particulate matter (PM) 

and 25 percent of NOx from mobile sources nationwide. Sulfur 

levels will be reduced in non-road diesel fuel by 99 percent from 

current levels, from approximately 3,000 parts per million (ppm) now 

to 15 ppm in 2009. New engine standards take effect, based on 

engine horsepower, starting in 2008. Together, these rules will 

substantially reduce local and regional sources of PM2.5 precursors. 

Requirement 5 of 6

Acceptable provisions to provide for new source review. 

Background

Ohio has a longstanding and fully implemented New Source Review 

(NSR) program. This is addressed in OAC Chapter 3745-3133. The 

Chapter includes provisions for the Prevention of Significant 

Deterioration (PSD) permitting program in OAC rules 3745-31-01 to 

3745-31-20. Ohio's PSD program was conditionally approved on 

October 10, 2001 (66 FR 51570) and received final approval on 

January 22, 2003 (68FR 2909) by U.S. EPA as part of the SIP. 

Demonstration

Any facility that is not listed in the 2005 emission inventory, or for the 

closing of which credit was taken in demonstrating attainment, will 

not be allowed to construct, reopen, modify, or reconstruct without 

meeting all applicable NSR requirements. Once the area is 

redesignated, Ohio EPA will implement NSR through the PSD 

program. 

Requirement 6 of 6

Assure that all existing control measures will remain in effect after redesignation 

unless the State demonstrates through modeling that the standard can be 

maintained without one or more control measures. 

Demonstration

Ohio commits to maintaining the aforementioned control measures 

after redesignation. Ohio hereby commits that any changes to its 

 

33 http://www.epa.ohio.gov/dapc/regs/3745_31.aspx 
 47 

rules or emission limits applicable to PM2.5, SO2, and NOx as 

required for maintenance of the annual PM2.5 standard in the 

Cincinnati-Hamilton area, will be submitted to U.S. EPA for approval 

as a SIP revision. 

Ohio, through Ohio EPA’s Legal section, has the legal authority and 

necessary resources to actively enforce any violations of its rules or 

permit provisions. After redesignation, it intends to continue 

enforcing all rules that relate to the emission of PM2.5 precursors in 

the Cincinnati-Hamilton area. 
 48 

CHAPTER SIX 

CONTINGENCY MEASURES 

CAA Section 107(d)(3)(E)(v) 

Requirement 1 of 4

A commitment to submit a revised plan eight years after redesignation. 

Demonstration

Ohio hereby commits to review its maintenance plan eight years 

after redesignation, as required by Section 175(A) of the CAA. 

Requirement 2 of 4

A commitment to expeditiously enact and implement additional contingency 

control measures in response to exceeding specified predetermined levels 

(triggers) or in the event that future violations of the ambient standard occur. 

Demonstration

Ohio hereby commits to adopt and expeditiously implement 

necessary corrective actions in the following circumstances: 

Warning Level Response:

A warning level response shall be prompted whenever the PM2.5

average of the weighted annual mean of 15.5 μg/m3 occurs in a 

single calendar year within the maintenance area. A warning level 

response will consist of a study to determine whether the PM2.5

value indicates a trend toward higher PM2.5 values or whether 

emissions appear to be increasing. The study will evaluate whether 

the trend, if any, is likely to continue and, if so, the control measures 

necessary to reverse the trend taking into consideration ease and 

timing for implementation as well as economic and social 

considerations. Implementation of necessary controls in response to 

a warning level response trigger will take place as expeditiously as 

possible, but in no event later than 12 months from the conclusion of 

the most recent calendar year. 

Should it be determined through the warning level study that action 

is necessary to reverse the noted trend, the procedures for control 

selection and implementation outlined under “action level response” 

shall be followed. 

Action Level Response: 

An action level response shall be prompted whenever a two-year 

average of the weighted annual means of 15.0 μg/m3 or greater 

occurs within the maintenance area. A violation of the standard 
 49 

(three-year average of the weighted annual means of 15.0 μg/m3 or 

greater) shall also prompt an action level response. In the event 

that the action level is triggered and is not found to be due to an 

exceptional event, malfunction, or noncompliance with a permit 

condition or rule requirement, Ohio EPA in conjunction with the 

metropolitan planning organization or regional council of 

governments, will determine additional control measures needed to 

assure future attainment of the NAAQS for annual PM2.5. In this 

case, measures that can be implemented in a short time will be 

selected in order to be in place within 18 months from the close of 

the calendar year that prompted the action level. Ohio EPA will also 

consider the timing of an action level trigger and determine if 

additional, significant new regulations not currently included as part 

of the maintenance provisions will be implemented in a timely 

manner and will constitute our response. 

Control Measure Selection and Implementation

Adoption of any additional control measures is subject to the 

necessary administrative and legal process. This process will 

include publication of notices, an opportunity for public hearing, and 

other measures required by Ohio law for rulemaking. 

If a new measure/control is already promulgated and scheduled to 

be implemented at the federal or State level, and that 

measure/control is determined to be sufficient to address the upward 

trend in air quality, additional local measures may be unnecessary. 

Furthermore, Ohio will submit to U.S. EPA an analysis to 

demonstrate the proposed measures are adequate to return the 

area to attainment. 

Requirement 3 of 4

A list of potential contingency measures that would be implemented in such an 

event. 

Demonstration

Contingency measures to be considered will be selected from a 

comprehensive list of measures deemed appropriate and effective at 

the time the selection is made. The selection of measures will be 

based on cost-effectiveness, emission reduction potential, economic 

and social considerations or other factors that Ohio EPA deems 

appropriate. Ohio EPA will solicit input from all interested and 

affected persons in the maintenance area prior to selecting 

appropriate contingency measures. Because it is not possible at 

this time to determine what control measures will be appropriate at 

an unspecified time in the future, the list of contingency measures 

outlined below is not exhaustive. 
 50 

1) Diesel reduction emission strategies. 

2) Alternative fuel (e.g., liquid propane and compressed natural 

gas) and diesel retrofit programs for fleet vehicle operations. 

3) Tighter PM2.5, SO2, and NOx emissions offsets for new and 

modified major sources. 

4) Impact crushers located at recycle scrap yards – upgrade wet 

suppression. 

5) Concrete manufacturing – upgrade wet suppression. 

6) Additional NOx RACT statewide. 

No contingency measure shall be implemented without providing the 

opportunity for full public participation during which the relative costs 

and benefits of individual measures, at the time they are under 

consideration, can be fully evaluated. 

Requirement 4 of 4

A list of PM2.5, SO2, and NOx sources potentially subject to future additional 

control requirements. 

Demonstration

The following is a list of PM2.5, SO2, and NOx sources potentially subject to 

future controls. 

• ICI Boilers - SO2 and NOx controls; 

• EGUs; 

• process heaters; 

• internal combustion engines; 

• combustion turbines; 

• other sources greater than 100 tons per year; 

• Fleet vehicles; 

• Concrete manufacturers; 

• Aggregate processing plants; 
 51 

CHAPTER SEVEN 

PUBLIC PARTICIPATION

Ohio published notification for a public hearing and solicitation for public 

comment concerning the draft redesignation petition and maintenance plan in the 

widely distributed county publications on October 28, 2010. 

The public hearing to receive comments on the redesignation request was held 

on November 29, 2010 at 2:30 P.M. at the Hamilton County Department of 

Environmental Services, Cincinnati, Ohio. The public comment period closed on 

November 30, 2010. No testimony was provided at the public hearing. 

Comments were received during the public comment period. Appendix E 

includes a copy of the public notice, the transcript from the public hearing, and 

the response to comments. 
 52 

CHAPTER EIGHT 

CONCLUSIONS

The Cincinnati-Hamilton annual PM2.5 nonattainment area has attained the 1997 

annual NAAQS for PM2.5 and complied with the applicable provisions of the 1990 

Amendments to the CAA regarding redesignations of PM2.5 nonattainment areas. 

Documentation to that effect is contained herein. Ohio EPA has prepared a 

redesignation request and maintenance plan that meet the requirements of 

Section 110 (a)(1) of the 1990 CAA. 

Based on this presentation, the Cincinnati-Hamilton annual PM2.5 nonattainment 

area meets the requirements for redesignation under the CAA and U.S. EPA 

guidance. Ohio has performed an analysis that shows the air quality 

improvements are due to permanent and enforceable measures. Furthermore, 

because this area is subject to significant transport of pollutants, significant 

regional SO2 and NOx reductions will ensure continued compliance 

(maintenance) with the standard with an increasing margin of safety. 

The State of Ohio hereby requests that the Cincinnati-Hamilton annual PM2.5

nonattainment area be redesignated to attainment simultaneously with U.S. EPA 

approval of the maintenance plan provisions contained herein. 
This page left intentionally blank
State of Ohio Environmental Protection Agency 

STREET ADDRESS: -- MAILING ADDRESS: 

Lararus Government Center ~ELE (614) E~+SOZO FAX: (614) 644.3784 ~vw.epe.~taie.oh US 

P.O. Box 1049 

50 W. Town St., Suite 700 Columbus, OH 43216-1049 

Columbus, Ohio 43215 

CERTIFIED NAIL 

April 1, 2010 

Cheryl L. Newton, Director 

Air and Radiation Division 

U,S.EPA, Region V 

77 West Jackson Boulevard 

Chicago, Illinois 60604 

RE: 2009 SLAMS PM,,and Ozone Data Certification 

Dear Ms. Newton: 

Please find enclosed our SLAMS Report (AMP-450, AMP-450NC and AMP255) for calendar year 2009 as required in 40 CFR, Part 58, Section 

58.15. The ambient concentration and the quality assurance data 

have been completely submitted to the AQS database. 

The remaining criteria pollutant data will be certified within the 

month of April. 

I certify that the Ozone and PM,, data in the report are accurate to 

the best of our knowledge taking into consideration the quality 

assurance findings and only to the extent of the activities 

performed by Ohio EPA. 

There were no incidents of air pollution that reached or exceeded 

levels as specified by Section 51.151 which could cause significant 

harm to the health of persons. 

Sincerely, - 

Robert Wodanbosi 

Chief, Division of Air Pollution Control 

Ted Strickland. Goveriior 

Lee Fisher, Lieutenant Governor 

Chris Korleski, Director 

Ohio EPA is an Equal Opportunity Employer 
UNITED STATES ENVIRONMENTAL PROTECTION AGENCY

QUICKLOOK CRITERIA PARAMETERS

Report Request ID: 787657 Report Code: AMP450 Sep. 8, 2010

Selection Criteria Page 1

User ID: GYE

State County Site Parameter POC City AQCR UAR CBSA CSA

EPA

Region Method Duration Begin Date End Date

39

39

39

39

21

21

21

061

017

025

165

015

037

117

GEOGRAPHIC SELECTIONS

PROTOCOL SELECTIONS

Parameter

Classification Parameter Method Duration

QUICK LOOK 88101

SELECTED OPTIONS

EVENTS PROCESSING

MERGE PDF FILES

Option Type Option Value

EXCLUDE REGIONALLY CONCURRED EVENTS

YES

SORT ORDER

1

2

3

4

5

6

7

Order Column

PARAMETER_CODE

STATE_CODE

COUNTY_CODE

SITE_ID

POC

DATES

EDT_ID

GLOBAL DATES

2007

Start Date End Date

2009

Tribal

APPLICABLE STANDARDS

Standard Description

PM25 24-hour 2006

PM25 Annual 2006
Sep. 8, 2010

Note: The * indicates that the mean does

not satisfy summary criteria.

UNITED STATES ENVIRONMENTAL PROTECTION AGENCY

AIR QUALITY SYSTEM

QUICK LOOK REPORT (AMP450)

Page 1 of 7

EXCEPTIONAL DATA TYPES

EDT DESCRIPTION

0

1

2

5

NO EVENTS

EVENTS EXCLUDED

EVENTS INCLUDED

EVENTS WITH CONCURRENCE EXCLUDED
Sep. 8, 2010

Note: The * indicates that the mean does

not satisfy summary criteria.

UNITED STATES ENVIRONMENTAL PROTECTION AGENCY

AIR QUALITY SYSTEM

QUICK LOOK REPORT (AMP450)

Page 2 of 7

PM2.5 - Local Conditions (88101) Kentucky Micrograms/cubic meter (LC) (105)

SITE ID

P

O

C PQAO CITY COUNTY ADDRESS YEAR METH #OBS

4TH

MAX CERT EDT

21-037-3002

21-037-3002

21-037-3002

21-117-0007

21-117-0007

21-117-0007

1

1

1

1

1

1

0584

0584

0584

0584

0584

0584

Highland 

Heights

Highland 

Heights

Highland 

Heights

Covington

Covington

Covington

Campbell

Campbell

Campbell

Kenton

Kenton

Kenton

524A John 

Hill Road

524A John 

Hill Road

524A John 

Hill Road

1401 DIXIE 

HWY, 

UNIVERSITY 

COLLEGE

1401 DIXIE 

HWY, 

UNIVERSITY 

COLLEGE

1401 DIXIE 

HWY, 

UNIVERSITY 

COLLEGE

2007

2008

2009

2007

2008

2009

118

118

145

118

118

118

34.0

30.5

24.5

34.7

30.5

24.5

Y

Y

5

0

0

5

0

0

24-HOUR 

98TH

PERCENTILE

VALUE

34.0

26.1

22.5

31.6

25.2

23.1

50

119

114

117

121

113

1ST

MAX

2ND

MAX

3RD

MAX

33.5

27.3

22.7

34.6

27.3

23.3

26.3

26.1

22.5

31.6

25.2

23.1

26.0

24.4

21.4

30.5

25.0

22.1

14.36*

11.83 

11.34 

14.20 

11.99 

11.04 

WTD

ARITH

MEAN
Sep. 8, 2010

Note: The * indicates that the mean does

not satisfy summary criteria.

UNITED STATES ENVIRONMENTAL PROTECTION AGENCY

AIR QUALITY SYSTEM

QUICK LOOK REPORT (AMP450)

Page 3 of 7

PM2.5 - Local Conditions (88101) Ohio Micrograms/cubic meter (LC) (105)

SITE ID

P

O

C PQAO CITY COUNTY ADDRESS YEAR METH #OBS

4TH

MAX CERT EDT

39-017-0003

39-017-0003

39-017-0003

39-017-0003

39-017-0003

39-017-0016

39-017-0016

39-017-0016

39-017-1004

39-025-0022

39-025-0022

39-025-0022

39-061-0006

39-061-0006

39-061-0006

39-061-0014

1

1

1

2

2

1

1

1

1

1

1

1

1

1

1

1

1259

1259

1259

1259

1259

1259

1259

1259

1259

1259

1259

1259

1259

1259

1259

1259

Middletown

Middletown

Middletown

Middletown

Middletown

Fairfield

Fairfield

Fairfield

Middletown

Batavia

Batavia

Batavia

Cincinnati

Cincinnati

Cincinnati

Cincinnati

Butler

Butler

Butler

Butler

Butler

Butler

Butler

Butler

Butler

Clermont

Clermont

Clermont

Hamilton

Hamilton

Hamilton

Hamilton

BONITA & ST 

JOHN

BONITA & ST 

JOHN

BONITA & ST 

JOHN

BONITA & ST 

JOHN

BONITA & ST 

JOHN

400 NILLES 

RD.

400 NILLES 

RD.

400 NILLES 

RD.

HOOK FIELD 

AIRPORT

2400 CLERMONT

CENTER DR.

2400 CLERMONT

CENTER DR.

2400 CLERMONT

CENTER DR.

11590 GROOMS 

RD

11590 GROOMS 

RD

11590 GROOMS 

RD

SEYMOUR & 

VINE ST.

2007

2008

2009

2008

2009

2007

2008

2009

2007

2007

2008

2009

2007

2008

2009

2007

120

120

000

000

000

120

120

000

120

120

120

120

120

120

120

120

37.8

38.4

31.5

38.1

29.9

38.0

39.5

33.0

37.6

40.8

25.3

23.5

40.8

33.9

29.7

41.5

Y

Y

Y

Y

Y

0

0

0

0

0

0

0

0

0

0

0

0

0

0

0

0

24-HOUR 

98TH

PERCENTILE

VALUE

36.8

27.1

25.3

30.9

22.8

34.5

31.5

27.2

36.4

33.5

23.6

22.0

34.7

27.0

24.2

36.5

118

119

116

58

59

115

118

113

112

114

116

121

296

174

122

109

1ST

MAX

2ND

MAX

3RD

MAX

37.1

31.2

27.4

30.9

22.8

36.8

32.7

29.5

36.9

34.1

24.5

22.4

39.2

28.1

26.3

38.1

36.8

27.1

25.3

27.3

22.2

34.5

31.5

27.2

36.4

33.5

23.6

22.0

38.1

28.1

24.2

36.5

35.3

26.3

24.3

27.2

21.9

34.0

27.6

25.5

35.5

33.1

23.5

21.8

37.2

27.0

23.9

36.2

15.41 

13.69 

12.68 

14.32 

12.49 

14.94 

13.75 

13.08 

14.63 

14.01 

11.75 

11.01 

14.63 

12.48 

12.11 

16.59 

WTD

ARITH

MEAN
Sep. 8, 2010

Note: The * indicates that the mean does

not satisfy summary criteria.

UNITED STATES ENVIRONMENTAL PROTECTION AGENCY

AIR QUALITY SYSTEM

QUICK LOOK REPORT (AMP450)

Page 4 of 7

PM2.5 - Local Conditions (88101) Ohio Micrograms/cubic meter (LC) (105)

SITE ID

P

O

C PQAO CITY COUNTY ADDRESS YEAR METH #OBS

4TH

MAX CERT EDT

39-061-0014

39-061-0014

39-061-0014

39-061-0014

39-061-0040

39-061-0040

39-061-0040

39-061-0042

39-061-0042

39-061-0042

39-061-0043

39-061-0043

39-061-7001

39-061-7001

39-061-7001

39-061-8001

1

1

2

2

1

1

1

1

1

1

1

1

1

1

1

1

1259

1259

1259

1259

1259

1259

1259

1259

1259

1259

1259

1259

1259

1259

1259

1259

Cincinnati

Cincinnati

Cincinnati

Cincinnati

Cincinnati

Cincinnati

Cincinnati

Cincinnati

Cincinnati

Cincinnati

Sharonville

Sharonville

Norwood

Norwood

Norwood

St. Bernard

Hamilton

Hamilton

Hamilton

Hamilton

Hamilton

Hamilton

Hamilton

Hamilton

Hamilton

Hamilton

Hamilton

Hamilton

Hamilton

Hamilton

Hamilton

Hamilton

SEYMOUR & 

VINE ST.

SEYMOUR & 

VINE ST.

SEYMOUR & 

VINE ST.

SEYMOUR & 

VINE ST.

250 WM. 

HOWARD TAFT

250 WM. 

HOWARD TAFT

250 WM. 

HOWARD TAFT

2101 W. 8TH 

ST.

2101 W. 8TH 

ST.

2101 W. 8TH 

ST.

3254 E. 

KEMPER RD.

3254 E. 

KEMPER RD.

2059 SHERMAN 

AVE.

2059 SHERMAN 

AVE.

2059 SHERMAN 

AVE.

300 MURRAY 

RD.

2008

2009

2008

2009

2007

2008

2009

2007

2008

2009

2007

2008

2007

2008

2009

2007

120

120

000

119

120

000

142

120

120

000

120

120

120

000

142

120

37.7

34.3

40.1

35.3

41.9

31.5

28.5

39.2

33.5

36.5

37.2

35.0

40.9

34.2

30.5

37.4

Y

Y

Y

Y

Y

Y

0

0

0

0

0

0

0

0

0

0

0

0

0

0

0

0

24-HOUR 

98TH

PERCENTILE

VALUE

33.0

27.1

34.7

31.1

34.7

25.5

24.8

35.9

27.5

27.0

34.0

28.2

33.7

30.3

25.7

35.4

119

355

58

62

107

107

116

110

111

109

116

117

111

112

119

110

1ST

MAX

2ND

MAX

3RD

MAX

33.3

33.9

34.7

31.1

35.3

26.6

25.7

36.3

32.2

28.2

34.0

28.5

35.0

31.9

27.8

36.3

33.0

29.5

33.0

30.4

34.7

25.5

24.8

35.9

27.5

27.0

34.0

28.2

33.7

30.3

25.7

35.4

31.7

29.1

32.1

25.1

33.1

25.0

24.8

33.6

27.5

26.3

32.6

28.0

32.0

28.9

25.7

32.8

15.12 

13.40 

15.25 

13.89 

15.09 

12.62 

12.73 

15.90 

14.40 

13.71 

14.85 

13.32 

15.09 

13.74 

12.97 

16.07 

WTD

ARITH

MEAN
Sep. 8, 2010

Note: The * indicates that the mean does

not satisfy summary criteria.

UNITED STATES ENVIRONMENTAL PROTECTION AGENCY

AIR QUALITY SYSTEM

QUICK LOOK REPORT (AMP450)

Page 5 of 7

PM2.5 - Local Conditions (88101) Ohio Micrograms/cubic meter (LC) (105)

SITE ID

P

O

C PQAO CITY COUNTY ADDRESS YEAR METH #OBS

4TH

MAX CERT EDT

39-061-8001

39-061-8001

39-165-0007

39-165-0007

39-165-0007

1

1

1

1

1

1259

1259

1259

1259

1259

St. Bernard

St. Bernard

Lebanon

Lebanon

Lebanon

Hamilton

Hamilton

Warren

Warren

Warren

300 MURRAY 

RD.

300 MURRAY 

RD.

416 SOUTHEAST

ST.

416 SOUTHEAST

ST.

416 SOUTHEAST

ST.

2008

2009

2007

2008

2009

120

120

120

120

120

37.4

30.8

40.8

27.7

26.5

Y

Y

0

0

0

0

0

24-HOUR 

98TH

PERCENTILE

VALUE

31.0

28.7

33.6

24.2

23.6

115

117

114

118

119

1ST

MAX

2ND

MAX

3RD

MAX

31.8

30.8

36.6

25.7

25.6

31.0

28.7

33.6

24.2

23.6

30.8

28.5

33.3

23.3

22.4

14.40 

13.44 

13.98 

11.92 

11.70 

WTD

ARITH

MEAN
Sep. 8, 2010

Note: The * indicates that the mean does

not satisfy summary criteria.

UNITED STATES ENVIRONMENTAL PROTECTION AGENCY

AIR QUALITY SYSTEM

QUICK LOOK REPORT (AMP450)

Page 6 of 7

88101

88101

88101

88101

88101

88101

000

118

119

120

142

145

MULTIPLE METHODS

R & P Model 2025 PM2.5 Sequential w/WINS

Andersen RAAS2.5-100 PM2.5 SAM w/WINS

Andersen RAAS2.5-300 PM2.5 SEQ w/WINS

BGI Models PQ200-VSCC or PQ200A-VSCC

R & P Model 2025 PM-2.5 Sequential Air Sampler

MULTIPLE METHODS

GRAVIMETRIC

GRAVIMETRIC

GRAVIMETRIC

Gravimetric

Gravimetric

PARAMETER

METHOD

CODE COLLECTION METHOD ANALYSIS METHOD

METHODS USED IN THIS REPORT
Sep. 8, 2010

Note: The * indicates that the mean does

not satisfy summary criteria.

UNITED STATES ENVIRONMENTAL PROTECTION AGENCY

AIR QUALITY SYSTEM

QUICK LOOK REPORT (AMP450)

Page 7 of 7

PQAOS USED IN THIS REPORT

PQAO AGENCY DESCRIPTION

0584

1259

Kentucky Division For Air Quality

Hamilton County Department Of Environmental Services
1

OHIO 

2005 Base Year PM2.5 SIP Inventory 

Ohio Environmental Protection Agency 

Lazarus Government Center 

50 West Town Street, Suite 700 

Columbus Ohio 43215 

Prepared by Ohio EPA 

Division of Air Pollution Control 

Emissions Inventory Unit 

February 2008 
2

Table of Contents 

Section Page

 Introduction ................................................................................................. 3 

1.0 Point Sources ............................................................................................. 4 

 

2.0 Area Sources .............................................................................................. 8 

3.0 Non Road Sources........................................................................15 

4.0 On Road Sources........................................................................................17 

5.0 MAR Sources..............................................................................43 

 

Table 

2-1 Categories included in the 2005 area source Inventory.............................8

2-2 Emission Factors used for Wood Burners included in area sources............11 

3-1 NMIM NCD Tables for Specific Years and States ........................................... 16

4-1 Federal Functional Class Categories............................................................23 

4-2 DVMT Summary by County.................................................................. .24 

4-3 Speed by Federal Functional Class .............................................................28

4-4 Link Group Codes & Associated BPR Curves .......................................... 29 

4-5 Mobile6 Inputs.................................................................................31 

4-6 LADCO Data Output............................................. .............39

4-7 County Summary Table of MPOs by County......................................... .40 

5-1 Number of operations and LTOs for 2005.............................................. 45 

5-2 EDMS Aircraft Emissions ..................................................................50 

5-3 Fleet Emission Factor Categories ........................................................51 

5-4 Pollutant by County (Sample) ............................................................. 54 

. 

Figure

1........................................ Speed Comparison Graphs.....................................27 
3

2005 Base Year PM2.5 SIP Inventory for Ohio 

Introduction 

The State of Ohio has a number of counties with air quality data showing nonattainment for the following PM2.5 standard: 

• Annual Standard = 15.0 ug/m3 

The Clean Air Act Amendments (CAAA) requires all states to revise and submit State 

Implementation Plans (SIP) for areas which are classified as non-attainment of the 1997 

Fine Particle (PM2.5) National Ambient Air Quality Standards (NAAQS). The Federal 

Register ( Vol. 72, No. 79/ Wednesday, April 25, 2007) provides the emissions inventory 

rules and regulations for the PM2.5 Clean Air Fine Particle implementation rule. An 

electronic version of the document can be found at http://www.epa.gov/fedrgstr/EPAAIR/2007/April/Day-25/a6347.pdf. 

As part of the designation of non-attainment areas for PM2.5 standards, a new 

attainment demonstration SIP will be necessary. A key element in the overall SIP 

planning process is the need for an updated emissions inventory. This document 

presents the 2005 Base Year Particulate SIP Emissions Inventory for Ohio as required 

by the CAAA. It includes emissions for point, area, on-road mobile and non-road mobile 

for the State of Ohio. 

This technical report documents the procedures and the methodologies that were used 

in the development of daily emissions for all counties in Ohio. This report describes the 

following: 

1. Identification of stationary and mobile sources included in the 

inventory; 

2. Sources of data, and data collection methods used in the development 

of the inventory; 

3. Methods and procedures used to estimate emissions; and 

4. Assumptions considered in the development of the emissions 

inventories. 

The intent of this report is to describe how the inventory was prepared, and what 

information was considered in the inventory development. 

This document is comprised of 5 sections, one section for each inventory type. The 

biogenic inventory is not being discussed in this document because Ohio EPA did not 

participate in the generation of this inventory. Lake Michigan Air Directors Consortium 

(LADCO) ran EPA’s BEIS model in the Emission Modeling System (EMS) to generate 

Summer Weekday emissions for VOC and NOx. 
4

SECTION 1

POINT SOURCES 

Emissions and source specific data for point sources are collected for the 2005 baseyear SIP inventory by the Ohio Environmental Protection Agency (Ohio EPA.) The 

primary source of data for point sources is facility reported STARShip files. STARShip 

is a software package developed by Ohio EPA, Division of Air Pollution Control (DAPC), 

to assist the regulated community in preparing and submitting a variety of electronic 

permit applications and reports to the DAPC. These data are reported by the Title V 

facilities annually as part of the emissions fee/inventory process conducted by Ohio 

EPA and include emissions, process rates, operating schedules, emissions control data 

and other relevant information. 

The STARShip files are electronically transferred to the DAPC and stored into the 

Division’s Oracle database, STARS. The files are reviewed by the local air agencies 

and Ohio EPA district and central office staff. After review, the data are imported into 

Excel and linked with an Access® database to further process the information into the 

federally approved National Emission Inventory (NEI) database format in version 3.0. 

The files are quality assured again using the United States Environmental Protection 

Agency’s (U.S.EPA) QA/QC software for format and content. The data is finally 

submitted to LADCO for emissions processing through the Emissions Modeling System. 

The State provided inventory for Electric Generating Units (EGU) is replaced with the 

Federal EGU inventory. The EGU inventory is compiled by U.S. EPA’s Acid Rain 

Program. It is based on facility reported emissions as measured by continuous 

emissions monitors. In conclusion, the final point source inventory is a hybrid of the 

federal EGU inventory and the state provided non-EGU units. 

A major distinction typically made in emissions inventories is that between point and 

area sources. In this inventory, point sources are sources for which individual records 

are maintained for that source. Such records are maintained for all Ohio Title V facilities 

(706 facilities statewide). The area source inventory accounts for facilities from nonTitle V facilities and calculates emissions information using surrogate emissions factors 

based on energy usage, population, employment records, or other reliable data. A 

more detailed discussion of the area source inventory is provided in Section 2. The 

point source inventory described herein is considered to be the most current and 

accurate source of emissions data available for 2005. 

1.1 Point Source Process Emissions 

Ohio EPA defines point source process emissions as those which occur at an 

identifiable Title V stationary stack or vent. Point source emissions not emitted from 

discrete stacks or vents are termed fugitive emissions and are discussed in Section 1.2. 
5

1.1.1 Source Identification and Data Collection 

The sources to be included in the 2005 base year inventory are identified using the Title 

V STARS database. Facility production and emissions data are included in this 

database. This information is facility-reported actual 2005 emissions. 

1.1.2 Non-reactive VOC Emissions Adjustments 

This section is primarily applicable for VOC pollutants. Sources are required to identify 

emissions of photochemically non-reactive Volatile Organic Compounds (VOC.) Based 

upon this information, those emissions have been specifically excluded from the 2005 

base line inventory in accordance with U.S. EPA’s “Recommended Policy on the 

Control of Volatile Organic Compounds.” A complete list of the compounds that U.S. 

EPA has identified as being photochemically non-reactive, and therefore not included in 

the inventory, are listed below: 

• Methane 

• Ethane 

• Methylene chloride 

• Methyl chloroform 

• Trichlorofluoromethane (CFC-11) 

• Dichlorodifluoromethane (CFC-12) 

• Chlorodifluoromethane (CFC-22) 

• Trifluoromethane (HFC-23) 

• Chlorofluoromethance (HCFC-31) 

• Difluoromethane (HFC-32) 

• Decafluoropentane (HFC-43-10mee) 

• Ethylfluoride (HFC-161) 

• Trichlorotrifluoroethane (CFC-113) 

• Dichlorotetrafluoroethane (CFC-114) 

• Chloropentafluoroethane (CFC-115) 

• 2,2-Dichloro-1,1,1-trifluoroethane (HCFC-123) 

• 1,1,2-Trifluoroethane (HCFC-123a) 

• 2-Chloro-1,1,1,2-tetrafluoroethane (HCFC-124) 

• Pentafluoroethane (HFC-125) 

• 1,1,2,2,-Tetrafluoroethane (HFC-134) 

• 1,1,1,2-Tetrafluoroethane (HFC-134a) 

• 1,1-Dichloro-1-fluoroethane (HCFC-141b) 

• 1-Chloro-1,1,-difluoroethane (HCFC-142b) 

• 1,1,1-Trifluoroethane (HFC-143a) 

• Fluoroethane (HCFC-151a) 

• 1,1-Difluoroethane (HFC-152a) 

• Pentafluoropropane (HFC-225ca) 

• Pentafluoropropane (HFC-225cb) 

• Hexafluoropropane (HFC-236ea) 

• Hexafluoropropane (HFC-236fa) 

• Pentafluoropropane (HFC-245ca) 

• Pentafluoropropane (HFC-245ea) 

• Pentafluoropropane (HFC-245eb) 
6

• Pentafluoropropane (HFC-245fa) 

• Pentafluorobutane (HFC-365mfc) 

• Parachlorobenzotrifluoride (PCBTF) 

• Methoxybutane 

• Nonaflourobutane 

• Heptafluoropropane ((CF3)2CFCF2OCH3) 

• Heptafluoropropane ((CF3)CFCF2OC2H5) 

• Perchloroethylene 

• Cyclic, branched or linear completely methylated siloxanes 

• Methyl acetate 

• Volatile methyl siloxanes 

• Acetone 

1.1.3 Emissions Estimation Methodologies 

Since source reported actual annual emissions are used in the 2005 base year 

inventory, no estimation methods are necessary. The reports are provided to LADCO in 

National Emissions Inventory Input Format (NIF) 3.0 format. LADCO imported and 

processed the NIF files in EMS and applied temporal and spatial profiles to the annual 

emissions to calculate weekday emissions rates. The final point source inventory is 

split into two separate reports, the Electric Generating Units (EGU) which is the U.S. 

EPA inventory for electric generating units and the non-EGU which is the state inventory 

minus the EGU units. 

1.2 Point Source Fugitive Emissions 

Another type of emissions data which is required to be filed from point sources is 

fugitive emissions. Before 1990, fugitive emissions were categorized as area sources 

due to the lack of detailed information available for fugitive sources. However, since 

these emissions are now electronically reported in the State’s ORACLE database, 

STARS, these emissions can be classified as point sources. 

1.3 References 

Getting Started: Emissions Inventory Methods for PM2.5 U.S. Environmental Protection 

Agency, Research Triangle Park, NC, September, 1999. 

Emissions Inventory Guidance for Implementation of Ozone and Particulate Matter 

National Ambient Air Qaulity Standards (NAAQS) and Regional Haze Regulations, 

Office of Air Quality Planning & Standards Research, Triangle Park, NC. November 

2005. 

Compilation of Air Pollution Emission Factors, Fourth Edition and Supplements, AP-42. 

U.S. Environmental Protection Agency, Research Triangle Park, NC, September 1985. 
7

Preparing 2002 Regional PM2.5 Emissions QAQPS PM Inventory Conference Inventory 

Conference San Diego, 2003. 

Documentation for the 2002 Electric Generating Unit National Emissions Inventory 

(NEI). Eastern research group, Inc., 1600 Perimeter Park Drive, Morrisville, NC 27560 

and E.H. Pechan and Associates, Inc., 5528–B Hempstead Way 
8

SECTION 2 

AREA SOURCES 

Area sources are sources which are typically small, individual, numerous, and have not 

been inventoried as specific point, mobile, or biogenic sources. For inventory purposes, 

they are grouped with other like sources into categories that allow emissions to be 

calculated collectively using one methodology. Since area sources are traditionally 

defined at the county level, most methods are designed to estimate area source 

emissions at the county level. 

Ohio EPA has either used published Emission Inventory Improvement Program (EIIP)6

methodologies or selected other methodologies which are shared by other states. The 

decision of which methodology to use was largely based on Ohio’s data availability. 

Data which was not available on a county-level is estimated by assigning a percentage 

of the state’s total activity to each county based on the state’s population or employment 

information. If Ohio county specific activity data is available through Ohio EPA or other 

State Agencies, that data is used rather than allocating activity by percentage. Table 2-1 

lists the sources which emit PM2.5, NOx and SO2 along with the respective EFs used to 

calculate each pollutant. 

Table 2-1 Categories in the 2005 PM2.5 SIP Area Source inventory 

Area Source NOx PM2.5 SO2 Section 

Commercial Natural 

Gas Combustion 94 lb/MMSCF 7.6 lb/MMSCF 0.6 lb/MMSCF 2.1 

Industrial Distillate Oil 

Combustion 20 lb/E3gal fuel 0.25 lb/E3gal fuel 42.6 lb/E3gal fuel 2.2 

Industrial Residual Oil 

Combustion 55 lb/E3gal fuel 4.67 lb/E3gal fuel 157 lb/E3gal fuel 2.2 

Industrial Natural Gas 

Combustion 94 lb/MMSCF 7.6 lb/MMSCF 0.6 lb/MMSCF 2.2 

Residential Coal 

Combustion 9.1 Lb/Ton Coal 3.8 Lb/Ton Coal 31 Lb/Ton Coal 2.3 

Residential Distillate 

Oil Combustion 18 lb/E3gal fuel 0.83 lb/E3gal fuel 42.6 lb/E3gal fuel 2.3 

Residential Natural 

Gas Combustion 94 lb/MMSCF 7.6 lb/MMSCF 0.6 lb/MMSCF 2.3 

Residential LPG 

Combustion 13 lb/E3gal fuel 0.17 lb/E3gal fuel 0.1 lb/E3gal fuel 2.3 

Human Cremation 1.01E+01 lb/Ton 

cremated 

0.0637 lb/Ton 

cremated NA 2.4 

Structure Fires 1.4 Lb/Ton 

burned 

10.8 Lb/Ton 

burned NA 2.5 

Outdoor Wood Boilers 2.8 Lb/Ton 2.76E+1 Lb/Ton 4 E-1 Lb/Ton 2.6 
9

Residential Wood 

Combustion 

Non-Certified 

Non-Catalytic 

Catalytic 

2.80E+00 lb/Ton 

2.80E+00 lb/Ton 

2.00E+00 lb/Ton

3.06E+01 lb/Ton 

1.96E+01 lb/Ton 

2.04E+01 lb/Ton 

4.00E-01 lb/Ton 

4.00E-01 lb/Ton 

4.00E-01 lb/Ton 

2.3 

2.1 Commercial Natural Gas Combustion (SCC 2103006000)

The 2005 total state-level commercial sector energy consumption is obtained from the 

Energy Information Administration (EIA)’s State Energy Data System (SEDS), and 

apportioned per county based on population4

. Emissions factors are given in table 2-1. 

The area source emissions are calculated based on an adjusted value by subtracting 

the emissions due to point sources. 

2.2 Industrial Fuel Combustion 

Industrial Distillate Oil Combustion (SCC 2102004000) 

Ohio’s fuel consumption is apportioned per county based on the county’s population4

. 

The area source NOX emissions are calculated and adjusted by subtracting the 

emissions due to point sources. A heating value of 140 MMBTU/1000 Gal is used and 

84,408 thousand gallons are consumed in 2005. [MMBTU stand for Million British 

Thermal Units]. Emissions factors are given in table 2-1. 

SO2 emissions were calculated using EF 42.6 Lb/1000 Gal. PM10 and PM2.5 emissions

are calculated using 1Lb/1000 Gal and 0.25 Lb/1000 Gal respectively. All Factors are 

obtained from AP-4219 

Industrial Residual Oil Combustion (SCC 2102005000) 

Ohio’s fuel consumption is apportioned per county based on the county’s population4

. 

The area source NOX emissions are calculated and adjusted by subtracting the 

emissions due to point sources. 54,652 thousand gallons14 are consumed in 2005 and 

a heating value of 140 MMBTU/1000 Gal is used. The SO2 emissions are calculated 

using EF 157 Lb/1000 Gal. PM10 and PM2.5 emissions are calculated using 7.17 Lb/1000 

Gal and 4.67 Lb/1000 Gal respectively. All factors are obtained from AP-4219 

Industrial Natural Gas Combustion (SCC 2102006000) 

Ohio’s fuel consumption is apportioned per county based on the county’s population4

. 

The area source NOX emissions are calculated and adjusted by subtracting the 

emissions due to point sources. 293,857 MMCF14 are consumed in 2005. The SO2
10

emissions are calculated using EF 0.6 Lb/MMBTU. The PM10 and PM2.5 emissions are 

calculated using 7.6 Lb/MMBTU. All factors were obtained from AP-4219 

2.3 Residential Fuel Combustion 

Residential Coal Combustion (SCC 2104001000) 

Ohio’s household consumption of coal is apportioned per county based on county 

population4

. NOX emissions are calculated using EF of 9.1 of coal. The SO2 emissions 

are calculated using EF 31Lb/1000 Gal. The PM10 and PM2.5 emissions are calculated 

using 6.2Lb/Ton and 3.8 Lb/Ton respectively. All factors were obtained from AP-4219 

Residential Distillate Oil Combustion (SCC 2104004000) 

Ohio’s household consumption of distillate oil is apportioned per county based on 

county population4. NOX emissions are calculated using EF of 18 lb/1000 gallons 

distillate fuel respectively. A heating value of 140 MMBTU/1000 Gal is used. The SO2

emissions are calculated using EF 42.6 Lb/1000 Gal. The PM10 and PM2.5 emissions

are calculated using 1.08Lb/1000 Gal and 0.83 Lb/1000 Gal respectively. All factors are 

obtained from AP-4219 

Residential Liquid Petroleum Gas Combustion (LPG) 

(SCC 2104007000) 

Ohio’s household consumption of LPG is apportioned per county based on county 

population4. NOX emissions are calculated using EF of 13 lb/1000 gallons LPG. The 

SO2 emissions are calculated using EF 0.1 Lb/1000 Gal. The PM10 and PM2.5 emissions

are calculated using 0.17Lb/1000 Gal. All factors are obtained from AP-4219 

Residential Natural Gas Combustion (SCC 2104006010) 

Ohio’s household consumption of LPG is apportioned per county based on county 

population4

. NOX emissions are calculated using EF of 94 lb/MMSCF. MMSCF stands 

for Million Standard Cubic Feet. This source also emits SO2 emissions which are 

calculated using EF 0.6 Lb/MMBTU. The PM10 and PM2.5 emissions are calculated 

using 7.6Lb/MMBTU. All factors are obtained from AP-4219 

Residential Wood Combustion 

NOX emissions from this area source are calculated for seven types of residential 

heating units that utilize wood for fuel. They are listed below with the appropriate SCC: 

Fireplaces without inserts 2104008001 

Fireplaces with inserts catalytic (non-U.S. EPA cert) 2104008002 

Fireplaces with inserts non -catalytic 2104008003 

Fireplaces with inserts catalytic (U.S. EPA cert) 2104008004 

Wood stoves – Conventional 2104008010 

Woodstoves – Catalytic 2104008030 

Wood stoves – Non catalytic 2104008050 
11

The number of Ohio homes with fireplaces are adjusted for those that burn wood. The 

following assumptions are applied to those adjusted homes: 

92 percent of wood combusted in non-certified units 

5.7 percent of wood combusted in non-catalytic units 

2.3 percent of wood combusted in catalytic units 

A state consumption value is applied which is apportioned to each county based on its 

population4

. Table 2-2 shows the EF used for each of the seven types of indoor wood 

burners which make-up this category: 

Table 2-2 Emission Factors Used for Wood Burners 

SCC 2104008002 2104008003 2104008004 

SCC 2104008010 2104008050 2104008030 

SCC 2104008001 

RAPIDS Code Non-Certified Non-Catalytic Catalytic Units 

SO2 4.00E-01 4.00E-01 4.00E-01 Lb/ton 

NOX 2.80E+00 2.80E+00 2.00E+00 Lb/ton 

PM2.5 3.06E+01 1.96E+01 2.04E+01 Lb/ton

To avoid double counting of wood consumption for fuel, this category is adjusted by 

subtracting the wood consumption from OWB to allow this category to account only for 

indoor wood burning emissions. 

Residential Wood combustion also emits SO2 which is calculated using EF 0.4 Lb/Ton 

EF. The PM2.5 emissions are calculated using EF as shown in table 2-2. All factors are 

obtained from AP-4219 

2.4 Human Cremation (SCC 2810060200) 

 

Not all Ohio counties possess a crematory so only those counties with crematories are 

used to calculate the number of cremations and their resulting NOx emissions. The 

2005 cremation data is obtained from the Ohio Department of Health, Vital Statistics17. 

It is estimated that 3% of deaths occur outside the State of Ohio with no available data 

to account for their disposition at the time this area source is being calculated. 

Therefore, those deaths are not accounted for in this category. 

The methodology does not offer an EF for NOx for this category nor is NOx required to 

be calculated for this area source. Ohio feels that it is a combustion source and NOx 

needs to be included in the inventory along with the other combustion sources. 

Through its Permits-to-Install for human cremation, Ohio has selected a NOx EF of 

10.13lb/ton cremated to calculate emissions from this area source. 
12

This source also emits PM, PM10, and PM2.5 emissions which are calculated using EF 

0.1 Lb/Ton, 0.071Lb/Ton and, 0.0637 Lb/Ton respectively. All factors are obtained from 

AP-4219

2.5 Structure Fires (SCC 2810030000) 

The Structure Fires category includes residential and commercial fires resulting from 

unintentional actions. Intentional fires, forest and wildfires, agricultural, and vehicle 

burning are not included in this area source. The State Fire Marshall Office, Fire 

Prevention Bureau15 provided data on the number of structure fires per county in 2005. 

This area source is considered a combustion source for NOX emissions which are 

calculated using EF 1.4 lb/ton burned. The residential and commercial structures fires 

for each county are tabulated and a fuel loading of 1.15 Ton/fire is applied. This source 

also emits PM, PM10, and PM2.5 emissions which are calculated using EF 10.8 Lb/Ton. 

This factor was obtained from AP-4219 

2.6 Outdoor Wood Boilers (SCC 2104008070) 

Outdoor Wood Boilers (OWB), are also known as outdoor water stoves and outdoor 

wood furnaces, are used as outdoor residential heaters. These boilers have wood 

burning fireboxes surrounded by a water reservoir vented by a chimney stack. The 

combustion of the wood in the firebox heats the water in the surrounding reservoir and 

the heated water is pumped to the residence. OWB units can also supply residential 

hot water. The water capacity ranges from 60 gallons to 764 gallons. The operational 

design creates long periods where the fire smolders and creosote is formed13. 

When the water circulating through the furnace reaches an upper set point, the air 

supply to the fire is cut-off, cooling the fire so the water will not overheat. The furnace 

operates in this "idle" mode until the water temperature hits a lower set point and the air 

supply is re-established. The OWB may be in idle mode far longer than in operating 

mode. This type of operating causes very poor combustion and heavy foul smoke. Most 

of the smoke emitted is fine condensed organic material that does not burn under cool, 

oxygen starved conditions. In addition, many owners burn green wood full of moisture 

which also causes poor combustion12. The smoke created from these outdoor wood 

burning units can contain several pollutants that are harmful to breathe, including fine 

particle pollution such as PM 2.5

11 in addition to NOx (research assisted by Deborah 

Lucas, DAPC intern, 2007) 

This new area source category has many unknowns and variables associated with it 

and Ohio does not possess accurate OWB unit sales data available to calculate 

emissions on the county level. Therefore, several assumptions are made in agreement 

with the Great Lake States in order to formulate a homogeneous inventory for the 

region. 
13

The assumptions are as follows: 

• 100% of wood combusted in non-certified units. 

• OWB units to be 90% in rural counties and 10% in urban counties 

• 11.68 cords of wood consumption per unit per year (includes heating efficiency of 

30-40%) 

• 5 months heating season = 3650 hours (24/7) 

• PM2.5 emissions factor (g/kg wood) =13.82 (Average of indoor and outdoor) or 

27.64 lb/ton of wood 

The agreed upon methodology requires that total number of OWB sold in Ohio be 

apportioned to each county based on rural or urban designation while observing the 9:1 

ratio in area sales. The guesstimated factors (see above) are applied to calculate the 

emissions from this outdoor wood burner. Total emissions obtained from this category 

are subtracted from the Residential Wood Combustion category to allow for accurate 

emissions from the indoor wood burning units. 

 

2.7 References 

1. Documentation For the 2002 Non-Point Source National Emission Inventory For 

CAPS and HAPS. U.S. Environmental Protection Agency. Emissions Factor and 

inventory Group. E.H Pechan and Associates, Inc. January 2004. 

2. United States Census Bureau. Population Division.

http://eire.census.gov/popest/data/counties/tables/CO-EST2002/CO-EST2002-01-

39.php (Accessed 2003) 

3. United States Census Bureau. County Business Patterns. 

http://censtats.census.gov/cbpnaic/cbpnaic.shtml

(Accessed 2003) 

4. Ohio Department of Development, Office of Strategic Research. Population Projects 

by Age and Sex: 2005-2030. http://www.odod.ohio.gov/research/files/p200.htm

(Accessed August 2006) 

5. Environmental Protection Agency (EPA). 1999 Base Year Non-point Source National 

Emission Inventory for Hazardous Air Pollutants, Research Triangle Park, NC. 

September 28, 2001. 

6. Environmental Protection Agency (EPA). STAPPA-ALAPCO-EPA Emission 

Inventory Improvement Program (EIIP). Volume III - Area Sources Preferred and 

Alternative Methods. November 1996. 

7. Documentation for the Draft 1999 National Emissions Inventory (Version 3.0) for 

Criteria Air Pollutants and Ammonia. Area Sources. E. H. Pechan & Associates, Inc. 

March 3, 2003 
14

8. U.S. Environmental Protection Agency, STAPPA-ALAPCO-EPA Emission Inventory 

Improvement Program (EIIP), Volume III - Area Sources Preferred and Alternative 

Methods, Chapter 8. September 1997. 

9. Spreadsheet formulation provided by “Buzz” David Asselmeier, Air Quality Planning 

Section, Inventory Group, Springfield, Illinois. 

10. Environmental Protection Agency (EPA). STAPPA-ALAPCO-EPA Emission 

Inventory Improvement Program (EIIP). Volume III - Area Sources Preferred and 

Alternative Methods. May 1997. 

11. (Environmental Chemistry.com) viewed on Feb 8th, 2007. 

[http://environmentalchemistry.com/yogi/environmental/200602outdoorwoodfurnaces.ht

ml] 

12. (Washington State, Department of Ecology) viewed on Feb 8th, 2007 

[http://www.ecy.wa.gov/programs/air/AOP_Permits/Boiler/Outdoor_Boilers_home.html]

13. U.S. Environmental Protection Agency. Reducing Pollution from Outdoor WoodFired Hydronic Heaters. Fact Sheet

http://www.epa.gov/owhh/pdfs/fact_sheet_1_29_07.pdf (Accessed 1/2007) 

14. Industrial Sector Energy Price and Expenditure Estimates, 1970-2001, Ohio. 

Energy Information Administration. U. S. Department of Energy. 

http://www.eia.doe.gov/emeu/states/sep_prices/ind/pr_ind_oh.html

http://www.eia.doe.gov/emeu/aer/pdf/pages/sec1_27.pdf (Accessed 2003) 

15. State Fire Marshal Office. Fire Prevention Bureau, Columbus, Ohio. 

http://www.com.state.oh.us/odoc/sfm/firecont.htm (Accessed 2003) 

16. Documentation for the Draft 1999 National Emissions Inventory (Version 3.0) For 

Criteria Air Pollutants and Ammonia. Area Sources. E. H. Pechan & Associates, Inc. 

March 3, 2003 

17. Ohio Department of Health, Vital Statistics 

18. Environmental Protection Agency. STAPPA-ALAPCO-EPA Emission Inventory 

Improvement Program (EIIP). Volume X – Emissions Projections. December 1999. 

http://www.epa.gov/ttn/chief/eiip/techreport/volume10/x01.pdf

(Accessed 2/2007) 

19. Environmental Protection Agency. AP-42. http://www.epa.gov/ttn/chief/ap42/ 
15

SECTION 3

NON-ROAD SOURCES 

The non-road inventory is generated regionally by running U.S. EPA’s National Mobile 

Inventory Model (NMIM) model. The Wisconsin Department of Natural Resources 

undertook the responsibility of customizing the NMIM input files and submitting the 

output file in NIF format to LADCO and U.S. EPA. LADCO processed the NMIM files in 

their emissions model and generated daily emissions rates. Grant Heatherington from 

the Wisconsin Department of Natural Resources provided the following descriptions... 

The National Mobile Inventory Model (NMIM) developed by USEPA was used to 

estimate emissions for all other non-road mobile categories. NMIM consolidates nonroad mobile emissions and on-road emissions modeling into a single modeling system. 

Only the non-road emissions modeling portion of NMIM was used in the development of 

this emission’s inventory. NMIM uses the USEPA’s NONROAD model to calculate nonroad mobile emissions. The basic NONROAD algorithm for calculating emissions uses 

base year equipment populations, average load factors, available engine powers, 

activity hours and emission factors. Before NMIM was run, modifications and additions 

were made to the NMIM input data. 

a. Added emission factors for diesel tampers/rammers provided by E.H. 

Pechan & Associates, Inc. Diesel tampers/rammers are a type of 

construction equipment. 

b. Revised PM2.5 ratios in SCC table to correctly calculate PM2.5 diesel 

emissions. This error was introduced with NMIM2005 and didn’t exist in 

NMIM2004. 

c. Revised gasoline parameters using updates provided by the states and 

E.H. Pechan & Associates, Inc. Gasoline parameters include Reid Vapor 

Pressure (RVP), oxygenate content and sulfur content. 

The NMIM NEI NIF files are on the LADCO ftp site at: 

ftp://ftp.airtoxics.org/inv2005/nonroad/NMIM/Base_L_ph2/2005/

Revised NMIM2005 Input Data 

Emission Factor Data 

All States: Pechan revised the brake specific fuel consumption (BSFC) emission factor data to 

include diesel tampers/rammers (2270002006). The revised NMIM file is saved as 

revBSFC.EMF.