March 10, 2003 73 of 80 dwcgi 5548 1049746973 175081000. xls  861  1998 Record for the Section 316( b) Phase II Existing Facilities Notice of Data Availability 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 59 A B C D E F G H I J from * P2 F: 861 Data  1999 query in 316bPlnt. mdb Revenues in $ 000 Original UTILCODE Original UTILNAME  1999 Sales to Consmers Sales for Resale Sales to Pwr Mrkt Frnshd W/ O Chrg Used by Elec Dpt Energy Losses Total Disposition Retail Revenue 189 Alabama Electric Coop Inc 107,220 6,798,317 83,071  40,293 230,547 7,259,448 3,443 195 Alabama Power Co 50,157,204 16,971,081 148,651 1,750 137,222 2,973,977 70,389,885 2,811,117 733 Appalachian Power Co 27,933,324 9,804,230  998  2,547,673 40,286,225 1,292,237 803 Arizona Public Service Co 20,961,836 1,465,412 15,603,782  55,960 1,082,960 39,169,950 1,716,236 807 Arkansas Electric Coop Corp  11,361,256 238,849   354,648 11,954,753

814 Entergy Arkansas Inc 18,663,671 12,460,205   52,078 1,696,716 32,872,670 1,172,352 924 Associated Electric Coop Inc 1,305,349 17,425,258 454,163  8,713 1,075,284 20,268,767 30,767 963 Atlantic City Electric Co 8,831,691 462,226   16,702 903,118 10,213,737 936,227 1009 Austin City of 299,795 125,608   1,042 14,994 441,439 18,923 1015 Austin City of 9,833,880 224,129    260,826 10,318,835 637,275 1167 Baltimore Gas & Electric Co 29,264,078 4,784,739   128,101 1,738,519 35,915,437 2,118,845 1307 Basin Electric Power Coop 761,492 14,840,968 33,169   748,169 16,383,798 23,607 1692 Big Rivers Electric Corp  3,513,100 695,745   73,700 4,282,545

1998 Boston Edison Co 12,864,155 1,660,340   53,300 1,106,182 15,683,977 1,338,479 2172 Brazos Electric Power Coop Inc  6,880,957    297,564 7,178,521

2442 Bryan City of 928,133 485,915    51,341 1,465,389 67,929 2777 Cajun Electric Power Coop Inc  9,112,715 696,456   303,174 10,112,345

2886 Cambridge Electric Light Co 1,377,503 108,438 15,871  1,529 23,913 1,527,254 104,801 2951 Canal Electric Co  306,012     306,012

3006 Cardinal Operating Co 3046 Carolina Power & Light Co 40,217,290 13,272,154 1,269,717  89,218 1,949,233 56,797,612 2,519,348 3242 Central Electric Power Coop  2,480,356     2,480,356

3249 Central Hudson Gas & Elec Corp 4,562,393 344,574 888,174 172 9,973 310,475 6,115,761 387,836 3252 Central Illinois Light Co 6,073,448 136,514 464,430  14,716 242,254 6,931,362 350,727 3253 Central Illinois Pub Serv Co 8,538,572 4,140,896 1,165,491   832,428 14,677,387 544,132 3258 Central Iowa Power Coop  2,455,981   1,932 56,501 2,514,414

3265 Cleco Utility Group Inc 8,099,438 78,075 6,236,084 4 10,517 666,289 15,090,407 468,169 3266 Central Maine Power Co 9,144,308 665,751 183,973 25 22,514 607,188 10,623,759 892,792 3277 Central Operating Co 3278 Central Power & Light Co 21,303,608 1,812,583 59  26,720 1,755,086 24,898,056 1,306,971 3285 UtiliCorp United 3542 Cincinnati Gas & Electric Co 20,070,826 11,419,890 16,146,827  22,539 1,062,027 48,722,109 1,259,683 3755 Cleveland Electric Illum Co 20,021,621 2,607,480   44,095 1,012,059 23,685,255 1,743,148 4062 Columbus Southern Power Co 16,435,078 4,104,661    1,144,148 21,683,887 1,062,454 4110 Commonwealth Edison Co 83,500,597 15,419,076 4,068,211 391,752  7,393,955 110,773,591 6,175,861 4176 Connecticut Light & Power Co 22,315,405 6,941,382    1,358,858 30,615,645 2,190,813 4226 Consolidated Edison Co NY Inc 32,630,506  9,105,786 38 151,090 2,332,375 44,219,795 4,500,992 4254 Consumers Energy Co 35,754,796 4,624,800   17,405 2,462,496 42,859,497 2,498,266 4538 Crisp County Power Comm 363,989    586 15,299 379,874 20,130 4716 Dairyland Power Coop  5,027,364  694 20,178 228,147 5,276,383

4922 Dayton Power & Light Co 14,315,947 1,739,779 831,160  18,326 1,345,982 18,251,194 964,329 5027 Delmarva Power & Light Co 13,733,682 9,157,794  38,828  667,355 23,597,659 947,410 5107 Detroit City of 570,428    20,000 39,480 629,908 45,585 5109 Detroit Edison Co 49,822,240 5,702,235   219,169 3,632,413 59,376,057 3,791,116 5416 Duke Energy Corp 74,109,763 6,529,110 908,799  211,460 4,960,103 86,719,235 4,093,115 5487 Duquesne Light Co 8,925,000 3,347,189   43,040 969,608 13,284,837 782,274 5580 East Kentucky Power Coop Inc  10,157,035 419,974  8,157 311,612 10,896,778

5748 Electric Energy Inc 7,013,929 4,104,491    69,252 11,187,672 136,875 5860 Empire District Electric Co 3,859,166 297,614 198,234  7,043 309,406 4,671,463 219,512 6204 Farmington City of 783,608 13,670 92,119   37,685 927,082 52,030 6452 Florida Power & Light Co 84,450,082 2,120,101 1,496,319  153,396 5,850,345 94,070,243 5,830,116 6455 Florida Power Corp 33,441,029 4,856,238   125,923 2,326,200 40,749,390 2,361,848 6616 Fort Pierce Utilities Auth 552,308   1,163  24,760 578,231 46,455 6958 Garland City of 1,993,111 374,264  1,265  102,265 2,470,905 136,105 7140 Georgia Power Co 70,972,000 6,537,777 318,397  146,386 3,543,879 81,518,439 4,129,088 7353 Golden Valley Elec Assn Inc 1,049,024 326   3,572 71,387 1,124,309 79,623 7423 GPU Nuclear Corp March 10, 2003 74 of 80 dwcgi 5548 1049746973 175081000. xls  861  1999 Record for the Section 316( b) Phase II Existing Facilities Notice of Data Availability 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 59 K L M N O P Q R S T U 00s Resale Revenue Rev Adjustments Other ( 456) Revenue Total Revenue Total Sales Total Electricity Revenue NERC Electricity Revenue per MWh Sold ( Average) Revenue per MWH Sold ( Retail) Revenue per MWH Sold ( Wholesale) Percent of Total Disposition Sold 272,086  2,765 278,294 6,988,608 275,529,000 SERC 39.82 32.11 39.54 96%

507,816  66,540 3,385,473 67,276,936 3,318,933,000 SERC 50.32 56.05 29.66 96%

269,368 8,688 80,644 1,650,937 37,737,554 1,570,293,000 ECAR 43.75 46.26 27.47 94%

301,534  36,949 2,054,719 38,031,030 2,017,770,000 WSCC 54.03 81.87 17.67 97%

394,069  52 394,121 11,600,105 394,069,000 SPP 33.98 33.97 97%

371,599  ( 2,057) 1,541,894 31,123,876 1,543,951,000 SERC 49.54 62.81 29.82 95%

587,963  5,314 624,044 19,184,770 618,730,000 SERC 32.53 23.57 32.88 95%

65,291  57,310 1,058,828 9,293,917 1,001,518,000 MAAC 113.93 106.01 141.25 91%

  120 19,043 425,403 18,923,000 MAPP 44.76 63.12 96%

25,303  31,943 694,521 10,058,009 662,578,000 ERCOT 69.05 64.80 112.89 97%

112,086  29,047 2,259,978 34,048,817 2,230,931,000 MAAC 66.37 72.40 23.43 95%

435,766   459,373 15,635,629 459,373,000 MAPP 29.38 31.00 29.30 95%

141,918  8,376 150,294 4,208,845 141,918,000 ECAR 35.71 33.72 98%

117,547 2,642 82,774 1,541,442 14,524,495 1,458,668,000 NPCC 106.13 104.05 70.80 93%

301,662  6,392 308,054 6,880,957 301,662,000 ERCOT 44.77 43.84 96%

26,588  3,730 98,247 1,414,048 94,517,000 ERCOT 69.48 73.19 54.72 96%

367,348  1,214 368,562 9,809,171 367,348,000 SERC 37.57 37.45 97%

6,072  873 111,746 1,501,812 110,873,000 NPCC 74.41 76.08 48.85 98%

43,571  3,771 47,342 306,012 43,571,000 NPCC 154.71 142.38 100%

  ECAR 554,682 2,500 81,838 3,158,368 54,759,161 3,076,530,000 SERC 57.68 62.64 38.14 96%

82,753  407 83,160 2,480,356 82,753,000 MAIN 33.53 33.36 100%

40,740  ( 767) 427,809 5,795,141 428,576,000 NPCC 73.82 85.01 33.05 95%

21,206  4,611 376,544 6,674,392 371,933,000 MAIN 56.42 57.75 35.29 96%

167,245 2,086 30,349 743,812 13,844,959 713,463,000 MAIN 53.72 63.73 31.52 94%

97,079  4,630 101,709 2,455,981 97,079,000 MAPP 41.41 39.53 98%

217,057 ( 2,776) 26,085 708,535 14,413,597 682,450,000 SPP 49.16 57.80 34.38 96%

30,591  44,222 967,605 9,994,032 923,383,000 NPCC 96.82 97.63 36.00 94%

  ECAR 75,836 ( 524) 100,192 1,482,475 23,116,250 1,382,283,000 ERCOT 64.13 61.35 41.84 93%

  WSCC 845,872  14,831 2,120,386 47,637,543 2,105,555,000 ECAR 44.51 62.76 30.68 98%

63,544  42,870 1,849,562 22,629,101 1,806,692,000 ECAR 81.73 87.06 24.37 96%

120,374  47,166 1,229,994 20,539,739 1,182,828,000 ECAR 59.88 64.65 29.33 95%

490,938  181,148 6,847,947 102,987,884 6,666,799,000 MAIN 66.49 73.96 25.19 93%

239,994 ( 30,278) 52,326 2,452,855 29,256,787 2,400,529,000 NPCC 83.84 98.17 34.57 96%

294,698 ( 10,256) 899,654 5,685,088 41,736,292 4,785,434,000 NPCC 136.21 137.94 32.36 94%

138,836 ( 13,354) 42,726 2,666,474 40,379,596 2,623,748,000 ECAR 66.04 69.87 30.02 94%

   20,130 363,989 20,130,000 SERC 55.30 55.30 96%

163,417  10,377 173,794 5,027,364 163,417,000 MAPP 34.57 32.51 95%

79,008  17,267 1,060,604 16,886,886 1,043,337,000 ECAR 62.81 67.36 30.73 93%

402,702  35,206 1,385,318 22,891,476 1,350,112,000 MAAC 60.52 68.98 43.97 97%

   45,585 570,428 45,585,000 ECAR 79.91 79.91 91%

181,694 ( 8,439) 37,387 4,001,758 55,524,475 3,964,371,000 ECAR 72.07 76.09 31.86 94%

449,371  92,319 4,634,805 81,547,672 4,542,486,000 SERC 56.84 55.23 60.42 94%

76,303  295,661 1,154,238 12,272,189 858,577,000 ECAR 94.05 87.65 22.80 92%

344,934  10,564 355,498 10,577,009 344,934,000 ECAR 33.61 32.61 97%

75,624  195 212,694 11,118,420 212,499,000 MAIN 19.13 19.51 18.42 99%

17,772  3,781 241,065 4,355,014 237,284,000 SPP 55.35 56.88 35.84 93%

1,104  1,897 55,031 889,397 53,134,000 WSCC 61.87 66.40 10.44 96%

167,334 ( 35,121) 95,163 6,057,492 88,066,502 5,962,329,000 FRCC 68.78 69.04 46.27 94%

228,855 ( 798) 42,677 2,632,582 38,297,267 2,589,905,000 FRCC 68.74 70.63 47.13 94%

 ( 3,946) 579 43,088 552,308 42,509,000 FRCC 78.01 84.11 96%

24,170  867 161,142 2,367,375 160,275,000 ERCOT 68.07 68.29 64.58 96%

285,522 ( 72,450) 110,151 4,452,311 77,828,174 4,342,160,000 SERC 57.21 58.18 41.64 95%

7  1,228 80,858 1,049,350 79,630,000 ASCC 77.06 75.90 21.47 93%

  MAAC March 10, 2003 75 of 80 dwcgi 5548 1049746973 175081000. xls  861  1999 Record for the Section 316( b) Phase II Existing Facilities Notice of Data Availability 60 61 62 63 64 65 66 67 68 69 70 71 72 73 74 75 76 77 78 79 80 81 82 83 84 85 86 87 88 89 90 91 92 93 94 95 96 97 98 99 100 101 102 103 104 105 106 107 108 109 110 111 112 113 114 115 116 117 118 119 120 A B C D E F G H I J 7483 Grand Haven City of 299,984 68,189   411 6,173 374,757 20,469 7490 Grand River Dam Authority 819,483 4,380,695 412,687   288,646 5,901,511 26,068 7570 Great River Energy  12,055,008 450 60,127 34,332 850,586 13,000,503

7634 Greenville Electric Util Sys 460,564 19,021    18,033 497,618 31,278 7801 Gulf Power Co 9,559,183 334,030 3,739,926 11,378 21,179 538,254 14,203,950 512,760 7806 Entergy Gulf States Inc 34,347,913 4,085,288   3,912 1,738,700 40,175,813 1,788,538 7977 Hamilton City of 573,626 41,060  11,126  38,353 664,165 41,787 8723 Holland City of 982,015     65,149 1,047,164 55,339 8779 Holyoke Water Power Co 95,883 1,918,013     2,013,896 5,897 8901 Reliant Energy HL& P 69,374,552 2,732,346    3,178,954 75,285,852 4,247,269 9162 IES Utilities Inc 10,454,840 1,363,894   21,512 563,322 12,403,568 593,690 9208 Illinois Power Co 18,215,452 1,507,217 5,019,048 59,387 60,366 1,178,638 26,040,108 1,138,822 9231 Independence City of 928,032 36,401 3,006  1,754 66,777 1,035,970 63,442 9267 Hoosier Energy R E C Inc  10,057,941    276,637 10,334,578

9269 Indiana Kentucky Electric Corp  8,487,027    44,841 8,531,868

9273 Indianapolis Power & Light Co 13,848,628 1,582,338 418,810  27,646 602,034 16,479,456 748,570 9324 Indiana Michigan Power Co 18,339,892 7,580,518  75  1,713,850 27,634,335 1,039,934 9392 Interstate Power Co 5,311,928 878,615   9,112 271,770 6,471,425 261,799 9617 Jacksonville Electric Auth 10,768,701 3,315,840 426,737   559,186 15,070,464 613,099 9726 Jersey Central Power& Light Co 18,951,186 1,622,166   59,456 1,818,301 22,451,109 2,010,735 9996 Kansas City City of 2,223,243 369,264  35,355 52,808 133,195 2,813,865 112,906 10000 Kansas City Power & Light Co 13,342,151 2,134,987 114,166  31,129 824,170 16,446,603 838,641 10015 KPL Western Resources Co 10171 Kentucky Utilities Co 16,307,546 6,575,903 3,612,466 54 20,650 1,141,180 27,657,799 638,959 10623 Lakeland City of 2,463,295 232,882 21,060   75,471 2,792,708 173,314 10704 Lansing City of 2,307,666 903,289    72,511 3,283,466 130,774 11142 Logansport City of 383,633     21,389 405,022 20,520 11208 Los Angeles City of 20,056,691 1,380,268 2,885,850  90,000 1,587,519 26,000,328 2,080,736 11241 Entergy Louisiana Inc 29,095,658 1,245,680   39,369 1,206,613 31,587,320 1,686,442 11249 Louisville Gas & Electric Co 11,203,916 4,802,858 3,625,614 780 124,691 434,806 20,192,665 559,791 11269 Lower Colorado River Authority 66,654 11,221,255    461,035 11,748,944 2,322 11479 Madison Gas & Electric Co 2,916,533 312,861   516 158,044 3,387,954 179,844 11571 Manitowoc Public Utilities 537,649 4,189   426 15,672 557,936 28,325 11701 Marquette City of 262,441 33,978   567 12,758 309,744 16,343 12298 Menasha City of 573,002 13,992   253 11,677 598,924 22,843 12341 MidAmerican Energy Co 16,007,300 5,845,003 1,322,446  49,469 2,058,656 25,282,874 1,024,652 12390 Metropolitan Edison Co 6,832,063 4,596,975   36,701 587,540 12,053,279 573,978 12647 Minnesota Power Inc 8,429,549 1,882,414 1,032,340  15,605 404,368 11,764,276 354,497 12658 Minnkota Power Coop Inc 34,466 3,770,802 61,096 36,952 6,948 247,734 4,157,998 638 12685 Entergy Mississippi Inc 12,517,845 2,199,433   15,576 925,542 15,658,396 737,120 12686 Mississippi Power Co 9,543,133 3,796,114   43,134 124,033 13,506,414 469,434 12698 UtiliCorp United Inc 8,121,358 3,028,622   18,784 773,789 11,942,553 505,765 12796 Monongahela Power Co 10,794,563 2,997,007 68,234  24,166 716,315 14,600,285 561,175 12819 Montana Dakota Utilities Co 12825 Montana Power Co 5,326,478 5,659,115 663,309   1,238,558 12,887,460 332,304 12833 Montaup Electric Co  3,563,080     3,563,080

13143 Muscatine City of 891,533 169,629 230,041 4,942 3,106 33,547 1,332,798 41,550 13262 North Atlantic Engy Serv Corp 13337 Nebraska Public Power District 3,094,328 14,300,534   10,656 653,617 18,059,135 163,102 13433 New England Power Co 6,530 2,860,129 103,774  1,458 433,754 3,405,645 457 13478 Entergy New Orleans Inc 5,896,732 621,918   2,325 256,837 6,777,812 393,928 13511 New York State Elec & Gas Corp 13,192,379 333,831 5,188,532 5 20,725 1,586,130 20,321,602 1,492,881 13573 Niagara Mohawk Power Corp 33,756,106 966,802 695,365  82,271 1,642,346 37,142,890 3,043,028 13756 Northern Indiana Pub Serv Co 15,627,599 1,163,598 1,423,396   701,102 18,915,695 1,000,390 13781 Northern States Power Co 31,645,688 11,794,258  1,304 42,511 2,638,918 46,122,679 1,922,997 13998 Ohio Edison Co 24,946,704 6,124,176   35,002 778,955 31,884,837 2,093,478 14006 Ohio Power Co 31,982,889 18,869,866    2,526,182 53,378,937 1,393,498 14015 Ohio Valley Electric Corp 9,805,889 6,538,119    225,274 16,569,282 197,877 14063 Oklahoma Gas & Electric Co 21,916,854 1,925,303  69,449 38,795 1,632,456 25,582,857 1,191,079 14127 Omaha Public Power District 8,145,388 1,829,028 1,449,666   389,336 11,813,418 440,187 14154 Orange & Rockland Utils Inc 3,509,266 1,708,173  16 19,475 265,774 5,502,704 332,249 March 10, 2003 76 of 80 dwcgi 5548 1049746973 175081000. xls  861  1999 Record for the Section 316( b) Phase II Existing Facilities Notice of Data Availability 60 61 62 63 64 65 66 67 68 69 70 71 72 73 74 75 76 77 78 79 80 81 82 83 84 85 86 87 88 89 90 91 92 93 94 95 96 97 98 99 100 101 102 103 104 105 106 107 108 109 110 111 112 113 114 115 116 117 118 119 120 K L M N O P Q R S T U 1,443 1,022  22,934 368,173 22,934,000 ECAR 62.29 68.23 21.16 98%

156,370  1,903 184,341 5,612,865 182,438,000 SPP 32.84 31.81 32.62 95%

395,522  14,937 410,459 12,055,458 395,522,000 MAPP 34.05 32.81 93%

2,036  770 34,084 479,585 33,314,000 ERCOT 71.07 67.91 107.04 96%

128,464  32,875 674,099 13,633,139 641,224,000 SERC 49.45 53.64 31.53 96%

147,547 94,835 53,438 2,084,358 38,433,201 2,030,920,000 SERC 54.23 52.07 36.12 96%

1,991  832 44,610 614,686 43,778,000 ECAR 72.57 72.85 48.49 93%

   55,339 982,015 55,339,000 ECAR 56.35 56.35 94%

67,063 ( 5) 700 73,655 2,013,896 72,955,000 NPCC 36.57 61.50 34.96 100%

83,992  151,866 4,483,127 72,106,898 4,331,261,000 ERCOT 62.17 61.22 30.74 96%

29,439 ( 1,221) 7,037 628,945 11,818,734 621,908,000 MAPP 53.22 56.79 21.58 95%

420,245  35,959 1,595,026 24,741,717 1,559,067,000 MAIN 64.47 62.52 64.39 95%

2,891  709 67,042 967,439 66,333,000 SPP 69.30 68.36 73.36 93%

316,394  189 316,583 10,057,941 316,394,000 ECAR 31.48 31.46 97%

155,381  67 155,448 8,487,027 155,381,000 ECAR 18.32 18.31 99%

41,167  10,600 800,337 15,849,776 789,737,000 ECAR 50.50 54.05 20.57 96%

303,533 ( 1,143) 51,795 1,394,119 25,920,410 1,342,324,000 ECAR 53.78 56.70 40.04 94%

25,163 ( 1,182) 9,209 294,989 6,190,543 285,780,000 MAPP 47.65 49.29 28.64 96%

145,569  25,625 784,293 14,511,278 758,668,000 FRCC 54.05 56.93 38.90 96%

64,262 ( 112,200) 29,460 1,992,257 20,573,352 1,962,797,000 MAAC 96.84 106.10 39.61 92%

20,280  3,329 136,515 2,592,507 133,186,000 SPP 52.66 50.78 54.92 92%

49,741  9,011 897,393 15,591,304 888,382,000 SPP 57.56 62.86 22.12 95%

  SPP 286,595 1,437 10,319 937,310 26,495,915 926,991,000 ECAR 35.38 39.18 28.13 96%

17,453  6,355 197,122 2,717,237 190,767,000 FRCC 72.55 70.36 68.73 97%

25,161  2,202 158,137 3,210,955 155,935,000 ECAR 49.25 56.67 27.85 98%

  556 21,076 383,633 20,520,000 ECAR 54.94 53.49 95%

174,872  33,488 2,289,096 24,322,809 2,255,608,000 WSCC 94.11 103.74 40.99 94%

81,177 ( 52,676) 91,651 1,806,594 30,341,338 1,714,943,000 SERC 59.54 57.96 65.17 96%

221,336 ( 2,479) 12,022 790,670 19,632,388 778,648,000 ECAR 40.27 49.96 26.26 97%

442,833 ( 12,816) 11,752 444,091 11,287,909 432,339,000 ERCOT 39.34 34.84 39.46 96%

7,164  ( 679) 186,329 3,229,394 187,008,000 MAIN 57.70 61.66 22.90 95%

821  454 29,600 541,838 29,146,000 MAIN 54.63 52.68 195.99 97%

2,606  667 19,616 296,419 18,949,000 MAIN 66.18 62.27 76.70 96%

1,498  406 24,747 586,994 24,341,000 MAIN 42.16 39.87 107.06 98%

151,717 ( 16,492) 18,619 1,178,496 23,174,749 1,159,877,000 MAPP 50.85 64.01 21.17 92%

163,466 27,200 138,183 902,827 11,429,038 764,644,000 MAAC 78.99 84.01 35.56 95%

117,423  15,925 487,845 11,344,303 471,920,000 MAPP 43.00 42.05 40.29 96%

104,228  4,862 109,728 3,866,364 104,866,000 MAPP 28.38 18.51 27.20 93%

94,550  1,150 832,820 14,717,278 831,670,000 SERC 56.59 58.89 42.99 94%

150,450  13,120 633,004 13,339,247 619,884,000 SERC 47.45 49.19 39.63 99%

148,779  7,477 662,021 11,149,980 654,544,000 SPP 59.37 62.28 49.12 93%

150,942  24,643 736,760 13,859,804 712,117,000 ECAR 53.16 51.99 49.24 95%

  MAPP 178,889  53,294 564,487 11,648,902 511,193,000 WSCC 48.46 62.39 28.29 90%

243,756  19,501 263,257 3,563,080 243,756,000 NPCC 73.88 68.41 100%

10,079  1,413 53,042 1,291,203 51,629,000 MAPP 41.08 46.61 25.22 97%

  NPCC 396,978 17,974 18,996 597,050 17,394,862 578,054,000 MAPP 34.32 52.71 27.76 96%

89,519 663 505,702 596,341 2,970,433 90,639,000 NPCC 200.76 69.98 30.20 87%

24,752 ( 3,500) 11,389 426,569 6,518,650 415,180,000 SERC 65.44 66.80 39.80 96%

185,657  84,653 1,763,191 18,714,742 1,678,538,000 NPCC 94.21 113.16 33.62 92%

47,988  156,571 3,247,587 35,418,273 3,091,016,000 NPCC 91.69 90.15 28.87 95%

73,850  33,292 1,107,532 18,214,593 1,074,240,000 ECAR 60.80 64.01 28.55 96%

152,442  191,103 2,266,542 43,439,946 2,075,439,000 MAPP 52.18 60.77 12.93 94%

238,516  33,970 2,365,964 31,070,880 2,331,994,000 ECAR 76.15 83.92 38.95 97%

572,136  82,888 2,048,522 50,852,755 1,965,634,000 ECAR 40.28 43.57 30.32 95%

146,868  743 345,488 16,344,008 344,745,000 ECAR 21.14 20.18 22.46 99%

70,811  24,954 1,286,844 23,842,157 1,261,890,000 SPP 53.97 54.35 36.78 93%

78,741 ( 5,000) 9,802 523,730 11,424,082 513,928,000 MAPP 45.84 54.04 24.02 97%

77,982 ( 22,573) 8,043 395,701 5,217,439 387,658,000 NPCC 75.84 94.68 45.65 95%

March 10, 2003 77 of 80 dwcgi 5548 1049746973 175081000. xls  861  1999 Record for the Section 316( b) Phase II Existing Facilities Notice of Data Availability 121 122 123 124 125 126 127 128 129 130 131 132 133 134 135 136 137 138 139 140 141 142 143 144 145 146 147 148 149 150 151 152 153 154 155 156 157 158 159 160 161 162 163 164 165 166 167 168 169 170 171 172 173 174 175 176 177 178 179 A B C D E F G H I J 14232 Otter Tail Power Co 3,393,860 1,222,510  28 12,118 1,016,683 5,645,199 183,478 14268 Owensboro City of 843,523 1,877,905   2,239 27,420 2,751,087 35,611 14328 Pacific Gas & Electric Co 70,186,749 110,336 76,803  28,289 8,481,649 78,883,826 6,785,994 14354 PacifiCorp 46,605,155 25,032,336 11,283,162  59,713 4,349,651 87,330,017 2,172,555 14610 Orlando Utilities Comm 4,497,553 2,869,519    47,466 7,414,538 289,142 14711 Pennsylvania Electric Co 8,190,632 4,219,325  1,610,275 38,491 632,789 14,691,512 612,166 14715 PPL Electric Utilities Corp 23,397,070 948,788 30,760,598  126,083 1,317,726 56,550,265 1,761,778 14716 Pennsylvania Power Co 3,306,062 1,117,867   6,103 1,101,411 5,531,443 240,158 14839 Peru City of 225,538     8,944 234,482 11,321 14940 PECO Energy Co 23,593,639 26,571,644 15,237,144  79,442 1,308,126 66,789,995 2,066,833 15095 Piqua City of 282,275 1,892  3,112  17,386 304,665 16,041 15263 Potomac Edison Co 13,174,622 1,711,722 75,628  8,082 918,632 15,888,686 715,280 15270 Potomac Electric Power Co 24,209,242 5,036,509   92,159 1,345,456 30,683,366 1,788,040 15296 Power Authority of State of NY 13,791,769 25,372,359 181,988 9,075 13,978 513,877 39,883,046 815,368 15466 Public Service Co of Colorado 23,337,607 5,204,356 12,792,874  40,298 1,116,903 42,492,038 1,375,599 15470 PSI Energy Inc 26,100,392 10,239,019 18,732,320  42,741 1,251,915 56,366,387 1,251,314 15472 Public Service Co of NH 6,957,064 5,875,136    613,778 13,445,978 853,654 15477 Public Service Electric& Gas Co 40,289,444 1,609,558 8,102,062  327,406 2,683,829 53,012,299 3,873,893 16181 Rochester Public Utilities 1,041,482 211,991   5,609 19,081 1,278,163 67,276 16183 Rochester Gas & Electric Corp 6,296,112 1,874,925 200  38,174 324,660 8,534,071 608,628 16604 San Antonio Public Service Bd 15,630,348 536,098 261,514  51,271 896,970 17,376,201 887,958 16609 San Diego Gas & Electric Co 14,718,306 109,390 273,994  20,426 392,571 15,514,687 1,415,141 16687 Savannah Electric & Power Co 3,712,902 128,537   50,903 146,659 4,039,001 238,804 17166 Sierra Pacific Power Co 8,432,466 1,786,004   15,911 585,601 10,819,982 548,507 17539 South Carolina Electric& Gas Co 18,878,812 2,096,105 771,097 7,975 81,558 1,041,772 22,877,319 1,124,176 17543 South Carolina Pub Serv Auth 10,059,501 10,225,961   14,823 468,661 20,768,946 403,268 17554 South Carolina Genertg Co Inc  4,462,825     4,462,825

17583 South Texas Electric Coop Inc  1,345,710 223,612  282 68,061 1,637,665

17609 Southern California Edison Co 67,206,530 393,800 1,600  153,003 11,277,637 79,032,570 6,692,164 17632 Southern Illinois Power Coop  1,337,020 188,794  540 34,702 1,561,056

17633 Southern Indiana Gas & Elec Co 5,110,945 1,599,157 230,613  3,949 298,828 7,243,492 242,317 17698 Southwestern Electric Power Co 16,049,294 7,500,927 20,590 56,556 16,523 958,029 24,601,919 776,476 17828 Springfield City of 1,684,179 260,134 1,397,977 29,821 3,625 92,767 3,468,503 99,762 17833 Springfield City of 2,575,588 407,731  74,559 2,036 117,389 3,177,303 116,716 17881 St Joseph Light & Power Co 1,667,937 160,972   7,003 128,922 1,964,834 87,028 18125 Stillwater Utilities Authority 448,119   12,712  21,349 482,180 25,123 18445 Tallahassee City of 2,357,583 99,961 35,656   139,717 2,632,917 173,098 18454 Tampa Electric Co 15,804,958 2,160,194   48,724 881,350 18,895,226 1,100,103 18642 Tennessee Valley Authority 25,051,417 123,650,599   9,605 3,804,988 152,516,609 735,346 18715 Texas Municipal Power Agency  3,042,555    32,826 3,075,381

18997 Toledo Edison Co 9,866,345 2,408,951   32,389 955,211 13,262,896 762,405 19390 UGI Utilities Inc 852,790 25,667   2,188 97,867 978,512 70,381 19436 Union Electric Co 33,565,723 5,523,774 1,341,989   2,486,101 42,917,587 2,036,863 19497 United Illuminating Co 5,652,050 1,009,866   11,781 278,710 6,952,407 639,596 19547 Hawaiian Electric Co Inc 6,997,936    15,728 343,061 7,356,725 729,557 19796 Vermont Yankee Nucl Pwr Corp  4,059,107     4,059,107

19804 Vero Beach City of 639,710 269,125   41,273  950,108 48,389 19876 Virginia Electric & Power Co 65,826,104 9,742,110   383,820 7,121,880 83,073,914 3,989,073 20387 West Penn Power Co 18,228,706 5,263,693 4,943,516  23,714 1,237,829 29,697,458 966,099 20404 West Texas Utilities Co 4,837,210 2,784,428   29,112 532,501 8,183,251 300,148 20847 Wisconsin Electric Power Co 26,877,397 2,731,339 804,787  72,000 1,694,742 32,180,265 1,550,536 20856 Wisconsin Power & Light Co 9,504,473 3,480,221   18,188 692,174 13,695,056 494,473 20860 Wisconsin Public Service Corp 9,971,356 1,910,896 37,896  19,073 619,709 12,558,930 466,297 20893 Wolf Creek Nuclear Oper Corp 21048 Wyandotte Municipal Serv Comm 274,815     8,383 283,198 21,812 21687 Northeast Nuclear Energy Co

26751 KeySpan Generation LLC  12,142,079    6,354 12,148,433

40577 American Mun Power Ohio Inc 181,897 6,056,704    272,100 6,510,701 3,768 44372 TXU Electric Co 95,927,336 2,495,211 866,045   6,750,281 106,038,873 5,851,857 March 10, 2003 78 of 80 dwcgi 5548 1049746973 175081000. xls  861  1999 Record for the Section 316( b) Phase II Existing Facilities Notice of Data Availability 121 122 123 124 125 126 127 128 129 130 131 132 133 134 135 136 137 138 139 140 141 142 143 144 145 146 147 148 149 150 151 152 153 154 155 156 157 158 159 160 161 162 163 164 165 166 167 168 169 170 171 172 173 174 175 176 177 178 179 K L M N O P Q R S T U 45,159  5,544 234,181 4,616,370 228,637,000 MAPP 50.73 54.06 36.94 82%

38,468  762 74,841 2,721,428 74,079,000 ECAR 27.50 42.22 20.48 99%

16,501 42,248 384,328 7,229,071 70,373,888 6,844,743,000 WSCC 102.72 96.68 88.18 89%

1,051,885 ( 2,567) 8,145 3,230,018 82,920,653 3,221,873,000 WSCC 38.95 46.62 28.97 95%

131,080   420,222 7,367,072 420,222,000 FRCC 57.04 64.29 45.68 99%

166,944 29,200 113,655 921,965 12,409,957 808,310,000 MAAC 74.29 74.74 39.57 84%

1,327,625  561,593 3,650,996 55,106,456 3,089,403,000 MAAC 66.25 75.30 41.87 97%

39,209  36,239 315,606 4,423,929 279,367,000 ECAR 71.34 72.64 35.07 80%

  75 11,396 225,538 11,321,000 ECAR 50.53 50.20 96%

1,500,001  528,350 4,095,184 65,402,427 3,566,834,000 MAAC 62.62 87.60 35.88 98%

189  99 16,329 284,167 16,230,000 ECAR 57.46 56.83 99.89 93%

118,571 ( 9,649) 9,324 833,526 14,961,972 824,202,000 ECAR 55.71 54.29 66.34 94%

387,366  16,990 2,192,396 29,245,751 2,175,406,000 MAAC 74.96 73.86 76.91 95%

589,981  53,027 1,458,376 39,346,116 1,405,349,000 NPCC 37.07 59.12 23.09 99%

548,232  118,157 2,041,988 41,334,837 1,923,831,000 WSCC 49.40 58.94 30.46 97%

839,645 6,254 38,494 2,135,707 55,071,731 2,097,213,000 ECAR 38.78 47.94 28.98 98%

268,312  38,606 1,160,572 12,832,200 1,121,966,000 NPCC 90.44 122.70 45.67 95%

305,868  143,038 4,322,799 50,001,064 4,179,761,000 MAAC 86.45 96.15 31.50 94%

9,627  992 77,895 1,253,473 76,903,000 MAPP 62.14 64.60 45.41 98%

90,600  ( 482) 698,746 8,171,237 699,228,000 NPCC 85.51 96.67 48.32 96%

39,080  6,592 933,630 16,427,960 927,038,000 ERCOT 56.83 56.81 49.00 95%

10,225  74,648 1,500,014 15,101,690 1,425,366,000 WSCC 99.33 96.15 26.67 97%

7,546  1,784 248,134 3,841,439 246,350,000 SERC 64.59 64.32 58.71 95%

52,523 ( 9,508) 20,531 612,053 10,218,470 591,522,000 WSCC 59.90 65.05 29.41 94%

91,361  10,629 1,226,166 21,746,014 1,215,537,000 SERC 56.39 59.55 31.86 95%

398,570  8,734 810,572 20,285,462 801,838,000 SERC 39.96 40.09 38.98 98%

105,529   105,529 4,462,825 105,529,000 SERC 23.65 23.65 100%

57,798   57,798 1,569,322 57,798,000 ERCOT 36.83 36.83 96%

11,853  627,338 7,331,355 67,601,930 6,704,017,000 WSCC 108.45 99.58 29.98 86%

53,937  284 54,221 1,525,814 53,937,000 MAIN 35.54 35.35 98%

58,733 ( 439) 6,957 307,568 6,940,715 300,611,000 ECAR 44.31 47.41 32.10 96%

172,076 ( 4,800) 21,275 965,027 23,570,811 943,752,000 SPP 40.94 48.38 22.88 96%

1,058  927 101,747 3,342,290 100,820,000 MAIN 30.44 59.23 0.64 96%

15,596  1,460 133,772 2,983,319 132,312,000 SPP 44.84 45.32 38.25 94%

2,996  280 90,304 1,828,909 90,024,000 MAPP 49.38 52.18 18.61 93%

  270 25,393 448,119 25,123,000 SPP 56.67 56.06 93%

6,544  16,046 195,688 2,493,200 179,642,000 FRCC 78.49 73.42 48.25 95%

86,263  21,016 1,207,382 17,965,152 1,186,366,000 FRCC 67.21 69.60 39.93 95%

5,532,083  86,932 6,354,361 148,702,016 6,267,429,000 SERC 42.73 29.35 44.74 97%

143,610   143,610 3,042,555 143,610,000 ERCOT 47.20 47.20 99%

139,775  18,979 921,159 12,275,296 902,180,000 ECAR 75.04 77.27 58.02 93%

667  4,949 75,997 878,457 71,048,000 MAAC 86.51 82.53 25.99 90%

229,657 ( 49,997) 58,796 2,275,319 40,431,486 2,216,523,000 MAIN 56.28 60.68 33.45 94%

24,334  16,045 679,975 6,661,916 663,930,000 NPCC 102.07 113.16 24.10 96%

  2,853 732,410 6,997,936 729,557,000 HI 104.66 104.25 95%

208,812   208,812 4,059,107 208,812,000 NPCC 51.44 51.44 100%

7,320   55,709 908,835 55,709,000 FRCC 61.30 75.64 27.20 96%

401,704 ( 3,437) 123,263 4,510,603 75,568,214 4,387,340,000 SERC 59.69 60.60 41.23 91%

348,415  70,395 1,384,909 28,435,915 1,314,514,000 ECAR 48.70 53.00 34.13 96%

103,212 ( 6,438) 42,787 439,709 7,621,638 396,922,000 ERCOT 57.69 62.05 37.07 93%

115,996  21,745 1,688,277 30,413,523 1,666,532,000 MAIN 55.51 57.69 32.80 95%

108,038 ( 346) 19,653 621,818 12,984,694 602,165,000 MAIN 47.89 52.03 31.04 95%

60,551  1,074 527,922 11,920,148 526,848,000 MAIN 44.29 46.76 31.07 95%

  SPP    21,812 274,815 21,812,000 ECAR 79.37 79.37 97%

470,990   470,990  470,990,000 NPCC 303,120  15,344 318,464 12,142,079 303,120,000 NPCC 26.23 24.96 100%

216,485  3,261 223,514 6,238,601 220,253,000 ECAR 35.83 20.72 35.74 96%

126,877  227,767 6,206,501 99,288,592 5,978,734,000 ERCOT 62.51 61.00 37.75 94%

March 10, 2003 79 of 80 dwcgi 5548 1049746973 175081000. xls  861  1999 Record for the Section 316( b) Phase II Existing Facilities Notice of Data Availability 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 A B C D E F G H I J K L M N O Electric Power PPI obtained from the BLS website http:// www. bls. gov/ ppi/ series ID WPU054 ( 1/ 28/ 2003)

ANNUAL AVG JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC Elect PPI 1995 130.8 127.6 128 128.3 126.4 130.2 135.3 136.6 136.5 133.7 131.4 127.6 127.7 Elect PPI 1996 131.6 127.9 127.1 127.8 129.1 135 137.5 136 136.2 136.2 131.2 127.1 127.7 Elect PPI 1997 130.8 128.3 128.1 128.2 127.3 129.7 135.1 135.9 134.7 136 130.1 127.9 128.3 Elect PPI 1998 130 127.4 127.2 126.7 126.4 129.2 133.8 134.8 135.2 135.2 130.4 127.6 126.6 Elect PPI 1999 128.9 126.1 125.5 125.5 125.2 127.4 131.6 133.9 133.9 134.1 129.5 127.5 126.5 Elect PPI 2000 131.5 126.8 126.7 126.7 126.8 128.6 133.6 136.2 137.4 137.8 134.1 130.9 132.7 Elect PPI 2001 141.1 136.4 136.4 136.5 135.1 136.2 148.4 149.5 148.9 148.2 143.8 137.3 136.9 Elect PPI 2002 139.9 136.3 135.4 135.7 135.4 137.9 143.6 144.9 145 145.7 139.6 140.1 139.6 Red indicates Preliminary Data Average Disposition Sold 94.9%

Adjustment 1995 1.07 Adjustment 1996 1.06 Adjustment 1997 1.07 Adjustment 1998 1.08 Adjustment 1999 1.09 Adjustment 2000 1.06 Adjustment 2001 0.99 March 10, 2003 80 of 80 dwcgi 5548 1049746973 175081000. xls  Rates


[Federal Register: October 16, 2007 (Volume 72, Number 199)]
[Rules and Regulations]
[Page 58546-58553]
[DOCID:fr16oc07-20]

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ENVIRONMENTAL PROTECTION AGENCY

40 CFR Parts 52 and 97

[EPA-R05-OAR-2007-0390; FRL-8481-2]

Approval of Implementation Plans; Ohio; Clean Air Interstate Rule

AGENCY: Environmental Protection Agency (EPA).

ACTION: Direct final rule.

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

SUMMARY: EPA is approving a revision to the Ohio State Implementation
Plan (SIP) submitted on September 26, 2007. Ohio initially submitted a
SIP revision on April 17, 2007, with a proposed rule and then revised
it and submitted a SIP revision with a final rule on September 26,
2007. This SIP revision incorporates provisions related to the
implementation of EPA's Clean Air Interstate Rule (CAIR), promulgated
on May 12, 2005, and subsequently revised on April 28, 2006, and
December 13, 2006, and the CAIR Federal Implementation Plan (CAIR FIP)
concerning sulfur dioxide (SO2), oxides of nitrogen
(NOX) annual, and NOX ozone season emissions for
the State of Ohio, promulgated on April 28, 2006 and subsequently
revised December 13, 2006. EPA is not making any changes to the CAIR
FIP, but is amending to the extent EPA approves Ohio's SIP revision,
the appropriate appendices in the CAIR FIP trading rules simply to note
that approval.
    The Ohio SIP revision that was submitted on April 17, 2007, was a
full CAIR SIP revision. In a letter submitted on September 26, 2007,
Ohio requested that EPA consider the September 26, 2007, submittal as
two separate submittals, i.e., as a full CAIR SIP and as an abbreviated
CAIR SIP. Ohio requested that EPA act on specific portions of the
September 26, 2007,

submittal as an abbreviated CAIR SIP. Consequently, today, EPA is
taking final action only on the abbreviated SIP revision and not the
full CAIR SIP revision, which will be the subject of a separate future
action. EPA is approving Ohio's abbreviated SIP revision that addresses
the methodology used to allocate annual and ozone season NOX
allowances to affected electric generating units (EGUs), and the opt-in
provisions, under the CAIR trading programs and the CAIR FIP.

DATES: This direct final rule is effective December 17, 2007 without
further notice, unless EPA receives adverse comment by November 15,
2007. If EPA receives such comments, it will publish a timely
withdrawal of the direct final rule in the Federal Register and inform
the public that the rule will not take effect.

ADDRESSES: Submit your comments, identified by Docket ID No. EPA-R05-
OAR-2007-0390, by one of the following methods:
    1. http://www.regulations.gov: Follow the on-line instructions for

submitting comments.
    2. E-mail<EMAIL_ADDRESS>    3. Fax:<PHONE_NUMBER>.
    4. Mail: Reference EPA-R05-OAR-2007-0390 Docket, Air Programs
Branch, U.S. Environmental Protection Agency, (AR-18J), 77 West Jackson
Boulevard, Chicago, Illinois 60604.
    5. Hand Delivery or Courier: John Mooney, Chief, Criteria Pollutant
Section, Air Programs Branch, U.S. Environmental Protection Agency,
(AR-18J), 77 West Jackson Boulevard, Chicago, Illinois 60604. Such
deliveries are only accepted during the Regional Office's normal hours
of operation. The Regional Office's official hours of business are
Monday through Friday, 8:30 to 4:30, excluding Federal holidays.
    Instructions: Direct your comments to Docket ID No. ``EPA-R05-OAR-
2007-0390''. EPA's policy is that all comments received will be
included in the public docket without change and may be made available
online at http://www.regulations.gov, including any personal information

provided, unless the comment includes information claimed to be
Confidential Business Information (CBI) or other information whose
disclosure is restricted by statute. Do not submit through
http://www.regulations.gov or e-mail, information that you consider to be CBI

or otherwise protected. The http://www.regulations.gov Web site is an

``anonymous access'' system, which means EPA will not know your
identity or contact information unless you provide it in the body of
your comment. If you send an e-mail comment directly to EPA without
going through http://www.regulations.gov, your e-mail address will be

automatically captured and included as part of the comment that is
placed in the public docket and made available on the Internet. If you
submit an electronic comment, EPA recommends that you include your name
and other contact information in the body of your comment and with any
disk or CD-ROM you submit. If EPA cannot read your comment due to
technical difficulties and cannot contact you for clarification, EPA
may not be able to consider your comment. Electronic files should avoid
the use of special characters and any form of encryption and should be
free of any defects or viruses. For additional information about EPA's
public docket visit the EPA Docket Center homepage at http://www.epa.gov/epahome/dockets.htm
.

    Docket: All documents in the electronic docket are listed in the
http://www.regulations.gov index. Although listed in the index, some

information is not publicly available, i.e., CBI or other information
whose disclosure is restricted by statute. Certain other material, such
as copyrighted material, is not placed on the Internet and will be
publicly available only in hard copy form. Publicly available docket
materials are available either electronically in http://www.regulations.gov or

in hard copy at the Environmental Protection Agency, Region 5, Air and
Radiation Division, 77 West Jackson Boulevard, Chicago, Illinois 60604.
EPA requests that if at all possible, you contact the person listed in
the FOR FURTHER INFORMATION CONTACT section to schedule your
inspection. The Regional Office's official hours of business are Monday
through Friday, 8:30 to 4:30, excluding Federal holidays.

FOR FURTHER INFORMATION CONTACT: John Paskevicz, Engineer, Criteria
Pollutant Section, Air Programs Branch (AR-18J), Environmental
Protection Agency, Region 5, 77 West Jackson Boulevard, Chicago,
Illinois 60604. The telephone number is<PHONE_NUMBER>. Mr. Paskevicz
can also be reached via electronic mail at<EMAIL_ADDRESS>
SUPPLEMENTARY INFORMATION:

Table of Contents

I. What Action Is EPA Taking?
II. What Is the Regulatory History of CAIR and the CAIR FIPs?
III. What Are the General Requirements of CAIR and the CAIR FIPs?
IV. What Are the Types of CAIR SIP Submittals?
V. Analysis of Ohio's CAIR SIP Submittal
    A. State Budgets for Allowance Allocations
    B. CAIR Cap-and-Trade Programs
    C. Applicability Provisions for Non-EGUs NOX SIP Call
Sources
    D. NOX Allowance Allocations
    E. Allocation of NOX Allowances From the Compliance
Supplement Pool (CSP)
    F. Individual Opt-in Units
VI. Final Action
VII. Statutory and Executive Order Reviews

I. What Action Is EPA Taking?

CAIR SIP Approval

    EPA is approving a revision to Ohio's SIP, submitted on September
26, 2007, that modifies the application of certain provisions of the
CAIR FIP concerning SO2, NOX annual, and
NOX ozone season emissions. (As discussed below, this less
comprehensive CAIR SIP is termed an abbreviated SIP.) Ohio is subject
to the CAIR FIPs that implement the CAIR requirements by requiring
certain EGUs to participate in the EPA-administered Federal CAIR
SO2, NOX annual, and NOX ozone season
cap-and-trade programs. The SIP revision provides a methodology for
allocating NOX allowances for the NOX annual and
NOX ozone season trading programs. The CAIR FIPs provide
that this methodology will be used to allocate NOX
allowances to sources in Ohio, instead of the federal allocation
methodology otherwise provided in the FIPs. The SIP revision provides a
methodology for allocating the compliance supplement pool in the CAIR
NOX annual trading program. The SIP also allows for
individual units not otherwise subject to the CAIR trading programs to
opt into such trading programs in accordance with opt-in provisions of
the CAIR FIPs. Consistent with the flexibility provided in the FIPs,
these provisions will be used to replace or supplement, as appropriate,
the corresponding provisions in the CAIR FIPs for Ohio. EPA is not
making any changes to the CAIR FIPs, but is amending to the extent EPA
approves Ohio's SIP revision, the appropriate appendices in the CAIR
FIP trading rules simply to note that approval.

II. What Is the Regulatory History of the CAIR and the CAIR FIPs?

    CAIR was published by EPA on May 12, 2005 (70 FR 25162). In this
rule, EPA determined that 28 States and the District of Columbia
contribute significantly to nonattainment and interfere with
maintenance of the national ambient air quality standards (NAAQS) for
fine particles (PM2.5) and/or 8-hour ozone in downwind
States in the eastern part of the country. As a result, EPA required
those upwind States to revise their SIPs to include

control measures that reduce emissions of SO2, which is a
precursor to PM2.5 formation, and/or NOX, which
is a precursor to both ozone and PM2.5 formation. For
jurisdictions that contribute significantly to downwind
PM2.5 nonattainment, CAIR sets annual State-wide emission
reduction requirements (i.e., budgets) for SO2 and annual
State-wide emission reduction requirements for NOX.
Similarly, for jurisdictions that contribute significantly to 8-hour
ozone nonattainment, CAIR sets State-wide emission reduction
requirements for NOX for the ozone season (May 1st to
September 30th). Under CAIR, States may implement these emission
budgets by participating in the EPA-administered cap-and-trade programs
or by adopting any other control measures.
    CAIR explains to subject States what must be included in SIPs to
address the requirements of section 110(a)(2)(D) of the Clean Air Act
(CAA) with regard to interstate transport with respect to the 8-hour
ozone and PM2.5 NAAQS. EPA made national findings, effective
May 25, 2005, that the States had failed to submit SIPs meeting the
requirements of section 110(a)(2)(D). The SIPs were due in July 2000, 3
years after the promulgation of the 8-hour ozone and PM2.5
NAAQS. These findings started a 2-year clock for EPA to promulgate a
Federal Implementation Plan (FIP) to address the requirements of
section 110(a)(2)(D). Under CAA section 110(c)(1), EPA may issue a FIP
anytime after such findings are made and must do so within two years
unless a SIP revision correcting the deficiency is approved by EPA
before the FIP is promulgated.
    On April 28, 2006, EPA promulgated FIPs for all States covered by
CAIR in order to ensure the emissions reductions required by CAIR are
achieved on schedule. Each CAIR State is subject to the FIPs until the
State fully adopts, and EPA approves, a SIP revision meeting the
requirements of CAIR. The CAIR FIPs require certain EGUs to participate
in the EPA-administered CAIR SO2, NOX annual, and
NOX ozone-season model trading programs, as appropriate. The
CAIR FIP SO2, NOX annual, and NOX
ozone season trading programs impose essentially the same requirements
as, and are integrated with, the respective CAIR SIP trading programs.
The integration of the CAIR FIP and SIP trading programs means that
these trading programs will work together to create effectively a
single trading program for each regulated pollutant (SO2,
NOX annual, and NOX ozone season) in all States
covered by CAIR FIP or SIP trading program for that pollutant. The CAIR
FIPs also allow States to submit abbreviated SIP revisions that, if
approved by EPA, will automatically replace or supplement the
corresponding CAIR FIP provisions (e.g., the methodology for allocating
NOX allowances to sources in the state), while the CAIR FIP
remains in place for all other provisions.
    On April 28, 2006, EPA published two more CAIR-related final rules
that added the States of Delaware and New Jersey to the list of States
subject to CAIR for PM2.5 and announced EPA's final
decisions on reconsideration of five issues without making any
substantive changes to the CAIR requirements.

III. What Are the General Requirements of CAIR and the CAIR FIPs?

    CAIR establishes State-wide emission budgets for SO2 and
NOX and is to be implemented in two phases. The first phase
of NOX reductions starts in 2009 and continues through 2014,
while the first phase of SO2 reductions starts in 2010 and
continues through 2014. The second phase of reductions for both
NOX and SO2 starts in 2015 and continues
thereafter. CAIR requires States to implement the budgets by either (1)
requiring EGUs to participate in the EPA-administered cap-and-trade
programs or (2) adopting other control measures of the State's choosing
and demonstrating that such control measures will result in compliance
with the applicable State SO2 and NOX budgets.
    The May 12, 2005, and April 28, 2006, CAIR rules provide model
rules that States must adopt (with certain limited changes, if desired)
if they want to participate in the EPA-administered trading programs.
    With two exceptions, only States that choose to meet the
requirements of CAIR through methods that exclusively regulate EGUs are
allowed to participate in the EPA-administered trading programs. One
exception is for States that adopt the opt-in provisions of the model
rules to allow non-EGUs individually to opt into the EPA-administered
trading programs. The other exception is for States that include all
non-EGUs from their NOX SIP Call trading programs in their
CAIR NOX ozone season trading programs.

IV. What Are the Types of CAIR SIP Submittals?

    States have the flexibility to choose the type of control measures
they will use to meet the requirements of CAIR. EPA anticipates that
most States will choose to meet the CAIR requirements by selecting an
option that requires EGUs to participate in the EPA-administered CAIR
cap-and-trade programs. For such States, EPA has provided two
approaches for submitting and obtaining approval for CAIR SIP
revisions. States may submit full SIP revisions that adopt the model
CAIR cap-and-trade rules. If approved, these SIP revisions will fully
replace the CAIR FIPs. Alternatively, States may submit abbreviated SIP
revisions. These SIP revisions will not replace the CAIR FIPs; however,
the CAIR FIPs provide that, when approved, the provisions in these
abbreviated SIP revisions will be used instead of or in conjunction
with, as appropriate, the corresponding provisions of the CAIR FIPs
(e.g., the NOX allowance allocation methodology).
    A State submitting an abbreviated SIP revision may submit limited
SIP revisions to tailor the CAIR FIP cap-and-trade programs to the
state submitting the revision. Specifically, an abbreviated SIP
revision may establish certain applicability and allowance allocation
provisions that, the CAIR FIPs provide, will be used instead of or in
conjunction with the corresponding provisions in the CAIR FIP rules in
that State. Specifically, the abbreviated SIP revisions may:
    1. Include NOX SIP Call trading sources that are not
EGUs under CAIR in the CAIR FIP NOX ozone season trading
program;
    2. Provide for allocation of NOX annual or ozone season
allowances by the State, rather than the Administrator, and using a
methodology chosen by the State;
    3. Provide for allocation of NOX annual allowances from
the CSP by the State, rather than by the Administrator, and using the
State's choice of allowed, alternative methodologies; and/or
    4. Allow units that are not otherwise CAIR units to opt
individually into the CAIR FIP cap-and-trade programs under the opt-in
provisions in the CAIR FIP rules.

With approval of an abbreviated SIP revision, the CAIR FIP remains in
place, as tailored to sources in the State by that approved SIP
revision.
    Abbreviated SIP revisions can be submitted in lieu of, or as part
of, CAIR full SIP revisions. States may want to designate part of their
full SIP as an abbreviated SIP for EPA to act on first when the timing
of the State's submission might not provide EPA with sufficient time to
approve the full SIP prior to the deadline for recording NOX
allocations. This will help ensure that the elements of the trading
programs where flexibility is allowed are

implemented according to the State's decisions. Submission of an
abbreviated SIP revision does not preclude future submission of a CAIR
full SIP revision. In this case, the September 26, 2007, submittal from
Ohio requests an abbreviated SIP revision. As discussed below, Ohio
requested three of the four provisions for which a State may request an
abbreviated SIP. The State requested that its allocation of
NOX annual and NOX ozone season allowances for
EGUs under the FIP be used instead of the corresponding provisions of
the CAIR FIPs in effect in the State. The State requested that its
allocation of NOX annual allowances from the compliance
supplement pool (CSP) be used instead of the corresponding provisions
of the CAIR FIPs in effect in the State. Finally, the State asked that
units, that are not otherwise CAIR units, may opt individually into the
CAIR FIP cap-and-trade program under the opt-in provisions in the CAIR
FIP rules.

V. Analysis of Ohio's CAIR SIP Submittal

A. State Budgets for Allowance Allocations

    The CAIR NOX annual and ozone season budgets were
developed from historical heat input data for EGUs. Using these data,
EPA calculated annual and ozone season regional heat input values,
which were multiplied by 0.15 lb/mmBtu, for phase 1, and 0.125 lb/
mmBtu, for phase 2, to obtain regional NOX budgets for 2009-
2014 and for 2015 and thereafter, respectively. EPA derived the State
NOX annual and ozone season budgets from the regional
budgets using State heat input data adjusted by fuel factors.
    The CAIR State SO2 budgets were derived by discounting
the tonnage of emissions authorized by annual allowance allocations
under the Acid Rain Program under title IV of the CAA. Under CAIR, each
allowance allocated under the Acid Rain Program for the years in phase
1 of CAIR (2010 through 2014) authorizes 0.5 ton of SO2
emissions in the CAIR trading program, and each Acid Rain Program
allowance allocated for the years in phase 2 of CAIR (2015 and
thereafter) authorizes 0.35 ton of emissions in the CAIR trading
program.
    The CAIR FIPs established the budgets for Ohio as 108,667 tons for
NOX annual emissions, 45,664 tons for NOX ozone
season emissions, and 333,520 tons for SO2 emissions. The
Ohio SIP revision, approved in today's action, does not affect these
budgets, which are total amounts of allowances available for allocation
for each year under the EPA-administered cap-and-trade programs under
the CAIR FIPs. In short, the abbreviated SIP revision only affects
allocations of allowances under the established budgets.

B. CAIR Cap-and-Trade Programs

    The CAIR NOX annual and ozone-season FIPs both largely
mirror the structure of the NOX SIP Call model trading rule
in 40 CFR part 96, subparts A through I. While the provisions of the
NOX annual and ozone-season FIPs are similar, there are some
differences. For example, the NOX annual FIP (but not the
NOX ozone season FIP) provides for a CSP, which is discussed
below and under which allowances may be awarded for early reductions of
NOX annual emissions. As a further example, the
NOX ozone season FIP reflects the fact that the CAIR
NOX ozone season trading program replaces the NOX
SIP Call trading program after the 2008 ozone season and is coordinated
with the NOX SIP Call program. The NOX ozone
season FIP provides incentives for early emissions reductions by
allowing banked, pre-2009 NOX SIP Call allowances to be used
for compliance in the CAIR NOX ozone-season trading program.
In addition, States have the option of continuing to meet their
NOX SIP Call requirement by participating in the CAIR
NOX ozone season trading program and including all their
NOX SIP Call trading sources in that program.
    The provisions of the CAIR SO2 FIP are also similar to
the provisions of the NOX annual and ozone season FIPs.
However, the SO2 FIP is coordinated with the ongoing Acid
Rain SO2 cap-and-trade program under CAA title IV. The
SO2 FIP uses the title IV allowances for compliance, with
each allowance allocated for 2010-2014 authorizing only 0.50 ton of
emissions and each allowance allocated for 2015 and thereafter
authorizing only 0.35 ton of emissions. Banked title IV allowances
allocated for years before 2010 can be used at any time in the CAIR
SO2 cap-and-trade program, with each such allowance
authorizing 1 ton of emissions. Title IV allowances are to be freely
transferable among sources covered by the Acid Rain Program and sources
covered by the CAIR SO2 cap-and-trade program.
    EPA used the CAIR model trading rules as the basis for the trading
programs in the CAIR FIPs. The CAIR FIP trading rules are virtually
identical to the CAIR model trading rules, with changes made to account
for federal rather than state implementation. The CAIR model
SO2, NOX annual, and NOX ozone season
trading rules and the respective CAIR FIP trading rules are designed to
work together as integrated SO2, NOX annual, and
NOX ozone season trading programs.
    Ohio is subject to the CAIR FIPs concerning SO2,
NOX annual, and NOX ozone season emissions, and
the CAIR FIP trading programs for SO2, NOX
annual, and NOX ozone season apply to sources in Ohio.
Consistent with the flexibility they give to States, the CAIR FIPs
provide that States may submit abbreviated SIP revisions that will
replace or supplement, as appropriate, certain provisions of the CAIR
FIP trading programs. The Ohio EPA September 26, 2007, submission is
such an abbreviated SIP revision.

C. Applicability Provisions for Non-EGU NOX SIP Call Sources

    In general, the CAIR FIP trading programs apply to any stationary,
fossil-fuel-fired boiler or stationary, fossil-fuel-fired combustion
turbine serving at any time, since the later of November 15, 1990, or
the start-up of the unit's combustion chamber, a generator with
nameplate capacity of more than 25 MWe producing electricity for sale.
    States have the option of bringing in, for the CAIR NOX
ozone season program only, those units in the State's NOX
SIP Call trading program that are not EGUs as defined under CAIR. EPA
advises States exercising this option to use provisions for
applicability that are substantively identical to the provisions in 40
CFR 96.304 and add the applicability provisions in the State's
NOX SIP Call trading rule for non-EGUs to the applicability
provisions in 40 CFR 96.304 in order to include in the CAIR
NOX ozone season trading program all units required to be in
the State's NOX SIP Call trading program that are not
already included under 40 CFR 96.304. Under this option, the CAIR
NOX ozone season program must cover all large industrial
boilers and combustion turbines, as well as any small EGUs (i.e. units
serving a generator with a nameplate capacity of 25 MWe or less), that
the State currently requires to be in the NOX SIP Call
trading program.
    Consistent with the flexibility given to States in the CAIR FIP
Ohio has not chosen, in the abbreviated CAIR SIP approved here, to
expand the applicability provisions of the CAIR NOX ozone
season trading program to include all non-EGUs in the State's
NOX SIP Call trading program. However, EPA notes that Ohio
has indicated that the full SIP revision submitted on September 26,
2007, expands the applicability provisions of CAIR NOX ozone
season trading program in this manner. As such, EPA is not taking final

action on the non-EGU portion of the State's September 26, 2007, full
CAIR SIP revision. The full CAIR SIP revision including actions to
approve the non-EGU portions of the State's CAIR rule will be the
subject of a separate future action.

D. NOX Allowance Allocations

    Under the NOX allowance allocation methodology in the
CAIR model trading rules and in the CAIR FIP, NOX annual and
ozone season allowances are allocated to units that have operated for
five years, based on heat input data from a three-year period that are
adjusted for fuel type by using fuel factors of 1.0 for coal, 0.6 for
oil, and 0.4 for other fuels. The CAIR model trading rules and the CAIR
FIP also provide a new unit set-aside from which units without five
years of operation are allocated allowances based on the units' prior
year emissions.
    The CAIR FIP provides States the flexibility to establish a
different NOX allowance allocation methodology that will be
used to allocate allowances to sources in the States if certain
requirements are met concerning the timing of submission of units'
allocations to the Administrator for recordation and the total amount
of allowances allocated for each control period. In adopting
alternative NOX allowance allocation methodologies, States
have flexibility with regard to:
    1. The cost to recipients of the allowances, which may be
distributed for free or auctioned;
    2. The frequency of allocations;
    3. The basis for allocating allowances, which may be distributed,
for example, based on historical heat input or electric and thermal
output; and/or
    4. The use of allowance set-asides and, if used, the size of the
set-aside.
    Consistent with the flexibility given to States in the CAIR FIPs,
Ohio has chosen to replace the provisions of the CAIR NOX
annual FIP concerning the allocation of NOX annual
allowances with its own methodology. Ohio has chosen to distribute
NOX annual allowances based upon heat input data from a
three year period adjusted for fuel type by using fuel adjustment
factors of 1.0 for coal, 0.6 for oil, and 0.4 for other fuels. Based on
this methodology, Ohio determined NOX allocations for EGUs
in the State under the CAIR FIP, and submitted its allocations to EPA
on April 24, 2007.
    Ohio also has included, in the abbreviated SIP revision, provisions
regarding set-aside programs for energy efficiency/renewable energy and
innovative technology projects under the CAIR NOX Ozone
Season program. The State's energy-efficiency/renewable energy (EE/RE)
and innovative technology set-aside program provisions establish two
set-asides for each control period, one set-aside for EE/RE projects
and one set-aside for innovative technology projects, and specify
procedures for allocating the allowances in the set-asides. Each set-
aside is limited to one percent of the state trading budget for
NOX ozone season allowance allocations. Beginning with the
end of 2009 and every three years thereafter, Ohio EPA will review the
number of allowances allocated from the set-asides and will, under
certain circumstances, increase the size of each set-aside in future
years as necessary, up to a maximum of five percent of the state
trading budget.
    EPA notes that the set-aside provisions do not explicitly state how
allowances will be reserved in the set-asides if the total amount of
allowances requested from a set-aside exceeds the total amount of
allowances in that set-aside. However, set-aside provisions explicitly
limit the amount of allowances available from each set-aside to one
percent of the state trading budget unless Ohio EPA expands the set-
asides in future years. In addition, Ohio informed EPA, in the
September 26, 2007, letter, that its guidance for the set-asides
provides that set-aside allowances will be reserved on a pro-rata basis
if the total requested allowances exceed the size of the set-aside.
Ohio has indicated that it will clarify its set-aside provisions
consistent with this guidance.
    The set-aside provisions also do not explicitly state how a set-
aside will be increased up to five percent of the state trading budget
if the existing set-aside amounts plus the total amounts allocated to
units with and without baseline heat input under Ohio's other
allocation provisions for NOX ozone season allowances
already equal the state trading budget. However, Ohio's CAIR
NOX ozone season allocation provisions clearly limit the
total allocations for each control period of CAIR NOX ozone
season allowances to the amount of the state trading budget for that
control period. Further, as written, the provisions for expanding the
set-asides cannot have any effect on the current allocations, which
Ohio has already submitted to the Administrator for phase 1 of the
trading program. In addition, Ohio informed EPA, in the September 28,
2007, letter, that Ohio EPA will reduce the total amount of allowances
allocated to existing units under the other allocation provisions to
the extent the size of a set-aside is increased in the future. Ohio has
indicated that it will clarify its allocation provisions consistent
with this statement in the September 28, 2007, letter.
    Consequently, EPA interprets Ohio's abbreviated SIP to limit the
total allocations for each control period of CAIR NOX ozone
season allowances (whether from current or expanded set-asides or under
the other allocation provisions in the abbreviated SIP) to the state
trading budget, consistent with the requirements of 40 CFR
51.123(ee)(2)(ii)(B).

E. Allocation of NOX Allowances From the Compliance Supplement Pool
(CSP)

    The CSP provides an incentive for early reductions in
NOX annual emissions. The CSP consists of 200,000 CAIR
NOX annual allowances of vintage 2009 for the entire CAIR
region, and a State's share of the CSP is based upon the State's share
of the projected emission reductions under CAIR. States may distribute
CSP allowances, one allowance for each ton of early reduction, to
sources that make NOX reductions during 2007 or 2008 beyond
what is required by any applicable State or Federal emission
limitation. States also may distribute CSP allowances based upon a
demonstration of need for an extension of the 2009 deadline for
implementing emission controls.
    The CAIR NOX annual FIP establishes specific
methodologies for allocations of CSP allowances. States may choose an
allowed, alternative CSP allocation methodology to be used to allocate
CSP allowances to sources in those States.
    Consistent with the flexibility given to States in the FIP, Ohio
has chosen to modify the provisions of the CAIR NOX annual
FIP concerning the allocation of allowances from the CSP. Ohio has
chosen to distribute CSP allowances using an allocation methodology
that provides more certainty to unit owners and operators that a known
quantity of allowances per unit will be available for distribution at
the beginning of the control period. Ohio also provides owners and
operators with an incentive for the operation of expensive post-
combustion control equipment year-round and provides incentives for
early reductions in emissions before 2009. Ohio EPA is required to
submit allocations from the CSP to the Administrator by July 1, 2009,
or such time when unit's 2008 emissions data are available so that the
allocations can be determined. Ohio's abbreviated SIP also states that
the Administrator will record the allocations by January 1, 2010. While
Ohio's abbreviated SIP does not explicitly state that allocations will
be submitted to the Administrator by

November 30, 2009, EPA notes that units' 2008 emissions data should
certainly be available before that date and that the allocations need
to be submitted by that date in order to ensure that the Administrator
will complete recordation of allowances by January 1, 2010. Further,
Ohio has indicated, in the September 26, 2007, letter, that it will
clarify its CSP provisions to provide for a deadline of November 30,
2009, for submission of CSP allocations to the Administrator.
Consequently, EPA considers the Ohio abbreviated SIP to meet the
requirements of 40 CFR 51.123(p)(2).

F. Individual Opt-in Units

    The opt-in provisions allow for certain non-EGUs (i.e., boilers,
combustion turbines, and other stationary fossil-fuel-fired devices)
that do not meet the applicability criteria for a CAIR trading program
to participate voluntarily in (i.e., opt into) the CAIR trading
program. A non-EGU may opt into one or more of the CAIR trading
programs. In order to qualify to opt into a CAIR trading program, a
unit must vent all emissions through a stack and be able to meet
monitoring, recordkeeping, and recording requirements of 40 CFR part
75. The owners and operators seeking to opt a unit into a CAIR trading
program must apply for a CAIR opt-in permit. If the unit is issued a
CAIR opt-in permit, the unit becomes a CAIR unit, is allocated
allowances, and must meet the same allowance-holding and emissions
monitoring and reporting requirements as other units subject to the
CAIR trading program. The opt-in provisions provide for two
methodologies for allocating allowances for opt-in units, one
methodology that applies to opt-in units in general and a second
methodology that allocates allowances only to opt-in units that the
owners and operators intend to repower before January 1, 2015.
    States have several options concerning the opt-in provisions. The
rules for each of the CAIR FIP trading programs include opt-in
provisions that are essentially the same as those in the respective
CAIR SIP model rules, except that the CAIR FIP opt-in provisions become
effective in a State only if the State's abbreviated SIP revision
adopts the opt-in provisions. The State may adopt the opt-in provisions
entirely or may adopt them but exclude one of the allowance allocation
methodologies. The State also has the option of not adopting any opt-in
provisions in the abbreviated SIP revision and thereby providing for
the CAIR FIP trading program to be implemented in the State without the
ability for units to opt into the program.
    Consistent with the flexibility given to States in the FIPs, Ohio
has chosen to allow non-EGUs meeting certain requirements to
participate in the CAIR NOX annual trading program, the CAIR
NOX ozone season trading program and the CAIR SO2
trading program. Ohio EPA submitted the CAIR SIP program rules, OAC
3745-109-08 and OAC 3745-109-14 and OAC 3745-109-21, which incorporate
the opt-in provisions as provided in the final EPA CAIR rule of April
28, 2006. These rules address opt-ins for NOX ozone season,
NOX annual, and SO2 annual programs.

VI. Final Action

    EPA is approving the rules contained in Ohio's abbreviated CAIR SIP
revision submitted on September 26, 2007. Ohio is covered by the CAIR
FIPs, which require participation in the EPA-administered CAIR FIP cap-
and-trade programs for SO2, NOX annual, and
NOX ozone season emissions. Under this abbreviated SIP
revision, and consistent with the flexibility given to States in the
FIPs, Ohio adopts provisions for allocating allowances under the CAIR
FIP NOX annual and ozone season trading programs. In
addition, Ohio adopts in the abbreviated SIP revision provisions that
establish a methodology for allocating allowances in the CSP and allow
for individual non-EGUs to opt into the CAIR FIP SO2,
NOX annual, NOX ozone season cap-and-trade
programs. As provided for in the CAIR FIPs, these provisions in the
abbreviated SIP revision will replace or supplement the corresponding
provisions of the CAIR FIPs in Ohio. The abbreviated SIP revision meets
the applicable requirements in 40 CFR 51.123(p) and (ee), with regard
to NOX annual and NOX ozone season emissions, and
40 CFR 51.124(r), with regard to SO2 emissions. EPA is not
making any changes to the CAIR FIPs, but is amending the appropriate
appendices in the CAIR FIP trading rules simply to note that approval.

VII. Statutory and Executive Order Reviews

Executive Order 12866: Regulatory Planning and Review

    Under Executive Order 12866 (58 FR 51735, October 4, 1993), this
action is not a ``significant regulatory action'' and, therefore, is
not subject to review by the Office of Management and Budget.

Executive Order 13211: Actions That Significantly Affect Energy Supply,
Distribution, or Use

    Because it is not a ``significant regulatory action'' under
Executive Order 12866 or a ``significant energy action,'' this action
is also not subject to Executive Order 13211, ``Actions Concerning
Regulations That Significantly Affect Energy Supply, Distribution, or
Use'' (66 FR 28355, May 22, 2001).

Regulatory Flexibility Act

    This action merely approves state law as meeting Federal
requirements and imposes no additional requirements beyond those
imposed by state law. Accordingly, the Administrator certifies that
this rule will not have a significant economic impact on a substantial
number of small entities under the Regulatory Flexibility Act (5 U.S.C.
601 et seq.).

Unfunded Mandates Reform Act

    Because this rule approves pre-existing requirements under State
law and does not impose any additional enforceable duty beyond that
required by State law, it does not contain any unfunded mandate or
significantly or uniquely affect small governments, as described in the
Unfunded Mandates Reform Act of 1995 (Pub. L. 104-4).

Executive Order 13175: Consultation and Coordination With Indian Tribal
Governments

    This rule also does not have tribal implications because it will
not have a substantial direct effect on one or more Indian tribes, on
the relationship between the Federal Government and Indian tribes, or
on the distribution of power and responsibilities between the Federal
Government and Indian tribes, as specified by Executive Order 13175 (59
FR 22951, November 9, 2000).

Executive Order 13132: Federalism

    This action also does not have Federalism implications because it
does not have substantial direct effects on the States, on the
relationship between the national government and the States, or on the
distribution of power and responsibilities among the various levels of
government, as specified in Executive Order 13132 (64 FR 43255, August
10, 1999). This action merely approves a State rule implementing a
Federal standard, and does not alter the relationship or the
distribution of power and responsibilities established in the Clean Air
Act.

Executive Order 13045: Protection of Children From Environmental Health
and Safety Risks

    This rule also is not subject to Executive Order 13045 ``Protection
of Children from Environmental Health Risks and Safety Risks'' (62 FR
19885, April 23, 1997), because it approves a State rule implementing a
Federal Standard.

National Technology Transfer Advancement Act

    In reviewing SIP submissions, EPA's role is to approve State
choices, provided that they meet the criteria of the Clean Air Act. In
this context, in the absence of a prior existing requirement for the
State to use voluntary consensus standards (VCS), EPA has no authority
to disapprove a SIP submission for failure to use VCS. It would thus be
inconsistent with applicable law for EPA, when it reviews a SIP
submission, to use VCS in place of a SIP submission that otherwise
satisfies the provisions of the Clean Air Act. Thus, the requirements
of section 12(d) of the National Technology Transfer and Advancement
Act of 1995 (15 U.S.C. 272 note) do not apply.

Paperwork Reduction Act

    This rule does not impose an information collection burden under
the provisions of the Paperwork Reduction Act of 1995 (44 U.S.C. 3501
et seq.).

Congressional Review Act

    The Congressional Review Act, 5 U.S.C. 801 et seq., as added by the
Small Business Regulatory Enforcement Fairness Act of 1996, generally
provides that before a rule may take effect, the agency promulgating
the rule must submit a rule report, which includes a copy of the rule,
to each House of the Congress and to the Comptroller General of the
United States. EPA will submit a report containing this rule and other
required information to the U.S. Senate, the U.S. House of
Representatives, and the Comptroller General of the United States prior
to publication of the rule in the Federal Register. A major rule cannot
take effect until 60 days after it is published in the Federal
Register. This action is not a ``major rule'' as defined by 5 U.S.C.
804(2).
    Under section 307(b)(1) of the Clean Air Act, petitions for
judicial review of this action must be filed in the United States Court
of Appeals for the appropriate circuit by December 17, 2007. Filing a
petition for reconsideration by the Administrator of this final rule
does not affect the finality of this rule for the purposes of judicial
review nor does it extend the time within which a petition for judicial
review may be filed, and shall not postpone the effectiveness of such
rule or action. This action may not be challenged later in proceedings
to enforce its requirements. (See section 307(b)(2).)

List of Subjects

40 CFR Part 52

    Environmental protection, Air pollution control, Electric
utilities, Incorporation by reference, Intergovernmental relations,
Nitrogen oxides, Ozone, Particulate matter, Reporting and recordkeeping
requirements, Sulfur dioxide.

40 CFR Part 97

    Environmental protection, Administrative practice and procedure,
Air pollution control, Electric utilities, Intergovernmental relations,
Nitrogen oxides, Ozone, Particulate matter, Reporting and recordkeeping
requirements, Sulfur dioxide.

    Dated: September 28, 2007.
Bharat Mathur,
Acting Regional Administrator, Region 5.

0
For the reasons set forth in the preamble, parts 52 and 97 of chapter 1
of title 40 of the Code of Federal Regulations are amended as follows:

PART 52--[AMENDED]

0
1. The authority citation for part 52 continues to read as follows:

    Authority: 42 U.S.C. 7401 et seq.

Subpart KK--Ohio

0
2. In Sec.  52.1870 is amended by adding paragraph (c)(140) to read as
follows:

Sec.  52.1870  Identification of plan.

* * * * *
    (c) * * *
    (140) Ohio Environmental Protection Agency submitted amendments on
September 26, 2007, to the State Implementation Plan to control
emissions from electric generating units (EGU). Rules affecting these
units include: Ohio Administrative Code (OAC) 3745-109-01 (B)(59) and
(72), 3745-109-04, 3745-109-08, 3745-109-14, 3745-109-17 (except the
following: the language in paragraph (A) referencing the state trading
budget for non-EGUs in 3745-109-17-01(C)(4), paragraphs
(C)(1)(a)(i)(d), (C)(2)(b), (C)(2)(d), (C)(2)(e), and (C)(2)(f), and
the language in paragraph (C)(3)(a) referencing non-EGUs), and 3745-
109-21.
    (i) Incorporation by reference. The following sections of the Ohio
Administrative Code (OAC) are incorporated by reference.
    (A) OAC 3745-109-01(B)(59) ``Energy efficiency/renewable energy
project''; OAC 3745-109-01(B)(72) ``Innovative technology project'';
OAC 3745-109-04 ``CAIR NOX allowance allocations''; OAC
3745-109-08 ``CAIR NOX opt-in units''; OAC 3745-109-14
``CAIR SO2 opt-in units''; and OAC 3745-109-21 ``CAIR
NOX ozone season opt-in units''; effective on September 27,
2007.
    (B) OAC 3745-109-17 ``CAIR NOX ozone season allowance
allocations''; effective on September 27, 2007, except the following:
the language in paragraph (A) referencing the state trading budget for
non-EGUs in 3745-109-17-01(C)(4), paragraphs (C)(1)(a)(i)(d),
(C)(2)(b), (C)(2)(d), (C)(2)(e), and (C)(2)(f), and the language in
paragraph (C)(3)(a) referencing non-EGUs.

PART 97--[AMENDED]

0
3. The authority citation for part 97 continues to read as follows:

    Authority: 42 U.S.C. 7401, 7403, 7410, 7426, 7601, and 7651, et
seq.

0
4. Appendix A to subpart EE is amended by adding in alphabetical order
the entry ``Ohio'' under paragraphs 1. and 2. to read as follows:

Appendix A to Subpart EE of Part 97--States With Approved State
Implementation Plan Revisions Concerning Allocations

    1. * * *
    Ohio
* * * * *
    2. * * *
    Ohio
* * * * *

0
5. Appendix A to subpart II is amended by adding in alphabetical order
the entry ``Ohio'' under paragraphs 1. and 2. to read as follows:

Appendix A to Subpart II of Part 97--States With Approved State
Implementation Plan Revisions Concerning CAIR NOX Opt-In
Units

    1. * * *
    Ohio
* * * * *
    2. * * *
    Ohio
* * * * *

0
6. Appendix A to subpart III of part 97 is amended by adding in
alphabetical order the entry ``Ohio'' under paragraphs 1. and 2. to
read as follows:

Appendix A to Subpart III of Part 97--States With Approved State
Implementation Plan Revisions Concerning CAIR SO2 Opt-In
Units

    1. * * *
    Ohio
* * * * *
    2. * * *
    Ohio
* * * * *

0
7. Appendix A to subpart EEEE of part 97 is amended by adding in
alphabetical order the entry ``Ohio'' to read as follows:

Appendix A to Subpart EEEE of Part 97--States With Approved State
Implementation Plan Revisions Concerning Allocations

* * * * *
    Ohio
* * * * *

0
8. Appendix A to subpart IIII of part 97 is amended by adding in
alphabetical order the entry ``Ohio'' under paragraphs 1. and 2. to
read as follows:

Appendix A to Subpart IIII of Part 97--States With Approved State
Implementation Plan Revisions Concerning CAIR NOX Ozone
Season Opt-In Units

    1. * * *
    Ohio
    2. * * *
    Ohio
* * * * *
 [FR Doc. E7-20252 Filed 10-15-07; 8:45 am]

BILLING CODE 6560-50-P