United States
        Environmental Protection
        Agency
Office of Air Quality
Fleming and Standards
Research Triangle Park. NC 27711
EPA-454/R-95-013
July 1995
        AJL.
EFtt
               1990 OTC NOx
    BASELINE EMISSION INVENTORY


-------
                                 EPA-454/R-95-013
           1990 OTC NOx
BASELINE EMISSION INVENTORY
         Office Of Air Quality Planning And Standards
             Office Of Air And Radiation
          U. S. Environmental Protection Agency
           Research Triangle Park, NC 27711

                 July 1995

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This report  has  been reviewed by  the Office Of Air Quality  Planning  And  Standards, U.  S.
Environmental Protection Agency, and has been approved for publication.  Any mention of trade
names or commercial products is not intended to constitute endorsement or recommendation for use.
                                    EPA^54/R-95-013
                                          11

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                        ACKNOWLEDGEMENTS
    Development of the Ozone Transport Commission (OTC) Oxide of Nitrogen (NOX)
Baseline Emission Inventory was a cooperative process involving the States, the U.S.
Environmental Protection Agency (EPA), and industry. State air quality personnel
contributing to the development include:

    Connecticut:  Joe Belanger, Nancy Pitblado
    District of Columbia: Tehseen Khokhar
    Delaware:  John Outten
    Massachusetts: Don Squires, Marc Cohen
    Maryland: Duane King
    Maine:  Jerry Bernier, Mike Karagiannes
    New Hampshire: N. Strickland, Andy Bodnarik
    New Jersey:  Ray Papalski, Greg Walker, Benjamin Loh
    New York: Rob Sliwinski
    Pennsylvania: Dean VanOrden, Joe White
    Rhode Island: Doug McVay
    Virginia:  Tom Ballou
    Vermont:  Paul Wishinski

    The OTC Stationary/Area Source Committee was tasked with the development of this
baseline inventory.  Jim Hambright of the Mid-Atlantic Regional Air Management
Administration (MARAMA) chairs this committee, which is comprised of State air quality
personnel. Bruce Carhart and David Foerter of the OTC also contributed to development
of this inventory.  Industry contribution to the inventory development was made through
participation in the Baseline  Review Group, as well as through cooperation with
individual States.

    Contributors at EPA include David Mobley and Roy Huntley of the Emission Factors
and Inventory Group, Barry Gilbert of the Ozone Policy and Strategies  Group, and Chet
Wayland of the Air Quality Monitoring Group.  Robert Wagoner of Pacific Environmental
Services assisted in conversion of the AIRS and PC inventory data.  Contributors from
E.H. Pechan & Associates, Inc. include Erica Laich, Gregory Stella, Susy Rothschild, and
Patty Carlson.
                                      in

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IV

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                                 GLOSSARY
Baseline - the baseline inventory includes the actual 1990 emissions of all fossil fuel-fired
boilers and indirect heat exchangers of 250 MMBtu/hr and greater plus electric generating
sources (e.g., turbines, 1C engines, and boilers) of 15 MW (approximately 150 MMBtu/hr)
and above.  The capacity of the source, not the generator, is used to determine whether or
not a source is included in the baseline.

Affected -  affected sources include all fossil fuel-fired boilers and indirect heat
exchangers of 250 MMBtu/hr or greater. Affected, for the purposes of the MOU, means
that  the source is subject to reductions, according to the zone in which it is located, for the
purposes of establishing emission targets. All other sources in the baseline may be
referred to  as nonaffected.

Target Emissions - the level of emissions for each source that complies with the
emission reductions established in the MOU.  The target level of emissions can be
summed to the facility, State, or zone level.  The target emissions will be summed to the
State or OTR level to aid in establishing the emission budget.

Budget - the budget includes applying the limits (percentage reduction or emission limit)
established in the MOU to the affected sources (at the boiler or point level). Added to this
are the actual or RACT (whichever is lower) emissions from the other sources in the
baseline. Also included in the establishment of the budget are any considerations for
exceptional circumstances. The Phase II budget also includes an additional 10,000 ton
reserve.

Allocation - the amount of the budget apportioned to an individual State, plant, or
source. Allocation to individual States is under the jurisdiction of the OTR. The
procedure for determining allocations has not yet been determined.

Default OTC Baseline Inventory - the default OTC baseline inventory is based on
EPA's Interim 1990 Emission inventory. The default baseline was to be used in the event
that  the State inventory was not acceptable to the OTC and EPA by the March 1,  1995
deadline.

Initial OTC State Baseline Inventory - the initial State inventory submittals that
were made  by the States to EPA in December of 1994.  The Initial OTC State Baseline
Inventory is dated December 29, 1994 and is available on the CHIEF Bulletin Board.

Revised. OTC State Baseline Inventory - any changes to the Initial OTC State
Baseline  Inventory are referred to as the Revised OTC State Baseline Inventory.  The
majority of the changes were generally made in January.

Final OTC State Baseline Inventory - the inventory as approved by the OTC on
June 13,  1995 is designated as the Final OTC State Baseline Inventory.

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Exceptional Circumstance - any source claiming exceptional circumstances must show
that operations in 1990 varied significantly from normal operations.  States considered
claims of exceptional circumstance on a case-by-case basis. The OTC made final decisions
on approval of exceptional circumstance.

New Source - a source that began operation after the 1990 5-month ozone season.

10,000 Ton Reserve - tonnage allocated to States that applies only to the 1997-2003
period (Phase II).

Adjusted Baseline - total of affected, nonaffected, exceptional circumstances, and 10,000
ton reserve.
                                         VI

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                         CONTENTS
                                                           Page

ACKNOWLEDGEMENTS	  iii

GLOSSARY	   v

TABLES 	  ix

FIGURES 	   x

CHAPTER I
INTRODUCTION 	   1

CHAPTER II
BASELINE EMISSION INVENTORY	   3

CHAPTER III
PHASE II AND III EMISSION BUDGET 	  15

APPENDIX A - PHASE II AND III TARGET LEVELS BY STATE	A-l

APPENDIX B - FINAL 1990 OTC NOX BASELINE INVENTORY:
FIVE MONTH DATA 	B-l

APPENDIX C - MEMORANDUM OF UNDERSTANDING	C-l

APPENDIX D - DEFAULT OTC NOX BASELINE INVENTORY	  D-l

APPENDIX E - INITIAL OTC NOX BASELINE INVENTORY  	E-l

APPENDK F - FINAL OTC NOX BASELINE INVENTORY	F-l

APPENDDC G - EXCEPTIONAL CIRCUMSTANCES	  G-l

APPENDDC H - 10,000 TON RESERVE	:	  H-l

APPENDIX I -- PROCEDURES DOCUMENT	1-1

APPENDK J - LIST OF FILES ON EPA TTN	J-l
                              Vll

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VU1

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                                  TABLES
                                                                           Page

II-l     State Summary of Baseline Sources	   4
II-2     State Summary of Affected Sources  	   5
II-3     State Summary of Nonaffected Sources 	   6
II-4     Zone/State Summary of Baseline Sources	   7
II-5     Zone/State Summary of Affected Sources 	   8
II-6     Zone/State Summary of Nonaffected Sources  	   9
II-7     Annual NOX Emissions by State	  13
II-8     Annual NOX Emissions by Zone and State 	  14
III-l    Phase H and III Target Level by State	  17
III-2    Phase II and III Target Level by Zone and State 	  18
III-3    Ozone Transport Region NOX Budget Summary	  19
III-4    Ozone Transport Region Phase II NO, Summary	  20
III-5    Ozone Transport Region Phase III NOX Summary  	  21
                                      IX

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                                 FIGURES
                                                                         Page

1-1     Development of OTC NOX Emission Data Base	   2
II-l    1990 Ozone Transport Region Annual NOX Emissions by Sector	  10
II-2    1990 NOX Emissions by State	  11
II-3    1990 NOX Emissions by Zone and State 	  12
III-l   Ozone Transport Region 5-Month NOX Emissions from Affected Sources  ....  22
III-2   NOX Emission Targets from Affected Sources by State	  23
III-3   NOX Emission Targets from Affected Sources by Zone and State	  24
III-4   OTR NOX Budget Summary	  25

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                                 CHAPTER I
                              INTRODUCTION
    The States of the OTC signed a Memorandum of Understanding (MOU) on
September 27, 1994 concerning the development of a regional strategy for the control of
NOX emissions from stationary sources. As part of this process, the OTC Stationary/Area
Source Committee developed a proposed regional NOX strategy that required NOX
reductions beyond reasonably available control technology (RACT) in two phases. Phase
II (initial reductions beyond RACT) would require reductions by May 1, 1999.  Phase III
would require further reduction by May 1, 2003. Work is proceeding on the development
of an implementation mechanism that will likely include a NO, budget and tradeable
allowances.

    The objective of this effort was to compile and quality assure a data base of NO,
emissions from fossil fuel-fired boilers and indirect heat exchanges greater than or equal
to 250 million British thermal units per hour (MMBtu/hr) capacity and electric generating
units greater than or equal to 15 megawatts (MW) in the Northeast Ozone Transport
Region (OTR). Emissions for the period May 1 through September 30, 1990 (referred to
as the 5-month summer season) were compiled and will be used as a basis for emission
reduction targeting and trading. A procedures document was developed in December of
1994 that described the process for completing the inventory including quality assurance,
calculation of 5-month emissions, selection of emission  factors, and determining
exceptional circumstances (a separate data base of exceptional circumstances was
developed to cover atypical operations in 1990).

    Figure 1-1 shows the schedule for completion of this inventory including both the
target dates and the actual date completed. The schedule was closely adhered to and the
baseline was approved at the February 28, 1995 OTC meeting with the condition that
further quality assurance checks would be completed by June 1. Exceptional
circumstances, to cover atypical operations in 1990, were also approved. In addition, the
OTC approved a further 10,000 ton reserve for Phase II targeting purposes.

    This document presents summaries and detailed reports of the Final OTC NOX
Baseline Inventory. The inventory was approved by the OTC at the June 13 meeting.
Chapter II presents a summary of the OTC NOX Baseline Inventory. Chapter III
summarizes Phase II and III target levels of emissions  resulting from application of the
MOU limits.

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                                                               Figure 1-1
                                            Development of OTC NO, Emission Data Base
1.     OTC determines calculation
      approach, emission estimation
     >• approach, data elements, and format.
2,     States submit initial data (currently
      available) to EPA.
3.     EPA develops default data base from
      Interim Inventory and provides to
      States for review.
4.     EPA compiles initial data base and
      provides to States for review.
5.     OTC/EPA proposes quality assurance
      protocol and procedure for modifying
      data.

6.     States quality assure the initial and
      default data bases.
7.     Sources return comments to States.
8.     State data available for public review.
   Target Date
     11/04/94
     11/18/94




     11/18/94



     12/02/94


     12/02/94




12/02/94 - 01/15/95
     01/06/95
12/07/94-01/15/95
9.     States submit data revisions.
10.    EPA compiles final data base.
11.    States/OTC/Baseline Review Group
      conducts final data review.
     01/15/95
     02/01/95
02/01/95 - 03/01/95
The Approach to the OTC NO, Data Base was approved by the OTC Stationary/Area
Source Committee on 4 November 1994.

Initial inventory data was downloaded from AIRS/AFS for CT, DC, DE, MA, MD, NH,
Rl, VA, and VT. ME provided in SAMS/STEPS format, NY provided in SAMS format,
NJ and PA provided in State system format.  All States available to EPA by 18
November 1994.
The default data base was submitted to the States at the 17 November 1994
Stationary/Area Source Committee Meeting and was available through the CHIEF
Bulletin Board on 21 November 1994.
The Initial State OTC NO, Baseline was compiled and submitted to the States for
review on 1 December 1994.
The Draft Procedures document was submitted to the States and Baseline Review
Group on 22 November 1994.  A second draft was submitted on 2 December 1994
and discussed at the 7 December 1994 Stationary/Area Source Committee meeting.
Document approved on 15 December 1994 and placed on the CHIEF Bulletin Board.
States submitted changes throughout this period and continuing through 16 February
1995. This involved constant interaction between the States, EPA, and Pechan. Q/A
reports were transferred back to States to ensure revisions were correctly
implemented.
Sources interacted with States throughout development/revision to the baseline.
Inventories for  11 States (all States except MD and NJ) were quality assured by the
States, approved for release, and publicly available on  6 December 1994 in hardcopy
form and subsequently in electronic form (through the CHIEF Bulletin Board). The
Initial State OTC NO, Baseline Inventory, including all States, was available on
CHIEF on 29 December 1994.
States submitted revisions through 16 February 1995.  Updated inventories for CT,
DE, DC, NH, Rl, VT, and MD were available 27 January 1995. Updated inventories
for all States except PA and NJ were available 6 February 1995.  Updated inventories
for all States available through CHIEF on 9 February 1995.
The Revised OTC Baseline Inventory was completed on 16 February 1995 and
approved at the February 28 OTC meeting with the condition that additional quality
assurance checks would be conducted.
Q/A continued through June 1, 1995.  All changes from the February 16 versions
were tracked and subject to OTC approval. The baseline was approved at the June
13 OTC meeting.

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                                CHAPTER II
                  BASELINE EMISSION INVENTORY
    The baseline emission inventory represents actual 1990 emissions for the 5-month
season.  Annual emissions are also included in the inventory (annual and ozone season
daily emissions did not undergo rigorous quality assurance and ozone season daily were
not provided by all States).

    Baseline emissions are designated as affected or nonaffected depending on the source
type and size. Affected include all fossil fuel-fired boilers and indirect heat exchanges
with capacity greater than or equal to 250 MMBtu/hr. Nonaffected are fossil fuel-fired
electric generating units greater than or equal to 15 MW, but below 250 MMBtu/hr.
Tables II-l through II-6 present State and zone/State summaries for all baseline sources,
affected sources, and nonaffected sources, respectively.

    NOX emissions from these sources were targeted for further control because they
contribute significantly to overall emissions.  Figure II-l shows the relative contributions
to annual emissions by sector for the OTR. Emissions for other sectors were taken from
the Interim 1990 Inventory (Version 4).  Figure II-2 shows the relative contributions by
State. Figure II-3  shows the same by zone and State.  NOX emissions for all sectors are
summarized in Tables II-7 and II-8 by State and zone/State, respectively.

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State
Connecticut
Delaware
District of Columbia
Maine
Maryland
Massachusetts
New Hampshire
New Jersey
New York
Pennsylvania
Rhode Island
Vermont
Virginia

Ozone Transport Region
260
                                                          Table 11-1
                                              State Summary of Baseline Sources
                                              (Final OTC NOx Baseline Inventory)
                                      Annual Heat
                                   Input (10x6Btu)
                                       145,044,487
                                        96,855,010
                                         8,622,798
                                        54,088,610
                                       297,221,746
                                       327,316,770
                                        57,157,004
                                       222,873,917
                                       901,664,563
                                     1,232,673,622
                                         7,598,820
                                          721,560
                                        43,029,710
912  1,431      1,120,717     3,394,868,617
Number of:
Plants
21
9
4
18
16
27
3
35
53
69
2
1
2

Units
59
26
12
45
60
80
7
243
152
206
5
1
16

SCCs
84
49
18
51
88
141
13
381
241
328
10
1
26
Annual
NOx (tons)
26,201
29,496
1,123
10,443
120,108
97,865
36,423
107,862
197,288
480,036
1,941
42
11,890

5-Month
NOx (tons)
11,203
13,180
576
4,419
. 54,990
40,367
12,946
44,360
84,484
199,639
1,099
30
5,799

5-Month Heat
Input (10x6Btu)
61,284,609
43,893,578
4,315,427
22,524,735
139,601,865
139,045,355
21,688,403
97,648,670
394,796,337
519,522,699
4,161,143
521,640
22,067,343
5-Month
NOx Rate
(lbs/10x6Btu)
0.366
0.601
0.267
0.392
0.788
0.581
1.194
0.909
0.428
0.769
0.528
0.115
0.526
473,092    1,471,071,804
0.643
This table summarizes heat input, emissions, and average emission rates for all baseline sources.

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                               Number of:
      State                     Plants
      Connecticut                    12
      Delaware                       5
      District of Columbia              3
      Maine                         17
      Maryland                      12
      Massachusetts                 14
      New Hampshire                 3
      New Jersey                    19
      New York                      41
      Pennsylvania                   56
      Rhode  Island                    2
      Vermont                        1
      Virginia                        2

en    Ozone Transport Region      187
                                                               Table II-2
                                                   State Summary of Affected Sources
                                                   (Final OTC NOx Baseline Inventory)


nits
33
16
10
44
30
36
7
53
86
156
5
1
10

*
sees
54
35
16
50
57
75
13
101
151
276
10
1
20

Annual
NOx (tons)
25,468
29,019
965
10,398
119,269
95,104
36,423
102,443
192,171
479,052
1,941
42
11,852

Annual Heat
Input (10x6Btu)
137,692,382
92,730,359
8,136,486
53,888,060
293,366,860
309,626,615
57,157,004
187,475,873
880,366,938
1,228,881,907
7,598,820
721,560
42,921,070

5-Month
NOx (tons)
10,839
12,934
497
4,412
54,375
39,070
12,946
41,523
82,271
199,137
1,099
30
5,765

5-Month Heat
Input (10x6Btu)
57,606,443
41,725,589
4,072.023
22,493,250
136,782,484
130,828,554
21,688,403
80,042,472
385,666,289
517,755,429
4,161,143
521,640
21,969,665
5-Month
NOx Rate
(lbs/10x6Btu)
0.376
0.620
0.244
0.392
0.795
0.597
1.194
1.038
0.427
0.769
0.528
0.115
0.525
487    859     1,104,145     3,300,563,934
464,897    1,425,313,384
0.652
      This table summarizes heat input, emissions, and average emission rates for affected sources.

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                                                          Table 11-3
                                            State Summary of Nonaffected Sources
                                             (Final OTC NOx Baseline Inventory)
State
Connecticut
Delaware
District of Columbia
Maine
Maryland
Massachusetts
New Jersey
New York
Pennsylvania
Virginia

Ozone Transport Region

Number of:
Plants
14
7
1
1
9
21
28
24
21
1


Units
26
10
2
1
30
44
191
66
50
6

•
sees
30
14
2
1
31
66
280
90
52
6

Annual
NOx (tons)
733
477
158
45
839
2,761
5,419
5,117
984
38

Annual Heat
Input (10x6Btu)
7,352,105
4,124,651
486,312
200,550
3,854,886
17,690,155
35,398,044
21,297,625
3,791,715
108,640

5-Month
NOx (tons)
364
246
79
7
616
1,297
2,836
2,214
503
34

5-Month Heat
Input (10x6Btu)
3,678,166
2,167,989
243,404
31,485
2,819,381
8,216,801
17,606,198
9,130,048
1,767,270
97,678
5-Month
NOx Rate
(lbs/10x6Btu)
0.198
0.227
0.650
0.449
0.437
0.316
0.322
0.485
0.569
0.698
127
426    572
16,571
94,304,683
8,195
45,758,420
0.358
This table summarizes heat input, emissions, and average emission rates for nonaffected sources.

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                                                       Table 11-4
                                         Zone/State Summary of Baseline Sources
                                           (Final OTC NOx Baseline Inventory)
   State

Inner Zone
   Connecticut
   Delaware
   District of Columbia
   Maryland
   Massachusetts
   New Hampshire
   New Jersey
   New York
   Pennsylvania
   Rhode Island
   Virginia
Total

Outer Zone
   Delaware
   Maryland
   New York
   Pennsylvania
Total

Northern Zone
   Maine
   New York
   Vermont
Total

Ozone Transport Region

Number of:


Plants Units
21
8
4
13
27
3
35
30
18
2
2
163
59
22
12
53
80
7
243
108
61
5
16
666

*
SCCs
84
41
18
79
141
13
381
163
98
10
26
1,054

Annual
NOx (tons)
26.201
12,927
1,123
111,592
97,865
36,423
107,862
97,304
18,525
1,941
11,890
523,652

Annual Heat
Input (10x6Btu)
145,044,487
57,017,631
8,622,798
279,436,332
327.316,770
57,157,004
222,873,917
566,037,458
91,454,368
7,598,820
43,029.710
1,805,589,295

5-Month
NOx (tons)
11,203
6,017
576
50,924
40,367
12,946
44,360
42,716
8,621
1,099
5,799
224,626

5-Month Heat
Input (10x6Btu)
61,284,609
26,673,862
4,315.427
131,038,110
139,045,355
21,688,403
97,648,670
253,049,312
40,861,491
4,161,143
22,067.343
801 ,833,725
5-Month
NOx Rate
(lbs/10x6Btu)
0.366
0.451
0.267
0.777
0.581
1.194
0.909
0.338
0.422
0.528
0.526
0.560
1
3
22
51
77
4
7
43
145
199
8
9
77
230
324
16,570
8,515
99,301
461,511
585,897
39,837,379
17.785,414
331,933,025
1,141,219.254
1,530.775,072
7,163
4,067
41,482
191,018
243,730
17,219,716
8.563,755
140,195,511
478,661,208
644,640,190
0.832
0.950
0.592
0.798
0.756
18
1
1
20
45
1
1
47
51
1
1
53
10,443
683
42
11,168
54,088,610
3,694,080
721,560
58,504,250
4,419
287
30
4,736
22.524.735
1,551,514
521,640
24,597.889
0.392
0.370
0.115
0.385
260
912    1431
1,120,717    3,394,868,617
473,092   1,471,071,804
0.643
This table summarizes heat input, emissions, and average emission rates for all baseline sources.

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00
   State

Inner Zone
   Connecticut
   Delaware
   District of Columbia
   Maryland
   Massachusetts
   New Hampshire
   New Jersey
   New York
   Pennsylvania
   Rhode Island
   Virginia
Total

Outer Zone
   Delaware
   Maryland
   New York
   Pennsylvania
Total

Northern Zone
   Maine
   New York
   Vermont
Total

Ozone Transport Region
                                Number of:
                                 Plants   Units
                                                               Table \\-S
                                                Zone/State Summary of Affected Sources
                                                   (Final OTC NOx Baseline Inventory)
      SCCs
12
4
3
9
14
3
19
20
15
2
2
103
1
3
20
41
65
17
1
1
19
33
12
10
24
36
7
53
48
38
5
10
276
4
6
37
118
165
44
1
1
46
54
27
16
49
75
13
101
84
73
10
20
522
8
8
66
203
285
50
1
1
52
Annual
NOx (tons)
25,468
12,449
965
110,755
95,104
36,423
102,443
93,955
17,932
1,941
11,852
509,286
16,570
8,514
97,533
461,120
583,736
10,398
683
42
11,123
Annual Heat
Input (10x6Btu)
137,692,382
52,892,980
8,136,486
275,585,645
309,626,615
57,157,004
187,475,873
551,769,892
89,615,003
7,598,820
42,921,070
1,720,471,770
39,837,379
17,781,215
324,902,966
1,139,266,904
1,521,788,464
53,888,060
3,694,080
721,560
58,303,700

5-Month
NOx (tons)
10,839
5,771
497
50,308
39,070
12,946
41,523
41,256
8,289
1,099
5,765
217,364
7,163
4,066
40,728
190,847
242,804
4,412
287
30
4,729

5-Month Heat
Input (10x6Btu)
57,606,443
24,505,873
4,072,023
128,220,429
130,828,554
21,688,403
80,042,472
246,840,257
39,846,302
4,161,143
21,969,665
759,781,564
17,219,716
8,562,055
137,274,518
477,909,127
640,965,416
22,493,250
1,551,514
521,640
24,566,404
5-Month
NOx Rate
(lbs/10x6Btu)
0.376
0.471
0.244
0.785
0.597
1.194
1.038
0.334
0.416
0.528
0.525
0.572
0.832
0.950
0.593
0.799
0.758
0.392
0.370
0.115
0.385
                                   187
487
859
1,104,145    3,300,563,934
464,897   1,425,313,384
0.652
       This table summarizes heat input, emissions, and average emission rates for affected sources.

-------
                                                       Table 11-6
                                       Zone/State Summary of Nonaffected Sources
                                           (Final OTC NOx Baseline Inventory)
   State

Inner Zone
   Connecticut
   Delaware
   District of Columbia
   Maryland
   Massachusetts
   New Jersey
   New York
   Pennsylvania
   Virginia
Total

Outer Zone
   Maryland
   New York
   Pennsylvania
Total

Northern Zone
   Maine
Total

Ozone Transport Region
Number of:
Plants
14
7
1
8
21
28
19
7
1
106
Units
26
10
2
29
44
191
60
23
6
391
SCCs
30
14
2
30
66
280
79
25
6
532
Annual
Annual Heat
5-Month
5-Month Heat
5-Month
NOx Rate
NOx(tons) Input (10x6Btu) NOx (tons) Input (10x6Btu) (lbs/10x6Btu)
733
477
158
838
2,761
5,419
3,348
593
38
14,365
7,352,105
4,124,651
486,312
3,850,687
17,690,155
35,398,044
14,267,566
1.839,365
108,640
85,117,525
364
246
79
615
1,297
2,836
1,459
332
34
7,263
3.678,166
2,167.989
243,404
2,817,681
8,216,801
17,606,198
6,209,055
1,015.189
97,678
42,052,161
0.198
0.227
0.650
0.437
0.316
0.322
0.470
0.654
0.698
0.345
1
5
14
20
1
6
27
34
1
11
27
39
1
1,769
392
2,161
4,199
7,030,059
1.952,350
8,986,608
0
754
171
925
1,700
2,920,993
752,081
3,674,774
0.520
0.516
0.454
0.504
  1
  1

127
  1
  1

426
  1
  1

572
    45
    45

16,571
   200,550
   200,550

94,304,683
    7
    7

8,195
    31,485
    31,485

45,758,420
0.449
0.449

0.358
This table summarizes heat Input, emissions, and average emission rates for nonaffected sources.

-------
                                                      Figure 11-1
                       1990 Ozone Transport Region Annual NOx Emissions by Sector
                                                   (tons per year)
                               Motor Vehicle
                                  42%
                                                                                Affected Sources
                                                                                    31%
                                                                                 Nonaffected Sources
                                                                               Other Point
                                                                                 7%
                                                      Nonroad
                                                        11%
Emissions for affected and nonaffected baseline sources are taken from the Final OTC NOx Baseline Inventory. Emissions from all other sources are from
the 1990 Interim Inventory (version 4).

-------
                                                           Figure 11-2

                                               1990 NOx Emissions by State
        1,200,000
                                    Nonroad
  CO

  O
  'w
  .2

  til
  X
  O
  z
        1,000,000 !
800,000
600,000 :
         400,000 ~\
         200,000
                                                                    Baseline (affected + nonaffected)
                   PA
                                                                                                    RI
                                                                                                   vr
DC
Emissions for baseline sources are taken from the Final OTC NOx Baseline Inventory,

Emissions from all other sources are from the Interim 1990 Inventory (version 4).

-------
        900,000
        800,000
to    O
                                                     Figure 11-3
                                    1990 NOx Emissions by Zone and State
                                                                                                 Other Point
                NJ    NY   MA   MD   PA   CT    VA    NH   DE    Rl    DC

               Inner Zone
PA   NY    MD   DE   MA    NY    VT   NH
Outer Zone              Northern Zone
   Emissions for baseline sources are taken from the Final OTC NOx Baseline Inventory.

-------
                                                                Table 11-7
                                                  Annual NOx Emissions by State (tons)
CO
             State
             Connecticut
             Delaware
             District of Columbia
             Maine
             Maryland
             Massachusetts
             New Hampshire
             New Jersey
             New York
             Pennsylvania
             Rhode Island
             Vermont
             Virginia
                                •
             Ozone Transport Region
Affected Nbnaffected
Sources
25,468
29,019
965
10,398
119,269
95,104
36,423
102,443
192,171
479,052
1,941
42
11,852
Sources
733
477
158
45
839
2,761
0
5,419
5,117
984
0
0
38
Other
Point
5,545
8,447
722
8,739
21,010
14,256
2,412
39,015
56,206
77,121
893
520
465

Area
14,717
2,805
2,756
6,760
21,674
29,319
8,093
40,664
77,278
86,108
6,130
3,084
3,852

Nonroad
20,648
4,845
4,775
4,393
41,608
51,712
1,834
59,605
89,720
86,748
3,577
1,284
18,367
Motor
Vehicle
90,051
22,780
10,291
48,812
140,428
154,288
39,174
187,910
365,853
312,609
23,785
24,412
37,425

TOTAL
157,163
68,373
19,667
79,147
344,828
347.440
87,935
435,056
786,346
1,042,622
36,326
29,343
71,999
1,104,145
16,571
235,352    303,240     389,117   1,457,820   3,506,245
             Emissions for affected and nonaffected baseline sources are taken from the Final OTC NOx Baseline Inventory.
             Emissions from all other sources are from the 1990 Interim Inventory (version 4).

-------
                                                Table 11-8
                              Annual NOx Emissions by Zone and State (tons)
    State                      Sources

 Inner Zone
    Connecticut                  25,468
    Delaware                    12,449
    District of Columbia              965
    Maryland                    110,755
    Massachusetts                95,104
    New Hampshire               36,423
    New Jersey                  102,443
    New York                    93,955
    Pennsylvania                 17,932
    Rhode Island                  1,941
    Virginia                       11,852
Total                          509,286

Outer Zone
    Delaware                     16,570
    Maryland                      8,514
    New York                     97,533
    Pennsylvania               461,120
Total                         583,736

Northern Zone
    Maine                        10,398
    New Hampshire                   0
    New York                       683
   Vermont                         42
Total                           11,123

Ozone Transport Region       1,104,145
ffected
ources
733
477
158
838
2,761
0
5,419
3,348
593
0
38
14,365
0
1
1,769
392
2,161
45
0
0
0
45
Other
Point
5,545
7.959
722
17,317
14,256
874
39,015
15.399
16,934
893
465
119,379
488
3,693
36.052
60,187
100,420
8,739
1,538
4,756
520
15,553

Area
14,717
2,392
2,756
18,096
29,319
5,649
40.664
45,246
28,738
6,130
3,852
197,559
413
3,578
28,081
57,370
89,442
6,760
2,444
3,951
3,084
16,239

Nonroad
20,648
4,108
4,775
35,647
51,712
. 1,364
59,605
50,454
30,673
3,577
18,367
280,931
737
5.960
34,096
56,075
96,869
4,393
470
5,171
1.284
11,317
Motor
Vehicle
90,051
16,622
10,291
113.182
154,288
26,815
187,910
171,607
76.143
23.785
37,425
908,119
6,158
27,247
166.060
236,467
435,932
48,812
12,359
28,186
24,412
113,769

TOTAL
157,163
44,007
19,667
295,834
347,440
71,125
435,056
380,009
171,013
36,326
71,999
2,029,640
24.365
48,994
363.591
871,610
1,308,559
79,147
16,810
42,746
29,343
168,046
16,571    235,352    303,240    389,117  1,457,820 3,506,245
Emissions for affected and nonaffected baseline sources are taken from the Final OTC NOx Baseline Inventory.
Emissions from all other sources are from the 1990 Interim Inventory (version 4).

-------
                                CHAPTER  III
                PHASE II AND III EMISSION  BUDGET
    The MOU recognizes the need to go beyond RACT-level controls in the Northeast to
achieve levels of ozone in compliance with the National Ambient Air Quality Standards.
The MOU establishes emission limits by zone for affected sources in two phases as
follows:

    Phase II

    Inner Zone: less stringent of 65 percent or 0.2 Ibs/MMBtu
    Outer Zone: less stringent of 55 percent or 0.2 Ibs/MMBtu
    Northern Zone:  RACT

    Phase III

    Inner Zone: less stringent of 75 percent or 0.15 Ibs/MMBtu
    Outer Zone: less stringent of 75 percent or 0.15 Ibs/MMBtu
    Northern Zone:  less stringent of 55 percent or 0.2 Ibs/MMBtu

For this analysis, if actual 1990 emissions or RACT emissions (defined here as 1990
operating levels combined with RACT emission rate limits) are lower than the Phase II or
III limits, then these values become the Phase II or III target. The target level of
emissions is established for each boiler (or unit) and is then summed to the plant,
zone/State, State, or OTR level. The final procedure for determining emission targets has
not yet been determined by the OTC and may differ from the procedure used in this
analysis.

    Tables III-l and III-2 show the target level of emissions by State and zone/State,
respectively, for affected sources. As shown in Table II-2, the Phase II target for States in
the inner zone may fall below the less stringent of the 75 percent/0.15 due to plants or
boilers where the 1990 or RACT emissions are already below the 75 percent/0.15 Phase II
limit.

    The overall budget takes the following into account (in addition to the affected
sources):

    Nonaffected Sources: 1990 or RACT emissions  (whichever is lower).

    Exceptional Circumstances: These are additional tonnage allocations based on
    atypical operation at specific facilities or boilers. The Phase II and III targets are
    estimated by applying the percentage reduction requirement for the applicable zone to
    the exceptional circumstance allocation.
                                       15

-------
    10,000 Ton Reserve: This is an additional reserve for the purpose of the Phase II
    budget only.  The reserve for each State (which is subject to approval by the OTC) is
    allocated to zones in this analysis according to the distribution of 1990 emissions
    (except for Maryland and Pennsylvania where the reserve was allocated based on
    specific facilities).  The Phase II target is estimated by applying the percentage
    reduction requirement based on the zone.  A 40 percent reduction is used in the
    Northern Zone to approximate RACT.

    Again, the final procedure for determining the emission budget will be determined by
the OTC and may differ from the procedure used in this analysis.

    Table III-3 shows the Phase II and III target baselines and budgets.  Tables III-4 and
III-5 summarize the Phase II and Phase III budget calculations, respectively.

    Figure III-l  shows the breakdown of the reductions achieved from affected sources
(i.e., does not include exceptional circumstances or 10,000 ton reserve) due to RACT,
Phase II, and Phase III. Emissions under each phase (including 1990 baseline and RACT)
are shown in Figures III-2 and III-3 by State and zone/State, respectively, for affected
sources only.

    Lastly, Figure III-4 compares the 1990 baseline with the total Phase II and Phase III
budgets, accounting for exceptional circumstances and the 10,000 ton reserve.

    The target level and budget calculations are preliminary and subject to change as
RACT levels and policy decisions are finalized.
                                          16

-------
Affected Sources Only

Target Report - May-September Emissions
State Level Emissions Data
                   Table 111-1
Phase II and III Target Level by State
08/15/95
State
Connecticut
Delaware
Washington DC
Maine
Maryland
Massachusetts
New Hampshire
New Jersey
New York
Pennsylvania
Rhode Island
Vermont
Virginia
OTR Total
Design Capacity Heat Input
(10x6Btu/hr) (10x6 Btu)
37,326
21.546
8.170
- 29,777
65.755
62,360
11,068
59,821
182,555
238,271
2,978
842
18.250
738,719
57,606,443
41,725,589
4,072,023
22,493,250
136.782,484
130,828,554
21,688,403
80,042.472
385.666,289
517,755,429
4,161,143
521,640
21,969,665
1,425,313,384
NOx Emissions
(Tons/May-Sept)
5-Month
10,839
12,934
497
4.412
54.375
39,070
12,946
41,523
82,271
199,137
1,099
30
5,765
464,897
55%
4,877
5,820
223
1.985
24,469
17,582
5,826
18,685
37,022
89,611
495
14
2,594
209,204
65%
3,794
4,527
174
1,544
19,031
13,675
4,531
14.533
28.795
69,698
385
11
2,018
162,714
75%
2,710
3,234
124
1.103
13.594
9,768
3.237
10,381
20,568
49,784
275
8
1,441
116,224
0.20
5,761
4,173
407
2,249
13,678
13,083
2,169
8,004
38,567
51,776
416
52
2,197
142,531
0.15
4,321
3,129
305
1.687
10,259
9,812
1,627
6,003
28,925
38,832
312
39
1,648
106,898
RACT
7,307
8,396
453
3,155
38.881
19,416
8,047
17,318
60,145
125,771
421
30
3,876
293,218
Less Stringent of
55%/0.2
6,409
6,097
407
2,456
25,350
19,165
5,827
19,119
45,226
92,069
495
52
2.755
225,427
65%/0.2
5,960
5,033
407
2,370
20,636
16,124
4,591
15,284
41,361
72,828
416
52
2,270
187,332
75%/0.15
4.449
3.662
305
1.767
14,907
11,805
3,319
10,998
30,744
52,281
312
39
1,668
136,256
Phase II
5,473
5,543
400
3,155
21,013
15,855
4,591
13,561
44.107
90,352
416
30
2.270
206,767
Phase III
4,204
3,623
304
2,454
14,907
11,805
3.319
10,699
30,642
51,646
312
30
1,668
135,613
77)0 MOU establishes Phase II and potential Phase HI NOx limits.
The methodology tor applying these limits, Including how RACT should be Incorporated, Is currently being considered by the OTC.
RACT (preliminary Information provided by the States) Is Included In the Phase II and III calculations.
The Phase II and III budgets also Incorporate nonaffected sources, exceptional circumstances, and the 10,000 ton reserve.

-------
 Affected Sources Only

 Target Report - May-September Emissions
 Zone-State Level Emissions Data
                      Table 111-2
Phase II and III Target Level by Zone/State
                                                                                                                                                       08/15/95
Stale
Inner Zone
Connecticut
Delaware
Washington DC
Maryland
Massachusetts
New Hampshire
New Jersey
New York
Pennsylvania
Rhode Island
Virginia
Northern Zone
Maine
New York
Vermont
Outer Zone
Delaware
Maryland
New York
Pennsylvania
OTR Total
Design Capacity Heat Input
(10x6 Btu/hri (10x6 Btu)

37,326
12,451
8.170
60,822
62,360
11.068
59,821
128,621
33,527
2,978
18,250

29.777
522
842

9,095
4,933
53,412
204,744
738,719

57,606.443
24.505,873
4.072.023
128.220,429
130,828,554
21.688,403
80.042.472
246,840,257
39,846,302
4.161.143
21,969,665

22,493,250
1,551,514
521,640

17,219,716
8,562.055
137.274.518
477,909,127
1,425,313,384
NOx Emissions
fTons/Mav-Seotl
5-Month

10,839
5,771
497
50,308
39,070
12,946
41,523
41,256
8,289
1.099
5,765

4,412
287
30

7,163
4,066
40,728
190,847
464,897
55%

4,877
2,597
223
22,639
17,582
5,826
18,685
18.565
3.730
495
2,594

1.985
129
14

3,223
1.830
18.327
85,881
209,204
65%

3,794
2,020
174
17,608
13,675
4,531
14,533
14,440
2,901
385
2,018

1,544
100
11

2.507
1,423
14,255
66,797
162,714
75%

2.710
1.443
124
12,577
9,768
3,237
10.381
10,314
2,072
275
1,441

1,103
72
8

1,791
1,017
10,182
47.712
116,224
0.20

5,761
2,451
407
12,822
13.083
2,169
8,004
24,684
3,985
416
2,197

2.249
155
52

1,722
856
13,727
47,791
142,531
0.15

4,321
1,838
305
9,617
9,812
1,627
6,003
18,513
2,988
312
1,648

1.687
116
39

1,291
642
10,296
35,843
106,898
PACT

7.307
4.165
453
35,133
19,416
8,047
17,318
31.186
5,978
421
3,876

3,155
194
30

4,231
3.748
28.765
119.793
293,218
55%/0.2

6,409
2,874
407
23.502
19,165
5,827
19,119
25.711
4.608
495
2.755

2.456
155
52

3,223
1,848
19,361
87.461
225,427
Leaa Stringent of
65%/0.2

5,960
2,526
407
19,165
16,124
4,591
15,284
25.074
4,140
416
2,270

2,370
155
52

2,507
1,472
16,132
68,687
187,332
75%/0.15

4,449
1,871
305
13,850
11,805
3,319
10,998
18,748
3,075
312
1,668

1,767
116
39

1,791
1,057
11,879
49,207
136,256
Phased

5,473
2,392
400
19,165
15,855
4,591
13,56'1
24,689
3,810
416
2,270

3,155
194
30

3,151
1,848
19,223
86,542
206,767
Phase III

4,204
1,833
304
13,850
11,805
3,319
10,699
18,608
2,895
312
1,668

2,454
155
30

1,791
1,057
11,879
48,750
135,613
The MOU establishes Phase II and potential Phase III NOx limits.
The methodology tor applying these limits, Including how PACT should be Incorporated. Is currently being considered by the OTC.
RACT (preliminary Information provided by the States) Is Included In the Phase II and III calculations.
The Phase II and III budgets also Incorporate nonaffected sources, exceptional circumstances, and the 10,000 ton reserve.

-------
                                                                      Table llt-3
                                                     Ozone Transport Region NOx Budget Summary
                                                      Final OTC NOx Baseline Emission Inventory
                                                               (5-month emissons -tons)
State

Connecticut
Delaware
District of Columbia
Maine
Maryland
Massachusetts
New Hampshire
New Jersey
New York
Pennsylvania
Rhode Island
Vermont
Virginia

Ozone Transport Region
Sources with •
Affected Exceptional NonAffected 10,000 Ton
Sources(1) Circumstances(2) Sources(3) Reserve (4)
10,839
12,934
497
4,412
54,375
39,070
12,946
41.523
82,271
199,137
1,099
30
5,765
0
80
0
0
0
963
1,631
449
740
3,452
0
0
332
364
246
79
7
616
1,297
0
2,836
2,214
503
0
0
34
344
86
43
129
3,576
602
129
817
1.847
2.126
86
43
172
Phase II
Adjusted
Baseline(S)
11.547
13.346
619
4,548
58.567
41,932
14,706
45,625
87,072
205.218
1,185
73
6,303
Phase III
Adjusted Phase II Target Phase III Target
Baseline(6) Emissions(7) Emissions(S)
11,203
13,260
576
4,419
54,991
41,330
14,577
44,808
85.225
203,092
1,099
30
6,131
5,910
5,792
494
3.237
22,881
17,218
5,207
15,430
46,700
93.204
446
56
2.480
4.522
3,830
383
2,459
15.523
12.861
3,727
12,236
32,349
52,857
312
30
1,785
464,898
7,647
8,196
10,000
490,741
480,741
219,055
142,874
(1) Fossil fuel fired boilers and other indirect heat exchangers with capacity of 250 million Btu/hr and above.
(2) Accounts for atypical operations as approved by the Stationary/Area Source Committee.
(3) Emission from sources in the baseline but not affected.
(4) Additional 10,000 ton reserve approved by the OTC for use in establishing Phase II targets.
(5) Total of affected, nonaftected, exceptional circumstances, and 10,000 ton reserve.
(6) Total of affected, nonaffected, and exceptional circumstances.
(7) Phase II limits on affected, exceptional circumstances, and 10,000 ton reserve plus RACT on nonaffected sources.
(8) Phase III limits on affected and exceptional circumstances plus RACT on nonaffected sources.

RACT limits are preliminary and based on default data where source specific information has not yet been provided.
This analysis incorporates RACT limits for affected sources (RACT limits are assumed if below Phase II or Phase III limits).
Phase II and III limits for exceptional circumstances are currently estimated by applying the percentage reduction to the emissions.
Applying the emission rate limit may result in higher Phase II or Phase III emissions for exceptional circumstances.

-------
                                                                    Table 111-4
                                                 Ozone Transport Region Phase II Budget Summary
                                                    Final OTC NOx Baseline Emission Inventory
                                                            (5-month emissions - tons)
 State

 Connecticut
 Delaware
 District of Columbia
 Maine
 Maryland
 Massachusetts
 New Hampshire
 New Jersey
 New York
 Pennsylvania
 Rhode Island
 Vermont
 Virginia

 Ozone Transport Region
fni
Sources with
Affected Exceptional Non Affected 10,000 Ton
Sources(1) Circumstances(2) Sources(3) Reserve (4)
10,839
12,934
497
4,412
54,375
39,070
12,946
41,523
82,271
199,137
1,099
30
5,765
0
80
0
0
0
963
1,631
449
740
3,452
. 0
0
332
364
246
79
7
616
1,297
0
2,836
2,214
503
0
0
34
344
86
43
129
3.576
602
129
817
1,847
2,126
86
43
172
ise ii uuagei{o; 	 •• 	 • 	 ........ 	
Plus Sources Plus Plus
Affected with Exceptional NonAffected 10,000 Ton
Sources Circumstances
5,473
5,543
400
3,155
21,013
15.855
4,591
13,561
44,107
90,352
416
30
2,270
5,473
5,571
400
3,155
21,013
16,192
5.162
13,718
44,440
91,899
416
30
2,386
Sources
5.790
5,757
479
3,160
21,629
17,007
5,162
15,144
45,961
92,247
416
30
2,420
Reserve
5,910
5,792
.494
3,237
22,881
17,218
5,207
15.430
46,700
93.204
446
56
2,480
464,898
7,647
8,196
10,000
206,766
209,855
215,202
219,055
(1) Fossil fuel fired boilers and other Indirect heat exchangers with capacity of 250 million Btu/hr and above.
(2) Accounts for atypical operations as approved by the Stationary/Area Source Committee.
(3) Emission from sources In the baseline but not affected.
(4) Additional 10,000 ton reserve approved by the OTC for use In establishing Phase II targets.
(5) Phase II limits on affected, exceptional circumstances, and 10,000 tons reserve plus RACT on nonaffected sources.

RACT limits are preliminary and based on default data where source specific Information has not yet been provided.
This analysis incorporates RACT limits for affected sources (RACT limits are assumed if below Phase II or Phase III limits).

Phase II limits for exceptional circumstances are currently estimated by applying the percentage reduction to the emissions.
Applying the emission rate limit may result in higher Phase II or Phase III emissions for exceptional circumstances.

Phase II limits for the 10,000 ton reserve are estimated by applying the applicable percentage reduction.  For States crossing zones,
the reserve was allocated according to the percentage of baseline emissions in each zone. A 40 percent  reduction was
applied in the Northern Zone to approximate RACT.

-------
                                                                Table 111-5
                                             Ozone Transport Region Phase III Budget Summary
                                                Final OTC NOx Baseline Emission Inventory
                                                        (5-month emissions - tons)
(S3
                               Affected
State                        Sources(1)

Connecticut                       10,839
Delaware                         12,934
District of Columbia                   497
Maine                             4,412
Maryland                         54,375
Massachusetts                    39,070
New Hampshire                   12,946
New Jersey                       41,523
New York                         82,271
Pennsylvania                    199,137
Rhode Island                      1,099
Vermont                              30
Virginia                            5,765

Ozone Transport Region         464,898
                                                     Sources with
                                                      Exceptional
                                                 Circumstances(2)
NonAffected
 Sources(3)
Phase III Budget(4)

        Affected
        Sources
0
80
0
0
0
963
1,631
449
740
3,452
0
0
332
364
246
79
7
616
1,297
0
2,836
2,214
503
0
0
34
4,204
3,623
304
2,454
14,907
11,805
3,319
10,699
30,642
51,646
312
30
1,668
Plus Sources
with Exceptional
Circumstances
4,204
3,643
304
2,454
14,907
12,046
3,727
10,811
30,827
52,509
312
30
1,751
Plus
NonAffected
Sources
4,522
3,830
383
2,459
15,523
12,861
3,727
12,236
32,349
52,857
312
30
1.785
                                                            7,647
       8,196
        135,613
137,525
142,874
        (1) Fossil fuel fired boilers and other indirect heat exchangers with capacity of 250 million Btu/hr and above.
        (2) Accounts for atypical operations as approved by the Stationary/Area Source Committee.
        (3) Emission from sources in the baseline but not affected.
        (4) Phase III limits on affected and exceptional circumstances plus PACT on nonaffected sources.

        PACT limits are preliminary and based on default data where source specific information has not yet been provided.
        This analysis incorporates RACT limits for affected sources (RACT limits are assumed if below Phase II or Phase III limits).

        Phase III  limits for exceptional circumstances are currently estimated by applying the percentage reduction to the emissions.
        Applying the emission rate limit may result in higher Phase II or Phase III emissions for exceptional circumstances.

-------
                                                                   Figure 111-1
                                         Ozone Transport Region 5-Month NOx Emissions
                                                               Affected Sources
                                        RACT Reductions
                                          (171,679 tons)
to
to
                                                                                                Affected Source Remainder
                                                                                                     (135,613 tons)
                                                                                               Phase III Reductions
                                                                                                  (71,154 tons)
                                                               Phase II Reductions
                                                                  (86,451 tons)
      RACT reductions are based on preliminary information and are estimated based on 1990 operating rates combined with RACT emission limits.
      The Phase II and III targets are preliminary and subject to change as RACT and policy decisions are finalized.
      This figure does not include emissions from nonaffected sources, exceptional circumstances, or the 10,000 ton reserve (phase II) which affect the overall budget.

-------
                                                                Figure 111-2

                                   NOx Emission Targets from Affected Sources by State
bo
CO
1

I
V)

o
'55
.52

UJ
x
O
z

I

o

0)
                    200,000
                    150,000  j
                    100,000
                     50,000
                                   NY    MD     NJ     MA    NH    DE    CT     VA    ME    Rl    DC     VT
DPhase III

[D Phase II

DRACT

m Baseline
               PA
                                                               State
                 RACT reductions are based on preliminary Information and are estimated based on 1990 operating rates combined with RACT emission limits.

                 The Phase II and III targets are preliminary and subject to change as RACT and policy decisions are finalized.

                 This figure includes only target emissions for affected sources; the Phase II and III budget also includes nonaffected sources, exceptional circumstances, and the
                 10,000 ton reserve (phase II only).

-------
                                                 Figure 111-3
               NOx Emission Targets from Affected Sources by Zone and State
                                                                                                  Baseline = 190,847
                                                                                                     RACT= 119,793
                                                                                                 D Baseline
                                                                                                    PACT
                                                                                                    Phase III
                                                                                                    Phase II
                                                     State
               Inner Zone
Northern Zone   Outer Zone
RACT reductions are based on preliminary Information and are estimated based on 1990 operating rates combined with RACT emission limits.
The Phase II and III targets are preliminary and subject to change as RACT and policy decisions are finalized.
This figure Includes only target emissions for affected sources; the phase II and III budget also Include nonaffected sources, exceptional circumstances, and
the 10,000 ton reserve (phase II only).

-------
         450,000 I
                i


         400,000 |

                i
                i

         350,000 +


     "w
     §   300,000 r
to
cn
 CO
 o
'55
 V)
III
     c
     o
         250,000
         200,000
         150,000
         100,000
          50,000
              0 \	
                                                           Figure III-4
                                                 OTR NOx Budget Summary
                               D 10,000 ton Reserve
                               • Exceptional Circumstances
                               • Baseline
                   1990 Baseline
                                  RACT
Phase I
Phase III
  RACT reductions are based on preliminary infomation and are estimated based on 1990 operating rates combined with RACT emission limits.
  The Phase II and III targets are preliminary and subject to change as RACT and policy decisions are finalized.

-------
26

-------
            APPENDIX A
PHASE II AND III TARGET LEVELS BY STATE

-------
Baseline Sources
Target Report - May-September Emissions
State Level Emissions Data
Final OTC NOx Baseline Inventory
08/10/95
Slate
Connecticut
Delaware
Washington DC
Maine
Man/land
Massachusetts
New Hampshire
New Jersey
New York
Pennsylvania
Rhode Island
Vermont
Virginia
OTR Total
Design Capacity Heat Input
(10x8 Btu/hr) (10x« Btu)
44.752
26.304
11.642
29.971
81,423
. 78.105
11,068
139,986
239.523
255.942
2,978
842
19,834
942,370
61,284.609
43,893,578
4,315.427
22,524,735
139,601,865
139,045.355
21,688,403
97,648,670
394,796.337
519.522.699
4,161,143
521,640
22,067,343
1,471,071,804
NOx Emissions
(Tom/May-Sept.)
5-Month
11.203
13,180
576
4,419
54,990
40,367
12.946
44,360
84.484
199,639
1,099
30
5,799
473,092
55%
5,041
5,931
259
1.989
24,746
18,165
5,826
19,962
38,018
89,838
495
14
2,610
212,892
65%
3,921
4,613
201
1,547
19,247
14.128
4.531
15,526
29.570
69.874
385
11
2,030
185,582
75%
2,801
3,295
144
1.105
13,748
10.092
3.237
11,090
21.121
49,910
275
8
1.450
118,273
0.20
6,128
4,389
432
2,252
13.960
13,904
2,169
9,765
39.480
51.952
416
52
2.207
147,107
0.15
4.596
3,292
324
1,689
10,470
10.428
1.627
7.324
29.610
38.964
312
39
1,655
110,330
RACT
7,625
8,582
532
3,160
39,497
20.231
8.047
18,744
61.667
126,119
421
30
3,910
298,566
5S%/0.2
6,785
6,327
443
2,460
25,672
20,016
5,627
21,125
46,351
92,306
495
52
2.771
230,630
Maximum of
65%/0.2
6.331
5,251
435
2,373
20,933
16,949
4,591
17.129
42,364
73.026
416
52
2,282
192,133
75%/0.15
4.728
3,825
325
1.769
15,127
12,423
3,319
12,365
31,486
52,426
312
39
1.676
139,819
Phased
5.790
5.729
479
3,160
21,629
16,670
4.591
14,987
45.628
90.700
416
30
2.304
212,115
Phase III
4.522
3,810
383
2,459
15,523
12,620
3,319
12,124
32.164
51,994
312
30
1.702
140,961
The MOU establishes Phase II and potential Phase III NOx fm/ta.
The methodology for applying these limits, Including how RACT should be Incorporated. Is currently being considered by the OTC.
RACT (preliminary Information provided by the State) Is Included in the Phase II and III calculations
The budget calculation also Incorporates consideration tor exceptional circumstances and the 10,000 ton reserve (Phase II only).

-------
Target Report - May-September Emissions
Plant Level Emissions Data
DMtan CiMcttv

001 FalrfMdCo
0195 UNITED ILLUMINATING - BRIDGEPORT HARBOR
341 7 CONN UGHT & POWER CO - GREENWICH
4214 CONN UGHT & POWER CO - NORWALK
003 Hartford Co
1510 PRATT « WHITNEY AIRC
3058 CONN UGHT & POWER CO -SOUTH MEADOW
3668 CAPITOL DISTRICT ENERGY CENTER
8601 DEXTER NONWOVENS DIV
005 UtchfMdCo
1424 CONN UGHT & POWER CO -FRANKUN OR
(10x6 Btu/hr)

6,857
765
2,834

1,614
2,592
717
555

230
1443 CONN UGHT & POWER CO - TORRINGTON TERM 230
Final
HMt Input
(10x6 Btu)

15,639,731
16.412
7,045,303

192.815
64,592
1.461.142
1,738,978

9,545
3,301
OTC NOx Baseline Inventory
Connecticut
Emtatlon NOx EmtelOM
Rat*
(lb«'10xfl Btu)

0.524
0.829
0.209

0.367
0.829
0.157
0.152

0.602
0.602
(Ton*/Miy-S»pU
8-Month

4,150
7
1,054

35
27
115
132

3
1
65%

1,868
3
474

18
12
52
60

1
0
65%

1,453
2
369

12
9
40
46

1
0
75%

1,038
2
263

9
7
29
33

1
0
0.20

1,584
2
705

19
6
146
174

1
0
0.18

1,188
1
528

14
5
110
130

1
0
RACT

2,692
4
878

24
16
115
131

2
1
Maximum of
6S%/0.2

1,889
3
705

19
12
146
174

1
0
65%/0.2

1,584
2
705

19
9
146
174

1
0
75V0.1S

1,188
2
528

14
7
110
130

1
0
PtaMll

1,584
4
705

19
16
115
131

2
1
1
08/10/95

Phtttlll

1,188
4
528

14
16
115
131

2
1
007  MlddlMMCo
0874   CONN LIGHT & POWER CO-MIODLETOWN        8,647
6.561,606
               0.664
2,179
                                    980
                                           763
545
                                                         656
              492
                      820
                              1,020
                                        855
621
                                                                                                             754
                                                                                                                      629
008 NmttavwiCo
0404 CONN LIGHT i POWER CO -BRANFORO
2514 CONN UGHT & POWER CO -DEVON
3346 UNITED ILLUMINATING CO - ENGLISH
3851 UNITED ILLUMINATING CO - NEW HAVEN HARBO
Oil New London Co
0604 PFIZER INC-CHEMICALS
1505 CONN UGHT & POWER CO -MONTVILLE
1544 AESTHAMESINC
240S NORWICH PUBLIC UTIL - 80. GOLDEN ST
2901 CONN UGHT & POWER CO - TUNNEL
3102 FEDERAL PAPER BOARD CO
3603 CONN UGHT & POWER CO
8tttt Total

270
S.S96
779
4,286

084
6,296
1,846
164
230
275
185
44,782

4,728
6.301,392
143,939
9,519,985

1,186,320
4,981,102
5,440,970
10,176
1.979
759,480
1,013
61,284,609

0.602
0.300
0.263
0.275

0.367
0.292
0.060
0.701
0.602
0.300
0.501
0.366

1
946
19
1,308

217
727
163
4
1
114
0
11,203

1
426
9
589

96
327
73
2
0
51
0
5,041

0
331
7
458

76
254
57
1
0
40
0
9,921

0
236
5
327

54
182
41
1
0
28
0
2,801

0
630
14
952

119
498
544
1
0
76
0
6,128

0
473
11
714

89
374
408
1
0
57
0
4,696

1
787
18
1,139

148
589
163
2
0
95
0
7,828

1
630
14
952

119
498
544
2
0
76
0
6,788

0
630
14
952

119
498
544
1
0
76
0
6,331

0
473
11
714

89
374
408
1
0
57
0
4,728

1
633
14
952

119
500
163
2
0
76
0
8,790

1
478
11
714

89
378
163
2
0
57
0
4,822
The MOU estabtshee Phase II and potential Phase III NOx tmlts.
The methodology tor applying these Units, Including how RACT should be Incorporated, Is currently being considered by the OTC.
RACT (preliminary Information provided by the States) Is Included In the Phase II and III calculations.
The budget calculation also Incorporates consideration for exceptional circumstances and the 10,000 ton reserve (Phase II only).

-------
Target Report - May-September Emissions
Plant Level Emissions Data
                                                         Final OTC NOx Baseline Inventory
                                                                           Delaware
                                                                                                          2

                                                                                                   08/10/95
                                         DMlgn Capacity
                                          (10x8 Btu/hr)
                                                        H*it Input
                                                                   EmlMton
                                                                     Rite
                                    (Toi»
-------
 Target Report • May-September Emissions
 Plant Level Emissions Data
              Final OTC NOx Baseline Inventory
                           Washington DC
                                                                                                             3
                                                                                                     06/10/95
                                          DMlgnCqMdty
                                            (me Btu/hf)
            Hut Input
                                                                     Emtsilon
                                                                       R«ta
                                      NOx EmlMloM
                                     (Ton»/M»y-6«pt)
            (10«8BtU)  (Ibt/IOrt Btu)  6-Month    65%   68%   75%    0.20
                                           ________   	Maximum ot
                                            0.16  RACT   65%/0.2   65V0.2  75%/D.1B  Ph-««lt  Ph-Mlll
 001  Washington
 0001   PEPCO • BENNINQ
 0024   QSA-WE8T HEATINQ
 0025   QSA-CENTRAL HEATINQ
 0040   PEPCO-BUZZARD POINT
 6574
 1.072
 1,524
 3,472
3.503.265
 341.071
 227.687
 243,404
0.239
0369
0.138
0.650
418
 63
 16
 79
168
 28
  7
 36
146
 22
  8
 28
104
 16
  4
 20
350
 34
 23
 24
283
 26
 17
 18
400
 38
 16
 79
350
 34
 23
 38
350
 34
 23
 28
263
 26
 17
 20
350
 34
 16
 79
283
 26
 16
 79
State Total
11,642
                                                          4,315,427
            0.207
                       576
                   259    201
                     144    432    324
                                532
                                  443
                                                        438
                                                        128
                                                                                                                                                          479
                                                                                                                                                                  383
The MOU establishes Phase II and potential Phase III NOx tmlts.
Tr*m*riodology tor applying these limits. Including hmr RACT should bo Incorporated, Is currently being consldond by the OTC.
MCTfpreimlrmry Information provided by the States) Is Included In the Phase II and III calculations.
The budget eateifartfen also Incorporates consideration tor exceptional circumstances and the 10,000 ton reserve (Phase II only).

-------
Target Report - May-September Emissions Final
Plant Level Emissions Data

Plant ID/NaiiM
003 AnxMtookCo
0001 MAINE PUBLIC SERVICE COMPANY, CARIBOU
0027 FRASER PAPER. LTD.
0051 FAIRFIELD ENERGY VENTURE, LP.
005 Cumberland Co .
0135 CENTRAL MAINE POWER WYMAN STATION
0138 S.D. WARREN CO. SCOTT PAPER CO.
007 Franklin Co
Oaalgn Capacity
(10x6 Btu/hr)

194
302
523

6.202
1,449

0021 INTERNATIONAL PAPER COMPANY-ANDROSCOGGIN2.994
0023 STRATTON ENERGY ASSOCIATION
009 Hancock Co
0004 CHAMPION INTERNATIONAL CORP
Oil KannebacCo
0062 SCOTT PAPER WINSLOW PLANT
015 Lincoln Co
0010 CENTRAL MAINE POWER • MASON STATION
017 Oxford Co
0045 BOISE CASCADE PAPER COMPANY
019 PanobacotCo
0029 BANQOR HYDRO- GRAHAM STATION
0034 JAMES RIVER CORP. (OLD TOWN)
0058 WHEELABRATOR-SHERMAN ENERGY CO.
0056 GREAT NORTHERN PAPER INC. (MILL.)
005S GREAT NORTHERN PAPER, INC (E.M.)
025 SonwrMtCo
0027 8. D. WARREN CO. SCOTT PAPER CO
029 Washington Co
0020 GEORGIA-PACIFIC CORPORATION
State Total
672

1,165

290

1,239

1,910

1,413
1,021
264
2.442
1,236

2,928

1.677
29,971
Haat Input
(10x6 Btu)

31,465
159,510
6,460

9,265,126
716,619

2,928,532
40,684

1,470,068

76.435

36.445

1,304,034

77.720
952,385
849
3,284,061
627,134

764,892

778316
22,524,738
OTCNG
Emission
. Rata
(Ib*/10x6 Btu)

0.449
0.386
0.132

0.319
0.685

0.369
0.164

0.380

0.362

0.447

1.000

0.440
0567
0.142
0.364
0564

0501

0562
0.392
>x Baseline
Maine
i Inventory
NOx Embatona
(Tons/May-Sapt.)
5-Month

7
29
0

1,463
245

540
3

279

14

9

652

17
175
0
595
114

115

141
4,419
55%

3
13
0

667
110

243
2

126

6

4

293

6
79
0
268
51

52

63
1,989
65%

2
10
0

519
88

189
1

96

5

3

226

6
61
0
206
40

40

49
1347
75%

2
7
0

371
61

135
1

70

4

2

163

4
44
0
149
26

29

35
1,106
0.20

3
16
1

929
72

293
4

147

8

4

130

6
95
0
326
63

76

78
2^52
0.15 RACT

2 5
12 16
0 0

696 1586
54 148

220 324
3 3

110 167

6 9

3 6

96 391

6 12
71 105
0 0
245 357
47 68

57 78

SB 65
1,6M 3,160
4
08/10/95
Maximum of
55%/OJ

3
16
1
•
929
113

293
4

147

8

4

296

6
95
0
326
63

76

78
2,460
65%/0.2

3
16
1

929
88

293
4

147

6

4

235

6
95
0
326
63

76

76
*37»
75V0.15

2
12
0

696
63

220
3

110

6

3

168

6
71
0
245
47

57

56
1,76t
Phaaall

5
16
0

1586
148

324
3

167

9

6

391

12
105
0
357
68

78

85
3,160
Phaaalll

5
16
0

929
112

293
3

147

6

4

296

8
95
0
326
63

76

78
2,459
The MOUeetabtsrm Phau II and potential Ptuue III NOx limits.
TkA •rurflinrfrtfcimf 4v mf^Julftft thnmn Am/to frw*Ju?feM RMM BAt*T *K/v jM Ma /MMUVWU*»*A*| tf jwMwutMk* KM/MM «Mui»l«tMMW An; AM S1W*
RACT (preliminary Information provided by tht States) Is Included In the Phase II and III calculations.
The budget calculation also Incorporates consideration tor exceptional circumstances and the 10,000 ton reserve (Phase II only).

-------
 Target Report • May-September Emissions
 Plant Level Emissions Data
                 Final
         OTC NOx Baseline Inventory
                    Maryland
                                                                                                  5

                                                                                          08/10/95
Pttrn JDrfMtm
DMign Capacity   H««i Input
 (10x6 Btu/hr)    (10x6 Btu)
                           EmtMton
                             Rate
                                                                                                 NOx Emtalom
                                                                                                 fTone/M»y-8«Pt.)
                                                                                 S-Month    55%   65%   75%   030    0.15  RACT   B5V/0.2  65V0.2  75%/0.15 Pheeell   Pheeelll
001  AlteganyCo
0011    WESTVACO

003  Arme Arundel Co
0014    BALTO. GAS & ELEC.-WAGNER STATION
0468    BALTO. GAS & ELEC.. BRANDON SHORES

005  BaMmonCo
    1.023
5,140.390
1.174     3,017     1,356   1,056    754    514    386  3,017     1,358     1,058     756    1.358      756
    8,814       17.202,714
    6.760       17.068,852
             0863      7.426     3,342  2.509   1,857  1,720   1,290  6,806
             0.419      3.576     1,606  1.252    894  1.707   1,280  3,576
                                                          3,401     2,702    1,649    2,702    1.949
                                                          1.707     1.707    1,280    1,707    1,280
0078 BALTO. GAS « ELEC. - NOTCHCUFF
0078 BALTO. OAS & ELEC. - RIVERSIDE
0079 BALTO. GAS & ELEC.- CRANE
017 CtwrtoCo
0014 POTOMAC ELECTRIC MORGANTOWN
019 Dorchester Co
0019 OELMARVA POWER VIENNA
02S rtarfordCo
0024 BALTO. GAS & ELEC. - FERRYMAN
031 Montgomery Co
0019 POTOMAC ELECTRIC DICKERSON
033 Prince George* Co
0014 POTOMAC ELECTRIC • CHALK POINT
1827 SMECO- CHALK POINT
043 Washington Co
0005 POTOMAC EDISON COMPANY
810 Baltimore
0008 BALTO. GAS & ELEC. -WESTPORT
0007 BALTO. GAS & ELEC.- GOULD STREET
0265 BALTO. GAS ft ELEC.- PHILADELPHIA RD
State Total
2.144
8.470
3,680

13,750

2,131

2,616

4,938

20,524
924

1,455

3.477
1.085
1,032
11,423
606.632
5,418.239
8.376.351

30,661,207

1,446,160

451,440

14,564,413

31,696,601
557.158

1,977,205

2.593.412
1,564,130
74.981
139,601,888
0.404
0.424
1.272

0.942

0.390

0.503

0.682

0.802
0.181

0.777

0.525
0.300
0.490
0.768
123
1.150
5,329

14.537

282

114

4,968

12,719
SO

768

680
235
16
84,990
55
517
2.398

8,542

127

51

2.235

5,723
23

346

306
106
8
24,746
43
402
1,665

5,088

99

40

1,738

4,452
18

269

238
82
6
19,247
31
287
1,332

3.634

71

26

1,242

3,180
13

192

170
59
5
13,748
61
542
838

3,086

145

45

1,456

3.170
56

198

259
158
7
13,980
45
406
628

2,315

108

34

1,092

2,377
42

148

195
117
8
10,470
123
835
5,329

5,944

262

114

4,988

7,611
50

450

442
235
18
M.497
81
562
2498

6,542

145

51

2.235

6,336
56

346

311
156
6
28,672
61
642
1.665

5,088

145

45

1.738

5,234
56

289

2S9
156
7
20,933
45
406
1,332

3,634

108

34

1,242

3,788
42

192

195
117
6
15,127
123
568
1,885

5.192

145

114

1.738

5,246
50

346

301
156
18
21,829
123
438
1,332

3.754

109

114

1.242

3.802
50

192

247
117
18
18,823
The MOUestatishes Phase II and potential Phase III NO* Imlts.
The methodology for applying these Hmtta, Including how MCTehouldbe Incorporated. Is currently being considered by the OTC.
RACT (preliminary Information provided by the States) te Included In the Phase II and III calculations.
Th« budget eateutafon also incorporates consideration tor exceptional circumstances and the 10,000 ton reserve (Phase II only).

-------
Target Report - May-September Emissions
Plant Level Emissions Data
                                Final  OTC NOx Baseline Inventory
                                               Massachusetts
                                                                                                                  6
                                                                                                          08/10/95
Plant ID/Nam*
                                           Cmtowon
               DMlgn Capacity   Haat Input  .   Rat*     	
                (10xeBtu/hr)     (10x6 Btu)  (Iba/10x6 Btu) B-Month
                                                                                                    NOxEmhaloM
                                                                                                   fTona/May-Sapt)
                                                                                Maximum of
                                                                                             55%   65%    75%    0.20   0.15   RACT   85X/D.2  65%/0.2  75%/0.15  PhaaaH  Phaaalll
001  Barmtabto Co
0054   CANAL ELECTRIC CO
•1200054'M
                                               10,229
                               21,246,827
                                                                          0.479
                        5.092
                  2,291   1.782   1,273  2,125   1.594   2,947    2,710     2,352
1,719    2,352
1.719
003  Berkshire Co
0006   ALTRESCO PITTSRELD     *1170006*M         1.290          658,659
0186   WOODLAND ROAD                            230           8,489
0167   DOREEN STREET                            230           7,268
0168   SILVER LAKE                                920           16,087

008  Bristol Co
0041    CANNON ST.STATION     '1200041*M          964          539.698
0060   MONTAUP- SOMERSET     '1200060'M         2.894        3.643,045
0061    NENQP-BRAYTON POINT  '120 0061'M       15,250       35,056,991
0067   TAUNTONMUN LIGHT PL    '1200067'M        1.671        1,371,446

009  EMWtCo
0138   GENERAL ELECTRIC CO     '1190138'M          643          665,406
0194   N.E.POWER-SALEM      '1190194'M           7.215       19,619.331
0.035
0.506
0.506
0.489
0.530
0.541
0.790
0.502
0.558
0.733
11
2
2
4
143
1.040
13.849
345
186
7.190
5
1
1
2
64
468
6,232
155
84
3,236
4
1
1
2
50
364
4.847
121
65
2,517
3
1
0
1
36
260
3,462
88
46
1.798
66
1
1
2
54
384
3.506
137
67
1,962
49
1
1
1
40
268
2,629
103
50
1.471
11
1
1
2
76
709
6,481
192
106
2,976
66
1
1
2
64
468
6,528
155
64
3,236
66
1
1
2
54
384
5,279
137
89
2.646
49
1
1
1
40
288
3,803
103
52
1.927
11
1
1
2
54
384
5,094
151
75
2.562
11
1
1
2
40
289
3.603
125
62
1.927
Oil  Franklin Co
0032   INDECK
                                                 240
                                                              353,806
                                                                          0.577
                                                                                     102
                                                                                              46
                                                                        36
                                                                                                            26    35     27
                                                                                                                                56
                                                                                                                                        46
                                                                                                                                                 36
                                                                                                                                                         27
                                                                                                                                                                  58
                                                                                                                                                                          58
013  rtempdwiCo
0001    MASS.WHOLESALE ELEC.    '042 000 VM
0038   HOLYOKEGAS&ELEC CABOT  '0420038'M
0040   HWP MT. TOM STATION     '042 0040'M
0117   WESTERN MASS.ELEC CO    '0420117'M

017  MMdtoMxCo
0092   COM.ELECT-BLACKSTONE    '1190092'M
0093   COM.ELECTRIC-KENDALL    M190093'M
0128   BOSTON EDISON MYSTIC    *119 0126'M
0265   LOWELL COGEN
0600   STATION 240
4040   PEPPERELL POWER

021  Norfolk Co
0133    STATION 446
0227    EDGAR STATION
0491    BRAINTREE ELECTRIC    M19 0491'M
                   4,760
                     547
                   1,450
                   2,722
                    828
                   1.469
                  10,301
                    286
                    594
                    390
                   2.022
                    396
                    652
 3,621.716
  323,565
 4,757,636
 1,021,821
  172,614
 1.222,246
21.013,323
  664,395
    7,952
 1.038,476
   56,762
    5,166
  793,296
0.300
0.515
1.000
0.268
0.532
0.536
0.269
0.316
                                             0.143
0.601
0.698
0.444
025  Suffolk Co
0012   BOSTON EDISON N.BOST    '1190012'M        7.612        19.147.172      0.549
0507   TRIGEN-aOST.ENER.COR    >118050rM        2.100        1,808,160      0.471
The UOU establishes Phase II and potential Phase III NOx Imlts.
The methodology for applying these limits, Including how RACT should be Incorporated, fe currently being considered by the OTC.
PACT (preimlnary Information provided by the States) Is Included In the Phase II and III calculations.
The budget calculation also Incorporates consideration for exceptional circumstances and the 10,000 ton reserve (Phase II only).
543
83
2,379
137
46
327
2,630
105
3
74
17
2
176
5,253
426
244
37
1,070
62
21
147
1.273
47
1
33
6
1
79
2,364
192
190
29
633
48
18
115
990
37
1
26
6
1
62
1,839
149
136
21
595
34
11
62
707
26
1
19
4
0
44
1,313
106
362
32
476
102
17
122
2,101
66
1
104
6
1
79
1,915
181
272
24
357
77
13
92
1,576
50
1
78
4
0
59
1.436
136
371
45
1,070
127
24
171
2,321
67
1
74
8
1
79
2,059
253
362
37
1,070
102
21
147
2.101
66
1
104
6
1
79
2,364
192
362
32
833
102
17
122
2,101
68
1
104
6
1
79
1,915
181
272
24
595
77
13
92
1,576
SO
1
78
4
0
59
1,436
136
371
44
833
102
24
122
2.102
67
1
74
6
1
79
1,915
181
371
44
595
77
24
92
1,576
67
1
74
8
1
79
1,436
136

-------
  Target Report - May-September Emissions             Final OTC NOx Baseline Inventory                                                         7

  Plant Level Emissions Data                                          Massachusetts                                                                08/10/95


                                                                    Emission                   NOiEmbskm*
                                          DMlgn Capably  HMthtput   .  Rite     	(Ton«/M«y-S»pl.)	   	M»»lmumof	
 PtocHIOfttom*	(10x6 Blu/hf)    (10x6 Btu)  (Ibt/IOrt Btu)  S-Monlh   68%    65%   75%   0.20    0.15   RACT   KtU02  6S%/0.2  75W0.1S  Ptm»n  PhmMffl

 025 Suffolk Co
 0507   TRtGEN-BOST.ENER.COR    M190507'M       2.100        1,608.160      0.471       426     192    140    100    181    136     253     102     181     136     181     138
 State Total                                    71,105      139,045,355     0.581     40,307   18,105  14,128  10,092  13,904  10,428  20,231   20,018   16,949   12,423   16,670   12,620
Th» MOU estabHshes «I«M // jmdpotonflW Phas» III NOx ftnfts.
Th» methodology tor implying thost HmHs, Including haw MCT should bo toa»poratrt. Is curnntly being considered by tho OTC.
RACT (prottmtnory Information provided by the States) Is Included In the Phase II and III calculations.
Th« budget cateutetten also incorporates consideration far exceptional circumstances and the 10,000 ton reserve (Phase II only).

-------
Target Report • May-September Emissions
Plant Level Emissions Data
             Final OTC NOx Baseline Inventory
                           New Hampshire
                                                                                                             8
                                                                                                      08/10/95
                                          DMl0n Capacity   Moat Input   .   Rate     	
                                           (10x0 Btu/hf)    (10x6 Btu)  (IbaflOrtMu)  6-Month
                                                  NOxEntfMlona
                                                 (Ton*/M«y-Sapt)
                                           85%    65%   75%   0.20   0.16  RACT   5S%/0.2  6SV0.2  76%/0.1S  PhaoaR  PhaaoHl
013  MwrtmaekCo
0026   PSNH. MERRIMACK STATION
 4,506
 9,303,363
                         2.055
         9,558    4.301   3,345  2,390    930    096  S.697
                                                4.301
                                                3345    2,390    3.345    2.390
015  RocktnghamCo *
0012   PSNH, SCHILLER
0054   PSNH. NEWINQTON
 2.152
 4.350
 3.854,351
 6.530.669
0.566
0.539
1.091
2,297
 491
1,034
382
604
273
574
385
853
269   863
640  1.488
 492
1,034
392
853
290
640
392
653
290
640
State Total
11,06*
21,688,403
                                                                      1.194
        12,946    8,826   4,831   1,237   2,189   1,627  1,047     5,827     4,891     8,31*     4,591
                                                                                                                                                                S.319
Jtm MOU MtaMfeftw Phau U md potential Phau III NOx Imlts.
77M mtthodohgy (or applying thasa Imlts, Including how MCT should bo incorporated, Is currently Mng consMendby tha OTC.
MCT(pr»trr^ln1orma«on provided by tha States) Is Included In the Phase Hand III calculations.
The budget calculation alto Ineoipontet consideration for exceptional circumstances and the 10.000 ton reserve (Phase II only).

-------
  Target Report - May-September Emissions
  Plant Level Emissions Data
                  Final OTC NOx Baseline Inventory
                                   New Jersey
                                                                                                                   9
                                                                                                           08/10/95
 PtontD/Nwiw
Dsslgn Cspsdty
 (10x6 Btu/hr)
                                                             H*st Input
            Emission
              Rat*
                          NOx Emissions
                          fTom/M«y-8«pt.)
                                                        Majdrnumof
(10x6 Blu)   (Ibs/10x6 Btu)  6-Month    85%    65%   75%   050    0.18   RACT   BS%/0.2   65%/0.2  75%A).1B  Phsss H  PhsSS III
 001  AttenttoCo
 0002   AC ELEC CO - MISSOURI
                                                  939
                                                                55,618
                                                                           0.502
                                                                                       14
                                                                                    11
                                                                                                                      11
                                                                                                                                                                           11
 003  BwgsnCo
 0012   PSE&G-BERGEN
 0803   PRIME ENERGY UMITEO PARTNERSHIP
    8,527
     700
6.601.039
2,347.849
1.077
0.192
4.631
 225
2,084   1.621
 101     79
1,158
  58
880
235
845
176
880
223
2,084
 235
1.621
 235
1,158
 176
880
223
880
223
 008  Burlington Co
 0003   PSE&G • BURLINGTON
                                                12.109
                1,296,844
                             0.554
                         359
                                  162
                                                                                                     126
                                                                                                            90
                                                                                                                  130
                                                                                                                          97
                                                                                                                                201
                                                                                                                                        162
                                                                                                                                                 143
                                                                                                                                                         106
                                                                                                                                                                  163
                                                                                                                                                                          138
 000 C&DS Msy Co
 0001   AC ELEC CO • B.L ENGL                       4.620
 0013   AC ELEC CO - MIDDLE ST                      1.058

 Oil CumtwrlsndCo
 0020   VINELAND MUNICIPAL ELECTRIC UTILITY          627
 0048   AC ELEC CO • CARLUS C                       1.306
 0171   VINELAND MUNICIPAL ELECTRIC UTILITY          417
 0222   AC ELEC CO • CUMBERLAND                   1.032

 013 EtttxCo
 0016   PSE&Q-ESSEX                             10.715
018 Gloucester Co
0004   COASTAL EAGLE POINT OIL COMPANY
0006   MOBIL OIL CORPORATION
0037   ACELECCO-MICKELTON
0999   PSE&Q • NATIONAL
017  Hudson Co
0021   PSE&Q-HUDSON                          12,503
0022   PSE&Q-KEARNY                           13,168
0577   COGEN TECHNOLOGIES -NEW JERSEY VENTURE  1.484
09B9   PSE&Q-BAYONNE                           810

019  HimtwtfonCo
0001    JCP&L-GILBERT                            8.926
0013   JCP&L-GLENGARD                         2,720
0110   KAMNE MILFOHD LIMITED PARTNERSHIP          438

021  MsresrCo
0001    PSE&G- MERCER                            8,304
                8.357.354
                 101,805
                 377.160
                 245.318
                  51.170
                 209,833
                2.758,300
              1.199
              0.501
              0.449
              0.693
              0.657
              0.073
             0.493
          5,009
            26
            85
            65
            17
            8
                                                                                     680
JS4
11
38
38
8
3
1.763
9
30
30
6
3
1,252
6
21
21
4
2
838
10
38
25
5
21
627
8
28
18
4
16
2,179
20
S3
25
10
8
2,315
11
38
38
8
21
1.837
10
38
30
6
21
1.318
8
28
21
4
16
1.837
20
38
25
10
8
1,318
20
28
25
10
8
                                                                                              306
                                                                                                    238
                                                                                                           170
                                                                                                                  276
                                                                                                                         207
                                                                                                                               246
                                                                                                                                        352
                                                                                                                                                287
                                                                                                                                                         207
               19.399,605
               1.453,045
               5,016,086
                  6,480
             1.422
             0.340
             0.029
             0.901
        13.794    6,207  4,828   3,448   1,940  1.455   3,872
          247      111     88     62    145    109     158
           72       32    25     18    502    376     72
            3        111101
               3.691,147       0587
                 573.552       0.482
                 550,200       0.431
                        714      321
                        138       82
                        119       S3
                         250
                          48
                          42
                      179
                       35
                       30
                    369
                     57
                     55
              277
               43
               41
             400
              58
              55
              376
               62
               55
              12.154.949
                                                                          1.717
                                                                                   10.432
                                               4.895   3.651   2,608   1715    912  6.050    4.695
                360
                 67
                 55
                                                                                                                                              3.651
                 277
                  43
                  41
                                                                                                                                                                 246
                 388
                  58
                  55
                                                                                                                                                                          246
1482
1,674
1,092
327
3.075,900
3,356,221
291.802
3,555
0.514
0.400
0.540
0.900
790
671
79
2
356
302
35
1
277
235
28
1
198
168
20
0
308
336
29
0
231
252
22
0
431
470
29
1
356
336
35
1
308
336
29
1
231
252
22
0
308
336
29
1
231
252
29
1
6,207
170
502
1
4,828
159
502
1
3.448
119
378
1
3,872
158
72
1
3,453
131
72
1
                                                                                                          2.608    3.655
                 365
                  58
                  41
                                                                                                                                                                        2.616
TheUOUestabtshes Phase II and potential Phase IttNOxtmlts.
The methodology for applying these tmlts, Including rwMCTshoutd be Incorporated. Is currently being considered by fo
MCT (preliminary Information provided by the States) Is Included In the Phase II and III calculations.
Th« budget calculation also Incotporatoe consideration tor exceptional circumstances and the 10.000 ton reserve (Phase II only)..

-------
Target Report - May-September Emissions
Plant Level Emissions Data
                 Final  OTC NOx Baseline Inventory
                                  New Jersey
                                                                                                                10
                                                                                                          08/10/95
Plant ft/Name
DMtgn Capacity
 (10*8 Btu/nf)
                                                           Hurt Input
                                                                         Rata
                                        NOxEmteatona
                                       (ToM/May-Sapt)
                                                                                                                                           Maximum of
(10x6 Btu)   (lba/10K6Btu)  8-Monlh    55%    65%   76%    0.20    0.18  RACT   85V0.2  65%/0.2  78W0.16  PhaaaN   Phaaalll
023  MlddleMxCo
0006   JCP&L-WERNER GE
0007   JCP&L -SAYERVILLE
0008   PSE&G-SEAWAREN
0023   CHEVRON USA. INC.
0008   PSE&G - EDISON
    9,970
    6,600
    7.260
      257
    9.720
  61B.773
 3.889,339
 4,431.044
  171.450
   81.128
0.575
0.450
0517
0.700
0.678
 178
 875
 480
  60
  38
80
394
218
27
18
62
306
166
21
12
44
219
120
15
9
62
389
443
17
8
46
292
332
13
6
98
434
451
24
16
                                           80
                                          421
                                          451
                                           27
                                           18
                                            68
                                           389
                                           448
                                            21
                                            12
                                              50
                                             292
                                             335
                                              15
                                               9
                                                82
                                               387
                                               451
                                                21
                                                16
                                                 71
                                                312
                                                342
                                                 IS
                                                 16
029  Ocean Co
0001    CIBAQEIGY CORPORATION
0007    ACELECCO-CEOARSTA
0255    JCP&L • FORKED RIVER
      259
    1.089
      900
  232,125
   56,014
  162,870
0.481
0.499
0.171
  56
  14
  16
 25
  6
  7
 20
  5
  5
 14
  3
  4
 23
  8
 18
 17
  4
 14
 26
 11
 16
 25
  6
 16
 23
  6
 18
 17
  4
 14
 23
 11
 16
 17
 11
 16
033  Salem Co
0001    AC ELEC CO • DEEPWATER
0044    PSE&G-SALEM
    5.131
      340
 5,688.320
    8,491
0.695
0.900
1,977
   4
       692
        1
       494
        1
      569
        1
       427
         1
     1.078
        2
        690
          2
        713
          1
        515
          1
        711
          2
        519
          2
039  Union Co
0011    PSE&G -LINDEN
0052    BAYWAY RERNING COMPANY
   13.947
      655
 6.823,984
 1,490,000
0.593
0.594
2,023
 443
910
199
706
155
506
111
682
149
612
112
947
209
910
199
731
155
526
112
729
155
540
112
State Total
  139,986
97,648,670
                                                                         0.909
         44,360   19,962  15,826  11,090   9,768   7,324  18,744   21,112   17,118    12,354   14,979   12,111
The MOU establishes Phase II and potential Phase III NOx Imlts.
The methodology for applying those limits, Including bow RACT should be Incorporated, Is currently being considered by the OTC.
RACT (preliminary Information provided by the States) Is Included In the Phase II and III calculations.
The budget calculation also Incorporates consideration for exceptional circumstances and the 10,000 ton reserve (Phase II only).

-------
Target Report - May-September Emissions
Plant Level Emissions Data
Plant n/Nama (10x6 Btu/nr)
001 Albany Co
0366 NIAGARA MOHAWK -ALBANY STATION 6.224
007 Broom* Co
0292 NYSEG - GOUDEY STATION 1 ,41 7
013 Chautauqua Co
0325 NIAGARA MOHAWK - DUNKIRK STATION 5.376
0340 S A CARLSON 677
017 Chcnango Co
0083 NYSEG • JENNISON STATION 1,072
029 EriaCo
0133 YERKES ENERGY 432
0161 BETHENERGY LACK COKE 422
0163 BSC BAR PRODUCTS DIV 590
1700 NIAGARA MOHAWK • C R HUNTLEY STEAM ST 7,084
031 EasaxCo
0105 TICONDEROGA MILL 522
048 J*ff*raon Co
0255 FORT DRUM HTW COGEN 651
047 King* Co
CE01 CON ED- HUDSON AVE GEN STA 8,149
GGEN CONEO-GOWANUSGEN 0.568
NGEN CON ED -NARROWS GEN 4,752
OSS MonroaCo
0258 KODAK PARK DIV 4,113
1152 RG&E-BEEBEE STATION 804
1752 RG&E- RUSSELL STATION 2.740
089 Naaiau Co
31 52 ULCO - E F BARRETT 7,430
4187 ULCO -QLENWOOO STATION 3,302
5705 TBG COGEN COGENERATI 324
061 NawYoricCo
CE01 CON ED -59THST GEN STATION 3.493
CE02 CON ED • 74TH ST GENERATING STATION 3,149
The MOU establishes Phase II and potential Phage HI NOx tmlts.
Final OTC NOx Baseline Inventory
New York
Emtoilon NOx Emlaalona
Hut Input . R«t* (Tom/May-8*pl)
(10x« Bto) (Ibs/IOxe 61u)

11.291,493

3.579.822

16.314.138
1,332.500

1,949,903

1.307,014
140,818
336.872
20,808,353

1.551,514

1,465.929

4,416.502
216,049
544,029

8,862,626
1,826559
6.490,245

12.601,665
5,922.543
1.745.896

1,433.608
2.325,671

0.237

0.603

0.516
0.828

0.400

0.463
0.545
0.545
0.920

0.370

0.160

0.358
0.740
0.423

1.005
0.490
0.518

0.305
0.226
0.309

0.209
0.324
5-Month

1.336

1.436

4,222
552

390

302
38
92
9.569

287

119

791
61
115

4,463
447
1.681

1,921
868
269

150
377
65% 65%

601 468

646 503

1,900 1.478
248 193

175 136

136 106
17 13
41 32
4,306 3,349

129 100

53 42

356 277
36 26
52 40

2.008 • 1.582
201 157
756 588

865 672
301 234
121 94

67 52
170 132
75% 0.20

334 1.129

359 358

1,056 1,631
138 133

97 195

78 131
10 14
23 34
2,392 2.081

72 155

30 149

198 442
20 22
29 54

1.116 888
112 183
420 649

480 1.260
167 592
67 175

37 143
94 233
0.16 RACT

847 1,282

268 804

1.224 3,422
100 397

148 292

98 131
11 14
25 34
1,561 7,343

116 194

111 119

331 552
16 44
41 109

866 2,240
137 383
487 1,360

945 1,639
444 881
131 227

108 149
174 291
Maximum of
S5%/0.2

1,129

646

1,900
248

195

138
17
41
4,306

155

149

442
38
54

2,008
201
756

1.274
594
175

144
233
65%/0.2

1,129

503

1*31
193

195

131
14
34
3.371

155

149

442
28
54

1,591
183
649

1,260
592
175

143
233
75%/0.1S

847

359

1,224
138

146

96
11
25
2,446

116

111

331
20
41

1,144
137
487

945
444
131

108
174
PhM*N

1,133

646

1,900
348

195

131
14
34
4,306

194

119

442
44
109

2,008
201
756

1,349
601
227

144
233
11
08/10/95
Phaaalll

855

359

1,224
310

146

131

25
2,448

155

111

332
109

1,144
137
487

1,059
455
227

108
175
The methodology for applying those Imlts. Induing how MCT should be Incorporated, Is currently being considered by the OTC.
flat^T /nmUtnlnmnt InfrujTT-** 	 *-* — '* — *•- - *-«— * 	 > •- • 	 »-.-« 	 i i^ *». _ «u 	 ••__.».....
Th* budget calculation also Incorporates consideration for exceptional circumstances and the 10,000 ton reserve (Phase II only).

-------
Target Report - May-September Emissions
Plant Level Emissions Data
DM Ign Capacity
Plant KMteim (10x6 Btu/hr)
061 New York Co
CE04 CON ED - EAST RIVER GENERATING
CEOS CON ED - WATERSIDE GENERATING
083 Niagara Co
0118 OCCIDENTAL CHEMICAL
0383 AMERICAN REF-FUEL Nl
0430 NYSEG - KINTIGH (SOMERSET)
071 Oranga Co
0370 CEN. HUDSON • DANSKAMMER POINT
0475 CEN. HUDSON • ROSETON GENERATING S
075 OmvegoCo

5,196
15,656

787
646
6,475

4,764
10,794

0115 NIAGARA MOHAWK -OSWEGO GENERATING STA. 10.132
021 1 OSWEGO ENERGY CO. - INDECK
081 Qtmna Co
CE01 CON ED • ASTORIA GENERATING STATION
CE02 CON ED • RAVENSWOOD GENERATIN
CE03 CON ED- RAVENSWOOD -A- HOUSE
ULC ULCO • FAR ROCKAWAY STATION
PANY CHARLES POLETTI POWE
OSS Richmond Co
CE01 CON ED • ARTHUR KILL GENERATI
PG01 PORT IVORY PLANT
087 RocMandCo
0228 BOWLINE POINT
0720 LOVET GENERATING STATION
533

17,469
23.055
1,420
1,060
8,266

7,481
360

10,920
4,722
Final
Heat Input
(10x6 Btu)

8.543,672
8.773,767

49.929
579.649
21,232.447

13,266,660
24,629.562

24,415.459
569,202

30.348.809
35,154.567
668.587
2.821,589
11,482.541

9,999,082
293,344

25,373,679
9,594,709
OTC NOx Baseline
New York
Emission
.. Rita
(Iba/10x6 Btu)

0.324
0.127

0.139
0.862
0.530

0.481
0.431

0.461
0.162

0.279
0.329
0.367
0.261
0.359

0.279
0.136

0.259
0.770
6-Month

1.385
556

3
250
5,625

3,191
5.302

5,625
52

4,235
5,788
126
368
2,063

1.396
20

3.264
3,695
55%

623
250

2
113
2,531

1,436
2,386

2.531
23

1.906
2.604
57
166
928

626
9

1.478
1,683
» Inventory
NOi Embalona
(Tom/May-Sapt)
65%

485
195

1
68
1,969

1.117
1,656

1,969
18

1.482
2,025
44
129
722

469
7

1,150
1.293
75%

346
139

1
63
1.406

798
1,328

1.406
13

1,059
1,447
31
92
516

349
5

821
924
0.20

654
877

5
58
2.123

1,327
2,463

2,442
57

3,035
3,515
69
282
1,148

1.000
29

2,537
959
0.18

641
658

4
43
1,592

995
1.847

1.831
43

2.276
2.637
51
212
861

750
22

1.903
720
RACT

1.052
556

3
130
4,778

2.373
3.077

3,050
49

3,687
4,214
86
353
1,435

1,232
20

3,040
2,018
Maximum of
65%/OJ

854
877

S
113
2,532

1,637
2,463

2,890
57

3,048
3,517
69
282
1.146

1,000
29

2,537
1,675
65V0.2

854
877

5
88
2,123

1.345
2,463

2,462
57

3,035
3,515
69
262
1,148

1,000
29

2.537
1,330
7S%/0.16

641
658

4
63
1,592

995
1.847

1.831
43

2.276
2,637
51
212
881

750
22

1,903
955
PhaaaN

854
556

3
113
2.532

1,292
2,463

2.810
49

3.092
3,554
69
282
1.148

1.000
20

2.537
1,330
12
08/10/95
Phnaltl

641
520

3
63
1,593

995
1,847

1,831
49

2.347
2.684
51
212
861

750
20

1.903
955
091  Saratoga Co
0146   HUDSON RIVER MILL
  589
              1.573,110       0.600
                           472      212    165     118     157     118     197
                                                                  212
                                                                                          185
                                                                                                   118
                                                                                                                                                                           197
                                                                                                                                                                                    118
101  SteubwiCo
0110   NYSEG - HICKLING STATION
 1,414
 2,824,605
               0.400
                           565
                     254
                                           198
                                                   141
                       282
212
424
262
                                                                           282
                                                                                    212
                                                                                                                                                                           282
                                                                                                                                                                                    212
103  Suffolk Co
1922   ULCO - NORTHPORT POWER STATION
2110   ULCO • HOLBROOK
3228   ULCO • PORT JEFFERSON PR ST
3537   ULCO - WADING RIVER
13,681
 7,380
 4.466
 2.571
32,394,318
  865,660
 8,823,623
  675,456
0.300       4,857
0.850        368
0.360       1,587
0.250         84
2,185   1,700   1.214  3239
  186     129      92     87
  714     556     397    682
  38     30      21     68
2.430
65
682
51
4,048
173
1.102
84
3.239
166
682
68
3,239
129
862
68
2,430
92
662
51
3,239
173
882
64
2.430
173
662
84
The MOU estabtshes Phase II and potential Phase III NOx Imlts.
The methodology for applying those Imlta, Including how RACT should be Incorporated. Is currently being considered by the OTC.
RACT (preliminary Information provided by the States) Is Included In the Phase II and III calculations.
The budget calculation also Incorporates consideration for exceptional circumstances and the 10,000 ton reserve (Phase II only).

-------
Target Report • May-September Emissions
Plant Level Emissions Data

103 Suffolk Co
BR1C ULCO - BBOOKHAVEN COM
EHIC ULCO - EAST HAMPTON 1
SHIC ULCO-SOUTHOLOICSI
WBIC ULCO • WEST BABYLON 1
100 TompkfmCo
0120 NYSEQ -MILUKEN STATION
110 WMtohMtorCo
Z504 CON ED • BUCHANAN
123 YatMCo
0028 NYSEQ - GREENIDQE STATION
Stata Total
Final
Daalgn Capacity H*at Input
(10x6 Btu/nr) (10x6 Btu)
677
274
223
678
3,001
785
1.877
239,523
2.441
55,785
4.591
39,030
9,490.781
11.837
3.713,457
394,796,337
OTC NOx Baseline Inventory
New York
Ccntewon
Rata
(IbaSIOrt Blu) 6-Month
0.596 1
0.750 21
0.549 1
0.550 11
0.670 3.179
0.713 4
0.573 1.064
0.428 64,484
NOx Emhaton*
(Tona/Miy-Sapt)
55% 65%
0 0
9 7
1 0
5 4
1,430 1.113
2 1
479 372
38,018 29,570
75%
0
5
0
3
795
1
266
21,121
0.20
0
6
0
4
949
1
371
39,480
0.15
0
4
0
3
712
1
279
29,610
RACT
0
11
1
6
1,993
2
785
61,667
Maximum of
85N/0.2
0
9
1
5
1,430
2
479
46,381
65%/OJ
0
7
0
4
1.113
1
396
42^64
75%/O.IS Phaaa II
0 0
5 11
0 1
3 a
795 1,430
1 2
294 479
31,486 45,628
13
08/10/95
Phaaain
0
11
1
8
795
2
294
32,164
77w MOUestabishes Ph*s» II and potential Phase IIINOxtmHs.
RACT (preliminary Information provided ty tha States) Is Included In the Phase II and III calculations.
The budget calculation also Incorporates consideration for exceptional circumstances and the 10.000 ton reserve (Phase II only).

-------
Target Report - May-September Emissions
Plant Level Emissions Data
Dealgn Capacity
Plant ID/Name (10x6 Btu/hr)
001 Adams Co
0017 METROPOLITAN EDISON COMPANY 978
KAMI MET EDISON HAMILTON 150
ORTA MET EDISON ORTANNA 150
003 Allegheny Co
0009 USX CORPORATION -EDGAR THOMSON WORKS 3,652
001 1 USX CORPORATION - CLAIRTON WORKS 3,495
0029 OUQUESNE LIGHT COMPANY. CHESWICK STATION 5,260
0031 DUOUESNE LIGHT COMPANY, BRUNOT STATION 3,604
0050 SHENANGO IRON & COKE WORKS 2,796
005 Armstrong Co
0001 WEST PENN POWER CO. 3.720
0012 PECO -KEYSTONE 15.160
007 Beaver Co
0005 PENN POWER CO, -BRUCE MANSFIELD 23,742
0011 LTV STEEL COMPANY 300
0032 ZINC CORPORATION OF AMERICA 1 ,200
0042 AES BEAVER VALLEY PARTNERS. INC. 1 ,377
011 Berks Co
0045 METROPOLITAN EDISON CO. -TITUS 2,635
013 Blair Co
0009 PECO-WILLIAMSBURG 388
017 Bucks Co
0006 PHILADELPHIA ELECTRIC CO. -CROYDEN 4,496
0055 UNITED STATES STEEL CORP., THE 1,676
029 Chester Co
0023 PHILADELPHIA ELECTRIC CO. -CROMBY 3,191
033 OesrfleldCo
0021 PECO-SHAWVILLE 6,700
035 Clinton Co
0006 INTERNATIONAL PAPER COMPANY 512
041 Cumberland Co
0045 METROPOLITAN EDISON COMPANY 652
The MOU establishes Phase II and potential Phase III NOx limits.
Final 0
H««t Input
TC NOx Baseline Inventory
Pennsylvania
EmtMton NOx Emtotona
Rat* (Tona/Miy-Scpt)
(10x6 Btu) (Ib*/10x6 Btu) 5-Month

193,400
18.716
13.130

3.255,586
4.292.119
15.025,581
26.656
1.066.641

10,362,568
47,807.134

57,539.558
358,936
2,549,403
4,834,651

5,309,156

200,874

605,846
2.431.745

2,917,890

15.619,223

2.439.581

102,145

The methodology tor applying these Units, Including how RACT should be Incorporated,

0.446 43
0.588 6
0.594 4

0.062 101
0.158 338
0.607 4,559
0.484 6
0.143 76

0.966 5,110
0.754 18.016

0.634 23,986
0.540 97
0.603 1,024
0.834 2.016

0.659 1,749

0.867 67

0.703 213
0.262 316

0.568 858

1.029 6,037

0.546 668

0.446 23

55% 65%

19 15
2 2
2 1

46 35
152 118
2.052 1,596
3 2
34 27

2,299 1,786
8,108 6.306

10,795 8,396
44 34
461 358
907 706

767 612

39 30

96 75
143 111

366 300

3.617 2.813

301 234

10 8

75%

11
1
1

25
65
1.140
2
19

1,277
4,504

5.997
24
256
504

437

22

S3
60

214

2,009

167

6

0.20

19
2
1

326
429
1,503
3
107

1,036
4.781

5.754
36
255
483

531

20

61
243

292

1.562

244

10

0.1S RACT

15 39
1 4
1 3

244 101
322 229
1,127 3,372
2 5
60 76

777 3,066
3,566 11,100

4,315 15,152
27 56
191 615
363 1.210

396 1.190

15 52

45 128
162 249

219 536

1.171 4,827

163 401

8 20

Maximum et
55%/OJ

19
2
2

326
434
2.052
3
107

2,299
6,108

10,795
44
461
907

787

39

96
243

433

3,617

301

10

65%/0.2

19
2
1

326
431
1,596
3
107

1,786
6,306

8,396
36
358
706

613

30

75
243

364

2,813

244

10

75X/0.15

15
1
1

244
323
1,140
2
80

1,277
4,504

5,997
27
256
504

436

22

S3
182

265

2.009

183

8

PhtteH

39
4
3

101
208
2.052
5
76

2.299
6,106

10,795
44
461
907

617

39

126
243

364

3,617

301

20

14
08/10/95
Pheaelll

39
4
3

101
167
1,140
5
76

1,277
4,504

5.997
27
256
504

442

22

128
182

265

2,009

183

20

Is currently being considered by the OTC.
RACT (pnimlnary Information provided by the States) Is Included In the Phase II and III calculations.
The budaet calculation also Incorporates consideration tor exceptional circumstances and the 10.000 ton reserve i 'Phase II onM.

-------
Target Report - May-September Emissions
Plant Level Emissions Data
Daalgn Capacity
Plant ID/Nama dOxB Btu/nrt
043 Dauphin Co
0013 HARRISBURG STEAM WORKS LTD.
046 Dataware Co
0014 PHILADELPHIA ELECTRIC CO. -EDDYSTONE
0016 SCOTT PAPER CO.
0030 SPOIL. INC.
0049 CONGOLEUMCORP.
047 Elk Co
0005 PENNTECH PAPERS. INC.
049 ErtaCo
0004 INTERNATIONAL PAPER CO.
0009 GENERAL ELECTRIC CO.
0016 PECO -FRONT STREET
059 Oraana Co
0006 WEST PENN POWER CO. -HATFIELD'S FERRY
063 Indiana Co
0001 PECO-CONEMAUGH
0002 PECO-SEWARD
0003 PECO - HOMER CITY
069 Lackawanna Co
0022 ARCHBALO POWER CORPORATION
071 LancastarCo
0054 PP&L-HOLTWOOO
073 LawiwnoaCo
0025 PENN POWER CO. • NEW CASTLE
079 LuzamaCo
0014 UGI CORP. -HUNLOCK POWER
089 MomoaCo
SHAW MET EDISON SHAWNEE
093 MonlourCo
0003 PP&L-MONTOUR

209

14,260
1,076
700
300

500

953
676
1.626

15.102

15.600
1.991
18.446

249

966

4.518

553

ISO

15,094
Final
Haat Input
(10x6 Btu)

21.939

13.489.536
1.923,290
667.254
4,386

1,174.460

564.258
932.588
2.145.761

36,348.453

45,673,710
5.813.593
48.658.492

206,896

3,553^18

6.920,932

1,621,127

15,285

43,237.237
OTC NOx Baseline Inventory
Pennsylvania
Emission NOx Emissions
. Rita (Tons/May-8»pi)
(Iba/10x6 Btu) 5-Month

0.137 2

0.462 3,119
0.138 133
0.435 189
0.547 1

0.830 467

0.570 166
0.896 416
0.685 628

1041 19,955

0.760 17.356
0.766 2.226
0.938 22,815

0.245 25

1.053 1,670

0.905 3,133

0.947 663

0.569 5

0.889 19,219
55% 65%

1 1

1,403 1.091
60 46
85 66
1 0

219 171

75 56
168 146
283 220

8.980 6.964

7,810 6,074
1,003 780
10,267 7.985

11 9

842 655

1,410 1.096

388 302

2 2

8,649 6.727
75% 0.20

0 2

780 1,349
33 192
47 87
0 0

122 117

42 58
104 93
157 215

4,989 3.835

4,338 4.567
557 561
5,704 4,866

6 21

468 355

763 692

216 162

1 2

4,805 4,324
0.1S RACT

2 2

1,012 2,470
144 105
65 113
0 1

88 292

44 100
70 251
161 487

2,876 11.973

3.426 10,416
436 1,343
3.649 15,092

16 25

266 1,122

519 1,880

137 516

1 3

3,243 11.535
Maximum of
65%/0.2

2

1.559
197
91
1

219

75
188
283

8.980

7.810
1.003
10.267

21

842

1,410

388

2

8.653
65%/0.2

2

1,349
192
87
0

171

59
146
220

6,984

6.074
780
7.965

21

655

1.096

302

2

6,732
75%/0.1S

2

1,012
144
65
0

122

44
104
164

4,989

4,339
557
5,704

16

468

783

216

1

4,809
PhaaaH

2

1,353
90
67
0

219

75
188
288

8,980

7,810
1,003
10,267

25

642

1,410

388

3

6,652
15
08/10/95
PhaaaKI

2

1.017
83
65
0

122

44
104
177

4,969

4439
557
5,704

25

468

763

216

3

4.809
The MOU establishes Phase Hand potential Phase III Nux tmns.
Tr» methodology for applying those limits. Including how RACT should be Incorporated, Is currently being considered by the OTC.
nAl*T AirMffmfnttfM lnfs\»f*imttrm Mju«.WriVtjtf hu M.A ^taftuil t
nACi (preliminary information provneo oy me statesf n
s Included In the Phase II and III calculations.
L»« AMM*k«*/u^i — ' 	 -a- — 	 __.J -• 	 tf M A4%J« A__ 	 	 tf\t 	 •• 	 «..t

-------
Target Report - May-September Emissions
Plant Level Emissions Data
                 Final  OTC NOx Baseline Inventory
                                 Pennsylvania
                                                                                                                16

                                                                                                         08/10/95
Plant ID/Mima
Daalgn Capacity   H«at Input   .   Rate     	
 (10x8B1u/hr)     (10x6 Btu)  (lb«/10«6 Btu) S-Monlh
                                                                                                   NOxEmlMleiM
                                                                                                  (Ton«/M«y-S«pt)
                                                                               Maximum of
                                 65%   65%    75%    0.20   0.16   PACT   55S/0.2  65%/OJ  76%/0.16  Pheae HPheee III
095  Northampton Co
0010   PP&L • MARTINS CREEK
0011   MET EDISON CO. - PORTLAND
0048   BETHLEHEM STEEL CORP.
   21,038        17,591,683      0.684     5,844     2,630  2,045   1,481   1,759  1,319   3,518
    4,239        8,222,634      0.633     2,601     1,171    910    650    822    817   1,835
    1,313        3,227,592      0.235       379      170    133     95    323    242    287
                                                                          2,709    2,252     1,650     2,634    1,596
                                                                          1,171     911      654     1,171      654
                                                                           323     323      242      287      242
097  Northumberland Co
0031    FOSTER WHEELER MT. CARMEL
      624
                                                             584,039
                              0.095
                                          28
                                                  12
                                                                                                    10
                                                                                                                 58
                                                                                   28
                                                                                            58
                                                                                                    58
                                                                                                                                                        44
                                                                                                                     28
                                                                                                                             28
101  Philadelphia Co
1501    SUN REFINING AND MARKETING 1 OF 2
1551    ALLIED CHEMICAL CORP
1568    CONTAINER CORP OF AMER
4901    PECO ENERGY - DELAWARE
4902    PHILA THERMAL - SANSOM
4903    PHILA ELECTRIC CO
4904    PECO ENERGY - SCHUYLKILL
4942    PHILA THERMAL -SOHUYLKILL
9702    US. NAVAL BASE
1,206
967
273
3.647
1,236
1,486
1,980
2,301
701
2.529.583
781.549
4.344,433
2,026,940
881,154
273,830
1,471,154
987,491
16,254
0.427
0.484
0.097
0.450
0.447
0.800
0.282
0.322
0.143
540
189
211
458
197
82
208
159
1
243
85
95
205
89
37
93
72
1
189
88
74
160
69
29
73
56
0
135
47
S3
114
49
21
52
40
0
253
78
434
203
88
27
147
99
2
190
59
326
152
66
21
110
74
1
324
113
208
304
132
55
148
111
1
253
85
434
205
89
37
148
99
2
253
79
434
203
88
29
147
99
2
190
59
326
152
66
21
110
74
1
253
79
208
207
88
55
148
99
1
190
59
208
157
66
55
112
74
1
107  SehuylMIICo
0022   WHEELABRATOR FRACKVILLE ENERGY COMPANY   504        1,603,100      0.136       109       40     36     27    160    120    109      160      160      120      109      109
0023   WESTWOOO ENERGY PROPERTIES, INCORPORAT   423        1.287.032      2.250      1,448      852    507    362    129     97    869      652      507      362      652      362
0024   SCHUYLKILL ENERGY RESOURCES. INC.          1.184        2,912.745      0.121       176       79     62     44    291    216    176      291      291      218      176      178
0025   GILBERTON POWER COMPANY                 1,040        2,678.086      0.130       188       84     66     47    288    216    188      288      288      216      188      188
109  SnydarCo
0002   PP&L-SUNBURY

123  WarranCo
0004   PECO-WARREN
    5.870



    1.024
14.602,445
                                                            2,284,743
                          0.652
                                                                         0.619
                                                                                   6,222
                                                                                    707
                                            2.800   2.176   1.556   1.460  1,095   3,774
                                 318
                                        248
                                               177
                                                      228
                                                            171
                                                                   570
                                          2.800
                                                                           318
                                           2,178     1.556
                                                                                    248
                                                                                                                                                       177
                                                    2.603
                                                                                                                                                                318
                                                                                                           1.561
                                                                                                                                                                        177
12S  Washington Co
0014   WEST PENN POWER CO. • MITCHELL
0024   DUOUESNE LIGHT CO. -ELRAMA
    2,546
    5,184
 5.968,482
 7,119,478
                         0.723
                         0.882
                                                                                   2,157
                                                                                   3,138
 971
1,412
 755
1.098
539
785
597
712
448
534
1,493
1,883
 971
1,412
 755
1,098
539
785
 971
1,412
539
785
129  Waatmoratond Co
0007   MONESSEN INC.
      030
                  587,980
                                                                         0.149
                                                                                     44
                                                                                              20
                                                                                                    15
                                                                                                           11
                                                                                                                  59
                                                                                                                        44
                                                                                                                                        59
                                                                                                                                                59
                                                                                                                                                                         44
131  Wyoming Co
0009   PROCTER A GAMBLE PAPER PRODUCTS CO.
      575
                 1,654,800
                                                                         0.684
                                                                                    566
                                                                                             255
                                                                                                    198
                                                                                                          141
                                                                                                                 185
                                                                                                                        124
                                                                                                                              340
                                                                                                                                       255
                                                                                                                                               196
                                                                                                                                                        141
                                                                                                                                                                255
                                                                                                                                                                        141
133  York Co
0016   GLATFELTER. P. H. CO.
1,491
77M MOU estabishes Phase H and potential Phase III NOx Km/to.
 3.745.732
                                                                         0.471
                                                                                    882
                                                 397
                                                                                                   309
               220    375
RACT (preliminary Information provided by the States) Is Included In the Phase II and III calculations.
The budget calculation also Incorporates consideration for exceptional circumstances and the 10.000 ton reserve (Phase II only).
                                                                                                                        281
                                                                                                                              570
                                                                                                                                       493
                                                                                                                                               434
                                                                                                                                                        318
                                                                                                                                                                481
                                                                                                                                                                        318

-------
 Target Report - May-September Emissions
 Plant Level Emissions Data
               Final OTC NOx Baseline Inventory
                               Pennsylvania
                                                                                                            17

                                                                                                      08/10/95
                                                                     Emtoton
 PtantKMtaflw
                                           DMlgn Capacity   H««t Input
                                                   NOx EmlMlofM
                                                   (Ton»/M«y-S«pt)
                                                                                                                                     Maximum of
(10x6BUVhr)     (10x6 Btu)   (lb«/10xe Btu> g-Month    BS%   65%   75%    0.20   0.18   RACT   K1U02   68%/D.2  75V0.15  Phwtl
 133  York Co
 0020   PPM. • BRUNNER ISLAND
 TOLN  MET EDISON TOLNA

 State Total
  14.215
    300

 2SS.M2
 39.536,884
    39.798


619,622,fl«
0.665
0.588
13,149
   12
S.917  4.602   3^87  3^54  2,965   6.875
   543438
5,917
   5
4,602
   4
3,287
   3
5.917
   B
3.287
   8
0.769    1M.839    M.838  69,074  49,«10  51,95J  M.964 126,119   92,306   73,026   52,426   90,760   51,994
T7» MOU MtaMs/Ms Phasa II *nd potential Phase III NO JMts.
The methodology for applying those limits, Including how RACT should be Incorporated, Is currently being considered by the OTC.
RACT (preHmlntry Information provided by the States) fe Included In the Phase II and III calculations.
Th» budget eafcutatfon also Incorporates consideration for exceptional circumstances and the 10,000 ton reserve (Phase II only).

-------
Target Report - May-September Emissions             Final OTC NOx Baseline Inventory                                                        18

Plant Level Emissions Data                                             Rhode Island                                                                  08/10/95


                                                                     Emission                    NOx Cmlaalona
                                          DMlgn Capacity   Haat Input   .  Rata     _ (Tona/May-Sapt) _   _ Maximum of _
Plant ID/Nama                                (10x6Btu/hr)    (10x8 Btu)  (Iba/10x6 BUi) 5-Month    55%   65%    75%   0.20   0.15  RACT   B5%/0.2   65V/0.2  75V0.1S  PhaaaH  Phaaam
007
0037   NARHAGANSETT EUECTRICJSOUTH STR. STATION 1,340        2,094,667      0.526      551      246    193     138    209    157    213      24B      209      157     209     157
0039   NARRAGANSETT ELECTRO                   1,636        2.066.476      0.530      548      246    192     137    207    155    206      246      207      155     207     155


Stata Total                                      2,978        4,161,143      0.528      1,099      495    385     275    416    312    421      495      416      312     416     312
The MOU establishes Phase /(ami potential Phau III NOx Units.
Tht mathodotogy for applying thtea Umlts, Including how MCT should be Inwrporatod, k currMtty being considered by tho OTC.
RACTfpnHmlnaiy Information provided by the States) Is Included In the Phase II and ill calculations.
The budget calculation also Incorporates consideration for exceptional circumstances and the 10,000 ton reserve (Phase II only).

-------
 Target Report - May-September Emissions             Final OTC NOx Baseline Inventory                                                      19

 Plant Level Emissions Data                                               Vermont                                                                  08/10/95


                                                                   EirfMton                   NOxCmlMloM
                                         DMlgnCtpttHy   KM! Input   .  IUrt«    	{Ton«/M«y-8«pt)	  	MMtmumol	
 Plant IDfltem*	(10x6 Btuftif)    (10x6 Blu)   (Ibi/IOrt Blu) 84lS       30      14     11      8    52    39     30     52      52      39      30      30
TN» MtM/MtabfeftM Hus* ffflndpotenfWPfWM IIINOxImlts.
Tho methodology for applying those tmtts. Including hew RACT should be Incorporated, Is currently being considered by the OTC.
MCT(pre*mtoary Information provided by the States) Is Included In the Phase II and III calculations.
The budget cafcujatfon also Incorporates consideration for exceptional circumstances and the 10.000 ton reserve (Phase II only).

-------
Target Report - May-September Emissions             Final OTC NOx Baseline Inventory                                                         20

Plant Level Emissions Data                                                 Virginia                                                                       08/10/95


                                                                      Emtoilon                    NOx EmtMkxw
                                          DMlgn Capacity   Hot Input   .  Rat*     	(Ton»/May-Sapt)	   	Maximum of	
Plant ID/Namo	(10x6BWnr)     (10x6 Btu)   (lb«/10x8B1u)  6-Menlh    85%   65%    75%   0.20    0.15  BACT   65K/0.2  65V0.2  75X/0.15 PhaM fl   PhtMlll

183  Prince William Co
0002  VIRGINIA POWER                          15.011        10,994.332      0.456      2.520    1,134    882     630   1.099    825   1,813    1,295    1.108      828    1.128      851

S10  Alexandria
0003  PEPCO                                   4.823        11,073.011      0.592      3.279    1,475   1,147     820   1.107    830   2.098    1.475    1,178      850    l.li'0      850

State Total                                      19,834        22,067,343      0.520      5,799    2,610   2,030   1,450   2£07   1,658   M10    2,771    2£82    1,676    2,304     1,702
77w MOUtstabtsIm Phu» II tnd potential Phase III NOx Imlts.
Tt* mtihodotogy tor applying thttitmlts, Deluding how RACT should be Incorporated, Is cumntfy being considered by the OTC.
RACT (pntHmtnary Information provided by the States) Is Included In the Phase II and III calculations.
The budget calculation also Incorporates consideration for exceptional circumstances and the 10,000 ton reserve (Phase II only).

-------
            APPENDIX B
FINAL 1990 OTC NOX BASELINE INVENTORY:
          FIVE MONTH DATA

-------
Detail Report - Five Month Data
Point-Segment Level Data
DMlgn 5-Monlh
Plant Capacity Activity
Affected Point SCC/Descriotfon (10x6Bturhr) Fee/Code
001 Fair-field Co - Inner Zone - Severe
Final OTC NOx Baseline in
Connecticut
Heat Content
(10x6 Btul Heat Input
Fuel Use/Units SCO Unit) (10x6 Btu)




ventory
Slat* Emission
Factor/Code Con.
(Ibs/SCC Unit) EM.


0195 UNITED ILLUMINATING - BRIDGEPORT HARBOR
Affected 160 10100401 Residual Oil 800 0.399 2
Affected 162 10100401 Residual Oil 1.700 0.504 2
Baseline 166 20100901 Kerosene/Naphtha 257 0.489 3
PS9 4.100
Affected 10100212 Bituminous Coal 0.432 2
Affected 10100404 Residual Oil 0.430 3
3417 CONN LIGHT & POWER CO - GREENWICH
BaieHna 052 20100901 Kerosene/Naphtha 255 0.707 1
Baseline 069 20100901 Kerosene/Naphtha 255 0.569 1
Baseline 064 20100901 Kerosene/Naphtha 255 0.570 1
4214 CONN LIGHT & POWER CO - NORWALK
028 1.467
Affected 10100404 RealdualOII 0.433 2
Affected 10100501 Distillate OH 0.420 3
090 1.467
Affected 10100404 Residual Oil 0.416 2
Affected 10100501 Distillate OH 0.420 3
003 Hartford Co - Inner Zone - Serious
1510 PRATT & WHITNEY AIRC
Affected 163 10200401 Residual Oil 269 0.417 3
Affected 164 10200401 RealdualOII 288 0.417 3
Affected 166 10200401 Residual Oil 286 0.417 3
Affected 167 10200401 Residual Oil 408 0.417 3
Affected 168 10200401 Residual Oil 406 0.417 3
3058 CONN LIGHT & POWER CO - SOUTH MEADOW
Baseline 260 20100901 Kerosene/Naphtha 324 0.773
Baseline 261 20100901 Kefoeene/Naphtha 324 0.773
Baseline 282 20100901 Kerosene/Naphtha 324 0.618
Baseline 283 20100901 Kerosene/Naphtha 324 0.618
Baseline 284 20100901 Karosene/Naphttia 324 0.844
Baseline 285 20100901 Kerosene/Naphtha 324 0.844
Baseline 286 20100901 Keroaene/Naphtha 324 0.761
Baseline 287 20100901 Kerosene/Naphtha 324 0.761
3666 CAPITOL DISTRICT ENERGY CENTER
P64 717
Baseline 20300102 Distillate Oil 0.417 3
Baseline 2030O202 Natural Gas 0.417 3
10.117.8
22.167.6
13.2

413.900.0
29.4

60.0
27.5
34.8


22.012.2
156.7

24.255.0
135.2


35.0
601.7
339.9
178.1
131.4

92.0
92.0
31.5
31.5
60.8
60.8
57.8
57.6


890.3
1, 336.5
1000 Gal
1000 Gal
1000 Gal

Tons
1000 Gal

1000 Gal
1000 Gal
1000 Gal


1000 Gal
1000 Gal

1000 Gal
1000 Gal


1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal

1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal


1000 Gal
10x6 Cu Ft
151.07
151.08
135.00

26.47
150.98

134.70
133.70
133.70


151.37
140.00

151.41
140.00


150.00
150.00
150.00
150.00
150.00

133.60
133.60
133.60
133.60
133.00
133.00
133.40
133.40


140.00
1.000.00
1,528,498
3,349,081
1.782

10,955.933
4.439

8.082
3.677
4.653


3.331.987
21,938

3,672.450
18.928


5.250
90.255
50,985
26,715
19.710

12^91
12.291
4,208
4.208
8,086
8,086
7,711
7.711


124.642
1.336.500
67.0
67.0
67.8

14.8
42.0

111.7
110.8
110.9


45.4
20.0

45.4
20.0


55.0
55.0
55.0
55.0
55.0

110.8
110.8
110.7
110.7
110.3
110.3
110.6
110.6


33.6
149.0
Sing Stk Rep Cond
Sing Stk Rep Cond
AP-42

1990 5 Mo. OEMS
AP-42

Sing 8ft Rep Cond
Sing 81k Rep Cond
Sing 61k Rep Cond


State Factor
AP-42

State Factor
AP-42


AP-42
AP-42
AP-42
AP-42
AP-42

Sing Stk Rep Cond
Sing 8* Rep Cond
Sing Stk Rep Cond
Sing Stk Rep Cond
Sing Stk Rep Cond
Sing Stk Rep Cond
Sing Stk Rep Cond
Sing Stk Rep Cond


State Factor
State Factor
Baseline
Five Emission Rats
Month flbs/IOrt Btu)

4,1504
338.9
742.6
0.4
3,068.3
3.087.7
0.6
M
3.4
1.S
1.9
1,053.6
50f.4
499.8
1.6
5522
550.9
1.4

35.4
1.0
16.5
9.3
4.9
3.6
264
5.1
5.f
1.7
1.7
3.4
3.4
312
32
114.6
114.8
15.0
99.6

0324
0.444
0.443
0.502
0.559


0429
0.829
0.829
0.829
0.299
0.299


0.299



0467
0.367
0.367
0.367
0.367
0.367
0429
0.829
0.829
0.829
0.829
0.829
0.829
0.829
0.829
0.157
O.J57


1
06/26/95
Target (Point Level)
RACT

2.692.1
191.1
418.6
0.3
2,0823


4.1
2,0
0.9
t.2
8784
416.1


460.4



24.1
0.7
11.3
6.4
3.3
2,5
16,1
3.f
3.1
1.0
1.0
2.0
2.0
1.9
1.9
1144
»T4.6


Phase II Phase III

1,5*4.1
152.9
334.9
0.3
1.096.0


4.1
2.0
0.9
1.2
704.5
335.4


369. 1



194
0.5
9.0
5.)
2,7
2.0
10,1
3.J
3.J
1.0
1.0
2.0
2.0
1.9
1.9
1144
114.6



1,188.1
114.6
251 J!
0.3
822.0


4.1
2,0
0.9
12
52M
25J.5


276.9



144
0.4
6.6
3.8
2.0
1.S
16.1
3.1
3.1
1.0
1.0
2.0
2,0
1.9
1.9
114.6
114.6



-------
Detail Report - Five Month Data Final OTC NOx Baseline Inventory
Point-Segment Level Data Connecticut
Design 5-Month Heat Content State Emission
Plant Capacity Activity (10x8 Btu/ Heat Input Factor/Code Con.
Affected Point SCCPeseriptkm 	 dOrt Btu/hrt Fac/Code Fuel Use/Units SCC Unit) (10x6 Ptu) 	 (IWSCC Unit) 	 Eft.
003 Hartford Co - Inner Zone - Serious
8601 DEXTER NONWOVENS DIV
P29 555
Baseline 20200103 Distillate OH 0.633 3
Baseline 20200203 Natural Gas 0.633 3
005 Litchf ield Co - Inner Zone - Serious
1424 CONN LIGHT & POWER CO - FRANKLIN DR
Baseline 067 20100901 Kerosene/Naphtha 230 0.745 1
1443 CONN LIGHT & POWER CO - TORRINGTON TERM
Baseline 068 20100901 Kerosene/Naphtha 230 0.636 1
007 Middlesex Co - Inner Zone - Serious
0874 CONN LIGHT & POWER CO - MIDDLETOWN
096 769
Affected 10100401 Residual Oil 0.516 2
Affected 10100501 Distillate Oil 0.380 3
098 1,143
Affected 10100401 Residual Oil 0.348 2
Affected 10100501 Distillate Oil 0.333 3
100 2.014
Affected 10100401 Residual Oil 0.467 2
Affected 10100601 Distillate OH 0.370 3
Baseline 102 20100901 Kerosene/Nsprmia 230 0.434 1
Baseline P02 10100401 Residual Oil 160 0.423 3
P03 4.331
Affected 10100404 Residual Oil 0290 2
Affected 10100601 Distillate OH 0.363 3
009 New Haven Co - Inner Zone - Serious
0404 CONN LIGHT & POWER CO - BRANFORD
Baseline 008 20100901 Kerosene/Naphtha 270 0.585 1
2514 CONN LIGHT & POWER CO - DEVON
BaseRne 039 10100401 Residual Oil 223 0453 3
Affected 042 10100401 Residual Oil 888 0.425 2
044 266
Affected 10100401 Residue! Oil 0.461 2
Affected 10100501 Distillate OK 0.360 3
045 266
Affected 10100401 Residual Oil 0.461 2
Affected 10100501 Distillate Oil 0.360 3
049 266
Affected 10100401 Residual Oil 0.409 2
407.7 1000 Gal
1,681.9 10x6CuFt

71.5

24.6



2.671.2
6.8

7.110.6
11.0

24.948.0
1.1
13.7
1.039.3

8,047.2
13.8


35.1

710.9
4,452.0

1.083.6
3.2

1.083.6
3.2

1.062.6

1000 Gal

1000 Gal



1000 Gat
1000 Gal

1000 Gal
1000 Gal

1000 Gal
1000 Gal
1000 Gal
1000 Gal

1000 Gal
1000 Gal


1000 Gal

1000 Gal
1000 Gal

1000 Gal
1000 Gal

1000 Gal
1000 Gal

1000 Gal
140.00
1,000.00

133.50

133.10



149.69
140.00

149.78
140.00

149.64
140.00
133.60
150.00

14927
140.00


134.70

150.00
15121

151.19
140.00

151.19
140.00

15124
57.078
1.681.900

9.545

3,301



399.852
952

1.065.026
1.540

3,733219
154
1.830
155.895

1201206
1.932


4.728

106.635
673.187

163.829
448

163.829
448

160.708
34.5
149.0

80.4

802



67.0
20.0

67.0
20.0

131.1
20.0
80.4
67.0

44.8
20.0


81.1

45.0
45.4

67.0
20.0

67.0
20.0

67.0
Baseflne
Five Emission Rate
Month nba/10x6Btu)
1324
132.3
State Factor 40.0 7.0
State Factor 40.0 125.3

Sing Stk Rep Cond

Sing Stk Rep Cond



AP-42
AP-42

AP-42
AP-42

Sing Slk Rep Cond
AP-42
Sing Stk Rep Cond
AP-42

Sing Stk Rep Cond
AP-42


Sing Stk Rep Cond

State Factor
State Factor

AP-42
AP-42

AP-42
AP-42

AP-42
2.9
2.9
1.0
1.0

2,178.7
89.6
89.5
0.1
238.3
2382
0.1
1.63S.2
1,6352
0.0
0.6
34.8
180.3
1802
0.1

M
».4
945.7
T6.0
101.0
38.3
364
0.0
36.3
36.3
0.0
35.6
35.6
0.152
0.152
0.602
0.602
0.602
0.602

0.664
0.448


0.449


0.876


0.602
0.447
0.300



0.602
0.602
0400
0.300
0.300
0.442


0.442


0.442

Target
2
06/26/95
(Point Level)
PACT pnase n KIWM m
131.0
131.0
1.7
1.7
0.6
0.6

820.1
50. f


1333


466.7


0.3
19.S
150.3



0.9
0.9
786.7
13.3
84. t
20.5


20.5


20.1

131.0
131.0
1.7
1.7
0.6
0.6

7S3£
40.1


106.7


466.7


0.3
19.5
120.3



0.9
0.9
632.9
13.3
67.3
16.4


16.4


16.1

1314)
131.0
1.7
1.7
0.6
0.6

628.9
30.1


80.0


408.8


0.3
19.5
902



0.9
0.9
478.1
13.3
50.5
12.3


12.3


12.1


-------
Detail Report - Five Month Data Final OTC NOX Baseline In
Point-Segment Level Data Connecticut
DMlgn 5-Montti Heal Content
Plant Capacity Activity (10x6 Btu/ Heat Input
Affected Point SCC/DetcrlDtten (10x6 Btu/hr) Fac/Code Fuel Use/Units SCCUnlt) (10x6 Btu)
009 New Haven Co - Inner Zone - Serious
2514 CONN LIGHT & POWER CO - DEVON
048 266
Affected 10100501 Distillate OH 0.353 3
049 266
Affected 10100401 RetldualOII 0.409 2
Affected 10100501 Distillate Oil
Affected 052 10100401 Residual Oil
055
Affected 10100404 Residual Oil
Affected 10100501 Distillate Oil
058
Affected 10100404 Residual Oil
Affected 10100501 Distillate Oil
Baseline P26 20100901 Kerosene/Naphtha
3346 UNITED ILLUMINATING CO -
142
Affected 10100401 Residual Oil
Affected 10100501 Distillate OH
144
Affected 10100401 Residual Oil
Affected 10100501 Distillate Oil
3851 UNITED ILLUMINATING CO -
P31
Affected 10100404 Residual OH
Affected 10100501 Distillate Oil
Affected 10100604 Natural Gas
01 1 New London Co - Inner
0604 PRZER INC-CHEMICALS
Affected 012 10200401 Residual OH
Affected P01 10200401 Residual OH
1505 CONN LIGHT & POWER CO -
013
Baseline 10100401 Residual OH
Baseline 10100601 Distillate OH
014
Baseline 10100401 Residual OH
Baseline 10100501 Distillate OH
017
Affected 10100404 Residual Oil
Affected 10100604 Natural Gas
020
Affected 10100404 Residual OH
0.353 3
877 0.452 2
1.139
0.430 2
0.410 3
1,139
0.416 2
0.360 3
266 0.527 1
ENGLISH
385
0.563 2
0.360 3
394
0.569 2
0.367 3
NEW HAVEN HARBO
4&6
0.349 3
0.407 3
0.675 3
Zone - Serious

393 0.370 3
271 0.413 3
MONTVILLE
166
0.377 3
0.377 3
166
0.377 3
0.377 3
905
0.233 2
0.675 2
4.059
0.390 2
3.5
1.062.6
3.5
4.699.6

15,262.8
66.0

12.117.0
54.4
16.6


373.6
1.8

571.2
2.2


49,375.2
35.8
1.972.5


4.860.3
3.028.5


628.5
12.1

12.8
0.4

2,625.0
1.297.4

20,785.8
1000 Gal
1000 Gal
1000 Gal
1000 Gal

1000 Gal
1000 Gal

1000 Gal
1000 Gal
1000 Gal


1000 Gal
1000 Gal

1000 Gal
1000 Gal


1000 Gal
1000 Gal
10x6CuFl


1000 Gal
1000 Gal


1000 Gal
1000 Gal

1000 Gal
1000 Gal

1000 Gal
10x6CuFt

1000 Gal
140.00
151.24
140.00
151.23

151.24
140.00

151.23
140.00
133.30


151.70
140.00

151.74
140.00


151.45
140.00
1.032.75


150.00
150.00


150.00
140.00

150.00
140.00

151.35
1.030.00

151.23
490
160,708
490
710,751

2.308.346
9,240

1.832,454
7.616
2.213


56.705
252

86.674
308


7.477.874
5,012
2.037.099


732.045
454.275


94.275
1.694

1.920
56

397.294
1,336.322

3,143.437
ventory
State Emission
Factor/Cod* Con.
(Ibs/SCC Unit) Eff.
20.0
87.0
20.0
45.4

42.2
20.0

42.0
20.0
60.4


40.0
20.0

40.0
20.0


42.0
20.0
275.0


55.0
55.0


67.0
20.0

67.0
20.0

42.0
275.0

45.4
AP-42
AP-42
AP-42
State Factor

Sing Stk Rep Cond
AP-42

AP-42
AP-42
Sing Stk Rep Cond


Sing Stk Rep Cond
AP-42

Sing Stk Rep Cond
AP-42


AP-42
AP-42
AP-42


AP-42
AP-»2


AP-42
AP-42

AP-42
AP-42

AP-42
AP-42

State Factor
Ba
AAlftW^
•viinv
Five Emission Rate
Month (ItM/IOxe Btu)
945.7
3S.6
0.0
35.6
35.6
0.0
106.6
322.7
322.0
0.7
255.0
254.5
0.6
0.5
18.0
7.5
7.5
0.0
11.4
11.4
0.0
1,308.5
1.306.5
1,036.9
0.4
271 3.

217.5
134.2
83.3
727.1
213
21.1
0.1
0.4
0.4
0.0
233.5
55.1
178.4
472.0
471.5
0.300
0.442
0.442

0.300
0378


0.277


0.453
0.263
0.264


0.264


0.275
0.276




0467
0.367
0.367
0.292
0.44»


0.439


0.272


0.300


3
06/26/95
Target (Point Level)
RACT Phase n Phase III
786.7
20. 1
20.1

88.8
289.2


229.6


0.3
18.0
7.1


10.9


1.138.8
1.138.8




148.3
9f.5
56.8
588.8
11.9


0.2


183.3


393.4

632.9
f&r
16.1

71.1
231.8


184.0


0.3
14.4
5.7


8.7


952.0
952.0




118.6
73.2
45.4
500.5
M.9


0.2


f73.4


315.0

478.1
12.1
12.1

S3.3
173.8


138.0


0.3
10.8
4.3


6.5


714.0
714.0




89.0
54.9
34. r
3784
Jt.9


0.2


130.0


236.2


-------
Detail Report - Five Month Data
Point-Segment Level Data
Final OTC NOx Baseline Inventory
Connecticut
Oaatan 5-Month Haat Content State Emission
Plant Capacity Activity (10*6 Btul H«at Input Factor/Cod* Con.
Affected Point SCC/DaacrlDtkM (10x8BhVhr) Fac/Code Fuel Use/Units SCO Unit) (10x6 Btu) flba/SCC Unit) EH.
01 1 New London Co - Inner Zone- Serious
1505 CONN LIGHT & POWER CO - MONTVILLE
020 4.059
Aftected 10100501 Distillate OH 0.423 3 43.6 1000 Gal 140.00 6.104 20.0 AP-42
1544 A ES THAMES INC
P10 923
Affected 10100217 Bituminous Coal 0.417 3 104.227.5 Tons 26.00 2.709,915 1.6 1990 5 Mo. OEMS
Affected 10100501 DlatHlate Oil 0.417 3 75.5 1000 Gal 140.00 10,570 6.4 1990 5 Mo. GEMS
P11 923
Affected 10100217 Bituminous Coal 0.417 3 104,227.5 Tons 26.00 2,709,915 1.6 19905Mo.CEMS
Affected 10100501 DisWIate Oil 0.417 3 75.5 1000 Gal 140.00 10,570 6.4 19905Mo. CEMS
2405 NORWICH PUBLIC UTIL - SO. GOLDEN ST
Baseline 001 20100101 Distillate Oil
184 0.685 1 73.0 1000 Gal 139.40 10,176 97.7 AP-42
2901 CONN LIGHT & POWER CO - TUNNEL
Baseline 001 20100901 Kerosene/Naphtha
3102 FEDERAL PAPER BOARD CO
Affected 00? 10200401 Residual Oil
3803 CONN LIGHT & POWER CO
Baseline 007 20100901 Kerosene/Naphtha
230 0.463 1 14.8 1000 Gal 133.70 1.979 60.5 Sing Slk Rap Cond

275 0.417 3 5.063.2 1000 Gal 150.00 759,480 45.0 State Factor

185 0.417 3 7.5 1000 Gal 135.00 1,013 67.8 AP-42
Baaatlna
Flv* Emtaaton Rate
Month flba/10M6Btu)
727.1
472.0
0.4
163.1
81.5
61.3
0.2
81.5
81.3
02
3.6
3.6
0.6
Off
113.9
113.9
0.3
0.3
0.282
0.300
0.080
0.060
0.000
0.701
0.70»
0.602
0.60?
OJOO
0.300
0.501
O.S01
4
06/26/95
Targat (Point Level)
PACT Phase II pnaaam
568.8
393.4
163.1
07.5
91.5
2.1
2.1
04
0.4
«4.«
94.9
0.2
0.2
500.5
31S.O
163.1
81.5
81.S
2.1
2.1
0.4
0.4
7S.9
75.9
0.2
0.2
3784
236.2
163.1
81.S
81.S
2.1
2.1
04
0.4
57.0
57.0
02
0.2

-------
Detail Report - Five Month Data
Point-Segment Level Data
Design
Plant Capacity
Affected Point SCC/DescriDtlon (10x6Btu/hr)
5-Month
Activity
Fac/Code
001 Kent Co - Inner Zone - Severe
0002 DOVER ELECTRIC, MCKEE RUN
007 ' 203
Baseline 10100601 Natural Gas 0.505 2
002 203
Baseline 10100601 Natural Gas 0.894 2
003 7,047
Affected 10100401 Residual Oil 0.603 2
Affected 10100601 Natural Gas 0.636 2
003 New Castle Co - Inner Zone - Severe
0005 DELMARVA POWER, DELAWARE CITY
007 737
Affected 10100401 Residual Oil 0.172 2
Affected 10100701 Process Gas
Baseline 002 20100101 Distillate Oil 796
0.504 2
0.340 3
Final OTC NOx Baseline In
Delaware
Heat Content
(10x6 Btu/ Heat Input
Fuel Use/Units SCO Unit) (10x6 Btu)
3335
204.9
11,382.0
110.5
155.4
813.7
11.6
10x6 CuR
10x6 Cu Ft
1000 Gal
10x6 CuFt
1000 Gal
10x6 CuFt
1000 Gal
1,033.83
1,033.39
151.52
1,033.94
15058
1.116.33
139.00
344,472
211,742
1.724.601
114,250
23,354
908,358
1.612
ventory
State Emission
Factor/Code
Obs/SCC Unit)
550.0 AP-42
550.0 AP-42
67.0 AP-42
550.0 AP-42
67.0 AP-42
550.0 AP-42
97.7 AP-42
0006 DELMARVA POWER, WEST SUBSTATION
Baseline 007 20100101 Distillate Oil 248
0007 DELMARVA POWER, EDGE MOOR
Baseline 007 20100101 Distillate Oil 270
002 983
Affected 10100212 Bituminous Coal
Affected 10100404 Residual OH
Affected 10100501 Distillate Oil
003 7,793
Affected 10100212 Bituminous Coal
Affected 10100404 Residual OH
Affected 10100501 Distillate Oil
004 4,557
Affected 10100401 Residual Oil
Affected 10100501 CHstHlate Oil
Affected 10100601 Natural Gas
0016 STAR ENTERPRISE.DELAWARE CITY
008 396
Affected 30600106 Process Gas
Affected 30600111 OH
Affected 019 30600106 Process Gas 287
Affected 034 30600106 Process Gas 338
068 678
Affected 10100401 ReeldualOII
Affected 10100701 Process Gas
Affected 10100601 Coke
069 676
Affected 10100401 Residual OH
0.340 3

0537 3

0.445 2
0.440 3
0.440 3

0.411 2
0.443 3
0.443 3

0.529 2
0.550 3
0.540 2
PLANT

0.417 3
0.417 3
0.437 3
0.423 3

0.427 3
0.427 3
0.427 3

0.430 3
44.3

13.3

90,800.0
80.1
37.4

126.900.0
693.3
47.0

31,722.6
148.5
1,355.1


0.0
0.0
0.0
0.0

0.0
0.0
0.0

0.0
1000 Gal

1000 Gal

Tons
1000 Gal
1000 Gal

Tons
1000 Gal
1000 Gal

1000 Gal
1000 Gal
10x6 Cu R


10x6 CuFt
1000 Gal
10x6 CuFt
10x8 CuR

1000 Gal
10x8 CuFt
Tons

1000 Gal
137.80

138.00

26.35
151.00
138.00

26.32
151.00
138.00

150.97
138.00
1,036.30


1.106.00
151.00
1.108.00
1.108.00

151.00
1.108.00
29.00

151.00
6,105

1.635

2.392,580
12,095
5,161

3.340.008
104.688
6.486

4.789,161
20,493
1,404,290


600,647
81.731
316.601
1.100,470

38,815
571,524
1509,794

42,659
97.7 AP-42

97.7 AP-42

14.4 AP-42
42.0 AP-42
20.0 AP-42

14.4 AP-42
42.0 AP-42
20.0 AP-42

67.0 AP-42
20.0 AP-42
550.0 AP-42


140.0 AP-42
67.0 AP-42
140.0 AP-42
140.0 AP-42

67.0 AP-42
550.0 AP-42
21.0 AP-42

67.0 AP-42
Baseline
Con. Five Emission Rate
Eft. Month (Ibs/10x6 Btu)
559.7
97.6
91.6
56.3
56.3
4/1.7
381.3
30.4
229.5
229.0
55
223.8
0.6
2.2
2.2
3,022.0
0.7
655.6
653.8
1.7
0.4
928.7
913.7
14.6
0.5
7.436.8
1.082.7
1.5
372.7
2,109.0
56.7
37.9
18.1
20.7
69.5
588.5
8.6
141.8
438.0
647.4
9.5
0.467
0.524
0.505
0.447
0.492
0.486

0.703
0.709
0.709
0300
0.708
0.545



0.540



0.463



0.437
0.764


0.726
0.726
0.647



0.647

5
06/26/95
Target (Point Level)
PACT
410.6
55.0
33.6
327.6
117.0
776.5

0.6
25
2.2
2.312.0
0.7
648.7



576.0



7.747.3



M154
54.3


20.7
69.5
345.8



440.5

Phase II Phase III
272.7
55.0
33.6
783.9
93.7
93.2

0.6
2.2
2.2
1508.1
0.7
247.0



345.7



627.4



907.0
54.3


20.7
69.5
206.0



226.6

226.7
55.0
33.8
737.9
70.4
69.9

0.6
25
22
906.3
0.7
780.7



258.6



466.0



7195
57.2


20.7
69.5
747.7



767.8


-------
Detail Report - Five Month Data
Point-Segment Level Data
DMlgn 5-Month
Plant Capacity Activity
Affected Point SCC/Deteriotlon (10x6 Btuthr) Fac/Code
003 New Castle Co - Inner Zone - Severe
0016 STAR ENTERPRISE.DELAWARE CITY PLANT
069 618
Affected 10100701 Process Ga« 0.430 3
Affected 10100801 Coke 0.430 3
070 737
Affected 10100401 Residual Oil 0.450 3
Affected 10100701 Process Gas 0.450 3
Affected 10100801 Coke
Affected 074 30600106 Process Gas 352
0046 DELMARVA POWER, MADISON ST
Baseline 001 20100101 Distillate Oil 242
0.450 3
0.423 3

0.387 3
Final OTC NOx Baseline Inventory
Delaware
Heat Content Stele Emission
BaaailM
6
06/26/95
(10x6 Btul Heat Input Factor/Cod* Con. Five Emission Rate Target (Point Level)
Fuel Use/Units SCO Unit) <10x6 Btu) flba/SCC Unit) EH. Month fltu/10x« Btu) RACT
0.0 10x6CuFt
0.0 Tons
0.0 1000 Gal
0.0 10x6CuFt
0.0 Tons
0.0 10x6CuFt

7.8 1000 Gel
1,108.00
29.00
151.00
1.108.00
29.00
1,108.00

138.30
628.901
1.330.749
40.226
593.334
1.255.345
1.847.552

1.079
550.0
21.0
67.0
550.0
21.0
140.0

97.7
AP-42
AP-42
AP-42
AP-42
AP-42'
AP-42

AP-42
0317 DELMARVA POWER, CHRISTIANA SUBSTATION
Baseline 001 20100101 Distillate OH 391
Baseline 002 20100101 Distillate Oil 39?
0388 DELMARVA POWER, HAY ROAD
001 1.336
Baseline 20100101 Distillate Oil
Baseline 20100201 Natural Gas
00? 1,338
Baseline 20100101 Distillate Oil
Baseline 20100201 Natural Gas
0.357 3
0.350 3


0.577 3
0.577 3

0.487 3
0.487 3
117.8 1000 Gal
112.1 1000 Gal


46.7 Lbs/hr*
903.0 Lbs/hr*

72.1 Lba/hr*
601.9 Lbs/hr*
137.90
137.80


138.00
1,032.00

138.00
1,032.00
16.245
15,447


6,445
931,896

9.950
621,161
97.7
97.7


24.7
107.3

27.0
108.4
AP-42
AP-»2


MulStk Non-1 990
MulStK Non-1 990

MulStk Non-1 990
MulStk Non-1 990
2.109.0
647.4
156.1
481.8
610.7
8.9
147.3
454.5
116.7
0.4
0.4
11.2
5.0
5.5
82.6
49.0
0.6
48.6
33.6
1.0
32.6
0.437
0.647
0.647

0.126
0.70$
0.705
0.700
0.709
0.709
0.105
O.f05


O.T06


1 ,415.3
440.5
368.3

116.7
0.4
0.4
11.2
5.8
5.5
82.6
49.0


33.6


PKWII-.
907.0
226.6
213.7

116.7
0.4
0.4
11.2
5.8
5.5
82.6
49.0


33.6


Phase III
719.2
161.8
1S2.7

116.7
04
0.4
11.2
5.8
5.5
82.6
49.0


33.8


005 Sussex Co - Outer Zone - Marginal
0001 DELMARVA POWER, INDIAN RIVER
001 1.090
Affected 10100202 Bituminous Coal
Affected 10100501 Distillate Oil
002 1.059
Affected 10100202 Bituminous Coal
Affected 10100501 Distillate Oil
009 T.855
Affected 10100202 Bituminous Coal
Affected 10100501 Distillate Oil
004 S.091
Affected 10100202 Bituminous Coal
Affected 10100501 Distillate Oil


0.365 2
0.104 2

0.434 2
0.297 2

0.535 2
0.330 2

0.408 2
0.368 2


69.600.0 Tons
462 1000 Gal

81,200.0 Tons
126.0 1000 Gal

170.400.0 Tons
483.0 1000 Gal

338.100.0 Tons
323.4 1000 Gal


26.01
136.72

26.07
137.88

26.14
138.81

25.74
138.69


1,810,296
6,316
r
2.116.884
17.373

4.454.256
67.045

8.702.694
44.852


21.7
20.0

21.7
20.0

21.7
20.0

21.7
20.0


AP-42
AP-42

AP-42
AP-42

AP-42
AP-42

AP-42
AP-42
7.163.2
755.6
755.2
0.5
682.3
881.0
14
T.853.7
1,848.6
4.8
3.671.6
3.668.4
3.2
0.832
0.828


0.828


0.819


0.838


4.230.8
755.6


882.3


762.1


1,830.8


3,1514
340.0


397.0


762.1


1.652.2


1,790.8
188.9


220.6


463.4


917.9



-------
Detail Report - Rve Month Data
Point-Segment Level Data
DMlgn
Plant Capacity
Affected Point SCC/DMCriDtlon (10x6Btu/nr)
Final OTC NOx Baseline Inventory
Washington DC
5-Month Heal Content State Emission
Activity (10x6 Btu/ Heat Input Factor/Code Con.
Fac/Code Fuel Use/Units SCCUnlt) (10x6 Btu) Obs/SCCUnH) Etl.
001 Washington - Inner Zone - Serious
0001 PEPCO-BENNING
005 2.623
Affected 10100501 Distillate OH 0.603 3
Affected 10100505 Distillate On 0.603 3
006 2,75;
Affected 10100501 DtetHlateOII 0.620 3
Affected 10100504 Distillate OH 0.620 3
120.0
12,653.4
217.0
11,522.1
1000 Gal
1000 Gal
1000 Gal
1000 Gal
137.00
143.00
137.00
143.00
16,440
1,809,436
29.729
1.647,660
27.4
31.5
27.4
37.2
MulStK Non-1 990
Mul Stk Non-1990
MulStK Non-1 990
Mul Stk Non-1 990
0024 GSA-WEST HEATING
Affected 001
Affected 002
003
Affected
Affected
005
Affected
Affected
10200206 Bituminous Coal
10200206 Bituminous Coal

10200401 Residual Oil
10200602 Natural Oas

10200401 Residual Oil
10200602 Natural Oas
268
268
268


268


0.073 3
0.137 3

0.423 3
0.423 3

0.433 3
0.433 3
331.6
850.1

992.8
1.7

1.082.5
2.2
Tons
Tons

1000 Gal
10x6CuFt

1000 Gal
10x6CuFt
27.00
27.00

147.00
1,050.00

147.00
1.050.00
8,953
22.953

145.942
1.785

159.128
2,310
9.5
9.5

55.0
140.0

55.0
140.0
AP-42
AP-42

AP-42
AP-42

AP-42
AP-42
0025 GSA-CENTRAL HEATING
00?
Affected
Affected
004
Affected
Affected
Affected 005
Affected 006

10200501 Distillate OH
10200602 Natural Oas

10200501 Distillate OH
10200602 Natural Oas
10200501 DIstmateOH
10200501 Distillate OH
500


500


262
262

0.213 3
0.213 3

0.133 3
0.133 3
0.103 3
0.143 3

165.3
89.7

51.5
43.6
106.0
317.5

1000 Gal
10x6CuFt

1000 Gal
10x6CuFt
1000 Gal
1000 Gal

137.00
1.050.00

137.00
1.050.00
137.00
137.00

22.646
94.185

7,056
45.780
14.522
43,498

20.0
140.0

20.0
140.0
20.0
20.0

AP-42
AP-42

AP-42
AP-42
AP-42
AP-42
0040 PEPCO-BUZZARD POINT
Baseline 001
Baseline 002
20100101 Distillate Oil
20100101 Distillate Oil
1,736
1.736
0.483 3
0.520 3
896.4
867.4
1000 Gal
1000 Gal
138.00
138.00
123,703
119,701
89.7
89.7
Mul Stk Non-1 990
Mul Stk Non-1 990
7
06/26/95
BaaeHnsj
FhfS) Emission Rate
Month (Ib*/10x6 Btu)
417.*
200.7
1.6
199.0
2/7.2
3.0
214.2
63.0
1.6
4.0
27.4
27.3
0.1
29.9
29.8
0.2
1S.7
7.9
1.7
6.3
3.6
0.5
3.1
I.I
3.2
79.1
40.2
38.9
0.239
0.220
0.259
0.369
0.352
0.352
0.371


0.371


0.138
0.136


0.135


0.146
0.146
0.650
0.650
0.650
Target (Point Level)
PACT Phase II Phase III
399.8
182.6
217.2
37.9
0.9
2.4
76.5


rao


15.7
7.9


3.6


1.1
3.2
79.1
40.2
39.9
3504
182.6
167.7
34.1
0.9
2.3
14.8


16.1


15.7
7.9


3.6


I.I
3.2
79.1
40.2
36.9
262.7
136.9
125.8
25.6
0.7
f.7
M.l


12.1


15.7
7.9


3.6


1.1
3.2
79.1
40.2
38.9

-------
Detail Report - Five Month Data Final OTC NOx Baseline Inventory
Point-Segment Level Data Maine
DMlgn month Heat Content State Emlaalon
Plant Capacity Activity (10x6 Btu/ Heat Input Factor/Cod* C
Affected Point SCC/Deacrtetton 	 (10x6 Btu/hr) Fee/Code Fuel Ute/Unlta SCC Unit) (10x6 BtMl 	 (lb»/SCC Unltl 	 E
003 Aroostook Co - Northern Zone - Attainment





0001 MAINE PUBLIC SERVICE COMPANY, CARIBOU
BaseNne 00? 10100401 Residual Oil 194
0027 FRASER PAPER, LTD.
Affected 002 10200401 Residual Oil 302
0051 FAIRFIELD ENERGY VENTURE, L.P.
Affected 001 10100501 Distillate Oil 583
0.157 3 209.9

0.417 3 1.063.4

0.427 3 33.3
1000 Gal

1000 Gal

1000 Gal
150.00

150.00

194.00
31,485

159.510

6.460
67.3

54.9

25.6
AP-42

AP-42

AP-42
Baseline
en. Five Emission Rate Targe
•ft. Month (Iba/IOxe Btu) flACT

7.1
7.1
292
29.2
O4
0.4

0.449
0.449
0466
0.366
0.132
0.132

4.7
4.7
173
J7.5
0.4
0.4
8
06/26/95
t(PomtL0vel)
Phase II Phasejli

4.7
4.7
174
17.5
0.4
0.4

4.7
4.7
16.0
76.0
0.4
0.4
005 Cumberland Co - Northern Zone - Moderate
0135 CENTRAL MAINE POWER WYMAN
Affected 002 10100401 Residual Oil 600
Affected 003 10100401 Residual Oil 600
Affected OEM 10100401 RaaidualOfi 1,132
Affected 005 10100401 RealdualOil 5.070
STATION
0.347 3 2.264.9
0.313 3 2.138.7
0.353 3 8.605.1
0.457 3 48.482.2

1000 Gal
1000 Gal
1000 Gal
1000 Gal

151.00
151.00
151.00
151.00

342.000
322.944
1.299.370
7.320,812

60.4
60.3
60.3
45.0

AP-42
AP-42
AP-12
State Factor
0138 S.D. WARREN CO, SCOTT PAPER CO.
001 1,074
Affected 10200202 Bituminous Coal
Affected 10200401 RealdualOil
Affected 10200501 Dtetfflate Oil
Affected 007 10200501 Distillate Oil 375
007 Franklin Co - Northern Zone •

0.357 3 20.456.1
0.357 3 1,019.2
0.357 3 30.3
0.393 3 213.4
• Attainment

Tons
1000 Gal
1000 Gal
1000 Gal


26.00
148.00
140.00
140.00


531,859
150.842
4.242
29.876


21.0
55.3
23.6
18.4


AP-42
AP-42
AP-42
AP-42

0021 INTERNATIONAL PAPER COMPANY-ANDROSCOGGIN
Affected OOf 10200401 Residual Oil 680
Affected 002 10200401 RealdualOil 680
Affected 003 10200401 RealdualOil 480
004 496
Affected 10200401 RealdualOil
Affected 10200501 DtotHtote Oil
Affected 005 10200401 RealdualOil 658
0023 STRATTON ENERGY ASSOCIATION
Affected 001 10100501 DtatHlate Oil 672
009 Hancock Co - Northern Zone
0004 CHAMPION INTERNATIONAL CORP
Affected 007 10200405 RealdualOil 371
004 814
Affected 10200104 Anthracite Coal
0.377 3 6,913.4
0.397 3 9.359.7
0.420 3 1,979.9

0.443 3 885.6
0.443 3 39.0
0.447 3 479.6

0.417 3 290.6
- Marginal

0.343 3 1,123.7

0.413 3 44.126.2
1000 Gal
1000 Gal
1000 Gal

1000 Gal
1000 Gal
1000 Gal

1000 Gal


1000 Gal

Tons
149.00
149.00
149.00

149.00
139.00
149.00

140.00


152.00

26.00
1.030.097
1.394.595
295.005
(
131.954
5.421
71.460

40.684


170.802

1,147.281
55.0
55.0
552

56.0
22.7
55.9

23.0


54.9

10.0
AP-42
AP-42
AP*2

AP-42
AP-42
AP-42

AP-42


AP-42

AP-42
1,4*42
68.4
64.5
259.5
1,090.9
24&4
243.5
214.9
282
0.4
2.0

540.1
190.0
257.3
54.6
24.8
24.4
0.4
13.4
34
3.3

279.1
30.9
248.2
220.5
0419
0.400
0.399
0.399
0.298
0.685
0.709



0.132

0469
0.369
0.369
0.370
0.367


0.375
0.164
0.164

0480
0.367
0.382

14854
51.3
48.4
794.9
1,090.9
1482
746.2



2.0

3242
774.0
754.4
32.8
15.7


8.0
34
3.3

1674
78.5
748.9

1,3854
57.3
48.4
794.9
7.090.9
148.2
746.2



2.0

3242
174.0
754.4
32.8
75.7


8.0
34
3.3

1674
78.5
748.9

9284
34.2
32.3
729.9
732.7
1114
709.6



2.0

292.9
703.0
739.5
29.5
73.7


7.7
34
3.3

147.0
77.7
729.9


-------
Detail Report - Five Month Data r
Point-Segment Level Data
DMlgn 5-Month
Plant Capacity Activity
Affected Point SCC/Descrtotlon (10x6Btufhrl Fac/Code
mai OTC NOX Baseline in'
Maine
Heat Content
(10x6 Btu/ Heat Input
Fuel Use/Units SCO Unit) (10x6 Btu)
009 Hancock Co - Northern Zone - Marginal
0004 CHAMPION INTERNATIONAL CORP
004 814
Affected 10200405 Residual Oil 0.413 3 999.9
01 1 Kennebec Co - Northern Zone - Moderate
0062 SCOTT PAPER WINSLOW PLANT
Affected 003 10200405 Residual Oil 290 0.417 3
015 Lincoln Co - Northern Zone - Moderate
0010 CENTRAL MAINE POWER - MASON STATION
Affected 005 10100401 Residual Oil 413 0.237 3
Affected 006 10100401 Residual Oil 413 0.263 3
Affected 007 10100401 Residual Oil 413 0.207 3
017 Oxford Co - Northern Zone - Attainment
0045 BOISE CASCADE PAPER COMPANY
Affected 004 10200401 Residual Oil 500 0.403 3
Affected 007 10200401 Residual Oil 274 0.087 3
012 S72
Affected 10200219 Bituminous Coal 0.593 3
Affected 10200405 Residual Oil 0.593 3
013 572
Affected 10200219 Bituminous Coal 0.593 3
Affected 10200405 Residual Oil 0.593 3

522.9


84.6
106.0
64.0


974.9
210.5

40.339.4
258.0

40.339.4
258.0
1000 Gal

1000 Gal


1000 Gal
1000 Gal
1000 Gal


1000 Gal
1000 Gal

Tons
1000 Gal

Tons
1000 Gal
152.00

150.00


151.00
151.00
151.00


150.00
150.00

13.00
150.00

13.00
150.00
151.985

78,435


12.775
16,006
9,664


146,235
31.575

524.412
38.700

524.412
38,700
ventory
State Emission
Baseline
Factor/Code Con. Five Emission Rate
(Ibs/SCCUnH) Elf. Month Obs/10x6Btu)
55.3

54.2


67.2
69.5
64.7


55.4
55.4

15.0
55.2

15.0
55.2
AP-42

AP-42


AP-42
AP-42
AP-42


AP-42
AP-42

AP-42
AP-42

AP-42
AP-42
279.1
248.2
27.7
14.2
»4.2

8.6
2.8
3.7
2.1

6S&2
27.0
S.8
309.7
302.5
7.1
309.7
302.5
7.1
0.380
0.382
0.362
0.362

0.447
0.445
0.460
0.428

1.000
0.369
0.369
1.100


f.fOO


9
06/26/95
Target (Point Level)
PACT Phase II Phase III
167.5
148.9
8.5
8.5

5.8
1.9
2.4
1.S

391.3
16.2
3.5
185.8


185.8


167.5
148.9
8.5
8.5

5.8
f.9
2.4
T.5

3914
f6.2
3.5
185.8


185.8


147.0
129.9
7.8
7.8

3.9
>.3
».7
».o

296.5
14.6
3.2
139.3


139.3


019 Penobscot Co - Northern Zone - Attainment
0029 BANGOR HYDRO- GRAHAM STATION
Affected 001 10100401 Residual Oil 372 0.437 3
Affected 002 10100401 Residual Oil 396 0.387 3
Affected 003 10100401 Residual Oil 645 0.310 3
0034 JAMES RIVER CORP. (OLD TOWN)
Affected OOf 10200401 Residual Oil 250 0.360 3
Affected 002 10200401 Residual Oil 250 0.393 3
Affected 004 10200401 Residual Oil 521 0.420 3
0055 WHEELABRATOR-SHERMAN ENERGY CO.
Affected 001 10100501 Distillate OH 264 0.417 3
0056 GREAT NORTHERN PAPER, INC. (MILL.)
Affected OOf 10200401 Residual Oil 370 0.480 3

80.8
128.9
305.0

2.630.5
3.241.1
477.5

4.6

5,193.1

1000 Gal
1000 Gal
1000 Gal

1000 Gal
1000 Gal
1000 Gal

1000 Gal

1000 Gal

151.00
151.00
151.00

150.00
150.00
150.00

141.00

151.00

12,201
19,464
46.055

394.575
486.165
71.625

649

784,158

64.9
66.1
67.1

55.0
55.1
54.5

20.0

55.1

AP-42
AP-42
AP-42

AP-42
AP-42
AP-42

AP-42

AP-42
17.1
2.6
4.3
10£
1744
72.4
89.2
13.0
0.0
0.0
594.6
143.0
0440
0.430
0.437
0.444
0.387
0.367
0.367
0.364
0.142
0.142
0.384
0.365
11.7
1.8
2.9
6.9
104.8
43.4
53.5
7.8
0.0
0.0
356.7
85.0
11.7
1.8
2.9
6.9
104.8
43.4
53.5
7.8
0.0
0.0
358.7
85.8
7.8
J.2
».9
4.6
95.2
39.5
48.6
7.2
0.0
0.0
328.4
78.4

-------
Detail Report - Five Month Data
Point-Segment Level Data
OMlgn 5-Month
Plant Capacity Activity
Affected Point SCC/DaaertoMon (10x8 Btti/hr) Fae/Code
Final OTC NOx Baseline Inventory
Maine
Heal Content State Emlaalon
(10x8 Btu/ Heat Input Factor/Coda
Fuel Use/Units SCO Unit) (10x6 Btu) (Iba/SCC Unit)
019 Penobscot Co - Northern Zone - Attainment
0056 GREAT NORTHERN PAPER, INC. (MILL.)
Affected 00? 10200401 ReeidualOII 370 0.567 3
Affected 009 10200401 ReetdutlOII 370 0.360 3
Affected 004 10200401 RaaldualOil 740 0.367 3
Affected 005 10200401 Residual Oil 59? 0.417 3
0058 GREAT NORTHERN PAPER, INC (E.M.)
Affected 001 10200401 RealdualOil 370 0.577 3
Affected 002 10200401 RaaldualOil 370 0.180 3
Affected 003 10200401 Residual Oil 498 0.437 3

5,366.1
2.856.6
6.001.2
2.199.3

3.153.9
667.8
131.5


1000 Oat
1000 Gal
1000 Gal
1000 Gal

1000 Gal
1000 Gal
1000 Gal


151.00
151.00
151.00
151.00

151.00
151.00
151.00


810,281
431.347
906.181
332,094

476,239
131.038
19.857


54.9
54.9
55.0
55.0

54.9
55.2
53.2


AP-42
AP-42
AP-42
AP-42

AP-42
AP-42
AP-42
Baseline
Con. Five Emission Hate
Elf. Month flbs/10x6Btu)

594.6
147,4
78.5
165.2
60.5
114.0
66.6
23.9
3.S

0364
0.364
0.304
0.365
0.364
0464
0.363
0.36S
0.352
10
06/26/95
Target (Point Laval)
PACT Phase ii pnaaam

356.7
89.5
47.1
99.1
36.3
68.4
S1.9
14.4
2.1

356.7
88.5
47.1
99.1
.36.3
MA
51.9
14.4
2.1

3264
81.0
43.1
90.6
33.2
62.7
47.0
13.1
2.0
025 Somerset Co - Northern Zone - Attainment
0027 S. D. WARREN CO. SCOTT PAPER CO
Affected 00? 10200401 Residual Oil 646 0.423 3
Affected 004 10200401 RaaldualOil 1.180 0.423 3
Affected 017 10200401 Residual Oil 900 0.340 3

3,288.0
563.7
306.0

1000 Gal
1000 Gal
1000 Gal

183.00
183.00
184.22

601.704
106.817
56,371

55.1
55.1
55.6

AP-42
AP-42
AP-42
115.1
90.5
16.1
8.5
0.301
0.301
0.301
0.302
763
60.2
»0.7
6.6
763
60.2
10.7
5.6
783
60S
10.7
5.6
029 Washington Co - Northern Zone - Attainment
0020 GEORGIA-PACIFIC CORPORATION
Affected 00) 10200401 RatldualOll 625 0.400 3
Affected 005 10200401 RaaldualOil 1.052 0.417 3

4.624.4
296.1

1000 Gal
1000 Gal

152.00
152.00

733.309
45.007

55.1
55.0

AP-42
AP-42
140.9
132.8
8.1
0.362
0.362
0.382
84.6
79.7
4.9
84.6
79.7
4.9
77.8
73.3
4.5

-------
Detail Report - Five Month Data F
Point-Segment Level Data
DMlgn 5-Month
Plant Capacity Activity
Affected Point SCC/DmeriDtlon (10x6Btu/hr) Fac/Code
001 Allegany Co - Outer Zone - Attainment
0011 WESTVACO
Affect** 001 10200203 Bituminous Coal 500 0.496 1
Affect*! 002 10200202 Bituminous Coal 785 0.504 1
Affected 003 10200601 Natural Gaa 338 0.417 1
003 Anne Arundel Co - Inner Zone - Severe
0014 BALTO. GAS & ELEC. - WAGNER STATION
001 2.740
Affected 10100202 BHumlnoua Coal 0.526 2
Affected 10100601 Natural Qaa 0.555 2
00? 4.200
Affected 10100401 RealdualOII 0.558 2
Affected 10100601 Natural Qaa 0.227 2
004 1.337
Affected 10100601 Natural Qa* 0.549 2
005 1.337
Affected 10100202 Bituminous Coal 0.459 2
Affected 10100601 Natural Gas 0.403 2
0468 BALTO. GAS & ELEC. - BRANDON SHORES
OOr 5,760
Affected 10100202 Bituminous Coal 0.438 2
Affected 10100501 Distillate Oil 0.331 2
005 Baltimore Co - Inner Zone - Severe
0076 BALTO. GAS & ELEC. - NOTCHCLIFF
Baseline 001 20100201 Natural Gaa 268 0.629
Baseline 002 20100201 Natural Gas 268 0.630
Baseline 003 20100201 Natural Gas 268 0.654
Baseline 004 20100201 Natural Gas 268 0.639
Baseline 005 20100201 Natural Gas 268 0.657
Baseline 006 20100201 Natural Gas 268 0.607
Baseline 007 20100201 Natural Gas 268 0.671
Baseline 008 20100201 Natural Gas 268 0.768
0078 BALTO. GAS & ELEC. - RIVERSIDE
Baseline 007 20100101 Distillate Oil 378 0.826 1
Baseline 002 20100101 Distillate OH 378 0.768 1
003 020
Affected 10100401 Residual Oil 0.006 2
Affected 10100601 Natural Gas 0.598 2
004 702
Affected 10100401 RealdualOII 0.370 2
Affected 10100601 Natural Gas 0.283 2
-inal OTC NOx Baseline In
Maryland
Heat Content
(10x6 Btu/ H«at Input
Fuel Use/Unit* SCC Unit) (10x6 Btu)


87.005.0
115.095.0
85.0



300.100.0
276.2

22,965.6
11.3

1.681.1

136,000.0
151.2


671,000.0
453.6


68.9
71.7
76.0
71.7
73.1
61.9
83.5
76.5

120.3
200.6

29.4
1.265.9

4.746.0
14.1


Tons
Tons
10x6 CuR



Tons
10x6 CuR

1000 Gal
10x6 CuR

10x6 Cu Ft

Tons
10x6CuFt


Tons
1000 Gal


10x6CuFt
10x6 Cu Ft
10x6 Cu Ft
10x6CuFt
10x6 CuR
10x6CuFt
10x6CuFt
10x6 CuR

1000 Gal
1000 Gal

1000 Gal
10x6 Cu Ft

1000 Gal
lOxflCuFt


25.00
25.00
1,034.00



26.00
1.040.26

150.31
1.039.73

1,039.63

26.00
1.040.54


25.34
138.34


1.040.00
1.040.00
1.040.00
1,040.00
1,040.00
1.040.00
1.040.00
1.040.00

138.00
138.00

150.00
1,040.78

149.07
1.040.71


2,175.125
2.877,375
87.890



7.802.600
287.321

3.452,060
11.749

1.955,655

3.536.000
157,329


17.006.100
62.752


71.656
74.568
79,040
74,568
76,024
64,376
86.840
79,560

16.601
27.683

4.410
1,317.523

707.503
14.674
ventory
State Emission
Factor/Code Con.
(Ibs/SCC Unit) EH.


40.5
21.5
413.6



30.7
550.3

82,7
551.0

322.3

21.3
550.5


10.6
21.0


420.2
420.2
420.2
420.2
420.2
420.2
420.2
420.2

67.6
86.9

67.2
3127

7S.O
651.6


MulStk Non-1 990
MulStK Non-1990
MulStk Non-1 990



MulStk Non-1990
AP-42

MulStk Non-1 990
AP-42

Mul Stk Non-1990

MulStk Non-1 990
AP-42


Non-19905Mo.CEMS
AP-42


AP-42
AP-42
AP-42
AP-42
AP-42
AP-42
AP-42
AP-42

MulStk Non-1990
Mut Stk Non-1990

AJM2
Sing Stk Rep Cond

AP-42
AP-42
Baseline
11
06/26/95
Five) Emission Rate Target (Point Level)
Month (Iba/10x6 Btu)

3,016.7
r.78».9
1,237.3
17.6

7,426.5
4,679.5
4,603.5
78.0
952.4
949.3
3.1
303.1
303.1
1.491.4
1,449.6
41.6
3,576.1
3.576. 1
3,571.3
4.8

122JS
14.5
15.1
16.0
15.1
15.4
13.0
17.5
16.1
1,149.7
4.1
8.7
198.8
1.0
197.6
»9».4
167.5
3.9

1.174
T.620
0.860
0.400

0.863
1.1S8


0.550


0.340

0.806


0.419
0.4 1 9



0.404
0.404
0.404
0.404
0.404
0.404
0.404
0.404
0.404
0.424
0.490
0.630
0.335


0.530


PACT

3,016.7
f.76f.9
1.237.3
17.6

6,606.3
4,679.5


951 £


244.5

731.1


3.576.1
3.57ft f



1223
14.5
1S.1
16.0
15.1
1S.4
13.0
17.5
16.1
S34.5
4.1
8.7
198.3


114.8


Phase II

1,338.4
792.8
556.8
8.8

2,701.8
1,637.8


346.4


195.6

522.0


1,706.9
1.706.9



122.5
/4.5
15.1
16.0
15.1
15.4
13.0
17.5
16.1
567.6
4.1
8.7
132.2


72.2


PfiM" III

756.4
440.5
309.3
6.6

1,949.2
1.169.9


259.8


146.7

372.8


1,280.2
1,280.2



122.5
14.5
15.1
16.0
15.1
15.4
13.0
17.5
16.1
437.6
4.;
8.7
99. 1


54.2



-------
Detail Report - Five Month Data
Point-Segment Level Data
Design 5-Month
Plan! Capacity Activity
Affected Point SCC/Descrtotlon UOxflBtufhr) Fac/Code
005 Baltimore Co - Inner Zone - Severe
0078 BALTO. GAS & ELEC. - RIVERSIDE
005 70?
Affected 10100401 Residual OH 0.488 2
Affected 10100601 Natural Oa* 0.458 2
006 880
Affected 10100401 Residual Oil 0.482 2
Affected 10100601 Natural Oat 0.394 2
007 702
Affected 10100401 Residual Oil 0.468 2
Affected 10100601 Natural Gas
Baseline 008 20100201 Natural Gas 1,968
0079 BALTO. GAS & ELEC. - CRANE
005 1.865
Affected 10100203 Bituminous Coal
Affected 10100501 Distillate Oil
006 1,815
Affected 10100203 Bituminous Coal
Affected 10100501 Distillate On
0.349 2
0.629 1


0.411 2
0.347 2

0.465 2
0.361 2
Final OTC NOx Baseline Inventory
Maryland
Heat Content State Emission
(10x6 Btu/ Heat Input Factor/Code Con.
Fuel Use/Units SCCUnll) (10x6 Btu) (Iba/SCCUnlt) Eft.
5.405.4 1000 Gal
23.0 10x6CuFt
8,706.6 1000 Gal
17.3 10x6 Cu Ft
6,699.0 1000 Gal
9.4 10X6CuR
167.3 10X6CuR


136,300.0 Tons
138.6 1000 Gal

172.300.0 Tons
180.6 1000 Gal
149.14
1.039.04
149.15
1,04023
14920
1.039.15
1.040.00


27.00
13828

27.00
138.35
606,135
23,898
1298.569
17.996
999.487
9.768
173.992


3,680,100
19,165

4,652,100
24.986
67.1
550.7
67.1
551.3
67.1
550.9
416.0


32.4
23.9

362
24.1
AP-42
AP-42
AP-42
AP-42
AP-12
AP-42
MulStk Non-1990


Non-1990 5 Mo. GEMS
AP-42

Non-1 990 5 Mo. CEMS
AP-42
Baseline
12
06/26/95
Five Emission Rate Target (Point Level)
Month flbi/IOrtBtu) RACT
1,149.7
W7.7
181.4
64
296.9
2922
4.8
227.5
224.9
2.6
34.8
64284
2.209.7
2208.1
1.7
3. 119.1
3,116.9
22
0424
0.452
0.45/
0.45/

0.400
1272
1.194


1.332


834.5
124.7
197.6
151.S

34.8
5,328.8
2,209.7


3.//9./


Phase II
567.6
83.0
131.7
100.9

34.8
1,865.1
773.4


/.09/.7


Phase III
437.6
62.3
98.7
75.7

34.8
14322
552.4


779.8


017 Charles Co - Inner Zone - Serious
0014 POTOMAC ELECTRIC MORGANTOWN
001 5.3/7
Affected 10100212 Bituminous Coal
Affected 10100404 Residual Oil
Affected 10100501 Distillate Oil
002 5.3/7
Affected 10100212 Bituminous Coal
Affected 10100404 Residual Oil
Affected 10100501 Distillate Oil
Baseline 007 20100101 Distillate Oil 250
Baseline 009 20100101 Distillate Oil 250
BaseHne 009 20100101 Distillate Oil 654
Baseline 0/0 20100101 Distillate Oil 654
Baseline Oil 20100101 Distillate Oil 654
Baseline 0/2 20100101 Distillate Oil 65<
019 Dorchester Co - Outer Zone -
0013 DELMARVA POWER VIENNA
Baseline 001 20100101 Distillate Oil 276
Affected 002 10100404 Residual Oil 1,855

0.433 2
0.510 2
1.000 2

0.512 2
0.799 2
1.000 2
1.000
1.000
1.000
1.000
1.000
1.000

600.000.0 Tons
520.8 1000 Gal
189.0 1000 Gal

587,200.0 Tons
970.2 1000 Gal
121.0 1000 Gal
133.0 1000 Gal
133.0 1000 Gal
739.6 1000 Gal
739.6 1000 Gal
739.6 1000 Gal
739.6 1000 Gal

25.61
149.00
138.00

25.18
149.00
138.00
138.00
138.00
138.00
138.00
138.00
138.00

15.367,500
77.599
26.082

14.783.800
144,560
16.698
18.354
18.354
102.065
102.065
102.065
102.065

24.3
70.0
24.7

23.9
70.0
24.7
109.0
109.0
98.0
98.0
98.0
98.0

AP-42
AP-42
AP-42

MulStk Non-1 990
AP-42
AP-42
AP-42
AP-42
AP-42
AP-42
AP-42
AP-42
14,537.3
7.320. /
7299.6
182
24
7.0S7.8
7.0224
34.0
1.5
7.3
7.3
3&2
36.2
3A2
362
0.942
0.947



0.947



0.790
0.790
0.7/0
0.7/0
0.7/0
0.7/0
5,944.2
2.940.4



2.044.4



7.3
7.3
362
362
36.2
36.2
5.191.7
2.562.0



2.470.2



7.3
7.3
362
36.2
36.2
36.2
3,753.9
1.830.0



1.764.4



7.3
7.3
36.2
362
36.2
36.2
Attainment

0.405 1
0.642 2

12.2 1000 Gal
9,643.2 1000 Gal

139.34
149.79

1.700
1.444.460

72£
58.4

AP-42
MulStk Non-1990
282.1
0.4
2»/.7
0400
0.520
0.390
282.1
0.4
281.7
144.9
0.4
144.4
1084
0.4
708.3

-------
Detail Report - Five Month Data
Point-Segment Level Data
Design
Plant
Affected Point
Capacity
SCC/Descrlotlon (10x6 Btu/hr)
1
5-Month
Activity
Fee/Code
-inal OTC NOx Baseline In
Maryland
Heat Content
(10x8 Btu/
Fuel Use/Units SCC Unit)
Heat Input
(10x6 Btu)
ventory
State Emission
Factor/Code Con.
Obs/SCC Unit) EH.
Baseline
13
06/26/95
Five Emission Rste Target (Point Level)
Month (Iba/10x6 Btu) RACT
025 Harford Co - Inner Zone - Severe
0024 BALTO. GAS & ELEC. - FERRYMAN
Baseline 001
Baseline 002
Baseline 003
Baseline 004
20100101 DtstniateOfl 704
201001Q1 Distillate Oil 704
20100101 Distillate OH 704
20100101 Distillate Oil 704
031 Montgomery Co - Inner Zone -
0.730 1
0.459 1
0.728 1
0.744 1
Serious
670.2 1000 Gal
384.3 1000 Gal
1,303.2 1000 Gal
913.6 1000 Gal

138.00
138.00
138.00
138.00

92.488
53.033
179.842
126.077

68.4
68.4
70.0
70.0

AP-42
AP-42
AP-42
AP-42

0019 POTOMAC ELECTRIC DICKERSON
001
Affected
Affected
00?
Affected
Affected
009
Affected
Affected
7,646
10100212 Bituminous Coal
10100501 Distillate On
1,646
10100212 Bituminous Coal
10100501 Distillate Oil
»,646
10100212 Bituminous Coal
10100501 Distillate OH

0.425 2
0.512 2

0.418 2
0.468 2

0.442 2
0.334 2

193,200.0 Tons
88.2 1000 Gal

196.400.0 Tons
92.4 1000 Gal

191,400.0 Tons
105.0 1000 Gal

25.00
138.00

25.00
138.00

25.00
138.00

4.830.000
12.172

4.910.000
12,751

4.785.000
14,490

16.3
24.0

17.5
24.0

17.5
24.0

Mul Stk Non-1990
AP-42

Mul Stk Non-1990
AP-42

Mul Stk Non-1 990
AP-42
113.6
22.9
»&2
4S.6
32.0

4.M&4
1,570.6
1,569.8
1.1
1.719.6
1,718.5
1.1
1.676.0
1.674.8
U
O.S03
0.496
0.496
0.507
0.507

0.682
0.649


0.699


0.698



113.6
22,9
13.2
45.6
32.0

4.96M
f.570.8


T.7r9.6


1,676.0


Phase II

113.6
22.9
13.2
45.6
32.0

1,738.3
549.0


601.9


586.6


Phase III

113.6
22.9
13.2
45.6
32.0

1,241.6
392.7


429.9


419.0


033  Prince Georges Co - Inner Zone - Serious
0014  POTOMAC ELECTRIC - CHALK POINT
Affected
Affected

Affected
Affected
Baselirw

Affected
Affected
Affected

Affected
Affected
Affected
Baseline
         oor
002
006
007
008
009
10100202 Bituminous Coal
10100501 Distillate Oil

10100202 Bituminous Coal
10100501 Distillate Oil
20100101 Distillate Oil

10100404 Residual Oil
10100501 Distillate Oil
10100604 Natural Gas

10100404 Residual Oil
10100501 Distillate OH
10100604 Natural Gas
20100101 Distillate OH
                                     3,123
3.123
 250
6,970
6.638
                                     420
0.425
0.409

0.403
0.336
1.000

0.494
1.000
0.735

0.734
1.000
0.628
1.000
346,500.0
   344.4

347.000.0
   357.0
   139.0

 28.782.8
  1.352.5
  3,723.8

 19.236.0
  1.331.5
  2,168.5
   128.0
Tons          25.79     8.935.600      32.0   Mui Stk Non-1990
1000 Gal      137.04       47,195      24.5   AP-42

Tons          25.56     8.869.500      31.4   Mul Stk Non-1990
1000 Gal      137.06       48.930      24.5   AP-42
1000 Gal      138.00       19.182     125.6   AP-42

1000 Gal      150.00     4,317.390      43.5   Mul Stk Non-1990
1000 Gal      138.00      166.645      24.7   AP-42
10x6 Cu Ft  1.044.41     3,889,180     206.9   Mul Stk Non-1990

1000 Gal      150.52     2.895.329      43.7   Mul Stk Non-1990
1000 Gal      138.00      183,747      24.7   AP-42
10x6 Cu Ft  1,045.48     2.288,039     209.1   Mui Stk Non-1990
1000 Gal      138.00       17,664     154.6   AP-42
12,718.9
 5.544.4
 5.5402
    42
 5.459.1
 5.454.7
    4.4
    8.7
 1.031.6
   626.0
    16.7
   388.9
   665.1
   410.8
    16.4
   228.8
                                                                                                                                        0.802
                                                                                                                                         1.234
1.223
0.910
0.255
0.245
                                                                                                            1.120
                                                                                                                       7,510.7    5,245.9   3,801.5
                                                                                                                       2,908.4    1,940.5   1.386.1
2,887.0    1,910.7    1,364.8
    8.7       8.7       8.7
1.031.6     839.3     629.5
                                                                                                                                                             665.1     536.7    402.5
                                                                                                                9.9
                                                                                                                                                                        9.9
                                                                                                                                                                                 9.9
1827 SMECO - CHALK POINT
         001
Baseline          20100101 Distillate OH
Baseline          20100201 Natural Gas
                                      924
                                               1.000  1        236.0  1000 Gal     138.00       32.568      49.7  AP-42
                                               1.000  1        502.0  10x6 Cu Ft   1.045.00      524,590     177.6  AP-42
                                                                                                                               803
                                                                                                                               50.5
                                                                                                                                5.9
                                                                                                                               44.6
                                                                                                            0.181         50.5      50.5      50.5
                                                                                                            O.T8f         50.5      50.5      50.5

-------
Detail Report - Five Month Data
Point-Segment Level Data
DMlgn 5-Month
Final OTC NOx Baseline Inventory
Maryland
Heat Content State Emission BaaafkM
Plant Capacity ActMty
Affected Point SCC/Descriotton (lOx6Btu/hr) Fac/Code
(10x6 Btul
Fuel Use/Units
043 Washington Co - Outer Zone - Attainment
0005 POTOMAC EDISON COMPANY
001 428
Affected 10100202 BHumJnoua Coal 0.133 2 1.300.0
Affected 10100501 Distillate Oil 0.222 2 16.8
002 1,027
Affected 10100212 BHumlnoua Coal 0.390 2 75.200.0
Affected 10100501 DMMate OK 0.457 2 88.2
510 Baltimore - Inner Zone - Severe
0006 BALTO. GAS & ELEC. - WESTPORT
Affected 002 10100401 Residual Oil 702 0X73
Affected 003 10100401 RaaidualOII 009 0.478
Baseline 004 20100201 Natural Oat 1.966 0.582
0007 BALTO. GAS & ELEC. - GOULD STREET
Affected 002 10100401 Residual Oil 1,085 0.500
0265 BALTO. GAS & ELEC. - PHILADELPHIA RD
Baseline 001 20100101 Distillate OH 258 0.621
Baseline 002 20100101 Distillate Oil 256 0.618
Baseline 003 20100101 Distillate OH 250 0.685
Baseline 004 20100101 Distillate Oil 258 0.250

2
2
1

2

1
1
1
1

5.863.2
8,647.8
427.4

10,428.6

137.4
137.8
134.4
133.6
Tons
1000 Gal
Tons
1000 Gal

1000 Gal
1000 Gal
10x6CuFt

1000 Gal

1000 Gal
1000 Gal
1000 Gal
1000 Gal
SCC Unit)
26.00
141.01
25.65
141.00

149.25
149.28
1,000.00

149.98

138.00
138.00
138.00
138.00
Heat Input
(10x6 Btu)
33,800
2,369
1,928,600
12.436

875,087
1.290,925
427/400

1.564.130

18.961
19.016
18.547
18.437
Factor/Code Con.
(Iba/SCC Unit) EH.
21.9
28.2
20.0
28.2

82.1
82.1
397.0

45.0

67.6
67.6
67.6
67.6
MufStk Non-1990
AP-42
Mul Stk Non-1990
AP-42 .

AP-42
AP-42
AP-42

Sing Stk Rep Cond

AP-42
AP-42
AP-42
AP-42
Five Emission Rat*
Month (Iba/10x6 Btul
767.0
14.S
14.3
02
7S3.4
7522
1.2
680.5
240.6
355.0
04.0
234.6
234.0
184
4.6
4.7
4.6
4.S
0.777
0.818
0.777
0.526
0.550
0.550
0.397
0.300
0.300
0490
0.490
0.490
0.490
0.490
14
06/26/95
Target (Point Level)
PACT
449.7
»4.5
435.2
4422
144.4
213.0
04.8
234.6
234.0
184
4.0
4.7
4.5
4.5
Phase II Phase ill
345.6
0.5
339.0
301.4
07.5
129.1
84.6
1564
156.4
184
4.0
4.7
4.5
4.5
192.0
3.6
188.4
247.3
05.0
90.0
04.0
117.3
117.3
184
4.0
4.7
4.5
4.5

-------
Detail Report - Five Month Data
Point-Segment Level Data
DM Ign
Plant Capacity
Affected Point SCC/Deeeriotlon (10x6 Btu/hr)
F
5-Month
Activity
Fac/Code
001 Barnstable Co - Inner Zone - Serious
0054 CANAL ELECTRIC CO *1200054*M
001 - ' 4.967
Affected 10100401 Residual Oil 0.370 2
Affected 10100501 Distillate Oil 0.417 3
004 5.262
Affected 10100401 RMldualOII 0.421 2
Affected 10100501 Distillate Oil 0.415 3
003 Berkshire Co - Inner Zone - Serious
0006 ALTRESCO PITTSFIELD *1 17 0006*M
001 430
Baseline 20200103 Distillate Oil 0.569 1
Baseline 20200203 Natural Gas 0.231 1
00? 430
Baseline 20200103 Distillate On 0.569 1
Baseline 20200203 Natural Gas 0.232 1
003 - 430
Baseline 20200103 Distillate Oil 0.569 1
Baseline 20200203 Natural Gas 0.230 1
0166 WOODLAND ROAD
Baseline 007 20100901 Kerosene/Naphtha
0167 DOREEN STREET
Baseline 001 20100901 Kerosene/Naphtha
0168 SILVER LAKE
Baseline 001 20100901 Kerosene/Naphtha
Baseline 002 20100901 Kerosene/Naphtha
Baseline 003 20100901 Kerosene/Naphtha
Baseline 004 20100901 Kerosene/Naphtha
005 Bristol Co - Inner Zone
0041 CANNON ST.STATION
001
Affected 10100401 Residual Oil
Affected 10100601 Natural Gas
00?
Affected 10100401 Residual Oil
Affected 10100601 Natural Gas
003
Affected 10100401 Residual Oil
Affected 10100601 Natural Gas

230

230

230
230
230
230

0.810 1

0.640 1

0.730 1
0.740 1
0.690 1
0.660 1
-inai ore NOX Baseline in
Massachusetts
twftt Content
(10x0 Btu/ Heal Input
Fuel Use/Units SCO Unit) (10x6 Btu)
68,212.2
36.3
73,038.0
10.8
495.0
136.0
888.0
97.0
723.0
124.0

63.3

54.2

39.0
32.5
36.4
22.6
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
10x6CuFt
1000 Gal
10x6CuFt
1000 Gal
10x6CuFt

1000 Gal

1000 Gal

1000 Gal
1000 Gal
1000 Gal
1000 Gal
150.43
140.00
150.32
140.00
139.00
1,025.00
139.00
1.025.00
139.00
1,025.00

134.10

134.10

138.60
138.60
138.60
138.60
10.261,161
5.082
10,979.072
1,512
68.805
139,400
123.432
99.425
100,497
127.100

8.489

7,268

5.405
4.505
5,045
3.132
ventory
State Emission

Factor/Code Con. Five Emission Rate
(Ibs/SCC Unit) EH. Month (lba/10x6Btu)
5.001.7
3.581. S
105.0 Non-1990 Other OEMS 3.581.1
20.0 AP-42 0.4
».5f0.2
41.4 Non-1990 Other GEMS 1,510.1
20.0 AP-42 0.1
114
3.5
5.6 Mu)Stk1990 95.0 1.4
30.8 MulStk1990 95.0 2.1
4.1
7.0 Mul8tk1990 95.0 3.1
20.5 Mul 6*1990 1.0
3.9
5.6 Mul8tk1990 95.0 2.0
30.8 Mul8tK1990 95.0 1.9

67.8 AP-42

67.8 AP-42

67.8 AP-42
67.8 AP-42
67.8 AP-42
67.8 AP-42
2.1
2.1
14
1.8
4A
1.3
1.1
12
0.8
0.479
0.700
0276
0.03S
0.032
0.030
0.03?
0408
0.506
0.508
0.505
0X89
0.409
0.409
0.409
0.409
15
06/26/95
Target (Point Level)
PACT Phase II Phase III
2.947.1 2,351.6
7,436.9 1,253.5
1.510.2 1.098.1
114 114
3.5 3.5
4.1 4.1
3.9 3.9
0.9
0.9
0.8
0.0
2.0
0.0
0.5
0.0
0.3
0.9
0.9
0.8
0.0
2.0
0.6
0.5
0.6
0.3
1,718.9
095.4
023.5
114
3.5
4.1
3.9
0.9
0.9
0.8
0.0
2.0
0.6
0.5
0.6
0.3
- Serious
•120 0041
271


271


422


*M

0.184
0.855

0.184
0.855

0.184
0.854


159.6
97.6

159.6
97.6

390.6
238.0


1000 Gal
10x6CuFt

1000 Gal
10x6CuFt

1000 Gal
10x6CuFt


150.04
1.000.00

150.04
1.000.00

150.04
1.000.00


23.946
97.600

23.946
97,600

58,606
238.000


67.0 AP-42
550.0 AP-42

67.0 AP-42
550.0 AP-42

67.0 AP-42
550.0 AP-42
142.0
32.2
5.3
26.8
32.2
S3
26.8
78.5
13.1
65.5
0430
0.494


0.494


0.494


7S.6
17.0


17.0


41.S


54.0
12.2


12S


29.7


404
9.1


9.1


22.2



-------
Detail Report - Five Month Data
Point-Segment Level Data
DftAlQn 3 Moott)
Plant Capacity Activity
Affaetad Point SCC/DeecriDtlon (10x8 Btufhrl Fac/Code
005 Bristol Co - Inner Zone
0060 MONTAUP - SOMERSET
007
Affected 10100212 Bituminous Coal
Affected 10100401 RMldualOil
Affected 10100501 Distillate OK
009
Affaetad 10100212 Bituminous Coal
Affected 10100401 Residual CHI
Affected
Baseline 0)0
Baseline Off
0061 NENG
001
Affected
Affected
Affected
002
Affected
Affected
Affected
003
Affected
Affected
Affected
004
Affected
Affected
10100501 Distillate OK
20100901 Kerosene/Naphtha
20100901 Kerosene/Naphtha
P - BRAYTON POINT

10100212 Bituminous Coal
10100404 Residual Oil
10100501 Distillate Oil

10100212 Bituminous Coal
10100404 Residual Oil
10100501 Distillate OH

10100202 Bituminous Coal
10100401 Residual Oil
10100501 Distillate Oil

10100401 Residual Oil
10100501 Distillate Oil
0067 TAUNTON MUN LIGHT PL
0013
Affected
Affected
004
Baseline
Baseline
Affected 005

10100401 Residual Oil
10100601 Natural Gas

20100101 Distillate Oil
20100201 Natural Gas
10100401 Residual Oil
- Serious
"1200060-M
959
0.446 2
0.638 1
0.883 1
1.403
0.278 2
0.586 1

266
266
•120
2.325



2.325



5.800



4,800


•120
J.03J


300


340
0.533 1
0.417 3
0.417 3
0061*M

0.461 1
0.177 1
0.256 1

0.429 1
0.066 1
0.189 1

0.339 1
0.384 1
0.728 1

0.434 1
0.313 1
0067*M

0.027 2
0.693 2

0.044 1
0.509 1
0.535 2
Final OTC NOx Baseline Inventory
Massachusetts
Heat Content State Emission

(10x6 Btu/ Heat Input Factor/Coda Con, Five Emission Rate Targe
Fuel Use/Units SCCUnIO (10x6 Btu) (Iba/SCCUnlt) Eft. Month (Iba/IOrt Btu) RACT
75,400.0
1.225.4
63.5
59.800.0
613.7
91.1
48.8
51.3


292.422.0
326.0
62.0

313,263.0
104.0
25.0

380.565.0
829.0
860.0

60,632.0
10.0


105.0
874.7

14.0
326.0
730.8
Tons
1000 Gal
1000 Gal
Tons
1000 Gal
1000 Gal
1000 Gal
1000 Gal


Tons
1000 Gal
1000 Gal

Tons
1000 Gal
1000 Gal

Tons
1000 Gal
1000 Gal

1000 Gal
1000 Gal


1000 Gal
10x6 CuFt

1000 Gal
10x6 CuFt
1000 Gat
26.12
150.00
140.00
26.13
150.00
140.00
135.00
135.00


26.00
150.00
137.00

26.00
149.00
134.00

26.00
149.00
137.00

150.00
137.00


150.00
1.031.00

140.00
1.050.00
150.00
1.969.448
183,810
8.890
1.562.574
92.055
12,754
6.588
6.928


7.602.972
46,900
11,234

8.144.838
15.496
3.350

9.894.690
123.521
117.820

9.094.800
1.370


15.750
901,816

1.960
342.300
109.620
14.4
67.0
20.0
14.4
67.0
20.0
67.8
67.8


18.2
42.0
20.0

182
42.0
20.0

36.4
67.0
20.0

45.0
20.0


67.0
550.0

97.7
462.0
67.0
AP-42
AP-42
AP-42
AP-42
AP-42
AP-42
AP-42
AP-12


Sing Sth Rep Cond
AP-42
AP-42

Sing Stk Rep Good
AP-42
AP-42

Sing Stk Rep Cond
AP-42
AP-42

State Factor
AP-42


AP-42
AP-42

AP-42
AP-42
AP-42
1.040.0
564.6
542.9
41.1
0.6
452.0
430.6
20.6
0.9
1.7
1.7
13,846.8
2.668.7
2.661.0
6.8
0.8
2,853.1
2,850.7
2.2
0.3
6.962.7
6.926.3
27.8
8.6
1,364.3
1.364.2
0.1
3443
244.1
3JS
2405
76.0
0.7
75.3
24.5
0.541
0.544
O.S46

0.502
0.502
0.700
0.892



0.694



1.363



0.300


0302
0.507


0.490


0.447
708.6
397.8
309.3

0.7
0.8
6,481.3
7,45f.5



1.S4S.7



£2522



1.227.9


192.0
128.5


482


15.3
16
06/26/95
I (Point Level)
Phase II
364.4
216.2
166.7

0.7
0.8
5.094.4
934.0



998.6



2.252.2



909.6


150.9
91.8


482


11.0
Phase III
288.7
162.2
125.1

0.7
0.8
3.803.3
667.2



713.3



1.740.7



6822


125.2
68.0


48.2


8.2
009 Essex Co - Inner Zone - Serious
0138 GENERAL ELECTRIC CO     *1190138*M
        003
Affected
Baseline  005
10100801  Natural Gas
20100101  Distillate Oil
                                        382
261
        0.679 1
        0.491 1
507.6  10x6 CuFt
945.9  1000 Gal
1,050.00
 140.00
532.980
132.426
550.0 AP-42
 97.7 AP-42
1854     0358
139.6     0.444
139.6
 462     0.696
105.8
 03.0

 21.9
75.1
53.3

21.9
61.8
40.0

21.9

-------
Detail Report - Five Month Data
Point-Segment Level Data
Design 5-Month
Plant Capacity Activity
Affected Point SCC/Deseitotion (10x6 Btu/hr) Fac/Code
009 Essex Co - Inner Zone - Serious
0194 N.E.POWER-SALEM *1190194*M
001 810
Affected 10100202 Bituminous Coal 0.429 1
Affected 10100401 Residual Oil 0.298 1
002 BIO
Affected 10100202 Bituminous Coal 0.427
Affected 10100401 Residual Oil 0.651
003 810
Affected 10100202 Bituminous Coal 0.362
Affected 10100401 Residual Oil 0.741
004 4,785
Affected 10100401 Residual Ol 0.481
Affected 10100501 Distillate Oil 0.375
01 1 Franklin Co - Inner Zone - Serious
0032 INDECK
Baseline 007 10200219 Bituminous Coal

240 0.420 4
Final OTC NOx Baseline In
Massachusetts
Heat Content
(10x6 Btu/ Heat Input
Fuel Use/Units SCO Unit) (10x6 Btu)
103,687.0
147.0
106,417.0
315.0
142,055.0
395.0
68.435.0
3.0

13,608.0
Tons
1000 Gal
Tons
1000 Gal
Tons
1000 Gal
1000 Gal
1000 Gal

Tons
26.00
151.00
26.00
150.00
26.00
151.00
151.00
140.00

26.00
2.695.862
22.197
2,766,842
47,250
3.693.430
59.645
10.333.685
420

353.806
ventory
State Emission
Factor/Code Con.
(Ibs/SCC Unit) Eft.
26.0 Sing Stk Rep Cond
67.0 AP-42
26.0 Sing Stk Rep Cond
67.0 AP-42
26.0 Sing Stk Rep Cond
67.0 AP-42
7S.5 Sing Stk Rep Cond
20.0 AP-42

15.0 AP-42
Baseline
Five Emission Rate
Month (lba/10x6Btu)
7.1902
1.352.9
1.347.9
4.9
f ,394.0
1.383.4
10.6
1,859.9
1.846.7
13.2
2,583.5
2.583.4
0.0
102.1
702.7
0.733
0.993
0.994
0.996
0.500
0377
0.577
17
06/26/95
Target (Point Level)
PACT Phase II Phase ill
2,975.6
447.9
463.1
617.8
1.446.7
58.4
58.4
2,562.2
447.9
463.1
617.8
1,033.4
58.4
58.4
1,926.7
3383
348.5
465.0
775.1
58.4
58.4
013 Hampden Co - Inner Zone - Serious
0001 MASS.WHOLESALE ELEC.
oor
Baseline 20100101 Distillate Oil
Baseline 20100201 Natural Gas
002
Baseline 20100101 Distillate Oil
Baseline 20100201 Natural Qas
003
Baseline 20100101 Distillate Oil
Baseline 20100201 Natural Oas
Baseline 004 20100101 Distillate Oil
Baseline 005 20100101 Distillate Oil
*042 0001*M
952
0.292
0.576
952
0.161
0.688
952
0.269
0.619
9S2 0.659
952 0.675


742.2
864.1

346.5
1,338.2

705.9
889.3
441.9
445.9


1000 Gal
10x6CuFt

1000 Gal
10x6CuFt

1000 Gal
10x6 CuR
1000 Gal
1000 Gal


140.00
1,050.00

140.00
1.050.00

140.00
1.050.00
140.00
140.00


103.908
907,305

48,510
1.405.110

98.826
933.765
61.866
62.426


42.0 Sing Stk Rep Cond
315.0 Sing Stk Rep Cond

42.0 Sing Stk Rep Cond
31 5.0 Sing Stk Rep Cond

42.0 Sing Stk Rep Cond
31 5.0 Sing Stk Rep Cond
42.0 Sing Stk Rep Cond
42.0 Sing Stk Rep Cond
0038 HOLYOKE GAS&ELEC CABOT *042 0038*M
oor
Affected 10100401 Residual Oil
Affected 10100801 Natural Oas
002
Baseline 10100401 Residual Oil
Baseline 10100601 Natural Qas
0040 HWP MT. TOM STATION
Affected 001 10100202 Bituminous Coal
347
0.010 1
0.171 1
200
0.176 1
0.586 1
•042 0040*M
7.450 0.436 1

16.8
19.2

235.6
252.9

182,986.0

1000 Gal
10x6CuFt

1000 Gal
10x6 CuR

Tons

150.00
1.050.00

150.00
1,050.00

26.00

2£20
20.160

35.340
265.545

4.757,636

67.0 AP-42
550.0 AP-42

67.0 AP-42
550.0 AP-42

26.0 Mul Stk Non-1990
5434
151.7
15.8
136.1
210.0
7.3
210.8
754.9
14.8
140.1
9.3
9.4
•34
S.8
0.6
5.3
77.4
7.9
69.5
2,3784
2.378.8
0.300
0.300


0.300


0.300


0.300
0.300
0.515
0.472


0.501


1.000
7.000
370.9
102.2


145.8


104.2


9.3
9.4
454
3.2


42.r


1,0704
1.070.5
370.9
J02.2


745.8


704.2


9.3
9.4
444
2.3


42.1


832.6
832.6
370.9
J02.2


745.8


704.2


9.3
9.4
434
1.7


42.1


594.7
594.7

-------
Detail Report - Five Month Data
Point-Segment Level Data
Design 5-Month
Plant Capacity Activity
Affected Point SCC/Deacriotton (10x6 Btu/hr) Fac/Code
013 Hampden Co - Inner Zone - Serious
0117 WESTERN MASS.ELEC CO *0420117*M
001 658
Affected 10100404 RMldualOil 0.139 1
Affected 10100501 DUtHlatoOII
Affected 002 10100404 Reddual Oil
00?
Affected 10100404 Residual Oil
Affected 10100501 Distillate OH
Affected 10100604 Natural Gas
Baseline 004 20100901 Kerosene/Naphtha
0.337 3
650 0.461 1
1.154
0.208 1
0740 3
0.240 3
252 0.540 1
Final OTC NOx Baseline Inventory
Massachusetts
Heat Content State Emission
(10x6 Btu/ Heat Input Factor/Code
Fuel Use/Units SCO Unit) (10x6 Blu) (Ibs/SCC Unit)
275.1 1000 Gal
54.3 1000 Gal
1.090.6 1000 Gal

1.649.3 1000 Gal
85.2 1000 Gal
520.1 10x6 Cu Ft
187 1000 Gal
150.50
140.00
150.50

150.50
140.00
1,050.00
133.40
41,403
7,602
164,135

248720
11,928
546.105
2.428
42.0
20.0
42.0

42.0
20.0
275.0
67.8
AP-42
AP-42
AP-42

AP-42.
AP-42
AP-42
AP-42
Bl
KAAlasAA
MWwW

Con. Five Emission Rste Target
Efl. Mon«i (lba/1tor8Btu)
138.8
6.3
6.8
0.5
22.0
J07.0
34.6
0.9
715
0.6
0768
0.260

0779
0.268



0.509
RACT
126.7
5.7

20.5
100.1



0.4
18
06/26/95
(Point Level)
Phase II Phase III
1024
4.0

. 16.4
00.6



0.4
76.8
3.7

12,3
60.5



0.4
017 Middlesex Co - Inner Zone - Serious
0092 COM.ELECT-BLACKSTONE
001
Baseline 10100401 Residual Oil
Baseline 10100601 Natural Gas
002
Baseline 10100401 Residual Oil
Baseline 10100601 Natural Gas
003
Baseline 10100401 Residual Oil
Baseline 10100601 Natural Gas
004
Baseline 10100401 Residual Oil
Baseline 10100601 Natural Gas
0093 COM.ELECTRIC-KENDALL
007
Affected 10100401 Residual Oil
Affected 10100601 Natural Gas
002
Affected 10100401 Residual Oil
Affected 10100601 Natural Gas
003
Affected 10100401 Residual Oil
Affected 10100601 Natural Gas
Baseline 006 20100901 Kerosene/Naphtha
Baseline 00? 20100901 Kerosene/Naphtha
0128 BOSTON EDISON MYSTIC
001
Affected 10100404 Residual Oil
Affected 10100604 Natural Gas
002
Affected 10100404 Residual Oil
Affected 10100501 Distillate OB
*1190092*M
179
0.400 2
0.746 2
179
0.036 2
0.340 2
235
0.038 2
0.357 2
235
0.047 2
0.461 2
•1190093*M
273
0.174 2
0.690 2
273
0.133 2
0.725 2
409
0.132 2
0.614 2
257 0.417 3
257 0.417 3
*119 0128*M
5.505
0.178 1
0.537 1
1,420
0.495 1
0.417 3


33.6 1000 Gal
37.5 10x6CuFt

33.6 1000 Gal
13.7 10x6CuFt

54.6 1000 Gal
40.9 10x6CuFt

67.2 1000 Gat
51.8 10x6CuFt


3197 1000 Gal
236.7 10x6CuFt

142.8 1000 Gal
144.5 10x6 Cu Ft

651.0 1000 Gal
665.9 10x6CuFt
28.8 1000 Gal
35.9 1000 Gal


9.680.0 1000 Gal
11,576.4 10«6CuFt

16.071.0 1000 Gal
927 1000 Gal


151.61
1,000.00

152.04
1.000.00

152.04
1.000.00

151.93
1.000.00


148.31
1.000.00

148.40
1.000.00

150.35
1,000.00
135.00
135.00


150.00
1,050.00

150.00
140.00


5.094
37.500

5.109
13.700

8.301
40.900

10710
51.800


47,341
236.700

21.192
144,500

97378
665.900
3,888
4,847


1.452,000
12.155720

2,410.650
12,908


67.0
550.0

67.0
550.0

67.0
550.0

67.0
550.0


67.0
550.0

67.0
550.0

67.0
550.0
67.6
67.8


42.0
275.0

42.0
20.0


AP-42
AP-42

AP-42
AP-42

AP-42
AP-42

AP-42
AP-42


AP-42
AP-42

AP-42
AP-42

AP-42
AP-42
AP-42
AP-42


AP*»2
AP-42

AP-42
AP-42
45.9
11.4
1.1
10.3
4.9
1.1
3.8
»3.»
1.8
117
16.5
2.3
147
327.4
75.8
10.7
65.1
44.5
4.8
39.7
204.0
21.8
183.1
f.O
13
2JZ4XT
1,795.0
203.3
1,591.8
338.4
337.5
0.9
0332
0.528


0.460


0.482


0.482


0338
0.504


0.504


0.508


0.502
0.502
0769
0767


0770


247
6.0


2.6


6.9


8.7


170.9
39.6


23.2


T06.0


0.4
0.5
2,320.7
J.307.0


302.3


24.2
6.0


2.6


6.0


8.7


122.3
28.4


16.6


76.4


0.4
0.5
2,101.5
1,360.7


242.4


247
6.0


2.6


6.0


8.7


92.0
2J.3


12.4


57.3


0.4
0.5
13764
J.020.5


181.8



-------
Detail Report - Five Month Data
Point-Segment Level Data
DM Ign
Plant Capacity
Affected Point SCC/DetcrtDtton (10x6Btuftu)
\
5-Month
Activity
Fac/Code
017 Middlesex Co - Inner Zone - Serious
0128 BOSTON EDISON MYSTIC *119 0128*M
003 1,510
Affected 10100404 Residual Oil 0.437 1
Affected 10100501 Distillate OH 0.417 3
004 1.420
Affected 10100404 RetldualOil 0.442 1
Affected
Baseline 005
Baseline 005
10100501 Distillate Oil
20100101 Distillate OH
10100401 Residual Oil

198
248
0.417 3
0.417 3
0.417 3
-inal OTC NOx Baseline in
Massachusetts
Heat Content
(10x6 Btul Heat Input
Fuel Use/Units SCC Unit) (10x6 Btu)
13.944.0
65.5
19.053.0
123.4
19.6
6.7
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
150.00
140.00
150.00
140.00
140.00
150.00
2.091.600
11,970
2.857.950
17.276
2,744
1,005
ventory
State Emission
Factor/Code Con.
(Iba/SCC Unit) EH.
42.0 AP-42
20.0 AP-42
42.0 AP-42
20.0 AP-42
97.7 AP-42
67.0 AP-42
0265 LOWELL COGEN
001
Baseline
Baseline

20100101 Distillate Oil
20100201 Natural Gas
286



0.403 1
0.403 1

47.7
643.0

1000 Gal
10x6CuFt

138.50
1.023.00

6.606 .
657.789

42.8 1990 Other CEMS
322.9 1990 Other CEMS
0500 STATION 240
Baseline 001
Baseline 002
Baseline 003
20100101 Distillate OH
20100101 Distillate Oil
20100101 Distillate Oil
196
198
198
0.420 4
0.420 4
0.420 4
18.2
19.7
16.9
1000 Gal
1000 Gal
1000 Gal
140.00
140.00
140.00
2,548
2,758
2.646
97.7 AP-42
97.7 AP-42
97.7 AP-42
4040 PEPPERELL POWER
007
Baseline
Baseline

20100101 Distillate OH
20100201 Natural Gas
021 Norfolk Co - Inner Zone
390



0.476 1
0.460 1

266.1
968.3

1000 Gal
10x6CuFt

140.00
1.034.00

37,254
1,001,222

32.2 Non-1990 Other CEMS
1 44.8 Non-1 990 Other CEMS
Baseline
Five Emission Rate
Month (Ibs/IOxe Btu)
2,829.7
293.7
292.8
0.9
401.3
400.1
1.2
1.0
0.2
104.8
104.8
1.0
103.8
it
0.9
1.0
0.9
74.4
74.4
4.3
70.1
0.269
0.279
0.279

0.698
0.446
0416
0.316


0.698
0.696
0.696
0.696
0.143
0.143


19
06/26/95
Target (Point Level)
RACT Phase II Phase III
2.320.7
262.3
356.5

0.5
0.2
68.5
66.5


1.3
0.4
0.5
0.4
74.2
74.2


2,101.5
270.4
267.5

0.5
0.2
663
66.5


M
0.4
0.5
0.4
74.2
74.2


1376.3
157.8
21S.6

0.5
0.2
M.5
66.5


14
0.4
0.5
0.4
74.2
74.2


- Serious
0133 STATION 446
001
Baseline
Baseline
002
Baseline
Baseline
003
Baseline
Baseline
004
Baseline
Baseline
005
Baseline
Baseline
006
Baseline
Baseline

20100101 Distillate OH
20100201 Natural Gas

20100101 Distillate OH
20100201 Natural Gas

20100101 Distillate OH
20100201 Natural Gas

20100101 DtstHlateOH
20100201 Natural Gas

20100101 Distillate OH
20100201 Natural Gas

20100101 Distillate OH
20100201 Natural Gas
337


337


337


337


337


337



0.530 3
0.530 3

0.530 3
0.530 3

0.530 3
0.530 3

0.530 3
0.530 3

0.530 3
0.530 3

0.530 3
0.530 3

42.1
4.6

42.2
4.6

44.6
2.9

44.6
2.9

32.4
4.2

32.4
4.2

1000 Gal
10x6CuFt

1000 Gal
10x8CuFt

1000 Gal
10x6CuFt

1000 Gal
10x6CuFt

1000 Gal
10x6CuFt

1000 Gal
10x6 CuR

140.00
1,000.00

140.00
1,000.00

140.00
1,000.00

140.00
1.000.00

140.00
1,000.00

140.00
1,000.00

5.894
4.600

5.908
4,600

6.244
2.900

8,244
2.900

4.536
4,200

4,536
4.200

97.7 AP-42
462.0 AP-42

97.7 AP-42
462.0 AP-42

97.7 AP-42
462.0 AP-42

97.7 AP-42
462.0 AP-42

97.7 AP-42
462.0 AP-42

97.7 AP-42
462.0 AP-42
17.0
3.1
2.1
1.1
3.»
2.1
1.1
2.8
Z2
0.7
2.8
2£
0.7
2.6
1.6
1.0
2.6
1.6
1.0
0.601
0.595


0.595


0.624


0.624


0.565


0.585


7.8
T.4


1.4


1.3


1.3


1.2


1.2


7.8
».4


1.4


1.3


1.3


1.2


1.2


7.8
1.4


1.4


1.3


1.3


1.2


1.2



-------
Detail Report - Five Month Data
Point-Segment Level Data
DMlgn 5-Month
Plant Capacity Activity
Affected Point SCC/Deterlotlon MOxBBtu/hr) Fac/Code
Final OTC NOx Baseline Inventory
Massachusetts
Heat Content State Emission
Baseline
20
06/26/95
(10x6 Bfaj/ Heat Input Factor/Code Con. Five Emission Rate Target (Point Level)
Fuel Use/Units SCO Unit) (lOx6Btu) flbs/SCC Unit) Ell. Month (Ibe/10x6 Btul RACT
021 Norfolk Co - Inner Zone - Serious
0227 EDGAR STATION
Baseline 001
Baseline 002
20100101 DMMateOB
20100101 Distillate OH
0491 BRAINTREE ELECTRIC
003
Baseline
Baseline

20100101 Distillate Oil
20100201 Natural Gaa
025 Suffolk Co - Inner Zone
0012 BOSTON EDISON N.BOST
007
Affoctod
Affoctod
002
Affoctod
Affected
Baseline 003

10100401 Residual Oil
10100601 Natural Gas

10100401 Residual Oil
10100601 Natural Gas
20100101 Distillate OH
0507 TRIGEN-BOST.ENER.COR
001
Affected
Affected
002
Affoctod
Affected
003
Affoctod
Affoctod
004
Affected
Affected

10200401 Residual Oil
10200601 Natural Gas

10200401 Residual Oil
10200601 Natural Gas

10200401 Residual Oil
10200601 Natural Gas

10200401 Residual Oil
10200801 Natural Gas
1SO 0.420 4
798 0.420 4
•1190491*M
85!
0.300 1
0.520 1
- Serious
•1190012*M
3,730
0.247 2
0.699 2
3.680
0.170 2
0.717 2
202 0.417 3
*1190507*M
500
0.417 3
0.417 3
500
0.417 3
0.417 3
600
0.417 3
0.417 3
500
0.417 3
0.417 3
17.4 1000 Gal
19.S 1000 Gal


69.4 1000 Gal
743.6 10x6 Cu Ft



11,558.4 1000 Gal
6,712.5 10x6CuFt

12.234.6 1000 Gal
6,315.5 10x6 Cu Ft
29.4 1000 Gal


1,163.4 1000 Gal
251.5 10x6CuFt

1.022.1 1000 Gal
216.8 10x6 Cu Ft

670.1 1000 Gal
422.4 10x6 Cu Ft

1.183.4 1000 Gal
251.5 10x6 Cu Ft
140.00
140.00


140.00
1,050.00



151.52
1.033.72

151.69
1.033.56
140.00


150.00
1.050.00

150.00
1.050.00

150.00
1,050.00

150.00
1.050.00
2.436
2.730


12,516
760,780



1,751,329
6.938,646

1.858,313
8.594,566
4,116


177.510
264,075

153.315
227,640

100.515
443.520

177.510
264.075
97.7
97.7


97.7
462.0



75.8
578.9

75.9
578.8
97.7


55.0
550.0

55.0
550.0

55.0
550.0

55.0
550.0
AP-«2
AP-42


AP-42
AP-42



Mul Slk Non-1990
MulStk Non-1990

Mul Stk Non-1990
MulStk Non-1990
AP-42


AP-42
AP-42

AP-42
AP-42

AP-42
AP-42

AP-42
AP-42
14
0.9
7.0
178.1
77ft 7
4.4
1714

6,253.2
2.380.7
4374
1.9424
2.077.7
4644
2.4084
1.4
425.7
707.7
324
692
87.7
28.1
594
134.6
18.4
1162
707.7
324
692
0.698
0.699
0.690
0X44
0.447



0449
0.535


0.532


0.690
0X71
0.461


0.461


0.495


0.467



0.9
0.4
0.6
794
79.5



2,059.4
939.7


7,779.6


0.7
253.1
67.0


S3.3


76.2


61.8


Phase II

0.9
0.4
0.5
794
79.5



1,915.0
069.0


7,045.3


0.7
1804
44.2


30.7


54.4


44.2


Phase III

0.9
0.4
0.5
794
79.5



1X3M
651.0


704.0


0.7
1354
33.7


20.6


40.0


33.7



-------
Detail Report - Five Month Data
Point-Segment Level Data

Plant
Affected Point

Design 5-Month
Capacity Activity
SCC/DescrtDtton (10x6Btufhr) Fac/Code
Final OTC NOx Baseline Inventory
New Hampshire
Heat Content State Emission
(10x6 Btu/
Fuel Use/Units SCC Unit)
013 Merrimack Co - Inner Zone - Marginal
0026 PSNH, MERRIMACK STATION
001 1.093
Affected 10100203 Bituminous Coal 0.388 1 127.447.0
Affected 10100501 Distillate OH 0.526 1 10.0
002 3.473
Affected 10100203 Bituminous Coal 0.335 1 223.076.0
Affected 10100501 Distillate Oil 0.485 1 16.0
015 Rockingham Co - Inner Zone - Serious
0012
Affected

Affected
Affected

Affocteo
Aftectod

Affected
Affected
0054

Affoctoo
Affected
PSNH,
002
004


005


006


PSNH,
001


SCHILLER
10100401 Residual Oil

10100202 Bituminous Coal
10100401 Residual Oil

10100202 BHumlnouiCoal
10100401 Residual Oil

10100202 Bituminous Coat
10100401 Residual Oil
NEWINGTON

10100404 Residual Oil
10100501 Distillate Oil

430 0.546 1
B74
0.165
0.672
574
0.227
0.669
574
0.162
0.726

4.350
0.394 1
0.333 1

2.313.0

10.592.0
5.535.0

10,485.0
5.913.0

13.506.0
5.220.0


54.758.0
390.0
Tons
1000 Gal
Tons
1000 Gal

1000 Gal

Tons
1000 Gal

Tons
1000 Gal

Tons
1000 Gal


1000 Gal
1000 Gal
27.00
139.00
27.00
139.00

155.00

26.00
155.00

26.00
155.00

26.00
155.00


155.00
136.00
Heat Input
(10x6 Btu)
3.387.514
1,401
5.912.201
2,247

359,797

277.499
860.127

275.313
916,527

354.966
610.122


8.477.712
52.977
Baaeime
21
06/26/95
Factor/Code Con. Five Emission Rate Target (Point Level)
(Ibs/SCC Unit) EH. Month (Ibs/10x6 Btu)
34.2
20.0
68.2
20.0

67.4

26.2
66.8

26.3
67.0

26.4
67.1


63.8
20.0
State Factor
AP-42
State Factor
AP-42

AP-42

State Factor
AP-42

State Factor
AP-42

State Factor
AP-42


State Factor
AP-42
••5S&3
2.179.1
2,179.0
0.1
7.3702
7.379.0
02
1.091.0
78.0
324.0
139.0
185.0
336.0
138.0
196.0
353.0
178.0
175.0
2.296.9
2,296.9
2.293.0
3.9
2.055
1.310
2.432
O.S66
0.434
0.758


0.701


0.794


0.539
0.543


PACT Phase II Phase III
ft
5,697.1
1.SS8.4
4./3A7
862.7
77.7
254.4


266.8


263.7


1,487.5
J.487.5


3J45A
762.7
2.582.7
392.5
36.0
113.8


119.2


123.6


853.1
853. 1


2,389.6
544.0
1,644.8
289.9
27.0
85.3


89.4


88.3


639.8
639.8



-------
Detail Report - Five Month Data
Point-Segment Level Data
Design 5-Month
Plant Capacity Activity
AHected Point SCC/Descftotion 	 (10x6 Btu/hrl Fee/Code
001 Atlantic Co - Inner Zone - Moderate
0002 AC ELEC CO - MISSOURI
Baseline 707 20100901 Kerosene/Naphtha 3(3 0.533 1
Baseline 777 20100901 Kerosene/Naphtha 373 0.624 1
Baseline 727 20100901 Kerosene/Naphtha 373 0.558 1
003 Bergen Co - Inner Zone - Severe
0012 PSE&G -BERGEN
077 2,625
Affected 10100601 Natural Gaa 0.536 1
027 2,625
Affected 10100601 Natural Gaa 0.776 1
Baseline 037 20100201 Natural Gas 327 0.717 t
0603 PRIME ENERGY LIMITED PARTNERSHIP
027 700
Baseline 20100101 DWIItateOR 0.172 1
Baseline 20100201 Natural Gas 0.434 1
005 Burlington Co - Inner Zone - Severe
0003 PSE&G - BURLINGTON
Affected 037 10100401 Residual Oil 7.950 0.531 1
Baseline 047 20100901 Kerosene/Naphtha 327 0.676 1
Baseline 727 20100901 Kerosene/Naphtha 407 0.594 1
Baseline 737 20100901 Kerosene/Naphtha 407 0.594 1
Baseline 147 20100901 Kerosene/Naphtha 401 0.658 1
Baseline 157 20100901 Kerosene/Naphtha 40? 0.658 1
Baseline 767 20100901 Kerosene/Naphtha 407 0.470 1
Baseline 777 20100901 Kerosene/Naphtha 407 0.470 1
Baseline 787 20100901 Kerosene/Naphtha 407 0.563 1
Baseline 797 20100901 Kerosene/Naphtha 407 0.563 1
Baseline 207 20100901 Kerosene/Naphtha 427 0.438 1
Baseline 277 20100901 Kerosene/Naphtha 427 0.438 1
Baseline 227 20100901 Kerosene/Naphtha 427 0.511 1
Baseline 237 20100901 Kerosene/Naphtha 427 0.511 1
Baseline 247 20100901 Kerosene/Naphtha 427 0.583 1
Baseline 257 20100901 Kerosene/Naphtha 427 0.583 1
Baseline 267 20100901 Kerosene/Naphtha 427 0.416 1
Baseline 277 20100901 Kerosene/Naphtha 427 0.416 1
Baseline 287 20100901 Kerosene/Naphtha 407 0.692 1
Baseline 297 20100901 Kerosene/Naphtha 407 0.692 1
Baseline 307 20100901 Kerosene/Naphtha 407 0.688 1
Baseline 377 20100901 Kerosene/Naphtha 407 0.688 1
Baseline 327 20100901 Kerosene/Naphtha 407 0.521 1
Baseline 337 20100901 Kerosene/Naphtha 407 0.521 1
Baseline 347 20100901 Kerosene/Naphtha 407 0.510 1
Final OTC NOx Baseline Inventory
New Jersey
Heat Content State Emission
Baseline
(10x6 Btu/ Heat Input Factor/Code Con. Five Emission Rate
Fuel UaefUnlts SCCUnlO (10x6 Btu) (Ibs/SCC Unit) Efl. Month (lbs/10x« Btul


111.9
165.7
139.9



4,206.6

4,071.5
46.4


239.6
2.204.1


6,449.7
38.1
95.9
95.9
95.9
95.9
95.9
95.9
95.9
95.9
94.9
94.9
94.9
94.9
94.9
94.9
94.9
94.9
111.4
111.4
111.4
111.4
111.4
111.4
111.4


1000 Gal
1000 Gal
1000 Gal



10x6CuFt

10x6 Cu Ft
10x6CuFt


1000 Gal
10x6CuFt


1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal


133.70
133.74
133.65



1,033.22

1.033.22
1,033.21


140.00
1.050.00


149.99
133.99
134.15
134.15
134.15
134.15
134.15
134.15
134.15
134.15
134.10
134.10
134.10
134.10
134.10
134.10
134.10
134.10
13452
13452
134.22
134.22
134.22
13452
13452


14.961
22.160
18.697



4,346.343

4,206,755
47.941


33.544
2.314.305


967.395
5.105
12.665
12.865
12.865
12.865
12,665
12,665
12.865
12,865
12.726
12.726
12.726
12.726
12.726
12.726
12.726
12.726
14,952
14.952
14,952
14,952
14.952
14.952
14,952


675
67.1
67.0



•M*

-..
516.8


74.9
196.4


70.5
120.7
107.4
107.4
107.4
107.4
107.4
107.4
107.4
107.4
107.3
107.3
107.3
107.3
107.3
107.3
107.3
107.3
107.4
107.4
107.4
107.4
107.4
107.4
107.4


State Factor
State Factor
State Factor



Mul Stk Non-1990

Mul Stk Non-1990
Mul Stk Non-1990


Mul Stk 1990
Mul Stk 1990


State Factor
Mul Stk Non-1 990
Mul 61k Non-1 990
Mul Stk Non-1990
Mul Stk Non-1990
Mul Stk Non-1990
Mul Stk Non-1990
Mul Stk Non-1990
Mul Stk Non-1990
Mul Stk Non-1990
Mul Stk Non-1990
Mul Stk Non-1990
Mul Stk Non-1990
Mul Stk Non-1990
Mul Stk Non-1990
Mul Stk Non-1 990
Mul Stk Non-1990
Mul Stk Non-1990
Mul Stk Non-1990
Mul Stk Non-1990
Mul Stk Non-1990
Mul Stk Non-1 990
Mul Stk Non-1990
Mul Stk Non-1 990
Mul Stk Non-1990

14.0
3.6
5.6
4.7

4.6)0.7
2.347.0
2.347.0
2.277.7
2571.7
12.0
225.4
225.4
9.0
216.4

359.4
227.3
2.3
5.2
5.2
5.2
5.2
5.2
5.2
5.2
62
5.1
5.1
5.1
5.7
5.7
5.7
5.7
5.7
6.0
6.0
6.0
6.0
6.0
6.0
6.0

0.502
0.500
0.500
0.500

1.077
7.088

7.089

0.500
0.192
0502



0554
0.470
0.900
0.800
0.800
0.800
0.800
0.800
0.800
0.800
0.800
0.800
0.800
0.800
0.800
0.800
0.800
0.800
0.800
0.800
0.800
0.800
0.800
0.800
0.800
0.800
Target
22
06/26/95
(Point Level)
flACT Phase II pnawiii

115
3.0
4.4
3.7

860.1
434.6

420.7

4.6
223.1
223.1



2014
135.4
7.0
2.6
2.6
2.6
2.6
2.6
2.6
2.6
2.6
iS
iS
iS
is
iS
iS
iS
iS
3.0
3.0
3.0
3.0
3.0
3.0
3.0

115
3.0
4.4
3.7
''
660.1
434.6

420.7

4.8
223.1
223.7



162.6
96.7
7.0
2.6
2.6
2.6
2.6
2.6
2.6
2.6
2.6
2.5
iS
iS
iS
iS
2.5
iS
iS
3.0
3.0
3.0
3.0
3.0
3.0
3.0

115
3.0
4.4
3.7

660.1
434.6

420.7

4.6
223.1
223.7



138.4
72.6
7.0
2.6
2.6
2.6
2.6
2.6
2.6
2.6
2.6
2.5
2.5
iS
iS
2.5
2.5
2.5
2.5
3.0
3.0
3.0
3.0
3.0
3.0
3.0

-------
Detail Report - Five Month Data
Point-Segment Level Data
Design 5-Monlh
Plant Capacity Activity
Affected Point SCC/Descriotlon (10x6 BtuAu) Fac/Code
005 Burlington Co - Inner Zone - Severe
0003 PSE&G- BURLINGTON
Baseline 357 20100901 Kerosene/Naphtha 401 0.510 1
009 Cape May Co - Inner Zone - Moderate
0001 ACELECCO-B.L.ENGL
Affected 011 10100203 Bltuminoua Coal 1.300 0.416 1
Affected 021 10100203 Bituminous Coal 1,600 0.429 1
Affected 031 10100404 Residual Oil 1,720 0.489 1
0013 AC ELEC CO - MIDDLE ST
Baseline 031 20100901 Kerosene/Naphtha 246 0.623 1
Baseline 041 20100901 Kerosene/Naphtha 246 0.71B 1
Baseline 057 20100901 Kerosene/Naphtha 566 0.596 1
01 1 Cumberland Co - Inner Zone - Severe
0020 VINELAND MUNICIPAL ELECTRIC UTILITY
Affected 051 10100401 Residual Oil 270 0.415 Z
061 357
Affected 10100401 Residual Oil 1.000 2
0048 AC ELEC CO - CARLL'S C
021 646
Baseline 20100201 Natural Gas 0.582 1
031 660
Baseline 20100201 Natural Gas 0.705 1
0171 VINELAND MUNICIPAL ELECTRIC UTILITY
Baseline 021 20100101 Distillate Oil 417 0.701 2
0222 AC ELEC CO - CUMBERLAND
Baseline 041 20100901 Kerosene/Naphtha 1,032 0.000 1
013 Essex Co - Inner Zone - Severe
0016 PSE&G -ESSEX
021 377
Baseline 20100201 Natural Gas 0.630 1
Baseline 20100901 Kerosene/Naphtha 0.042 1
031 377
Baseline 20100201 Natural Gas 0.630 1
Baseline 20100901 Kerosene/Naphtha 0.042 1
041 377
Baseline 20100201 Natural Gas 0.593 1
Final OTC NOx Baseline In
New Jersey
Heat Content
(10x6 Btu/ Heat Input
Fuel Use/Units SCC Unit) (10x6 Btu)


111.4


120,172.6
144,600.8
10,846.0

313.4
266.0
183.2


659.4

1,855.0


116.7

118.8

365.5

1.554.3



72.5
2.0

72.5
2.0

72.5


1000 Gal


Tons
Tons
1000 Gal

1000 Gal
1000 Gal
1000 Gal


1000 Gal

1000 Gal


10x6 Cu Ft

10x6CuFt

1000 Gal

1000 Gal



10x8 Cu Ft
1000 Gal

10x6 Cu Ft
1000 Gal

10x8 CuR


13472


25.41
25.34
151.17

133.62
133.63
133.65


150.00

150.00


1.041.52

1.041.86

140.00

135.00



1.032.17
135.00

1,032.17
135.00

1,032.17


14,952


3.053,586
3.664.185
1,639.583

41.876
35,645
24,484


98.910

278,250


121.545

123.773

51,170

209,833



74,832
270

74,832
270

74,832
ventory
State Emission
Factor/Code Con.
(Ibs/SCC Unit) EH.


107.4


362
36.1
42.3

66.9
66.9
66.9


66.9

67.5


721.9

722.1

92.0

9.9



619.3
130.0

619.3
130.0

619.3


MulStk Non-1990


State Factor
State Factor
State Factor

State Factor
State Factor
State Factor


Sing Stk Rep Cond

Sing Stk Rep Cond


Sing Stk Rep Cond

Sing Stk Rep Cond

Sing Stk Rep Cond

State Factor



Mul Stk Non-1 990
MulStk Non-1990

Mul Stk Non-1990
Mul Stk Non-1 990

Mul Stk Non-1990
Baseline
Five Emission Rats
Month (Ibs/10x6 Btu)

359.4
6.0

5,008.2
2.172.6
2,607.1
229.5
25.5
10.5
8.9
6.1

84.7
22. 1
62.6
62.6
8S.O
42. 1
42.1
42.9
42.9
16.8
16.8
7.7
7.7

879.8
22.6
22.5
0.1
22.6
22.5
0.1
22.0
22.5

0354
0.800

1.199
1.420
1.420
0.280
0.501
0.500
0.500
0.500

0449
0.450
0.609

0.693
0.700

0.708

0.657
0.660
0.073
0.070

0493
0.627


0.82t


0.620

23
06/26/95
i Target (Point Level)
PACT

20U
3.0

2,1794
916.1
1.099.3
164.0
204
8.4
7.1
4.9

524
13.8
39.0

24.5
7212

12.4

10.2
70.2
7.7
7.7

2464
7.5


7.S


7.5

Phase II

162.6
3.0

1.836.9
760.4
972.5
764.0
204
8.4
7.1
4.9

37.7
9.9
27.8

24.5
72.2

72.4

10.2
70.2
7.7
7.7

2464
7.5


7.5


7.5

Phase III

1384
3.0

1.317.9
543.2
657.8
723.0
204
8.4
7.1
4.9

28.3
7.4
20.9

24.5
72.2

72.4

10.2
70.2
7.7
7.7

2464
7.5


7.5


7.5


-------
Detail Report - Five Month Data
Point-Segment Level Data
Plant
Affected Point SCC/DescrlPtlon 	
013 Essex Co - Inner Zone
0016 PSE&G- ESSEX
041
Baseline 20100901 Kerosene/Napntha
077
Baseline 20100201 Natural Gat
Baseline 20100901 Kerosene/Naphtha
101
Baseline 20100201 Natural Gas
Baseline 20100901 Kerosene/Naphtha
777
Baseline 20100201 Natural Gas
Baseline 20100901 Kerosene/Naphtha
727
Baseline 20100201 Natural Gas
Baseline 20100901 Kerosene/Naphtha
737
Baseline 20100201 Natural Gat
Baseline 20100901 Kerosene/Naphtha
747
Baseline 20100201 Natural Gas
757
Baseline 20100201 Natural Gas
767
Baseline 20100201 Natural Gas
777
Baseline 20100201 Natural Gas
707
Baseline 20100201 Natural Gaa
797
Baseline 20100201 Natural Gat
201
Baseline 20100201 Natural Gas
277
Baseline 20100201 Natural Gat
227
Baseline 20100201 Natural Gat
231
Baseline 20100201 Natural Gas
241
Baseline 20100201 Natural Gat
251
Baseline 20100201 Natural Gat
261
Baseline 20100201 Natural Gat
277
Baseline 20100201 Natural Gas
281
Baseline 20100201 Natural Gas
297
Baseline 20100201 Natural Gat
Design
Capacity
(10x6 Btu/hr)
- Severe

405

377


377


377


377


377


422

422

422

422

422

422

422

422

422

422

422

422

422

422

422

422

5-Month
Activity
Fee/Code



0.040 1

0.593 1
0.040 1

0.572 1
0.037 1

0.572 1
0.037 1

0.642 1
0.027 1

0.642 1
0.027 1

0.663 1

0.663 1

0.593 1

0.593 1

0.615 1

0.615 1

0.717 1

0.717 1

0.812 1

0.812 1

0.671 1

0.671 1

0.618 1

0.618 1

0.541 1

0.541 1
Final OTC NOx Baseline Inventory
New Jersey
Heat Content State Emlttlon
(10x6 Btu/ Heat Input Factor/Cod* Con.
Fuel Use/Units SCCUnlt) (10x6 Btu) (Ibs/SCC Unit) Erf.



2.0

72.5
2.0

72.5
2.0

72.5
2.0

72.5
2.0

72.5
2.0

102.8

102.8

102.8

102.8

102.8

102.8

102.8

102.8

86.6

86.6

86.6

86.6

86.6

86.6

86.6

86.6



1000 Gal 135.00

10x6 CuFt 1.032.17
1000 Gal 135.00

10x6 CuFt 1.032.17
1000 Gal 135.00

10x6 CuFt 1.032.17
1000 Gal 135.00

10x6 CuFt 1.032.17
1000 Gal 135.00

10x6 CuFt 1.032.17
1000 Gal 135.00

10x6 CuFt 1,032.78

10x6 CuFt 1.032.78

10x6 CuFt 1.032.76

10x6 CuFt 1.032.78

10x6 CuFt 1.032.78

10x6 CuFt 1.032.78

10x6 CuFt 1.032.78

10x6 CuFt 1.032.78

10x6 CuFt 1.03327

10x6 CuFt 1.03327

10x6 CuFt 1.03327

10x6 CuFt 1.03327

10x6 CuFt 1,03327

10x6 CuFt 1.03327

10x6 CuFt 1.03327

10x6 CuFt 1,03327



270

74.832
270

74.832
270

74.832
270

74,632
270

74.632
270

106.170

108.170

108,170

106.170

106.170

106,170

108.170

106.170
•
89.481

89.481

89.481

89.481

89.481

89.481

89.481

89.481



130.0 Mul Stk Non-1990

619.3 Mul Stk Non-1990
130.0 Mul Stk Non-1990

619.3 Mul Stk Non-1990
130.0 Mul Stk Non-1990

6194 Mul Stk Non-1990
130.0 Mul Stk Non-1990

619.3 Mul Stk Non-1990
130.0 Mul Stk Non-1990

619.3 Mul Stk Non-1990
130.0 Mul Stk Non-1990

619.7 Mul Stk Non-1 990

619.7 Mul Stk Non-1990

619.7 Mul Stk Non-1990

619.7 Mul Stk Non-1990

619.7 Mul Stk Non-1990

619.7 Mul Stk Non-1990

619.7 Mul Stk Non-1 990

619.7 Mul Stk Non-1990

619.9 Mul Stk Non-1990

619.9 Mul Stk Non-1 990

619.9 Mul Stk Non-1990

619.9 Mul Stk Non-1990

619.9 Mul Stk Non-1990

619.9 Mul Stk Non-1990

619.9 Mul Stk Non-1990

619.9 Mul Stk Non-1990

Five
Month

679J
22.6
0.1
22.6
22.5
0.1
22.0
22.5
0.1
22.6
22.5
0.1
22.6
22.5
0.1
22.6
22.5
0.1
31.9
31.9
31.9
31.9
37.9
31.9
37.9
31.9
37.9
31.9
37.9
31.9
37.9
31.9
37.9
31.9
26.0
26.8
26.0
26.8
26.0
26.8
26.0
26.8
26.8
26.8
26.0
26.8
26.8
26.8
26.6
26.6
BateHrw
Emission Rate
(iba/lOxflBtu)

0493
0.620

0.620


0.627


0.627


0.632


0.632


0.637

0.637

0.626

0.626

0.604

0.604

0.624

0.624

0.673

0.673

0.676

0.676

0.676

0.676

0.627

0.627

24
06/26/95
Target (Point Level)
RM?T

2464
7.5

7.5


7.5


7.5


7.5


7.5


70.6

70.6

70.6

70.6

70.6

70.6

70.6

70.6

0.9

8.9

8.9

8.9

8.9

8.9

8.9

8.9

Phased

2464
7.5

7.5


7.5


7.5


7.5


7.5


70.0

70.6

70.6

70.6

70.6

70.6

70.6

70.6

6.9

0.9

0.9

0.9

0.9

0.9

0.9

6.9

Phase III

2464
7.5

7.5


7.5


7.5


7.5


7.5


70.0

70.6

70.6

70.6

70.6

70.6

70.6

70.6

0.9

0.9

0.9

0.9

0.9

0.9

0.9

0.9


-------
Detail Report - Five Month Data
Point-Segment Level Data
Plant
Affected Point SCC/Deserlotlon
1
Design 5-Month
Capacity Activity
(10x6 Btu/hr) Fac/Code
Final ore NOX Baseline in
New Jersey
Heat Content
(10x6 Btu/ Heat Input
Fuel Use/Units SCO Unit) (10x6 Btu)
ventory
State Emission
Factor/Code Con.
(Ibs/SCC Unit) EH.
Baseline
Five Emission Rate
Month (Ibs/10x6 Btu)
013 Essex Co - Inner Zone - Severe
0016 PSE&G -ESSEX
Baseline 357 20100201 Natural Gas
015 Gloucester Co - Inner

7,059
Zone-

0.398 1
Severe

573.5 10x6 CuR


1.032.74


592^76


103.3 State Factor

0004 COASTAL EAGLE POINT OIL COMPANY
547
Affected 10200401 Residual Oil
Affected 10200701 Process Gas
851
Affected 10200401 Residual Oil
Affected 10200701 Process Gas
067
Affected 10200401 Residual Oil
Affected 10200701 Process Gas
077
Affected 10200401 Residual Oil
Affected 10200701 Process Gas
0006 MOBIL OIL CORPORATION
077
Affected 10200401 Residual Oil
Affected 10200701 Process Gas
072
Affected 10200401 Residual Oil
Affected 10200701 Process Gas
027
Affected 10200401 Residual Oil
Affected 10200701 Process Gas
022
Affected 10200401 Residual Oil
Affected 10200701 Process Gas
047
Affected 10200401 Residual Oil
Affected 10200701 Process Gas
042
Affected 10200401 Residual Oil
Affected 10200701 Process Gas
0037 AC ELEC CO - MICKELTON
Baseline 077 20100201 Natural Gas
0999 PSE&G -NATIONAL
Baseline 077 20100901 Kerosene/Naphtha
346


346


346


344



279


279


279


279


279


279



1.092

327

0.417 3
0.417 3

0.417 3
0.417 3

0.417 3
0.417 3

0.417 3
0.417 3


0.347 1
0.382 1

0.347 1
0.382 1

0.347 1
0.382 1

0.327 1
0.405 1

0.406 1
0.326 1

0.325 1
0.408 1

0.673 1

0.661 1

667.5 1000 Gal
637.0 10x6 CuR

667.5 1000 Gal
637.0 10x6 CuR

667.5 1000 Gal
637.0 10x6CuFt

667.5 1000 Gal
637.0 10x6CuFt


1.083.0 1000 Gal
318.6 10x6 Cu Ft

1.083.0 1000 Gal
318.6 10x6CuFt

1.083.0 1000 Gal
316.6 10x6CuFt

954.4 1000 Gal
297.4 10x6CuFt

338.4 1000 Gal
85.0 10x6 CuR

2.046.8 1000 Gal
637.2 10x6 CuR

280.0 10x6 CuR

26.5 1000 Gal

150.00
1.050.00

150.00
1.050.00

150.00
1.050.00

150.00
1.050.00


149.99
1,200.00

149.99
1.200.00

149.99
1,200.00

149.99
1.200.00

150.01
1.200.00

148.81
1,200.00

1,042.15

134.15

100.125
668,850

100.125
668.850

100.125
668.650

100,125
668,850


162,444
382.321

162.444
382.321

162,444
382,321

143,153
356,833

50,764
101.952

304,582
764.642

291,802

3.555

67.1 State Factor
550.2 State Factor

67.1 State Factor
550.2 State Factor

67.1 State Factor
550.2 State Factor

67.1 State Factor
550.2 State Factor


60.0 Industry Factor
460.0 Industry Factor

60.0 Industry Factor
480.0 Industry Factor

60.0 Industry Factor
480.0 Industry Factor

60.0 Industry Factor
480.0 Industry Factor

60.0 Industry Factor
479.8 Industry Factor

59.5 Industry Factor
480.0 Industry Factor

562.8 AP-42

1 20.8 Mul Stk Non-1 990
679.8
29.6

790.5
797.6
22.4
175.2
797.6
22.4
175.2
197.6
22.4
175.2
797.6
22.4
175.2
671.2
709.0
32.5
76.5
709.0
32.5
76.5
709.0
32.5
76.5
700.0
28.6
71.4
30.5
10.2
20.4
213.9
60.9
152.9
78.8
70.0
1.8
7.6
0493
0.700

0.514
0.577


0.577


0.577


0.577


0400
0.407


0.407


0.407


0.407


0.407


0.407


0440
0.540
0.900
0.900
25
06/26/95
Target (Point Level)
PACT Phase II Phase ill

2464
29.6

430.6
707.7


707.7


707.7


707.7


469.9
76.3


76.3


76.3


70.0


27.4


749.7


29.2
29.2
0.7
0.7

2464
29.6

307.6
76.9


76.9


76.9


76.9


335.6
54.5


54.5


54.5


50.0


75.3


706.9


29.2
29.2
0.7
0.7

2464
29.6

230.7
57.7


57.7


57.7


57.7


251.7
40.9


40.9


40.9


37.5


77.5


00.2


29.2
29.2
0.7
0.7

-------
Detail Report - Five Month Data
Point-Segment Level Data
DMlgn 5-Month
Plant Capacity Activity
Affected Point SCC/DMcrlntlon (10x6 Btu/hr) Fac/Code
017 Hudson Co - Inner Zone - Severe
0021 PSE&G- HUDSON
031 6.072
Affected 10100202 Bituminous Coal 0.396
Affected 10100601 Natural Gas O.S53
061 4.127
Affected
Baseline 081
Baseline 08?
Baseline 083
Baieline 084
Baseline 085
Baseline 006
Baseline 087
Baseline 088
10100601 Natural Oas
20100901 Kerosene/Naphtha
20100901 Kerosene/Naphtha
20100901 Kerosene/Naphtha
20100901 Kerosene/Naphtha
20100901 Kerosene/Naphtha
20100901 Kerosene/Naphtha
20100901 Kerosene/Naphttia
20100901 Kerosene/Naphtha

288
280
288
288
288
288
288
288
0.460
0.579
0.579
0.579
0.579
0.579
0.579
0.579
0.579 1
Final OTC NOx Baseline Inventory
New Jersey
Heat Content State Emission
(10x6 Btu/ Heat Input Factor/Code Con.
Fuel Use/Units SCCUnlt) (10x6 Btu) flbs/SCC Unit) Elf.
484,460.8 Tons
689.5 10x6CuR
5.610.4
47.9
47.9
47.9
47.9
47.9
47.9
47.9
47.9
10x6CuFt
1 000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
26.51
1.032.60
1.032.60
133.80
133.80
133.80
133.80
133.80
133.80
133.80
133.80
12.843.056
711,978
5.793.299
6.409
6.409
6.409
6.409
6.409
6.409
8.409
6.409
47.7
702.2
7022
120.3
120.3
120.3
120.3
120.3
120.3
120.3
120.3
State Factor
State Factor
MulStk Non-1 990
MulStk Non-1 990
MulStk Non-1990
Mul Stk Non-1990
MulStk Non-1990
MulStk Non-1 990
MulStk Non-1 990
Mul Stk Non-1990
0022 PSE&G -KEARNY
Affected 031
Affected 041
Baseline 05 f
Baseline 06?
Baseline 071
Baseline 081
Baseline 091
Baseline 101
Baseline 111
Baseline 121
Baseline 151
161
Baseline
162
Baseline
163
Baseline
164
Baseline
16S
Baseline
166
Baseline
167
Baseline
f68
Baseline
Baseline 171
172
Baseline
173
Baseline
10100401 Residual Oil
10100401 Residual Oil
20100901 Kerosene/Naphtha
20100901 Kerosene/Naphtha
20100901 Kerosene/Naphtha
20100901 Kerosene/Naphtha
20100901 Kerosene/Naphtha
20100901 Kerosene/Naphtha
20100901 Kerosene/Naphtha
20100901 Kerosene/Naphtha
20100201 Natural Oas

20100201 Natural Qas

20100201 Natural Qas

20100201 Natural Qas

20100201 Natural Qas

20100201 Natural Qas

20100201 Natural Qas

20100201 Natural Qas

20100201 Natural Qas
20100201 Natural Qas

20100201 Natural Qas

20100201 Natural Qas
1.86S
1.865
483
483
483
483
483
483
483
483
327
328

328

328

328

328

328

328

328

328
328

328

0.592
0.614
0.335
0.335
0.335
0.335
0.335
0.335
0.335
0.335 1
0.644 1

0.185 1

0.185 1

0.185 1

0.185 1

0.185 1

0.185 1

0.185 1

0.185 1
0.552 1

0.552 1

0.552 1
4.032.5
3.301.2
119.1
119.1
119.1
119.1
119.1
119.1
119.1
119.1
48.5

16.0

16.0

16.0

16.0

16.0

16.0

16.0

16.0
8.1

8.1

B.1
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
10x6CuFt

10x6CuFt

10x6 Cu Ft

10x6CuFt

10x6 Cu Ft

10x6 Cu Ft

10x6CuFt

10x6CuFt

10x6 Cu Ft
10x6CuFt

10x6CuFt

10x6CuFt
146.70
146.70
134.74
134.74
134.74
134.74
134.74
134.74
134.74
134.74
1.031.92

1.030.00

1,030.00

1.030.00

1.030.00

1.030.00

1.030.00

1.030.00

1.030.00
1.032.59

1.032.59

1,032.59
591.575
484.286
16.048
16.048
16.048
16.048
16.048
16.046
16.048
16.048
50.048

16.480

16.480

16.480

16,480

16.480

16.480

16,460

16.480
8.364

8.364

8,364
29.3
29.3
161.7
161.7
161.7
161.7
161.7
161.7
161.7
161.7
515.9

515.0

515.0

515.0

515.0

515.0

515.0

515.0

515.0
516.0

516.0

516.0
MulStk Non-1990
Mul Stk Non-1990
Mul Stk Non-1 990
Mul Stk Non-1 990
Mul Stk Non-1990
Mul Stk Non-1 990
Mul Stk Non-1990
Mul Stk Non-1990
Mul Stk Non-1 990
Mul Stk Non-1990
Mul Stk Non-1 990

Mul Stk Non-1 990

Mul Stk Non-1990

Mul Stk Non-1990

Mul Stk Non-1990

Mul Stk Non-1990

Mul Stk Non-1990

Mul Stk Non-1990

Mul Stk Non-1990
Mul Stk Non-1990

Mul Stk Non-1 990

Mul Stk Non-1 990

Five Emission Rate
Month flba/IOxe Btu)
13,793.6
11, BOM
11.558.8
242.1
1,969.7
1.969.7
2.9
2.9
2.9
2.9
2.9
2.9
2.9
2.9
246.8
59.2
48.4
9.6
9.6
9.6
9.6
9.6
9.6
9.6
9.6
12.S
4.1
4.1
4.1
4.1
4.1
4.1
4.f
4.1
4.1
4.1
4.1
4.1
4.J
4.1
4.1
4.1
2.1
2.1
2.1
2.1
2.1
1.422
1.7S7
0.680

0.900
0.900
0.900
0.900
0.900
0.900
0.900
0.900
0.340
0.200
0.200
J.200
1300
1300
1300
1.200
1.200
1300
1300
0.500
0.500

0.500

0.500

0.500

0.500

0.500

0.500

0.500

0.500
0.566

0.566

Target
RACT
3.871.5
3.282.0
579.3

1.3
1.3
1.3
1.3
1.3
1.3
1.3
1.3
158.1
59.2
48.4
33
3.2
3.2
3.2
3.2
3.2
3.2
3.2
5.0
1.6

1.6

1.6

1.6

1.6

1.6

1.6

1.6

0.8
0.8

0.8

26
06/26/95
(Point Level)
Phased Phase III
3,871.5
5,282.0
579.3

1.3
1.3
1.3
1.3
1.3
1.3
1.3
1.3
158.1
59.2
48.4
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
5.0
1.6

1.6

1.6

1.6

1.6

1.6

1.6

1.6

0.8
0.8

0.8

3/152.9
2,950.2
492.4

1.3
1.3
1.3
1.3
1.3
1.3
1.3
1.3
131.2
44.4
36.3
33
3.2
3.2
33
3.2
3.2
3.2
3.2
5.0
1.6

1.6

1.6

1.6

1.6

1.6

1.6

1.6

0.8
0.8

0.8


-------
Detail Report - Five Month Data 1
Point-Segment Level Data
Design 5-Month
Plant Capacity Activity
Affected Point SCC/Descrlotlon (10x6Btu/hr) Fac/Code
017 Hudson Co - Inner Zone - Severe
0022 PSE&G-KEARNY
174 328
Baseline 20100201 Natural Qw 0.552 1
ITS 328
Baseline 20100201 Natural Gas 0.552 1
176 328
Baseline 20100201 Natural Gas 0.552 1
177 328
Baseline 20100201 Natural Gas 0.552 1
178 328
Baseline 20100201 Natural Gas 0.552 1
Final OTC NOx Baseline In
New Jersey
Heat Content
(10x6 Btu/ Heat Input
Fuel Use/Units SCO Unit) (10x6 Btu)
8.1
8.1
8.1
8.1
8.1
10x6 Cu Ft
10x6CuFt
10x6 CuR
10x6CuFt
10x6 Cu Ft
1.032.59
1.032.59
1.032.59
1,032.59
1,032.59
8.364
8,364
8.364
8.364
8.364
ventory
Slate Emission
Factor/Code Con.
(Ibs/SCC Unit) Eft.
516.0
516.0
516.0
516.0
516.0
MulStk Non-1990
MulStk Non-1 990
Mul Slk Non-1990
MulStk Non-1 990
MulStk Non-1990
0577 COGEN TECHNOLOGIES - NEW JERSEY VENTURE
Baseline 011 20100201 Natural Gas
Baseline 021 20100201 Natural Gas
Baseline 041 20100201 Natural Gas
0999 PSE&G - BAYONNE
Baseline Oil 20100901 Kerosene/Naphtha
Baseline 021 20100901 Kerosene/Naphtha
488
488
488

405
405
019 Hunterdon Co - Inner Zone -
0001 JCP&L- GILBERT
081
Affected 10100401 Residual Oil
Affected 10100501 Distillate OH
Affected 10100601 Natural Gas
082
Affected 10100401 Residual Oil
Affected 10100501 Distillate OH
Affected 10100601 Natural Gas
101
Baseline 20100101 Dtstirtate OH
Baseline 20100201 Natural Gas
111
Baseline 20100101 Distillate Oil
Baseline 20100201 Natural Gas
121
Baseline 20100101 Distillate Oil
Baseline 20100201 Natural Gas
131
Baseline 20100101 Distillate OH
Baseline 20100201 Natural Gas
151
Baseline 20100101 Distillate Oil
Baseline 20100201 Natural Gas

310



310



730


730


730


730


385


0.434 1
0.447 1
0.444 1

0.988 1
0.000 1
Severe


0.397 1
0.150 1
0.979 1

0.397 1
0.150 1
0.979 1

0.228 1
0.562 1

0.226 1
0.562 1

0.226 1
0.562 1

0.226 1
0.562 1

0.018 1
0.814 1
1,564.0
1.613.0
1,600.2

42.8
5.1



346.3
5.5
42.0

272.1
4.3
33.0

292.3
585.4

292.3
585.4

292.3
585.4

292.3
585.4

0.3
56.1
10x6 Cu Ft
10x6CuFt
10x8CuFt

1000 Gal
1000 Gal



1000 Gal
1000 Gal
10x6CuFt

1000 Gal
1000 Gal
10x6CuFt

1000 Gal
10x6CuF1

1000 Gal
10x6CuFt

1000 Gal
10x6CuFt

1000 Gal
10x6CuFt

1000 Gal
10x6CuFt
1,050.03
1,050.00
1.049.99

135.28
135.29



150.01
139.09
1,050.50

150.01
139.53
1,050.55

140.01
1.050.05

140.01
1.050.05

140.01
1,050.05

140.01
1.050.05

150.00
1.050.16
1,642.252
1.693.645
1.680.189

5.790
690



51,949
765
44.121

40.817
600
34.668

40.926
614.697

40.926
614,697

40,926
614,697

40,926
614.697

45
58.914
32.7
25.2
32.5

122.0
121.6



48.0
18.2
544.3

48.0
18.6
544.2

92.4
388.5

92.4
388.5

92.4
388.5

92.4
388.5

133.3
609.3
Non-1990 5 Mo. CEMS
Non-1990 5 Mo. CEMS
Non-1990 5 Mo. CEMS

MulStk Non-1 990
MulStk Non-1 990



Mul Stk Non-1990
AP-42
AP-42

Mul Stk Non-1 990
AP-42
AP-42

Mul Stfc Non-1990
Mul Stk Non-1990

Mul Stk Non-1990
Mul Stk Non-1990

Mul Stk Non-1990
Mul Stk Non-1990

Mul Stk Non-1990
Mul Stk Non-1990

Mul Stk Non-1990
MulStk Non-1990
Baseline
Five Efnlaalon Rate
Month (Ibs/10x6 Btu)
246.8
2.1
2.1
2.1
2.1
2.1
2.1
2.1
2.1
2.1
2.1
71.0
25.6
20.3
26.0
2.9
2.6
0.3

714.4
19.8
8.3
0.1
11.4
1S.6
6.5
0.0
9.0
127.2
13.5
113.7
1273
13.5
113.7
127.2
13.5
113.7
127.2
13.5
113.7
17.1
0.0
17.1
0440
0.566
0.566
0.566
0.566
0.566
0.029
0.030
0.020
0.030
0.901
0.900
0.900

0.387
0.365



0.365



0.411


0.411


0.411


0.411


0.589


27
06/26/95
Target (Point Level)
RACT Phase II Phase III
158.1
0.8
0.8
0.8
0.8
0.8
71.9
25.6
20.3
26.0
14
1.2
0.1

399.8
11.7



9.2



69.7


69.7


69.7


69.7


5.9


158.1
0.8
0.8
0.8
0.8
0.8
71.9
25.6
20.3
26.0
1.3
1.2
0.1

385.5
9.7



7.6



69.7


69.7


69.7


69.7


5.9


131.2
0.8
0.8
0.8
0.8
0.8
71.9
25.6
20.3
26.0
1.3
1.2
0.1

364.7
7.3



5.7



69.7


69.7


69.7


69.7


5.9



-------
Detail Report • Five Month Data Final OTC NOx Baseline Inventory
Point-Segment Level Data New Jersey
OMlgn 5-Month Hail Content State Emlttlen
Plant Capacity Activity (10x« Blu/ Heat Input Factor/Cod* Cot
AHactad Point SCC/DeacriDtlon (10x>Btu/hr) Fac/Code Fuel Use/Unit* SCO Unit) (10x6 Btu) (Ibs/SCCUnlt) En
019 Hunterdon Co - Inner Zone - Severe
0001 JCP&L- GILBERT
161 385
Baseline 20100101 Distillate Ott 0.018 1 0.3 1000 Gal 150.00 45 133.3 Mul Stk Non-1990
BaMllna 20100201 Natural Gas 0.814 1 50.1 10x6 Cu Ft 1,050.16 58.914 609.3 Mul StK Non-1990
171 385
Baaallna 20100101 Distillate OH 0.018 1 0.3 1000 Gal 150.00 45 133.3 Mul Gtk Non-1 990
Baselina 20100201 Natural Ga« 0.814 1 56.1 10x6 Cu Ft 1.050.16 58.914 609.3 Mul Stk Non-1 990
181 385
Baaallna 20100101 Dlallllata Oil 0.018 1 0.3 1000 Gal 150.00 45 133.3 Mul Stk Non-1990
Baselina 20100201 Natural Ga» 0.814 1 56.1 10x6 CuR 1.050.16 58.914 609.3 Mul Stk Non-1990
211 845
Affected 10100401 Residual Oil 0.332 1 2.087.3 1000 Gat 150.00 313.096 66.0 Mul Stk Non-1990
Affected 10100501 Distillate Oil 0.165 1 35.5 1000 Gal 139.89 4,966 19.7 AP-42
Affected 10100601 Natural Gat 0.901 1 325.6 10x6 Cu Ft 1,049.87 341,837 199.4 Mul Stk Non-1990
0013 JCP&L - GLEN CARD
031 340
Baaallna 20100101 Distillate OH 0.140 1 3.3 1000 Gal 140.91 465 109.1 Mul Stk Non-1990
Baseline 20100201 Natural Gas 0.765 1 67.8 10x6CuFt 1.050.58 71.229 504.1 Mul Stk Non-1 990
041 340
Baseline 20100101 Distillate Oil 0.140 1 3.3 1000 Gal 140.91 465 109.1 Mul Stk Non-1990
Baseline 20100201 Natural Gas 0.765 1 67.8 lOxSCuFt 1,050.58 71.229 504.1 Mul Stk Non-1 990
051 340
Baseline 20100101 Distillate Oil 0.140 1 3.3 1000 Gal 140.91 465 109.1 Mul Stk Non-1990
Baseline 20100201 Natural Gas 0.765 1 67.8 10x6 Cu Ft 1.050.58 71.229 504.1 Mul Stk Non-1990
061 340
Baseline 20100101 Distillate Oil 0.140 1 3.3 1000 Gal 140.91 465 109.1 Mul Stk Non-1 990
Baseline 20100201 Natural Gas 0.765 1 67.8 10x6 Cu Ft 1.050.58 71.229 504.1 Mul Stk Non-1 990
071 340
Baseline 20100101 Distillate Oil 0.140 1 3.3 1000 Gal 140.91 465 109.1 Mul Stk Non- 1990
Baseline 20100201 Natural Gas 0.765 1 67.8 10x6 Cu Ft 1.050.58 71.229 504.1 Mul Stk Non-1990
061 340
Baselina 20100101 Distillate Oil 0.140 1 3.3 1000 Gal 140.91 465 109.1 Mul Stk Non-1990
Baselina 20100201 Natural Gas 0.765 1 67.8 10x6 Cu Ft 1.050.58 71.229. 504.1 Mul Stk Non-1 990
091 340
Baseline 20100101 Distillate Oil 0.140 1 3.3 1000 Gal 140.91 465 109.1 Mul Stk Non-1990
Baseline 20100201 Natural Gas 0.765 1 67.8 10x6 Cu Ft 1,050.56 71.229 504.1 Mul Stk Non-1990
101 340
Baseline 20100101 Distillate OH 0.140 1 3.3 1000 Gal 140.91 465 109.1 Mul Slk Non-1990
Baseline 20100201 Natural Gas 0.765 1 67.6 10x6 Cu Ft 1.050.58 71.229 504.1 Mul Stk Non-1990
0110 KAMINE MILFORD LIMITED PARTNERSHIP
Affected 012 10100601 Natural Gas 438 0.507 3 524.0 10x6 CuR 1,050.00 550.200 452.6 State Factor
28
06/26/95
Baseline
n. Five Emission Rate Target (Point Level)
1. Month nua/IOxeatu) PACT Phase II PhasaJU
714.4 0487 399.8 385.5 364.7
17.1 0.588 S.9 5.9 5.9
0.0
17.1
17.1 0.588 5.9 5.9 5.9
0.0
17.1
17.1 0.888 5.9 5.9 5.9
0.0
17.1
101.7 0.363 76.7 66.0 49.5
68.9
0.4
32.5
138.2 0.482 57.7 57.7 S7.7
17.3 0.490 72 7.2 72
02
17.1
17.3 0.490 7.2 7.2 7.2
02
17.1
17.3 0.490 72 7.2 7.2
0.2
17.1
17.3 0.490 72 7.2 7.2
02
17.1
17.3 0.490 72 7.2 72
0.2
17.1
17.3 0.490 72 7.2 72
02
17.1
17.3 0.490 72 72 72
02
17.1
17.3 0.490 72 72 72
02
17.1
118.8 0.431 550) 55.0 41 J
118.6 0.430 55.0 55.0 41.3

-------
Detail Report - Five Month Data
Point-Segment Level Data
Design
Plant Capacity
Affected Point SCC/DescrlDtlon 110x6 Btu/hr)
021 Mercer Co - Inner Zone •
0001 PSE&G- MERCER
011
Affected 10100202 BtturrHnout Coal
Affected 10100601 Natural Gat
021
Affected 10100202 Biturrtnout Coal
Affected 10100601 Natural Oat
Batellne 071 20100901 Kerotene/Naphtha
Baseline 072 20100901 Kerosene/Naphtha
Baseline 073 20100901 Kerotene/Naprrtha
Batellne 074 20100901 Kerotene/Naphtfia
Batellne 075 20100901 Kerotene/Naphtha
Batellne 076 20100901 Kerotene/Naphtha
Batellne 077 20100901 Kerotene/Naphtha
Batellne 070 20100901 Kerotene/Naphtha
Final OTC NOx Baseline Inventory
New Jersey
5-Month Heat Content Slate Emission
Activity (10x6 Btu/ Heat Input Factor/Code Con.
Fac/Code Fuel Ute/Wnltt SCO Unit) (10x6 Btu) (Ibs/SCC Unit) En.
• Severe
3,000
0.380 1 222.101.3 Tons
0.583 1 763.0 10x6CuFt
3.000
0.295 172.664.6 Tont

288
288
288
288
288
288
288
288
0.438 435.0 10x6CuF1
0.646 62.4 1000 Gal
0.646 62.4 1000 Gal
0.646 62.4 1000 Gal
0.846 82.4 1000 Gal
0.846 82.4 1000 Gal
0.646 82.4 1000 Gal
0.846 82.4 1000 Gal
0.846 82.4 1000 Gal
27.36
1.030.60
27.36
1.030.80
141.33
141.33
141.33
141.33
141.33
141.33
141.33
141.33
6,076.692
607.116
4.729.575
448.398
11.646
11.646
11.646
11,646
11,646
11,646
11.646
11.646
49.2 Mul Stk Non-1990
*•*.* State Factor
49.2 Mul Stk Non-1990
•".• State Factor
127.2 Mul Stk Non-1990
127.2 Mul Stk Non-1990
127.2 Mul Stk Non-1990
127.2 Mul Stk Non-1990
127.2 Mul Stk Non-1990
127.2 Mul Stk Non-1990
127.2 Mul Stk Non-1 990
127.2 Mul Stk Non-1990
Baseline
Five Emission Rate
Month flbs/10x6Btu)
10,432*4
S.89$.4
5.469.0
427.4
4.494.1
4.256.6
237.4
S.2
63
5*
S3
S3
S3
63
S3
1.717
1.741
1.756

0.900
0.900
0.900
0.900
0.900
0.900
0.900
0.900
29
06/26/95
Target (Point Level)
PACT Phase II Phase III
6,0495
3.44 1.9
2.589.0

2.3
2.3
2.3
2.3
2.3
2.3
2.3
2.3
3,655.3
2.063.7
1,572.9

2.3
2.3
2.3
2.3
2.3
2.3
2.3
2.3
2,616.2
1.474.1
1.123.5

2.3
2.3
2.3
2.3
2.3
2.3
2.3
2.3
023 Middlesex Co - Inner Zone - Severe
0006 JCP&L - WERNER GE
067
Affected 10100401 Residual Oil
Affected 10100501 Distillate OH
Batellne 091 20100101 Distillate OH
Batellne 101 20100101 DlttfllateOH
Batellne 111 20100101 Collate Oil
Batellne 121 20100101 Distillate OH
0007 JCP&L -SAYERVILLE
091
Affected 10100401 Residual Oil
Affected 10100501 Distillate Oil
Affected 10100601 Natural Oat
092
Affected 10100401 Residual Oil
Affected 10100501 Distillate Oil
Affected 10100601 Natural Oat
101
Affected 10100401 RetldualOII
Affected 10100501 CHttHlateOH
Affected 10100601 Natural Oat
111
Affected 10100401 RetldualOII
Affected 10100501 WstfflateOH
Affected 10100601 Natural Oat
121
Batellne 20100101 DfttfflateOII
Baseline 20100201 Natural Oat

650


830
830
830
830

490



490



1,150



1.1 SO



830




0.926 2.756.1 1000 Gal
0.266 34.8 1000 Gal
0.639 357.5 1000 Gal
0.639 357.5 1000 Gal
0.639 357.5 1000 Gal
0.639 357.5 1000 Gal


0.436
0.667
0.623

0.436
0.667
0.823

0.637
0.695
0.673

0.395
0.532
0.741

0.219
0.640
10.1 1000 Gal
6.6 1000 Gal
39.3 10x6Cuf=t

37.0 1000 Gal
24.1 1000 Oal
157.3 10x6CuFt

3,561.5 1000 Gal
8.9 1000 Gal
629.4 10x6CuFt

4.271.3 1000 Gal
10.2 1000 Gal
1.001.3 10x6CuFt

11.3 1000 Gal
184.6 10x6CuFt


150.00
140.11
139.98
139.98
139.98
139.98


150.69
140.15
1,050.89

150.19
140.12
1.050.22

150.00
139.44
1.049.92

150.00
139.31
1.050.01

139.73
1.050.06


413.721
4,876
50.044
50.044
50.044
50.044


1.522
925
41,300

5,557
3.377
165,199

534,219
1,241
660,822

640,697
1.421
1,051.379

1,579
193,841


73.5 Mul Stk Non-1990
20.1 AP-42
106.4 Mul Stk Non-1990
106.4 Mul Stk Non-1 990
106.4 Mul Stk Non-1990
106.4 Mul Stk Non-1 990


674 AP-42
24.2 State Factor
178.6 Mul Stk Non-1990

67.0 AP-42
24.1 State Factor
178.5 Mul Stk Non-1990

51.0 Mul Stk Non-1990
20.2 AP-42
630.0 Mul Stk Non-1990

51.0 Mul Stk Non-1990
19.6 AP-42
630.0 Mul Stk Non-1990

106.2 Mul Stk Non-1990
378.0 Mul Stk Non-1 990
177.8
101.7
101.4
0.4
19.0
19.0
19.0
19.0
675.1
3.9
0.3
0.1
3.5
15.6
\2
0.3
14.0
289.2
90.8
0.1
198.3
424.4
106.9
0.1
315.4
35.5
0.6
34.9
0.573
0.476


0.760
0.760
0.760
0.760
0.450
area



0.186



0.480



0.461



0.369


98.3
50.3


10.0
10.0
10.0
10.0
433.6
3.0



T5.I



141.0



194.9



19.7


81.9
41.9


10.0
10.0
10.0
10.0
386.7
3.0



J5.1



119.6



169.3



19.7


7M
3J.4


10.0
10.0
10.0
10.0
311.9
3.3



13.1



89.7



127.0



19.7



-------
Detail Report - Five Month Data
Point-Segment Level Data
Design 5-Month
Plant Capacity Activity
Affected Point SCC/Dmcrtotlon (10x6Btu/hr) Fac/Code
023 Middlesex Co - Inner Zone - Severe
0007 JCP&L - S AVER VILLE
141 850
Baseline 20100101 Distillate Oil 0.219
Baseline 20100201 Natural Gas 0.640
151 830
Baseline 20100101 Distillate Oil 0.219
Baseline 20100201 Natural Gas 0.640
161 830
Baseline 20100101 Distillate Oil 0.219
Baseline 20100201 Natural Gas 0.640
0008 PSE&G - SEAWAREN
Oil 1,215
Affected 10100404 Residual Oil 0.104 1
Affected 10100604 Natural Gas 0.642 1
021 1,118
Affected 10100404 Residual Oil 0.112 1
Affected 10100604 Natural Gas 0.607 1
031 1,135
Affected 10100404 Residual Oil 0.199 1
Affected 10100604 Natural Gas 0.656 t
041 1,328
Affected 10100404 Residual Oil 0.216 1
Affected 10100604 Natural Gas
Baseline 121 20100901 Kerosene/Naphtha
Baseline 131 20100901 Kerosene/Naphtha
Baseline 141 20100901 Kerosene/Naphtha
Baseline 151 20100901 Kerosene/Naphtha
Baseline 161 20100901 Kerosene/Naphtha
Baseline 171 20100901 Kerosene/Naphtha
Baseline 181 20100901 Kerosene/Naphtha
Baseline 191 20100901 Kerosene/Naphtha
0023 CHEVRON U.S.A., INC.
Affected 012 10200401 Residual Oil
0908 PSE&G -EDISON
Oil
Baseline 20100201 Natural Gas
Baseline 20100901 Kerosene/Naphtha
021
Baseline 20100201 Natural Gas
Baseline 20100901 Kerosene/Naphtha
031
Baseline 20100201 Natural Gas
Baseline 20100901 Kerosene/Naphtha
041
Baseline 20100201 Natural Gas

269
288
288
288
288
288
368
368

257

377


377


377


377

0.623 1
0.668
0.668
0.668
0.668
0.668
0.668
0.668
0.668

0.417 3


0.217
0.479

0.217
0.479

0.217
0.479

0.217 1
Final OTC NOx Baseline Inventory
New Jersey
Heat Content State Emission
(10x6 Btu/ Heat Input Factor/Code Con.
Fuel Use/Units ?CCUnll) (10x6 Btu) Obs/SCC Unit) Eff,
11.3 1000 Gal
184.6 10x6CuFt
11.3 1000 Gal
164.6 10x6CuFt
11.3 1000 Gal
164.6 10x6CuFt
214.1 1000 Gal
72S.4 lOxfiCuFt
333.2 1000 Gal
1.006.2 10x6CuFt
263.5 1000 Gal
915.5 10x6CuFt
531.0 1000 Gal
1.373.4
74.8
74.8
74.8
74.8
74.8
74.8
74.8
74.8

1,143.0


0.4
20.6

0.4
206

0.4
20.6

0.4
10x6CuFt
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal

1000 Gal


10x6CuFt
1000 Gal

10x6CuFt
1000 Gal

10x6 Cu Ft
1000 Gal

10x6CuFt
139.73
1.050.06
139.73
1.050.06
139.73
1.050.06
147.09
1.031.82
147.11
1.031.73
147.11
1,031.74
147.13
1.031.78
134.41
134.41
134.41
134.41
134.41
134.41
134.41
134.41

150.00


99750
137.72

997.50
137.72

997.50
137.72

997.50
1.579
193.641
1.579
193.641
1.579
193.641
31.492
748,481
49,016
1,040,194
41,705
944,559
78.125
1,417.040
10.054
10,054
10,054
10.054
10,054
10.054
10.054
10.054
,
171.450


399
2.837

399
2.837

399
2.837

399
106.2
378.0
106.2
378.0
106.2
378.0
42.7
206.4
42.7
206.3
42.7
206.4
42.7
206.3
120.9
120.9
120.9
120.9
120.9
120.9
120.9
120.9

105.0


500.0
124.3

500.0
124.3

500.0
124.3

500.0
Mul Stk Non-1990
Mul Stk Non-1990
Mul Stk Non-1990
Mul Stk Non-1990
Mul Stk Non-1990
Mul Stk Non-1990
Mul Stk Non-1990
Mul Stk Non-1990
Mul Stk Non-1990
Mul Stk Non-1990
Mul Stk Non-1 990
Mul Stk Non-1990
Mul Stk Non-1 990
Mul Stk Non-1990
Mul Stk Non-1 990
Mul Stk Non-1 990
Mul Stk Non-1990
Mul Stk Non-1990
Mul Stk Non-1990
Mul Stk Non-1 990
Mul Stk Non-1990
Mul Stk Non-1 990

State Factor


Mul Stk Non-1990
Mul S* Non-1990

Mut Stk Non-1990
Mul Stk Non-1990

Mul Stk Non-1990
Mul Stk Non-1 990

Mul Stk Non-1 990
Bsseflne
Five Emission Rat*
Month (Ibs/10x6 Btu)
875.1
35.S
0.6
34.9
35.S
0.6
34.9
35.5
0.6
34.9
4M.2
79.4
4.6
74.8
111.1
7.1
104.0
100.5
6.1
94.5
153.0
11.3
141.7
4.5
4.5
4.S
4.5
4.5
4.5
4.5
4.S
60.0
00.0
35.6
1.4
0.1
1.3
r.<
0.1
1.3
1.4
0.1
1.3
1.4
0.1
0450
0.369
0.369
0.369
0.217
0.219
0.218
0*11
0*12

0.900
0.900
0.900
0.900
0.900
0.900
0.900
0.900
0.700
0.700
0.878
0.005


0.005


0.005


0.005

Target
30
06/26/95
[Point Level)
RACT Phssell PhSSeiH
433.6
19.7
19.7
19.7
451.1
70.0
10B.9
90.fi
149.5

2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
244)
24.0
15.7
0.6


0.6


0.6


0.6

386.7
19.7
19.7
19.7
451.1
70.0
108.9
98.6
149.5

2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
21 JO
21.0
15.7
0.6


0.6


0.6


0.6

311.0
19.7
19.7
19.7
3424
50.5
81.7
74.0
112.1

2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
1S.O
J5.0
15.7
0.6


0.6


0.6


0.6


-------
Detail Report - Five Month Data
Point-Segment Level Data
Plant
Affected Point SCC/Descrlotlon
Design
Capacity
(10x6Btu/hr)
5-Month
Activity
Fac/Code
Final OTC NOx Baseline In
New Jersey
Heat Content
(10x6 Btu/ Heat Input
Fuel Use/Units SCO Unit) (10x6 Btu)
ventory
State Emission
Factor/Code Con.
(Ibs/SCC Unit) EH.

Five
Month
Baseline
Emission Rate
flbs/10x6 Btu)
023 Middlesex Co - Inner Zone - Severe
0908 PSE&G- EDISON
04?
Baseline 20100901 Kerosene/Naphtha
051
Baseline 20100201 Natural Oat
Baseline 20100901 Kerosene/Naphtha
06?
Baseline 20100201 Natural Gas
Baseline 20100901 Kerosene/Naphtha
071
Baseline 20100201 Natural Gas
Baseline 20100901 Kerosene/Naphtha
081
Baseline 20100201 Natural Gas
Baseline 20100901 Kerosene/Naphtha
091
Baseline 20100201 Natural Gas
Baseline 20100901 Kerosene/Naphtha
ro>
Baseline 20100201 Natural Gat
Baseline 20100901 Kerosene/Naphtha
111
Baseline 20100201 Natural Gas
Baseline 20100901 Kerosene/Naphtha
121
Baseline 20100201 Natural Gas
Baseline 20100901 Kerosene/Naphtha
131
Baseline 20100201 Natural Gas
Baseline 20100901 Kerosene/Naphtha
141
Baseline 20100201 Natural Gas
Baseline 20100901 Kerosene/Naphtha
151
Baseline 20100201 Natural Gas
Baseline 20100901 KereMrw/Naphtha
161
Baseline 20100201 Natural Gas
Baseline 20100901 Kerosene/Naphtha
171
Baseline 20100201 Natural Gas
Baseline 20100901 Kerosene/Naphtha
181
Baseline 20100201 Natural Gas
Baseline 20100901 Kerosene/Naphtha
191
Baseline 20100201 Natural Gas
Baseline 20100901 Kerosene/Naphtha
201
Baseline 20100201 Natural Gas

405

377


377


377


377


377


377


377


377


377


377


377


377


377


377


377


377



0.479 1

0.217 1
0.479 1

0.217 1
0.479 1

0517 1
0.479 1

0517 1
0.479 1

0.159 1
0.816 1

0.159 1
0.816 1

0.159 1
0.816 1

0.159 1
0.816 1

0.159 1
0.816 1

0.159 1
0.816 1

0.159 1
0.816 1

0.159 1
0.818 1

0.383 1
0.728 1

0.383 1
0.728 1

0.383 1
0.726 1

0.383 1


20.6

0.4
20.6

0.4
20.6

0.4
20.6

0.4
20.6

0.1
29.3

0.1
29.3

0.1
29.3

0.1
29.3

0.1
29.3

0.1
29.3

0.1
29.3

0.1
29.3

0.2
195

0.2
19.2

0.2
19.2

0.1


1000 Gal 137.72

10x6CuFt 997.50
1000 Gal 137.72

10x6CuFt 997.50
1000 Gal 137.72

10x6CuFt 997.50
1000 Gal 137.72

10x6CuFt 997.50
1000 Gal 137.72

10x6 Cu Ft 620.00
1000 Gal 138.02

10x6CuFt 620.00
1000 Gal 138.02

10x6CuFt 620.00
1000 Gal 138.02

10x6CuFt 620.00
1000 Gal 138.02

10x6CuFt 620.00
1000 Gal 138.02

10x6CuFt 620.00
1000 Gal 138.02

10x6CuFt 620.00
1000 Gal 138.02

10x6CuFt 620.00
1000 Gal 138.02

10x6CuFt 785.00
1000 Gal 137.81

10x6CuFt 785.00
1000 Gal 137.81

10x6CuFt 765.00
1000 Gal 137.81

10x6CuFt 1,530.00


2,837

399
2,837

399
2,837

399
2,837

399
2,837

62
4.044

62
4,044

62
4,044

62
4,044

62
4,044

62
4.044

62
4.044

62
4.044

153
2.646

153
2.648

153
2.646

153


124.3 MulSlk Non-1 990

500.0 MulStk Non-1 990
124.3 MulStk Non-1 990

500.0 MulSlk Non-1990
124.3 MulStk Non-1 990

500.0 MulStk Non-1990
124.3 Mul Stk Non-1990

500.0 Mul Stk Non-1 990
124.3 Mul Stk Non-1 990

400.0 Mul Stk Non-1 990
1245 Mul Stk Non-1 990

400.0 Mul Stk Non-1990
1245 Mul Stk Non-1 990

400.0 Mul Stk Non-1 990
124.2 MulSlk Non-1 990

400.0 Mul Stk Non-1 990
1245 Mul Stk Non-1 990

400.0 Mul Stk Non-1 990
1245 MulStk Non-1 990

400.0 Mul Stk Non-1 990
124.2 Mul Stk Non-1990

400.0 Mul Stk Non-1990
1245 Mul Stk Non-1 990

400.0 Mul Stk Non-1 990
1245 MulSlk Non-1 990

400.0 Mul Stk Non-1990
124.0 Mul Stk Non-1 990

400.0 MulStk Non-1 990
124.0 Mul Stk Non-1 990

400.0 Mul Stk Non-1990
124.0 Mul Stk Non-1 990

800.0 Mul Stk Non-1990
35.6
1.4
1.3
1.4
0.1
1.3
1.4
0.1
1.3
1.4
0.1
1.3
1.4
0.1
1.3
1.8
0.0
1.8
1.8
0.0
1.8
1.8
0.0
1.8
1.8
0.0
1.8
1.8
0.0
1.8
1.8
0.0
1.8
1.8
0.0
14
1.8
0.0
1.8
W
0.0
15
13
0.0
15
1.2
0.0
15
1.2
0.0
0.878
0.505

0.805


0.805


0.005


0.005


O.fl7t


0.871


0.871


0.871


0.871


0.871


0.871


0.871


0.861


0.861


0.861


0.861

31
06/26/95
Target (Point Level)
RACT

15.7
0.0

0.6


0.6


0.6


0.6


0.8


0.8


0.8


0.8


0.8


0.8


0.8


0.8


0.5


0.5


0.5


0.5

Phase II

15.7
0.6

0.6


0.6


0.6


0.6


0.8


0.8


0.8


0.8


0.8


0.8


0.8


0.8


0.5


0.5


0.5


0.5

Phase III

15.7
0.0

0.6


0.6


0.6


0.6


0.8


0.8


0.8


0.8


0.8


0.8


0.8


0.8


0.5


0.5


0.5


0.5


-------
Detail Report - Five Month Data
Point-Segment Level Data
Design
Plant Capacity
A fleeted Point SCC/DMcrtDtlon (10x6Btu/hr)
9-Month
Activity
Fee/Code
023 Middlesex Co - Inner Zone - Severe
0908 PSE&G- EDISON
201 405
Baseline 20100901 Kerosene/Naphtha 0.726 1
21 t 377
Baseline 20100201 Natural Gas 0.383 1
Batelfne 20100901 Kerosene/Naphtha 0.726 1
22t 377
BMeline 20100201 Natural Ga* 0.383 1
Baseline 20100901 Kerosene/Naphtha 0.726 1
231 377
Baseline 20100201 Natural Gas 0.383 1
Baseline 20100901 Kerosene/Naphtha 0.726 1
247 377
Baseline 20100201 Natural Gas 0.383 1
Baseline 20100901 Kerosene/Naphtha 0.726 1
029 Ocean Co - Inner Zone - Severe
0001 CIBA GEIGY CORPORATION
S71 259
Affected 10200401 Residual Oil 0.417 3
Affected 10200601 Natural Gas 0.416 3
0007 AC ELEC CO - CEDAR STA
Baseline 021 20100901 Kerosene/Naphtha
Baseline 031 20100901 Kerosene/Naphtha
Baseline 041 20100901 Kerosene/Naphtha
0255 JCP&L- FORKED RIVER
011
Baseline 20100101 Distillate Oil
Baseline 20100201 Natural Gas
021
Baseline 20100101 DtoWtote OK
Baseline 20100201 Natural Gas
033 Salem Co - Inner Zone -
0001 AC ELEC CO - DEEPWATER
011
Affected 10100401 ReatdualOil
Affected 10100601 Natural Gas
Affected 031 10100401 Residual Oil
Affected 032 10100401 Residual Oil
041
Affected 10100202 Bituminous Coal
Baseline 20100102 Distillate Oil

363
363
363

450


450


Severe

828


426
314
659



0.657 1
0.870 1
0/471 1


0.782 1
0.385 1

0.782 1
0.385 1



0.361
0.518
0.282
0.262

0.273
0.434
Final OTC NOx Baseline Inventory
New Jersey
Heat Content State Emission
Bl

(10x6 Btu/ Heat Input Factor/Code Con. Five Emission RaM
Fuel Use/Units SCCUnlt) (10x6 Blu) flb»/SCeUnH» Elf. Month (lba/10x6Btu)
19.2 1000 Gal
0.2 10x6CuR
19.2 1000 Gal
0.2 10x6CuR
19.2 1000 Gal
0.2 10x6CuFt
19.2 1000 Gal
0.2 10x6CuFt
19.2 1000 Gal
483.5 1000 Gal
152.0 10x6CuFt

115.3
115.3
188.9


413.4
32.0

413.4
32.0



2.254.2
807.8
773.7
773.7

27.425.8
930.1

1000 Gal
1000 Gal
1000 Gal


1000 Gal
10x6 CuFt

1000 Gal
10x6 CuFt



1000 Gal
10x6 CuFt
1000 Gal
1000 Gal

Tons
1000 Gal
137.81
765.00
137.81
765.00
137.81
765.00
137.81
765.00
137.81
150.00
1,050.00

133.45
133.45
133.62


140.00
1.048.72

140.00
1.048.72



146.29
1.040.49
147.92
147.92

25.14
14621
2.646
153
2.646
153
2.646
153
2.646
153
2.646
72,525
159,600

15.387
15.387
25.240


57.876
33.559

57.876
33.559



334,282
840.508
114.444
114.444

689,485
137,847
124.0
400.0
124.0
400.0
124.0
380.0
124.0
400.0
124.0
57.7
550.3

66.6
66.6
66.7


27.3
136.3

27.3
136.3



66.1
5442
41.4
41.4

20.3
415
MulS* Non-1990
MuiStk Non-1990
MulStk Non-1 990
Mul StK Non-1990
MulStk Non-1 990
MulStk Non-1 990
MulStk Non-1 990
Mul Stk Non-1990
MulStk Non-1990
State Factor
State Factor

State Factor
State Factor
State Factor










State Factor
State Factor
AP-42
AP-42

State Factor
State Factor
3S.6
1.2
12
1.2
0.0
12
1.2
0.0
12
1.2
0.0
12
1.2
0.0
12
SS.S
55.0
14.0
41.8
14.0
3.8
3.8
6.3
15.6
7.8
5.6
22
7.8
5.6
22

1,976*
294.3
74.5
219.8
16.0
16.0
297.5
2782
19.3
047*
0.861
0.861
0.861
0.861
0.861
0.481
0.479
0.499
0.500
0.500
0.500
0.171
0.162


0.162



0495
0.495


0280
0280
0.810



Target
32
06/26/95
(Point Level)
RACT Phase II pnaae ill
15.7
0.5
0.5
0.5
0.5
0.5
26.1
26.1
112
3.1
3.1
5.0
15.6
7.8


7.8



1,064.5
130.9


16.0
16.0
1SS.1


15.7
0.5
0.5
0.5
0.5
0.5
23.2
23.2
112
3.1
3.1
5.0
15.6
7.8


7.8



711.1
117.5


11.4
11.4
97.4


15.7
0.5
0.5
0.5
0.6
0.5
17.4
»7.4
112
3.1
3.1
5.0
15.6
7.8


7.8



518.7
88. 1


8.6
8.6
69.6



-------
Detail Report - Five Month Data
Point-Segment Level Data
Design
Plant Capacity
Affected Point SCC/Descriotlon 110x6 Btu/hr)
033 Salem Co - Inner Zone -
0001 ACELECCO-DEEPWATER
057
Affected 10100202 Bituminous Coal
Affected lOIOMOt Residual Oil
Affected 10100601 Natural Gas
061
Affected 10100202 Bituminous Coal
Affected 10100401 Residual CHI
Baseline 063 10100404 Residual Oil
Baseline 064 10100404 Residual Oil
091
Baseline 20100201 Natural Gas
0044 PSE&G- SALEM
Baseline 021 20100101 Distillate Oil
Baseline 031 20100101 Distillate Oil
039 Union Co - Inner Zone -
0011 PSE&G -LINDEN
011
Affected 10100401 Residual Oil
Affected 10100601 Natural Gas
021
Affected 10100401 Residual Oil
Affected 10100601 Natural Gas
031
Affected 10100401 Residual Oil
041
Affected 10100401 Residual Oil
Affected 10100601 Natural Gas
051
Affected 10100401 Residual Oil
Affected 10100601 Natural Gas
061
Affected 10100401 Residual Oil
Affected 10100601 Natural Gas
Baseline 071 20100201 Natural Gas
Baseline 081 20100201 Natural Gat
Baseline 091 20100201 Natural Gas
Baseline 101 20100201 Natural Gas
Baseline 111 20100201 Natural Gas
Baseline 121 20100901 Kerosene/Naphtha
Baseline 131 20100901 Kerosene/Naphtha
Baseline 141 20100901 Kerosene/Naphtha
Baseline 161 20100901 Kerosene/Naphtha
Baseline 161 20100901 Kerosene/Naphtha
Baseline 171 20100901 Kerosene/Naphtha
Severe
820
732

190
190
329


170
170
Severe

1,190


1.190


1.190

1.190


1J40


1.860


327
474
474
474
474
483
483
483
483
483
483
5-Month
ActMty
Fac/Code
0.451
0.290
0.000
0.403
0.186
0.452
0.452

0.655 1

0.587 1
0.531 1



0.451 1
0.621 1

0.509 1
0.981 1

0.1 14 1

0.832 1
0.684 1

0.832 1
0.684 1

0.350 1
0.090 1
0.665 1
0.612 1
0.704 1
0.526 1
0.875 1
0.364 1
0.384 1
0.384 1
0.364 1
0.384 1
0.384 1
Final OTC NOx Baseline In
New Jersey
Heat Content
(10x« Btu/ Heat Input
Fuel Use/Units SCO Unit) (10x6 Blu)
76.564.1
59.2
1.4
49.362.5
430.8
632.2
148.3

81.0

31.7
30.3



14,586.6
1.9

14.586.6
1.9

2,759.4

2,253.9
1.6

2.253.9
1.6

6.690.6
1.1
98.5
56.7
62.3
66.9
60.5
92.4
92.4
92.4
92.4
92.4
92.4
Tons
1000 Gal
10x6 CuFt
Tons
1000 Gal
1000 Gal
1000 Gal

10x6CuFt

1000 Gal
1000 Gal



1000 Gal
10x6CuFt

1000 Gal
10x6CuFt

1000 Gal

1000 Gal
10x6CuFt

1000 Gal
10x6 Cu Ft

1000 Gal
10x6 CuFt
10x6CuFt
10x6 CuFt
10x6 CuFt
10x6 CuFt
10x6 CuFt
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
25.26
148.31
1.040.00
25.30
148.63
148.26
148.25

1.042.41

136.97
136.93



147.40
1.030.00

147.40
1,030.00

147.38

147.38
1,033.13

147.38
1.033.13

147.38
1.030.00
1.032.18
1,031.82
1.032.34
1,031.41
1.032.64
138.57
138.57
138.57
138.57
138.57
138.57
1.934.009
8.780
1.467
1.248.870
64.031
93.732
21,986

84,435

4,342
4,149



2,150.065
1.957

2.150,065
1,957

406.683

332,177
1.653

332.177
1.653

986,067
1.133
101,670
58.504
64,315
69,001
62.475
12.804
12.804
12.804
12,804
12.804
12,804
ventory
State Emission
Factor/Code Con.
Obs/SCCUnin En.
20.4
55.7
471.4
20.4
41.6
100.8
100.9

448.1

123.0
123.4



88.4
547.4

88.4
547.4

88.4

100.2
550.0

1002
550.0

65.7
545.5
516.1
619.0
619.3
618.6
619.5
1662
1662
1662
1662
1662
1662
State Factor
Sing Stk Rep Cond
Sing Stk Rep Cond
State Factor
State Factor
AP-42
AP-42

AP-«2

Mul Stk Non-1990
Mul Stk Non-1 990



Mul Stk Non-1990
AP-42

Mul Stk Non-1 990
AP-42

Mul Stk Non-1990

Mul Stk Non-1990
AP-42

Mul Stk Non-1990
AP-42

Mul Stk Non-1 990
AP-42
Mul Stk Non-1990
Mul Stk Non-1990
Mul Stk Non-1 990
Mul Stk Non-1 990
Mul Stk Non-1 990
Mul Stk Non-1 990
Mul Stk Non-1990
Mul Stk Non-1 990
Mul Stk Non-1 990
Mul Stk Non-1 990
Mul Stk Non-1 990
Baseline
Five Emission Rate
Month (Ibs/10x6 Btu)
1.976.6
782.4
780.4
1.7
0.3
572.9
503.9
9.0
31.9
7.5
182
182
3.6
2.0
1.9

2,0232
645.5
645.0
0.5
645.5
645.0
0.5
722.0
122.0
773.4
112.9
0.4
113.4
112.9
0.4
220.2
219.9
0.3
26.4
• 7.5
79.3
20.7
18.7
7.7
7.7
7.7
7.7
7.7
7.7
0.69S
0.007
0.757

0.680
0.680
0.433

0.900
0.900
0.900

0.593
0.600


0.600


0.600

0.679


0.679


0.450


0.500
0.600
0.600
0.600
0.600
t.200
».200
f.200
7.200
T.200
1300
33
06/26/95
Target (Point Level)
RACT Phase II Phase ill
1,064.5
436.5
290.0

9.4
22
8.4

1.7
0.9
0.0

946.9
30J.2


30T.2


56.9

46.7


46.7


138.2


10.2
5.9
6.4
6.9
6.2
2.6
2.6
2.6
2.6
2.6
2.6
711.1
273.8
179.5

9.4
2.2
8.4

1.7
0.9
0.8

728.7
225.9


225.9


42.7

39.7


39.7


96.7


fO.2
5.9
6.4
6.9
6.2
26
2.6
2.6
2.6
2.6
2.6
518.7
795.6
1283

9.4
2JI
8.4

1.7
0.9
0.6

540.1
767.4


767.4


30.5

2fl.3


26.3


74.0


10.2
5.9
6.4
6.9
6.2
2.6
2.6
2.6
2.6
2.6
2.6

-------
Detail Report - Five Month Data
Point-Segment Level Data
Plant
Affected Point SCC/DescrlDtloo
039 Union Co - Inner Zone
0011 PSE&G- LINDEN
Baseline 181 20100901 Kerosene/Naphtha
Baseline 191 20100901 Kerosene/Naphtha
Design S-Month
Capacity Activity
(10x8 Btu/hr) Fac/Code
- Severe

483 0.384 1
403 0.364 1
Final OTC NOx Baseline Inventory
New Jersey
Heal Content State Emission Baseline


Fuel Use/Units


92.4
92.4


1000 Gal
1000 Gal
(10x6 Btu/
SCC Unit)


138.57
138.57
Heat Input
(10x6 Btu)


12.804
12.804
Factor/Code Con.
(Ibs/SCC Unit) Eff.


166.2 MulStk Non-1 990
166.2 MulStk Non-1 990
0052 BAYWAY REFINING COMPANY
Affected 031 10200701 Process Gas
101
Affected 10200401 Residual CXI
Affected 10200701 Process Gas
314 0.41S 1
341
0.419 1
0.398 1
283.3

1.200.0
808.3
10x6CuFt

1000 Gal
1 0x6 Cu Ft
1.200.00

150.00
1.200.00
340.000

160.000
970.000
696.1 AP-42

105.0 AP-42 '
696.0 AP-42
Five
Month

2.023.2
7.7
7.7
442.9
98.6
344.3
63.0
281.3
Emission Rate
(Iba/10x6 Btu)

0.593
1.200
1300
O.S94
0.500
0.590


34
06/26/95
Target (Point Level)
HACT

946.9
2.6
2.6
206.6
47.6
161.0


Phase II

728.7
2.6
2.6
15S.O
34.5
1ZO.S


Phase III

540.1
2.6
2.6
111.8
2S.S
86.3



-------
Detail Report - Five Month Data
Point-Segment Level Data
OMlgn 5-Month
Plant Capacity Activity
Affected Point SCC/Descrlntlon (10x6 Btu/hr) Fac/Code
001 Albany Co - Outer Zone - Marginal
0366 NIAGARA MOHAWK - ALBANY STATION
001 1.030
Affected 10100404 Residual Oil 0.344
Affected 10100^04 Natural Qu 0.496
00? 1.030
Affected 10100404 Residual Oil 0.239
Affected 10100604 Natural Gas 0.658
003 1,030
Affected 10100404 Residual CXI 0.303
Affected 10100604 Natural Gas 0.479
004 1.030
Affected 10100404 Residual Oil 0.489
Affected 10100604 Natural Gas 0.584
Baseline 02? 20100201 Natural Gas 2,104 0.457
007 Broome Co - Outer Zone - Attainment
0292 NYSEG - GOUDEY STATION
001 ' 1.417
Affected 10100202 Bituminous Coal 0.373 1
Affected 10100501 Distillate Oil 1.000 1
Final OTC NOx Baseline In
New York
Heat Content
(10x6 Btu/ Heat Input
Fuel Use/Units SCO Unit) (10x6 Btu)
2.856.0
2.065.1
5,263.0
2.011.0
3.599.0
2.059.0
4,965.0
2.147.0
155.4



138.847.0
62.4
1000 Gal
10x6CuFt
1000 Gal
IQxBCuR
1000 Gal
10x6CuFt
1000 Gal
10x6CuR
10x6CuFt



Tons
1000 Gal
151.00
1.037.00
151.00
1.037.00
151.00
1,037.00
151.00
1.037.00
1.030.00



25.70
139.00
431.256
2.162,249
794,713
2.085.407
543.449
2.135,183
752.735
2.226.439
160,062



3,568,368
11,454
ventory
State Emission
Factor/Code Con.
(Ibs/SCC Unit) EH.
42.3
228.1
42.3
228.1
42.3
228.1
42.3
228.1
462.0



20.7
34.7
Sing Stk Rep Cond
Sing StK Rep Good
Sing 8tk Rep Cond
Sing Stk Rep Cond
Sing Stk Rep Cond
Sing Stk Rep Cond
Sing Stk Rep Cond
Sing Stk Rep Cond
AP-42



Mul Stk Non-1 990
Mul Stk Non-1 990
Baseline
Five Emission Rate
Month (Iba/10x6 Btu)
1.336.0
290.2
60.4
237.9
340.7
111.3
229.4
311.0
76.1
234.9
3S0.3
105.4
244.9
3S.9

1.436.5
1.436.S
1.435.0
1.4
0.237
0.233
OJS1
0*37
0337

0.449

0.803
0.004


35
06/26/95
Target (Point Level)
RACT
1,282.3
291.8
328.7
302.8
339.0

20.0

804.3
004.3


Phase II
1.133.2
2S9.4
288.0
267.9
297.9

20.0

646.4
646.4


Phase III
854.9
194.5
216.0
200.9
223.4

20.0

350.1
359.1


013 Chautauqua Co - Outer Zone - Attainment
0325 NIAGARA MOHAWK - DUNKIRK STATION
001 896
Affected 10100212 Bituminous Coal 0.358 1
Affected 10100501 Distillate Oil 1.000 t
002 696
Affected 10100212 Bituminous Coal 0.562 1
Affected 10100501 Distillate Oil 1.000 1
009 3.584
Affected 10100212 Bituminous Coal 0.415 1
Affected 10100501 Distillate Oil 1.000 1
0340 S A CARLSON
003 190
Baseline 10100212 Bituminous Coal 0.443 1
004 190
Baseline 10100212 Bituminous Coal 0.445 1
005 297
Affected 10100212 Bituminous Coal 0.445 1


88,100.0
10.3.

107.400.0
26.4

422.900.0
149.8


17.900.0

17.100.0

18.300.0


Tons
1000 Gal

Tons
1000 Gal

Tons
1000 Gal


Tons

Tons

Tons


26.40
138.00

28.40
141.00

26.30
141.00


25.00

25.00

25.00


2,325,840
5,824

2,835.360
3,722

11.122.270
21,122


447,500

427.500

457,500


11.9
19.4

11.9
19.7

14.5
19.8


26.2

15.0

20.7


Non-1 990 Other CEMS
Non-1 990 Other CEMS

Non-1 990 Other CEMS
Non-1 990 Other CEMS

Non-1 990 Other CEMS
Non-1 990 Other CEMS


Mut Stk Non-1990

Mut Stk Non-1 990

Mul Stk Non-1 990
4,222.0
523.7
523.3
0.4
638.2
638.0
0.3
3.060.1
3.058.6
1.5
551.7
234.5
234.5
128.3
128.3
189.0
189.0
0.518
0.450


0.450


0.550


0428
1.048

0.600

0.826

3,421.7
488.8


595.7


2.337.2


M745
134.3

128.3

135.0

1.899.9
235.7


287.2


1.377.0


347.5
134.3

128.3

85.0

1.223.6
»74.9


212.9


835.8


309.7
134.3

128.3

47.2

017 Chenango Co - Outer Zone - Attainment
0083 NYSEG - JENNISON STATION
Affected 001 10100205 Bituminous Coal 509 0.426 1

51,730.0

Tons

20.50

1,060.465

6.2

Mul Stk Non-1 990
390.0
212.1
0.400
0.400
292.5
159.1
195.0
106.0
146.2
79.5

-------
Detail Report - Five Month Data
Point-Segment Level Data
DMlgn 5-Month
Plant Capacity Activity
Affected Point SCC/DescrlDtkM MOxBBtu/nr) Fee/Code
Final OTC NOx Baseline Inventory
New York
Heat Content State Emission
(10x6 Btu/ Heat Input Factor/Code Con.
Fuel Use/Units SCO Unit) (10x6 Btu) flbs/SCC Unit) EH.

Five
Month
ilaaa lfc»«
BBMIwlV
Emission Rat*
nbm/10x6 Btu)
017 Chenango Co - Outer Zone - Attainment
0083 NYSEG - JENNISON STATION
Affected 002 10100205 Bituminous Coal 564 0.333 1
029 Erie Co - Outer Zone - Marginal
0133 YERKES ENERGY
004 432
Baseline 20100101 Distillate OH 0.417 1
Baseline 20100201 Natural Gas 0.417 1
0161 BETHENERGY LACK COKE
Affected 018 10200601 Natural Gat 422 0.417 1
0163 BSC BAR PRODUCTS DIV
Affected 00? 10200601 Natural Gas 590 0.417 1
1700 NIAGARA MOHAWK - C R HUNTLEY STEAM ST
004 3.532
Affected 10100201 Bituminous Coal 0.411 1
Affected 10100501 Distillate Oil 1.000 1
005 3,552
Affected 10100212 Bituminous Coal 0.421 1
Affected 10100501 Distillate OH 1.000 1
031 Essex Co - Northern Zone - Attainment
0105 TICONDEROGA MILL
Affected 076 10200401 Residual Oil 522 0.420 1
045 Jefferson Co - Outer Zone - Marginal
0255 FORT DRUM HTW COGEN
001 esi
Affected 10300101 Anthracite Coal 0.417 3
Affected 10300217 Bituminous Coal 0.417 3
Affected 10300501 Distillate On 0.417 3
047 Kings Co - Inner Zone - Severe
CE01 CON ED - HUDSON AVE GEN STA
Affected 001 10100401 Residual Oil 4.635 0.324 1
Affected 002 10100401 Residual Oil 2,168 0.425 1
Baseline OZZ 20100101 Distillate Oil 1.146 0.624 1

42,968.0



120.1
1,283.9

139.7

334.0


391.700.0
29.6

409,400.0
146.0


10,483.2



5,561.7
49,372.5
505.8


5,528.2
24,276.0
400

Tons



1000 Gal
10x6 Cu Ft

10x6CuFt

10x6 Cu Ft


Tons
1000 Gal

Tons
1000 Gat


1000 Gal



Tons
Tons
1000 Gal


1000 Gal
1000 Gal
1000 Gal

20.70



139.00
1.005.00

1,008.00

1.008.00


26.20
138.00

25.70
138.00


148.00



24.00
26.00
135.00


146.00
148.00
137.00

889,438



16.694
1,290.320

140.818

336.672


10,262,540
4,085

10,521.580
20.148


1.551.514



133,961
1,283,685
68,283


818.174
3.592,848
5.480

6.3



97.7
462.0

549.2

549.3


33.8
19.6

14.4
19.3


54.8



6.7
4.0
13.5


53.9
52.8
71.0

Mul Slk Non-1 990



AP-42
AP-42

AP-42

AP-42


AP-42
AP-42

AP-42
AP-42


Mul Stk Non-1990



Non-1 990 Other OEMS
Non-1990 Other GEMS
Non-1990 Other CEMS


Sing Stk Max Load
Sing Stk Max Load
Sing Stk Max Load
390.0
177.9

3024
302.4
5.9
296.6
384
30.4
91.7
91.7
9,568.7
6.619.6
6.619.3
0.3
2.949.1
2.947.7
1.4

287.0
287.0

118.8
118.8
15.9
99.5
3.4

7»M
149.0
641.0
1.4
0400
0.400

0463
0.463


0.548
0.545
0548
0.545
0.920
1.290


0.550



0470
0.370

0.160
O.T60




0458
0.364
0.357
0.510


36
06/26/95
Target (Point Level)
RACT

292.5
133.4

130.7
130.7


14.1
14.1
33.7
33.7
7,3424
5,131.6


2.210.9



193.9
193.9

11M
118.8




552.5
(02.3
449.?
1.1
phase II

195.0
60.9

130.7
130.7


14.1
14.1
33.7
33.7
4.305.9
2.978.8


1.327.1



193.9
T93.9

1184
118.8




4422
81.8
359.3
1.1
Phase III

1462
66.7

130.7
130.7


10.6
10.6
254
25.3
2,4454
1.654.9


790.6



155.2
155.2

111.4
111.4




331.8
61.4
269.5
1.1

-------
Detail Report - Five Month Data
Point-Segment Level Data
Design
Plant Capacity
Affected Point SCC/DeacrlDtlon MOx6Btu/hr)
5-Month
Activity
Fac/Code
Final ore NOx Baseline in
New York
Heat Content
(10x6 Btu/ Heat Input
Fuel Use/Units SCO Unit) (10x6 Btu)
ventory
Slate Emission
Factor/Coda Con.
(Ibs/SCC Unit) EN.
Baaatlne
37
06/26/95
Five Emission Rate Target (Point Level)
Month (Iba/10x6 Blu)
047 Kings Co - Inner Zone - Severe
GGEN CON ED - GOWANUS GEN
Baseline OZZ 20100101 Distillate OH
NGEN CON ED - NARROWS GEN
OZZ
Baseline 20100101 Diatfflate Oil
Baaallna 20100201 Natural Gaa
055 Monroe Co - Outer Zone
0258 KODAK PARK DIV
Affected 001 10200204 Bituminoua Coal
002
Affected 10200203 Bituminoua Coal
Affected 10200401 Residual Oil
003
Affected 10200203 Bituminoua Coal
Affected 10200401 ReeMualOII
004
Affected 10200203 BNurrtnoua Coal
Affected 10200212 Bituminoua Coal
Affected 10200401 RealdualOII
Affected 10200501 Distillate Oil
1 1 52 RG&E - BEEBEE STATION
007
Affected 10100202 Bituminoua Coal
Affected 10100501 Distillate OH
1752 RG&E - RUSSELL STATION
oo>
Affected 10100212 Bituminoua Coal
Affected 10100501 Distillate OH
00?
Affected 10100212 Bituminous Coal
Affected 10100501 Distillate OH
059 Nassau Co - Inner Zone
3152 LILCO - E F BARRETT
001
Affected 10100404 Residual Oil
Affected 10100604 Natural Gaa
002
Affected 10100404 RealdualOII
Affected 10100604 Natural Gaa

9,568

4,752



0.372 1


0.121 1
0.360 1

1,591.6


155.7
506.0

1000 Gal


1000 Gal
10x6CuFt

137.00


137.00
1.033.00

218.049


21,331
522,698

101.4


101.3
423.5
60.7
80.7
115.0
115.0
7.9
107 2
0.740
0.740
0423
0.447


RACT

43.6
43.6
108.8
108.8


Phase II

43.6
43.6
108.8
106.8


Phase III

43.6
43.6
1084
108.8


- Attainment

908
895


1.000


1,310





804



1.260


1.490



0.476 1

0.010
0.540

0.460
0.134

0.479
0.392
0.131
0.159


0.361 1
0.333 1


0.402 1
0.532 1

0.453 1
0.431 1

49,465.9

653.0
4,072.0

122.359.2
61.4

61.434.6
51,797.8
40.0
17.5


69.400.0
12.6


97.500.0
105.0

151.300.0
50.4

Tons

Tons
1000 Gal

Tons
1000 Gal

Tons
Tons
1000 Gal
1000 Gal


Tons
1000 Gal


Tons
1000 Gal

Tons
1000 Gal

27.00

27.00
150.00

27.00
150.00

27.00
27.00
150.00
139.00


26.30
136.00


26.00
136.00

26.00
136.00

1,335,579

17,631
610.600

3.303,698
9,210

2,198,734
1.398.541
6,000
2,433


1,825.220
1,739


2.535,000
14,490

3,933,800
6,955

12.7 MulStk Non-1 990

33.8 MulStk Non-1 990
75.0 MulStk Non-1990

32.4 MulStk Non-1 990
134.9 MulStk Non-1990

37.0 MulStk Non-1990
18.9 MulStk Non-1990
135.0 MulStk Non-1990
34.3 MulStk Non-1 990


12,9 MulStk Non-1 990
17.5 MulStk Non-1 990


13.7 MulStk Non-1990
16.0 Mul Stk Non-1990

13.4 Mul Stk Non-1 990
33.7 Mul Stk Non-1 990
4,462.6
313.9
163.7
11.0
152.7
1.986.4
1,962.2
4.1
1.996.6
1.508.1
489.5
2.7
0.3
4474
447.3
4472
0.1
1,681.0
668.0
667.2
0.6
1.013.0
1.01&2
0.9
1.005
0.470
0.959


7.T97


1.07B




0490
0.490


0.518
0.525


0.5)4


2,239.5
200.3
129.8


993.9


915.5




3834
383.4


1,360.1
533.2


826.9


2.008.2
141.2
73.7


893.9


899.4




2014
201.3


756.5
300.6


455.9


1,1434
1002
47.1


496.6


499.7




137.0
J37.0


486.8
1912


295.6


- Severe

1.71B


1.715




0.129 1
0.551 1

0.048 1
0.557 1


822.2
5,460.2

763.7
5,557.0


1000 Gal
10x6CuFt

1000 Gal
10x6CuFt


150.00
1.030.00

150.00
1,030.00


123,330
5,644.606

114,555
5.723,710


52.5 Mul Stk Non-1990
298.7 Mul Stk Non-1 990

52.5 Mul Stk Non-1 990
298.7 Mul Stk Non-1 990
1,0214
840.1
21.6
818.5
850.0
20.1
829.9
0405
0.295


0.30»


1,639.2
72T.O


729.8


1449.1
576.6


583.8


1,058.9
432.6


437.9



-------
Detail Report - Five Month Data
Point-Segment Level Data
DMlgn
Plant Capacity
Affected Point SCC/Descrtotton 	 (lp»8 Btu/hr)
059 Nassau Co - Inner Zone
3152 LILCO - E F BARRETT
004
Baseline 20100101 Distillate Oil
Baseline 20100201 Natural Gas
005
BaMllrw 20100101 Distillate OH
Baseline 20100201 Natural Oa*
006
Baseline 20100101 Distillate Ofl
Baseline 20100201 Natural Qas
007
Baseline 20100101 Distillate OH
Baseline 20100201 Natural Gas
009
Baseline 20100101 Distillate Oil
Baseline 20100201 Natural Qas
009
Baseline 20100101 Distillate OK
Baseline 20100201 Natural Gas
OOA
Baseline 20100101 Distillate Oil
Baseline 20100201 Natural Gas
008
Baseline 20100101 Distillate Oil
Baseline 20100201 Natural Gas
OOC
Baseline 20100101 Distillate Oil
Baseline 20100201 Natural Gas
000
Baseline 20100101 Distillate Oil
Baseline 20100201 Natural Gas
OOE
Baseline 20100101 Distillate Oil
Baseline 20100201 Natural Gas
OOF
Baseline 20100101 Distillate OH
Baseline 20100201 Natural Gas
OOQ
Baseline 20100101 Distillate Oil
Baseline 20100201 Natural Gas
00H
Baseline 20100101 Distillate OH
Baseline 20100201 Natural Gas
001
Baseline 20100101 Distillate Oil
Baseline 20100201 Natural Gas
OOJ
Baseline 20100101 Distillate OH
5-Month
Activity
Fae/Coda
- Severe

250


250


250


250


2SO


250


250


250


250


250


250


250


250


250


250


250



0.046 1
0.499 1

0.046 1
0.499 1

0.046 1
0.499 T

0.046 1
0.499 1

0.046 1
0.499 1

0.046 1
0.499 1

0.046 1
0.499 1

0.046 1
0.499 1

0.049 1
0.500 1

0.049 1
0.500 1

0.049 1
0.500 1

0.049 1
0.500 1

0.049 1
0.500 1

0.049 1
0.500 1

0.049 1
0.500 1

0.049 1
Final OTC NOx Baseline Inventory
New York
Heat Content State Emission
(10x6Btu/ Heat Input Factor/Code Con.
Fuel Use/Units SCO Unit) (10x6 Btu) 	 (Ibs/SCC Unit) 	 Eft.



0.7
53.2

0.7
53.2

0.7
53.2

0.7
53.2

0.7
53.2

0.7
53.2

0.7
53.2

0.7
53.2

1.0
71.0

1.0
71.0

1.0
71.0

1.0
71.0

1.0
71.0

1.0
71.0

1.0
71.0

1.0


1000 Gal 137.40
10x6CuFt 1.000.00

1000 Gal 137.40
10x6CuR 1.000.00

1000 Gal 137.40
10x6CuFt 1.000.00

1000 Gal 137.40
10x6 CuR 1,000.00

1000 Gal 137.40
10x6CuFt 1.000.00

1000 Gal 137.40
10x6 CuR 1,000.00

1000 Gal 137.40
10x6CuFt 1,000.00

1000 Gal 137.40
10x6CuFt 1,000.00

1000 Gal 137.40
10x6CuFt 1,000.00

1000 Gal 137.40
10x6CuFt 1,000.00

1000 Gal 137.40
10x6CuFt 1.000.00

1000 Gal 137.40
10x6CuFt 1.000.00

1000 Gal 137.40
10x6CuFt 1,000.00

1000 Gal 137.40
10x6 CuR 1,000.00

1000 Gal 137.40
10x6 CuR 1,000.00

1000 Gal 137.40



96
53.200

96
53,200

96
53,200

96
53,200

96
53,200

96
53.200

96
53,200

96
53,200

137
71.000

137
71.000

137
71.000

137
71.000

137
71.000

137
71.000

137
71.000

137



85.7 Mul Stk Non-1 990
350.0 Mul Stk Non-1 990

85.7 Mul Stk Non-1990
350.0 Mul Stk Non-1990

85.7 Mul Stk Non-1990
350.0 Mul Stk Non-1 990

85.7 Mul Stk Non-1990
350.0 Mul Stk Non-1 990

85.7 Mul SIX Non-1990
350.0 Mul Stk Non-1990

85.7 Mul Stk Non-1 990
350.0 Mul Stk Non-1990

85.7 Mul Stk Non-1990
350.0 Mul Stk Non-1 990

85.7 Mul Stk Non-1990
350.0 Mul Stk Non-1990

100.0 Mul Stk Non-1990
550.1 Mul Stk Non-1990

100.0 Mul Stk Non-1 990
550.1 Mul Stk Non-1 990

100.0 Mul Stk Non-1990
550.1 Mul Stk Non-1 990

100.0 Mul Stk Non-1990
550.1 Mul Stk Non-1990

100.0 Mul Stk Non-1990
550.1 Mul Stk Non-1 990

100.0 Mul Stk Non-1990
550.1 Mul Stk Non-1990

100.0 Mul Stk Non-1990
550.1 Mul Stk Non-1 990

100.0 Mul Stk Non-1 990

Five
Month

1,921.4
9.3
0.0
9.3
0.3
0.0
94
9.3
0.0
9.3
9.3
0.0
94
9.3
0.0
94
9.3
0.0
94
9.3
0.0
94
9.3
0.0
94
19.6
0.1
195
19.6
0.1
195
19.6
0.1
195
19.6
0.1
195
19.6
0.1
19.5
19.6
0.1
195
19.6
0.1
195
19.6
0.1
BaMllrw
Emission Rate
nba/10x8Btu)

0405
0.354


0.354


0.354


0.354


0.354


0.354


0.354


0.354


0.554


0.554


0.554


0.554


0.554


0.554


0.554


0.554

Targs
PACT

1.639.2
9.3


9.3


9.3


9.3


9.3


9.3


9.3


9.3


14.2


14.2


14.2


14.2


143


14.2


143


14.2

38
06/26/95
it (Point Level)
Phase II

1,349.1
9.3


9.3


9.3


9.3


9.3


9.3


9.3


9.3


14.2


14.2


14.2


14.2


143


14.2


143


14.2

Phase III

1,058.9
9.3


9.3


9.3


9.3


9.3


9.3


9.3


9.3


14.2


143


143


143


143


143


143


143


-------
Detail Report - Five Month Data
Point-Segment Level Data
DMlgn
Plant Capacity
Affected Point SCC/Descrlotlon (10x8 Btu/hr)
5-Month
Activity
Fac/Code
059 Nassau Co - Inner Zone - Severe
3152 LILCO - E F BARRETT
OOJ 2SO
Baseline 20100201 Natural Gas 0.500 1
4187 ULCO - GLENWOOD STATION
007 1,060
Affected 10100404 Residual Oil 0.068 1
Affected 10100604 Natural Oat 0.603 1
008 1.060
Affected 10100404 RetldualOil 0.057 1
Affected 10100604 Natural Oa»
Baseline 009 20100101 Distillate Oil
Baseline OOA 20100101 Distillate Oil

597
597
0.624 1
0.523 1
0.523 1
Final OTC NOx Baseline In
New York
Heat Content
(10x6 Btu/ Heat Input
Fuel Use/Units SCO Unit) (10x6 Btu)
71.0
377.0
2.857.0
418.4
2,864.4
302.7
302.7
10x6CuFt
1000 Gal
10x6CuFt
1000 Gal
10x6 Cu Ft
1000 Gal
1000 Gal
1,000.00
148.00
1,000.00
146.00
1,000.00
137.80
137.80
71,000
55.796
2.857,000
61,923
2,664,400
41,712
41,712
ventory
State Emission
Factor/Code Con.
Obs/SCC Unit) EH.
550.1 Mul Slk Non-1990
39.9 Mul Stk Non-1990
220.0 Mul Stk Non-1 990
40.0 Mul Stk Non-1 990
220.0 Mul Stk Non-1990
75.8 Mul Stk Non-1 990
75.8 Mul Stk Non-1 990
5705 TBG COGEN COGENERATI
Baseline 01 A 10100601 Natural Gas
Baseline 03A 10100601 Natural Gas
162
162
0.420 1
0.420 1
846.7
646.7
10x8CuFt
10x6CuFt
1.031.00
1,031.00
872,948
872,948
333.0 Non-1990 Other GEMS
303.1 Non-1990 Other GEMS
Daseflne
Five Emission Rate
Month (Ibs/10x6 Btu)
1,921.4
79.6
19.5
068.2
321.8
7.5
314.3
323.4
8.4
315.1
11 £
11.5
2694
141.0
128.3
0405
0.554
0.226
0.227
022*

0.550
0.550
0409
0.323
0394
39
06/26/95
Target (Point Level)
RACT Phased Phase III
1,639.2
14.2
660.7
321.2
322.8

8.3
8.3
227.0
113.5
113.5
1,349.1
14.2
600.6
291.3
292.6

8.3
8.3
227.0
113.5
113.5
1,058.9
14.2
454.6
218.5
219.5

8.3
8.3
227.0
113.5
113.S
061 New York Co - Inner Zone - Severe
CE01 CON ED - 59TH ST GEN STATION
Affected 001 10100404 Residual Oil
Affected 002 10100401 Residual Oil
Baseline 022 20100101 Distillate OH
1,939
1.334
220
0.281 1
0.312 1
0.501 1
4.376.4
5,292.0
19.6
1000 Gal
1000 Gal
1000 Gal
148.00
148.00
137.00
647,707
783,216
2.685
29.6 Sing Stk Max Load
31.7 Sing Stk Max Load
106.1 Sing Stk Max Load
CE02 CON ED - 74TH ST GENERATING STATION
Affected OOJ 10100404 Residual Oil
Baseline OZZ 20100101 Distillate Oil
CE04 CON ED - EAST RIVER
002
Affected 10100401 Residual Oil
Affected 10100601 Natural Gas
003
Affected 10100401 Residual Oil
Affected 10100601 Natural Gas
CEOS CON ED -WATERSIDE
001
Affected 10100604 Natural Gas
00?
Affected 10100604 Natural Gas
003
Affected 10100404 Residual Oil
Affected 10100604 Natural Gas
2,703
446
GENERATING
3.256


1.940


GENERATING
f.303

1.792

2.S62


0.656 1
0.761 1


0.342 1
0.571 1

0.354 1
0.497 1


0.196 1

0.503 1

0.168 1
0.452 1
15,598.6
10.8


25,582.2
1,561.0

11,600.4
1,381.0


337.0

2,191.0

1.087.8
5,807.0
1000 Gal
1000 Gal


1000 Gal
10x6CuFt

1000 Gal
10x6CuFt


10x6CuFt

10x8CuFt

1000 Gal
10x6CuFt
149.00
137.00


146.00
1,034.00

148.00
1,033.00


1.032.00

1,033.00

148.00
1.033.00
2,324.191
1,460


3.786,166
1,614,074

1.716.859
1,426.573


347,784

2.263.303

160.994
5.998,631
48.3 Sing Stk Max Load
105.6 Sing Stk Max Load


51.5 Sing Stk Max Load
237.8 Sing Stk Max Load

47.5 Sing Stk Max Load
384.3 Sing Stk Max Load


77.2 Sing Stk Max Load

188.0 Sing Stk Max Load

34.1 Sing Stk Max Load
109.5 Sfng Slk Max Load
149.8
64.8
84.0
1.0
377.1
376.5
0.6
1,345.3
844.4
658.8
185.6
540.9
275.6
265.3
556JZ
13.0
13.0
206.0
206.0
336.5
18.6
317.9
0.209
0.200
0.215
0.775
0424
0.324
0.770
0424
0.324


0.340


0.127
0.125

0.193

0.114


1494
64.8
84.0
0.5
290.8
290.5
0.3
1.051.8
658.9


332.9


556.1
73.0

208.0

330.5


143.6
64.8
78.3
0.5
232.7
232.4
0.3
854.4
540.0


314.3


556.1
T3.0

206.0

336.5


107.9
48.6
58.7
0.5
174.6
774.3
0.3
640.8
405.0


235.0


510.8
T3.0

769.0

336.5



-------
Detail Report - Five Month Data
Point-Segment Level Data
Dealgn 5-Month
Plant Capacity Activity
Affected Point SCC/Deacrtotlon (10i6Btu/hr) Fac/Coda
061 New York Co - Inner Zone - Severe
CEOS CON ED - WATERSIDE GENERATING
Baseline 022 20100101 Distillate On 9.999 0.472 1
063 Niagara Co - Outer Zone - Marginal
0118 OCCIDENTAL CHEMICAL
Affected 006 10200501 Distillate Oil 286 0.364 1
007 507
Affected 10200501 DiatMateOU 0.364 1
Affected 10200602 Natural Gas 0.363 1
0383 AMERICAN REF-FUEL Nl
Affected OOC 10200401 Residual Oil 359 0.417 1
007 287
Affected 10200202 Bituminous Coal 0.370 1
Affected 10200501 Distillate OK 0.372 1
0430 NYSEG - KINTIGH (SOMERSET)
Affected 007 10100202 Bituminous Coal 6,280 0.459 1
Baseline 002 10100501 Distillate OH 795 0.167 1
071 Orange Co - Inner Zone - Severe
0370 CEN. HUDSON - DANSKAMMER POINT
007 620
Affected 10100804 Natural Gas 0.554 1
002 657
Affected 10100604 Natural Gas 0.491 1
003 7,474
Affected 10100212 Bituminous Coal 0.455 1
Affected 10100604 Natural Gas 0.328 1
004 2.079
Affected 10100212 Bituminous Coal 0.450 1
Affected 10100604 Natural Gas 0.264 1
0475 CEN. HUDSON - ROSETON GENERATING S
007 5,397
Affected 10100404 Residual Oil 0.429 1
Affected 10100501 Distillate OK 0.365 1
002 5,397
Affected 10100404 Residual Oil 0.364 1
Affected 10100501 Distillate Oil 1.000 1
Final OTC NOx Baseline Inventory
New York
Heat Content State Emission
(10x6 Btu/ Heat Input Factor/Code Con.
Fuel Use/Units SCCUnlt) (10x6 Btu) (Ibs/SCCUnrt) Eft.


22.3


28.0

28.0
40.7

29.6

22.960.3
9.3

806.948.0
70.4



1.654.9

1,465.2

154,700.0
8.2

223.800.0
53.0


89.628.0
138.0

73,206.0
163.8


1000 Gal


1000 Gal

1000 Gal
10x6CuFt

1000 Gal

Tons
1000 Gal

Tons
1000 Gal



10x6 Cu Ft

10x6 Cu Ft

Tons
10x6CuFt

Tons
10x8 Cu R


1000 Gal
1000 Gal

1000 Gal
1000 Gal


137.00


143.00

143.00
1.030.00

154.00

25.00
138.00

26.30
138.00



1.034.00

1,034.00

26.36
1,035.00

26.36
1.033.00


151.00
138.00

151.00
138.00


3.055


4,004

4,004
41,921

4.558

574.008
1.283

21,222.732
9.715



1,711.167

1,515,017

4,077.892
8.487
,
5.899.368
54.749


13,533.828
19.044

11.054.108
22,604


67.3


20.0

20.0
142.5

56.1

21.7
20.0

13.9
34.4



165.3

180.9

15.6
275.6

15.3
274.7


66.4
23.9

63.4
23.9


Sing S* Max Load


AP-12

AP-42
AP-42

AP42

AP-42
AP-42

Non-1990 Other CEMS
Non-1 990 Other CEMS



MulStk Non-1990

MulStk Non-1990

Non-1990 Other CEMS
AP-42

Non-1990 Other CEMS
AP-«2


MulStk Non-1990
MulStk Non-1990

MulStk Non-1990
MulStk Non-1 990
BaseHne
40
06/26/95
Five Emission Rate Target (Point Level)
Month (Iba/I0x6 Btu) PACT Phase II

556.2
0.6

34
0.3
3.2
04
2.9
290.0
0.6
249.2
249.1
0.1
5,629.2
5.624.0
1*

3,191.1
736.6
136.8
732.5
1324
7,203.9
1.2024
1.1
7.777.8
1,710.6
74
5,3024
2,979.7
2,9774
1.7
2,323.3
2,3214
2.0

0.127
0.497

0.139
0.740
0.739


0462
0.364
0.866


0430
0.530
0349

0481
0.770

0.784

0.589


0.575


0431
0.440


0.420



556.1
0.6

34
0.3
3.2


130.1
0.6
729.2


4,7764
4.775.1
7.2

2.3724
736.6

732,5

857.5


7,246.7


3477.1
7.693.4


7.383.7



556.1
0.6

34
0.3
3*


112.6
0.5
772.7


2,5324
2.530.8
7.2

1,2914
736.8

732.5

427.4


607.2


2463.0
7,355.3


1.107.7


l»hase III

5194
0.6

34
0.3
3.2


624
0.3
62.3


1,5924
7.597.7
7.2

995.0
728.3

773.6

306.5


446.6


1,847.2
7.076.5


830.7



-------
Detail Report - Five Month Data 1
Point-Segment Level Data
Design 5-Month
Plant Capacity Activity
Affected Point SCC/Dascflrrtton 110x6 Btu/hr) Fac/Code
075 Oswego Co - Outer Zone - Attainment
Final OTC NOx Baseline in
New York
Heat Content
OOrtBtu/ Heat Input
Fuel Use/Units SCO Unit) (10x6Btu)




iventory
State Emission
Factor/Code Con.
(Ibs/SCC Unit) Eft.


011 5 NIAGARA MOHAWK - OSWEGO GENERATING STA.
002 1.735
Affected 10100401 Residual Oil 0.401 1
Affected 10100601 Natural Gat 0.415 1
004 8,397
Affected 10100401 Residual Oil 0.407 1
Affected 10100601 Natural GM 0.435 1
021 1 OSWEGO ENERGY CO. - INDECK
001 S33
Ba*ellne 20200103 Distillate OH 0.377 3
Baseline 20200203 Natural Oa« 0.377 3
081 Queens Co - Inner Zone - Severe
CE01 CON ED - ASTORIA GENERATING STATION
001 1.890
Affected 10100401 Residual Oil 0.269 1
Affected 10100601 Natural Gaa 0.535 1
002 1.790
Affected 10100401 Residual Oil 0.192 1
Affected 10100801 Natural GM 0.517 1
003 3,700
Affected 10100401 Residual Oil 0.206 1
Affected 10100601 Natural Gas 0.554 1
004 3.550
Affected 10100404 Residual Oil 0.950 1
Affected 10100604 Natural Gas 1.513 1
005 3.960
Affected 10100404 ResWualOII 0.392 1
Affected 10100604 Natural Gat 0.531 1
022 2,579
Baseline 20100101 Distillate OH 0.496 1
Baseline 20100201 Natural Gas 0.405 1
CE02 CON ED - RAVENSWOOD GENERATIN
OOf 3.750
Affected 10100404 ResWualOII 0.256 1
Affected 10100604 Natural Gas 0.444 1
002 3.660
Affected 10100604 Natural Gas 0.616 1
003 9.240
Affected 10100404 Residual Oil 0.344 1
Affected 10100604 Natural Gas 0.529 1
Q22 6.405
Baseline 20100101 OistHlateOH 0.400 1

62.891.2
2.150.9

63.866.2
64.6


436.2
492.6



3.297.0
3.907.0

2.784.6
4,153.0

6.094.2
6,932.0

14.401.6
2,909.0

19.521.6
4.323.0

1.436.9
360.0


2,984.4
6,686.0

6.179.0

48,090.0
13.279.0

233.7

1000 Gal
10x6 Cu Ft

1000 Gal
10x6CuFt


1000 Gal
10x6 Cu Ft



1000 Gal
10x6 Cu Ft

1000 Gal
10x6CuFt

1000 Gal
10x6CuFt

1000 Gal
10x6CuFt

1000 Gal
10x6 Cu Ft

1000 Gal
10x6 Cu Ft


1000 Gal
10x6CuFt

10x6 Cu R

1000 Gal
10x6 Cu Ft

1000 Gal

151.20
1.032.00

150.20
1,032.00


139.00
1,032.00



148.00
1.033.00

148.00
1,033.00

148.00
1.033.00

148.00
1.033.00

148.00
1.033.00

137.00
1.033.00


148.00
1.033.00

1.033.00

148.00
1.033.00

137.00

12.533,149
2.219.729

9.595.707
66,674


60,632
506370



487,956
4.035.931

412,121
4,290.049

901,942
7.160.756

2.131.466
3,004,997

2,869.197
4,465.659

196.655
371,680


441.691
7.113,238

6.382,907

7.117.320
13.717.207

32.017

89.1
542.9

42.1
206.5


67.4
150.6



44.1
309.9

44.3
309.9

61.7
301.6

40.0
216.9

40.0
216.9

97.7
478.3


40.7
226.2

226.2

53.7
431.8

100.8

Mul S* Non-1990
State Factor

Non-1990 Other CEMS
Non-1 990 Other CEMS


Non-1 990 Other CEMS
Non-1 990 Other CEMS



Sing Stk Max Load
Sing Stk Max Load

Sing Stk Max Load
Sing Stk Max Load

Sing Stk Max Load
Sing Stk Max Load

Sing Stk Max Load
Sing Stk Max Load

Sing Stk Max Load
Sing Stk Max Load

Sing Stk Max Load
Sing Stk Max Load


Sing Stk Max Load
Sing Stk Max Load

Sing Stk Max Load

Sing Stk Max Load
Sing Stk Max Load

Sing S* Max Load

Five
Month

5.624.9
4.274.8
3.691.0
583.8
f. 350. »
1,343.4
6.7
51J
51.8
14.7
37.1

4.2S&2
678.1
72.7
605.4
705.?
61.6
643.5
1,233.5
188.1
1.045.5
603.3
287.8
3153
858.9
390.0
468.9
756.3
70.2
66.1
5,786.1
839.6
60.7
778.9
696.9
698.9
4,156.7
1.291.8
2.866.9
80.0
11.8
Bsseflnt)
Emission Rate
flba/10x6 Btu)

0.461
0.580


0.279


0.182
0.182



0.279
0.300


0.300
»

0.324


0.236


0.238


0.539


0429
0.224


O22J

0.394


0.464



41
06/26/95
Target (Point Level)
RACT

3,0504
1.844.1


1.206.2


49.2
49.2



3.688.8
565.5


507.0


f.007.0


502.0


830.0


»»3.7


4.213.8
834. T


690.9

2.604.3


76.4

Phase II

2,8104
»,044. 1


966.2


492
49.2



3,091.7
452.4


470.2


006.3


5J3.6


735.5


113.7


3,553.7
755.5


638.3

2.083.5


76.4

Phase III

1,831.1
1.106.5


724.7


49.2
49.2



2,347.2
339.3


352.7


604.7


305.2


55J.6


113.7


2,6844
566.6


478.7

f.562.6


76.4


-------
Detail Report - Five Month Data
Point-Segment Level Data
OMlgn
Plant Capacity
Affected Point SCC/DMCftoHon (10x6 BtuJhr)
5-Month
Activity
Fee/Code
081 Queens Co - Inner Zone - Severe
CE02 CON ED - RAVENSWOOD GENERATIN
022 6,405
Baseline 20100201 Natural Gas 0.384 1
Final OTC NOx Baseline Inventory
New York
Heat Content State Emission
Baseflntt
(10x6Btu/ Heat Input Factor/Coda Con. Five Emission Rate Targe
Fuel Use/Unlfs SCO Unit) (10x6 Btu) flba/SCC Unit) Eff. Month (lbe/10x6Btu) RACT
339.0 10x6CuFt
1.033.00
350.187
454.5
Sing Stk Max Load
CE03 CON ED - RAVENSWOOD -A- HOUSE
Affected 001 10100401 RMldualOil 710
Affected 002 10100401 Residual Oil 770
LILC LILCO - FAR ROCKAWAY STATION
oor r.000
Affected 10100404 RMldualOil
Affected 10100604 Natural Gas
PANY CHARLES POLETTI POWE
002 8,266
Affected 10100401 Residual Oil
Affected 10100601 Natural Gas
0.362 1
0.362 1


0.111 1
0.651 1


0.105 1
0.425 1
2.319.1 1000 Gal
2,320.0 1000 Gal


1.101.7 1000 Gal
2.578.6 10x6CuFt


7,258.0 1000 Gal
10,095.4 10x6CuFt
148.00
148.00


148.00
1.031.00


148.00
1.031.00
343,227
343,360


163,052
2,658.537


1.074,184
10.408.357
54.3
54.3


41.4
268.1


66.6
360.8
Sing Stk Max Load
Sing Stk Max Load


Mul Stk Non-1 990
Mul Stk Non-1 990


Mul Stk Non-1990
Mul Stk Non-1990
5,786.1
88.8
77.0
126.0
03.0
03.0
368.4
368.4
22*
345.8
2,0832
2,063.2
241.7
1,821.5
0.329
0.464
0.367
0.367
0.367
0261
0.265


0459
0.379


4,213.8
76.4
85.8
42.9
42.9
352.7
352.7


1,435.3
t.435.3


42
06/26/95
I (Point Level)
Phased
3,553.7
76.4
68.7
34.3
34.3
2822
202.2


1,148.3
1,148.3


Tnaseffl
2.684.4
76.4
513
25.7
25.0
211.6
211.6


8612
06J.2


085 Richmond Co - Inner Zone - Severe
CE01 CON ED - ARTHUR KILL GENERATI
007 7.246
Affected 10100401 Residual Oil
Affected 10100404 Residual Oil
Baseline OZZ 20100101 Distillate Oil 235
PG01 PORT IVORY PLANT
Affected 00; 10200602 Natural Gas 360


0.870 1
0.465 1
0.706 1

0.417 1


31.655.4 1000 Gal
35,880.6 1000 Gal
27.4 1000 Gal

284.8 10x6CuFt


148.00
148.00
137.00

1,030.00


4.684.999
5.310.329
3.754

293.344


47.4
36.0
68.6

140.6


Sing Stk Max Load
Sing Stk Max Load
Sing Stk Max Load

AP-42
1,395.7
1.394.0
749.6
6452
0.9
20.0
20.0
0279
0.260


O.SOf
0.136
0.137
1231.6
1,230.8


0.8
20.0
20.0
1,000.3
999.5


0.0
20.0
20.0
750.4
749.7


0.8
20.0
20.0
087 Rockland Co - Inner Zone - Severe
0228 BOWLINE POINT
00) 5.546
Affected 10100404 Residual Oil
Affected 10100604 Natural Gas
00? 5.974
Affected 10100401 Residual Oil
Affected 10100601 Natural Gas
0720 LOVET GENERATING STATION
Affected 002 10100001 Natural Gas 252
Affected 003 10100604 Natural Gas 715
004 1,835
Affected 10100202 Bituminous Coal
Affected 10100601 Natural Gas


0.462 1
0.153 1

0.357 1
0.603 1

1.000 1
0.429 1

0.515 1
0.346 1


58.451.4 1000 Gal
684.0 10x6CuFt

18.950.4 1000 Gal
12.711.2 10x6CuFt

13.5 10x6 Cu Ft
1,180.8 10x6 Cu Ft

177.400.0 Tons
234.6 10x6CuFt


148.70
1.035.00

148.70
1.035.00

1.034.00
1.034.00

26.00
1.034.00
•

8.691.723
707,940

2.817,924
13.156,092

13.959
1.220,947

4.612,400
242,576


38.7
269.1

58.0
238.1

296.3
413.6

24.8
413.8


Mul Stk Non-1 990
Mul Stk Non-1 990

Mul Stk Non-1 990
Mul Stk Non-1990

Mul Stk Non-1990
Mul Stk Non-1 990

Mul Stk Non-1990
Mul Stk Non-1 990
3.2844
f ,222.0
1,129.9
92.0
2,062.5
549.5
1,513.0
3,694.6
2.0
244.2
2.246.3
2.197.8
48.5
02S9
0.260


0.272


0.770
0.287
0.400
0.913


3,040.1
1.17S.O


1.86S.2


2,017.6
f.7
752.6
1,086.3


2£37J
940.0


1.S97.4


1,330.4
1.4
122.1
786.2


1,9034
705.0


1,196.0


954.7
1.0
91.6
S61.6



-------
Detail Report - Five Month Data
Point-Segment Level Data
DMlgn
Plant Capacity
Affected Point SCC/DetcrloHoo (lOx6Btu/hr)
1
5-Month
ActMty
Fac/Code
087 Rockland Co - Inner Zone - Severe
0720 LOVET GENERATING STATION
005 1.920
Affected 10100202 Bituminous Coal 0.365 1
Affected 10100601' Natural Gas 0.365 1
091 Saratoga Co - Outer Zone - Marginal
0145 HUDSON RIVER MILL
Affected 007 10200401 Residual Oil
101 Steuben Co - Outer Zone
0110 NYSEG - HICKLING STATION
Affected 001 10100205 Bituminous Coal
Affected 002 10100205 Bituminous Coal
103 Suffolk Co - Inner Zone -

589

0.420 1
-mai OTC NOX Baseline in
New York
Heat Content
(10x8 Btu/ Heat Input
Fuel Use/Units SCCUnlt) (10x6 Btu)
116,800.0 Tons
452.2 10x6CuFt

10.487.4 1000 Gal
26.00
1,035.00

150.00
3,036.800
468,027

1,573.110
ventory
State Emission
Factor/Code Con.
(Ibs/SCC Unit) Eft.
19.0 MulStk Non-1 990
414.0 MulStk Non-1 990

90.0 MulStk Non-1 990
Bl
ftmwW
Fhre Emission Rail
Month flba/IOxC Btu)
3,694.*.
1.202.0
1,108.4
93.6
471.9
471.9
0.770
0.680
0.800
0.600

43
06/26/95
Target (Point Level)
RACT
2,017.6
776.9
196.6
196.6
Phase II
1,3304
420.7
196.6
(96.6
Phase III
954.7
300.5
118.0
118.0
- Attainment

562
632

0.357 1
0.405 1

52,798.0 Tons
77,980.0 Tons

21.60
21.60

1.140.437
1.684.368

8.6 MulStk Non-1 990
8.6 MulStK Non-1 990
565.0
226.1
336.9
0.400
0.400
0.400
423.7
171.1
252.7
282.5
114.0
168.4
211.9
85.5
f26.3
Severe
1922 LILCO - NORTHPORT POWER STATION
oor
Affected 10100404 Residual Oil
Affected 10100501 Distillate Oil
002
Affected 10100404 Residual Oil
Affected 10100501 Distillate Oil
003
Affected 10100404 Residual Oil
Affected 10100501 Distillate OH
004
Affected 10100404 Residual Oil
Affected 10100501 Distillate Oil
2110 LILCO -HOLBROOK
Baseline OOf 20100101 Distillate OH
Baseline 002 20100101 Distillate Oil
Baseline 003 20100101 Distillate Oil
Baseline 004 20100101 Distillate OH
Baseline 005 20100101 Distillate OH
Baseline 009 20100101 Distillate OH
Baseline 007 20100101 Distillate Oil
Baseline 008 20100101 Distillate Oil
Baseline 009 20100101 Distillate Oil
Baseline OOA 20100101 Distillate OH
Baseline OOB 20100101 Distillate OH
Baseline OOC 20100101 Distillate OH
Baseline 000 20100101 Distillate Oil
Baseline 00? 20100101 Distillate Oil
3.435


3,435


3.381


3.430



402
402
402
402
402
402
402
402
402
402
336
336
336
336

0.412
0.367

0.483
0.495

0.520
0.561

0.374
0.333

0.459
0.459
0.459
0.459
0.459
0.459
0.459
0.459
0.459
0.459
0.459
0.459
0.459
0.459

49.410.6 1000 Gal
78.1 1000 Gal

59.060.0 1000 Gal
105.4 1000 Gal

63,526.4 1000 Gal
119.4 1000 Gal

42,193.2 1000 Gal
71.0 1000 Gal

314.1 1000 Gal
314.1 1000 Gal
314.1 1000 Gal
314.1 1000 Gal
314.1 1000 Gal
314.1 1000 Gal
314.1 1000 Gal
314.1 1000 Gal
314.1 1000 Gal
314.1 1000 Gal
314.1 1000 Gal
314.1 1000 Gal
314.1 1000 Gal
314.1 1000 Gal

151.00
138.00

151.00
138.00

151.00
138.00

151.00
138.00

137.80
137.80
137.80
137.80
137.80
137.80
137.80
137.80
137.80
137.80
137.80
137.80
137.80
137.80

7,461,001
10.778

8.918.060
14,545

9.592,486
16.477

6,371,173
9.798

43,283
43,283
43.283
43.283
43.283
43,283
43,283
43,283
43,283
43,283
43.283
43,283
43,283
43,283

45.3 MulStk Non-1 990
27.7 MulStk Non-1 990

45.3 MulStk Non-1 990
27.5 MulStk Non-1 990

45.3 MulStk Non-1990
27.6 MulStk Non-1990

45.3 MulStk Non-1 990
27.6 MulStk Non-1 990

117.2 MulStk Non-1 990
117.2 MulStk Non-1990
117.2 MulStk Non-1990
117.2 MulStk Non-1990
117.2 MulStk Non-1 990
117.2 MulStk Non-1 990
117.2 MulStk Non-1990
117.2 MulStk Non-1990
117.2 MulStk Non-1990
117.2 MulStk Non-1 990
117.2 MulStk Non-1 990
117.2 MulStk Non-1990
117.2 MulStk Non-1 990
117.2 MulStk Non-1 990
4,856.6
1,120.2
1.119.2
1.1
1,339.2
1,337.7
1.5
1.440.5
1.438.9
1.7
956.7
955.7
1.0
368.0
16.4
18.4
18.4
18.4
18.4
18.4
18.4
18.4
18.4
18.4
18.4
16.4
18.4
18.4
OJOO
0.300


0.300


0.300


0.300


0450
0.850
0.850
0.850
0.850
0.850
0.850
0.850
0.850
0.850
0.850
0.850
0.850
0.850
0.850
4,048.0
933.7


1.116.2


1,200.7


797.4


173.1
0.7
8.7
0.7
8.7
8.7
8.7
8.7
8.7
8.7
8.7
6.7
8.7
8.7
8.7
3,239.4
747.2


893.3


960.9


630.1


173.1
0.7
0.7
8.7
0.7
0.7
0.7
0.7
0.7
0.7
0.7
8.7
8.7
0.7
0.7
2,429.6
560.4


669.9


720.7


478.6


173.1
0.7
0.7
0.7
0.7
0.7
0.7
8.7
8.7
8.7
8.7
0.7
0.7
0.7
0.7

-------
Detail Report - Five Month Data
Point-Segment Level Data
DMlgn
Plant Capacity
Affected Point SCC/Descriotlon MOxB Btuftir)
103 Suffolk Co - Inner Zone -
2110 LILCO-HOLBROQK
Baseline OOF 20100101 Distillate OH
Baseline COO 20100101 DMMatoOD
Baseline OOH 20100101 Distillate Oil
Baseline 001 20100101 Distillate OH
Baseline OOJ 20100101 Distillate Oil
Baiellrw OOK 20100101 Distillate OH
3228 LILCO - PORT JEFFERSON PR
Affected 001 10100404 Residual Oil
002
Affected 10100404 Residual Oil
Affected 10100501 Distillate Oil
003
Affected 10100404 Residual Oil
Affected 10100501 Distillate Oil
3537 LILCO -WADING RIVER
Baseline OOA 20100101 Distillate Oil
Baseline 008 20100101 Distillate Oil
Baseline OOC 20100101 Distillate Oil
BRIG LILCO - BROOKHAVEN COM
Baseline 013 20100101 Distfflate Oil
Baseline 014 20100101 Distillate Oil
EHIC LILCO - EAST HAMPTON 1
Baseline 001 20100101 Distillate OH
SHIC LILCO - SOUTHOLD 1C SI
Baseline 001 20100101 Distillate Oil
WBIC LILCO - WEST BABYLON 1
Baseline 001 20100101 DistfflateOII
Final OTC NOx Baseline Inventory
New York
S-Month Heal Content Slate Emission
AetMty (lOrtBtu/ Heal Input Factor/Code Con.
Fac/Code Fuel Use/Units SCO Unit) (10x6Blu) (Ibt/SCCUnH) Eff.
Severe

336
336
336
336
336
336
ST
1.060
1.693


1.693



8S7
857
857

423
254

274

223

578

0.459
0.459
0.459
0.459
0.459
0.459

0.389 1

0.418 1
0.291 1

0.449 1
0.346 1

0.497 1
0.497 1
0.497 1

0.098 1
0.100 1

0.967 1

0.670 1

0.517 1


314.1 1000 Gal
314.1 1000 Oat
314.1 1000 Gal
314.1 1000 Gal
314.1 1000 Gal
314.1 1000 Gal

4,603.4 1000 Gal

28,267.8 1000 Gal
34.9 1000 Gal

25,499.6 1000 Gal
34.9 1000 Gal

1.623.3 1000 Gal
1.623.3 1000 Gal
1,623.3 1000 Gal

13.6 1000 Gal
4.0 1000 Gal

402.2 1000 Gal

33.1 1000 Gal

281.4 1000 Gal


137.80
137.80
137.80
137.80
137.80
137.80

151.00

151.00
138.00

151.00
138.00

138.70
138.70
138.70

138.70
138.70

138.70

138.70

138.70


43.283
43.283
43.283
43.283
43.283
43,283

695.113

4.268,438
4,816

3.650,440
4,816

225,152
225,152
225,152

1,886
555

55.785

4,591.

39,030


117.2 MulStk Non-1990
117.2 MulStk Non-1990
117.2 MulStk Non-1 990
117.2 Mul Stk Non-1990
117.2 Mul Stk Non-1990
117.2 Mul Stk Non-1 990

54.4 Mul Stk Non-1990

54.4 Mul Stk Non-1 990
17.8 Mul Stk Non-1 990

54.4 Mul Stk Non-1 990
17.8 Mul Stk Non-1 990

34.7 Mul Stk Non-1 990
34.7 Mul Stk Non-1990
34.7 Mul Stk Non-1 990

76.5 Mul Stk Non-1990
105.0 Mul Stk Non-1990

104.0 Mul Stk Non-1 990

76.1 Mut Stk Non-1990

76.3 Mul Stk Non-1990

Five

36BJ
16.4
18.4
18.4
18.4
18.4
18.4
1,587.1
12S.1
768.6
768.3
0.3
093.4
693.1
0.3
84.4
28. 1
28.1
28.1
0.7
0.5
0.2
20.0
20.9
14
J.3
10.7
10.7
nmmmtktm
BMVIinV
Emission Rate
(Iba/IOxeBtu)

0.830
0.850
0.850
0.850
0.850
0.850
0.850
0.360
0.360
0.360


0.360


0.250
0.250
0.250
0.250
0388
O.SS1
0.757
0.750
0.750
0349
0.549
0350
0.550
Targ«
RACT

173.1
8.7
8.7
8.7
8.7
6.7
6.7
1,102.4
66.9
533.9


481.6


84.4
28.7
28. 1
28.1
0.5
0.4
0.1
11.2
113
0.8
0.9
7.8
7.8
44
06/26/95
it (Point Level)
Phase II

173.1
8.7
8.7
8.7
8.7
8.7
8.7
M2.4
69.5
427.3


385.5


84.4
28. 1
28.1
28.1
0.5
0.4
0.1
11.2
11.2
0.8
0.9
7.8
7.8
Phase III

173.1
8.7
8.7
8.7
6.7
6.7
6.7
661.1
52.1
320.6


289.1


84.4
2ft 1
28.1
28.1
03
0.4
0.1
11.2
JT.2
0.9
0.9
7.8
7.8
109 Tompkins Co - Outer Zone - Attainment
0120 NYSEG - MILLJKEN STATION
001
Affected 10100212 Bituminous Coal
Affected 10100501 Distillate Oil
002
Affected 10100212 Bituminous Coal
Affected 10100501 Distillate Oil

1.484


1.S17




0.433 1
0.454 1

0.447 1
0.212 1


193.054.0 Tons
15.9 1000 Gal

197.062.0 Tons
7.0 1000 Gal


24.32
138.00

24.32
138.00


4.695,073
2,194

4,792.548
966


16.3 Mul Stk Non-1990
34.0 Mul Stk Non-1 990

16.3 Mul Stk Non-1990
34.3 Mul Stk Non-1990
3,178.7
1.S73.1
1,572.9
0.3
1.605.6
1.605.5
0.1
0.670
0.070


0.670


1,992.8
986.2


1.006.6


1,430.4
707.9


722.5


794.7
393.3


401.4



-------
Detail Report - Five Month Data
Point-Segment Level Data
Plant
Affected Point SCC/Deserlutton
DMlgn 5-Month
Capacity Activity
M0x« BtiVhr) Fac/Code
119 Westchester Co - Inner Zone - Severe
Z504 CON ED - BUCHANAN
Baseline 022 20100101 Distillate Oil
123Yates
0028 NYSEG
007
Affected
Affected
008
Affected
Affoctod
Co - Outer Zone
785 0.796 1
- Attainment
-GREENIDGE STATION
750
10100202 Bituminous Coal 0.173 1
10100501 Distillate Oil 0.403 1
1,117
10100212 Bituminous Coal 0.430 1
10100501 Distillate Oil 0.368 1
Final OTC NOx Baseline In
New York
Heat Content
(10x< Btu/ Heat Input
Fuel Use/Units SCO Unit) (10x6 Btu)

06.4 1000 Gal

19,673.0 Tons
95.5 1000 Gat
130.671.0 Ton*
63.0 1000 Gal

137.00

24.68
135.00
24.50
138.00

11.837

485.530
12.893
3.206.340
8.694
ventory
State Emission
Factor/Code Con.
Obs/SCC Unit) EH.

97.7 AP-42

21.5 MulStk Non-1 990
33.7 MulStk Non-1 990
13.0 Mul Stk Non-1990
34.6 Mul SIX Non-1 990

FK» Emission Rate
Month Oba/10x6Btu)

42
4.2

1,0610
212.8
211.2
1.6
850.8
649.7
1.1

arts
0.713

0.573
0.863
0.529
45
06/26/95
Target (Point Level)
RACT

2.4
2.4

7854
110.9
674.4
Phase II Phase III

2.4
2.4

478.6
95.8
382.8

2.4
2.4

294J
53.2
241.1

-------
Detail Report - Five Month Data Final OTC NOx Baseline Inventory
Point-Segment Level Data Pennsylvania
DMtgn S-Month Heat Content State Emission
Plant Capacity Activity (10x6 Btu/ Heat Input Factor/Coda Con.
Affected Point SCC/Deacrlotlon (10x6Btu/hr) Fac/Code Fuel Use/Units SCO Unit) (10x6 Btu) (Iba/SCC Unit) EH.
001 Adams Co - Outer Zone
- Marginal





0017 METROPOLITAN EDISON COMPANY
Baseline 031 20100201 Natural Gaa
Baseline 032 20100201 Natural Gas
Baseline 033 20100201 Natural Gas
HAMI MET EDISON HAMILTON
Baseline 031 20100101 Distillate On
ORTA MET EDISON ORTANNA
Baseline 031 20100101 Distillate OH
320 0.417 3
320 0.417 3
320 0.417 3

T50 0.557 1

750 0.809 1
86.7
28.2
71.6

136.7

94.8
10x6 CU Ft
10x6 Cu Ft
10x6 Cu Ft

1000 Gal

1000 Gal
1.037.00
1.037.00
1.037.00

136.00

138.00
89.908
29.243
74.249

18,716

13.130
462.0 AP-42
462.0 AP-42
462.0 AP-»2

80.5 Sing Stk Rep Cond

82.3 Sing StK Rep Cond
Baseline
Five Emission Rah
Month (Iba/10x6 Btu

43.1
20.0
0.5
76.5
5.5
5.5
3.9
3.9


-------
Detail Report - Five Month Data
Point-Segment Level Data
                                                         Final OTC NOx Baseline Inventory
                                                                        Pennsylvania
                                                                                                                                                   47

                                                                                                                                             06/26/95
        Plant
AHected  Point
                SCC/Peseription
                                      Design
                                      Capacity
                                    (10x6 Btu/hr)
                                  5-Month
                                  Activity
                                  Fac/Code
                                                           Fuel Use/Units
                                  Heat Content             Slat* EmUalon
                                   (10x6 Btu/   Heat Input    Factor/Cod*        Con.
                                   SCO Unit)   (10x6 Btu)    (Ibs/SCC Unit)	Eft.
                                                                                                                                Baaeflrw
                                                                      Emlaalon Rat*
                                                               Month  (Ibs/IOrt Btu)
                                                                  Target (Point Level)
                                                                 RACT  Phase II  Pha»e llf
003 Allegheny Co - Outer Zone - Moderate
0050  SHENANGO IRON & COKE WORKS
Affected  005
Affected  005
Affected  007
Affected  008
Affected  009
Affected  OrO
              10200704 ProceMGas
              10200707 ProceMGas
              10200501 Distillate Oil
              10200704 Process Gas
              10200707 Process Gas
              10200501 Distillate Oil
400
400
400
532
532
532
0.003
0.390
0.340
0.003
0.483
0.353
3
3
3
3
3
3
6.5
1,049.9
24.8
3.8
832.3
45.6


1000 Gal


1000 Gal
66.00
561.00
140.00
66.00
561.00
140.00
558
588.983
3.472
324
466,920
6.384
23.1
80.0
20.0
22.6
60.0
20.0
005 Armstrong Co - Outer Zone - Moderate
0001  WEST PENN POWER CO.
Affected
Affected

Aftectftd
Affected
        031
        032
10100202 Bituminous Coal
10100501 DistfflataOII

10100202 BituminouaCoal
10100501 Distillate OH
0012 PECO - KEYSTONE
Affected
Affected

Affected
Affected
        oar
        032
10100212 Bituminous Coal
10100501 Distillate Oil

10100212 Bituminous Coal
10100501 Distillate Oil
                                        1,860
1,860
                                        7,580
7.580
0.420
0.417
0/444
0.417
0.407
0.587
0.420
0.673
1
3
1
3
3
3
3
3
203.618.0
0.0
190,398.0
0.0
1,046.913.0
167.6
937.079.3
1.206.6
Tons
1000 Gal
Tons
1000 Gal
Tons
1000 Gal
Tons
1000 Gal
26.30
139.00
26.30
139.00
24.00
139.00
24.00
139.00
5,355,101
0
5.007.467
0
25.125,912
23.324
22,489,903
167,995
 007 Beaver Co - Outer Zone - Moderate
 0005  PENN POWER CO. - BRUCE MANSFIELD
        03»                             7.9M
               10100202 Bituminous Coal
               10100501 Distillate Oil
Affected
Affected
                                  0.416 3
                                  0.353 3
Affected
AfmCtOu

Affoctoo
Affected
        032
        033
10100202 Bituminous Coal
10100501 DlstmateOII

10100202 Bituminous Coal
10100501 Distillate OH
0011 LTV STEEL COMPANY
Affected  03T    10200601  Natural Gaa
                                        7.974
                                        7.9/4
                                        300
0032 ZINC CORPORATION OF AMERICA
        034                              600
Affected         10200202 Bituminous Coal
Affected         10200601 Natural Gaa
         0.407 3
         0.370 3

         0.518 3
         0.317 3
                                  0.366 3
                                                0.489  3
                                                0.421  3
691,398.2 Tons
   185.2 1000 Gal

693.894.6 Tons
    82.6 1000 Gal

801,394.0 Tons
  1,6352 1000 Gal
 24.00    16,593.557
137.00       25.372

 24.00    21,453.470
137.00       11.318

 24.00    19,233,456
136.00      222,387
                                                              351.9 10x6 Cu Ft  1,020.00     358.938
                                             51,114.9  Tons        27.00    1,360,102
                                                 0.5  10x6CuFt  1.050.00        525
                                       25.0  Non-1990 Other OEMS
                                        0.0  Non-1990 Other CEMS

                                       26.9  Non-1990 Other CEMS
                                        0.0  Non-1990 Other CEMS
                                        19.2  Sing Stk Rep Cond
                                        20.3  Sing Slk Rep Cond

                                        17.0  Sing Stk Rep Cond
                                        20.0  Sing Stk Rep Cond
21.7  AP-42
23.8  AP-42

21.7  AP-«2
242  AP-42

21.7  AP-42
24.0  AP-42
                                                                                   550.7 AP-42
                                                           21.7 AP-42
                                                          800.0 AP-42
78.1
0.1
42.0
0.2
0.0
33.3
0.5
5,109.8
2,546.4
IS 2.546.0
IS 0.4
2,563.4
IS 2,563.0
IS 0.4
18,017.8
10.044.7
10.043.0
1.7
7.973.1
7.981.0
12.1
23,988.2
7.504.0
7,501.8
2.2
9.699.8
9,698.8
1.0
6.784.4
222 6.764.8
19.6
98.9
96.9
1,0242
554.0
554.6
0.143
0.269
0.143
0.143
0.265
0.143
0.143
0.986
0.952


1.022


0.754
0.799


0.705


0.834
0.903


0.903


0.70J


0340
0.540
0.803
0.004

78.1
0.1
42.0
0.2
0.0
33.3
0.5
3,085.9
1,527.8


1.538.0


1 1.099 J
6.027.5


5,072.3


15.151.5
4,503.3


5.620.3


4,028.0


58.1
50. 1
614.5
332.9

78.1
0.1
42.0
0.2
0.0
33.3
0.5
2299.4
1.145.9


1.153.5


8,108.0
4.520.1


3.587.9


10,794.7
3.376.8


4.364.9


3,053.0


43.8
43.6
480.9
249.7

76.1
0.0
420
0.2
0.0
33.3
0.5
1277.5
636.6


640.9


4,504.5
2.511.2


1,993.3


5.997.1
1.876.0


2,425.0


1.696.1


28.9
26.9
258.1
»30.7


-------
Detail Report - Five Month Data
Point-Segment Level Data
Design S-Month
Plant Capacity Activity
AHaetod Point SCCfDaterlotlon (10x6Btu/hr) Fac/Code
007 Beaver Co - Outer Zone - Moderate
0032 ZINC CORPORATION OF AMERICA
035 600
Affected 10200202 Bituminous Coal 0.360 3
Affected 10200601 Natural Gas 0.360 3
0042 AES BEAVER VALLEY PARTNERS, INC.
032 459
Affected 10200202 Bituminous Coal 0.418 3
Affected 10200501 DfctHlateOil 0.357 3
033 459
Affected 10200202 Bituminous Coal 0.350 3
Affected 10200501 Distillate Oil 0.357 3
034 459
Affected 10200202 Bltumlnoua Coal 0.413 3
Affected 10200501 Distillate Oil 0.357 3
01 1 Berks Co - Inner Zone • Moderate
0045 METROPOLITAN EDISON CO. - TITUS
03J 780
Affected 10100212 Bltumlnoua Coal 0.448 3
Affected 10100501 Distillate Oil 0.349 3
032 760
Affected 10100212 Bltumlnoua Coal 0.397 3
Affected 10100501 Distillate Oil 0.376 3
033 780
Affected 10100212 Bltumlnoua Coal 0.437 3
Affected 10100501 Distillate Oil 0.342 3
034 243
Batellne 20100101 Distillate OH 0.747 3
Baseline 20100201 Natural Oas 0.468 3
035 252
Baseline 20100101 Distillate OH 0.741 3
Baseline 20100201 Natural Oas 0.391 3
013 Blair Co - Outer Zone - Marginal
0009 PECO-WILUAMSBURG
031 388
Affected 10100202 Bituminous Coal 0.217 3
Affected 10100501 Distillate OH 0.211 3
017 Bucks Co - Inner Zone - Severe
0006 PHILADELPHIA ELECTRIC CO. -CROYDEN
Buollne 031 20100101 Distillate Oil 56? 0.659 3
Baseline 032 20100101 Distillate OH 562 0.545 3
Final OTC NOx Baseline Inventory
Pennsylvania
Heat Content State Emission
(10x6 Btu/ Heat input Factor/Code Con.
Fuel Uae/Unlta SCCUnltl (10x6 Btu) (Iba/SCCUnH) Eft.


43.218.0
1.8


67.026.6
30.0

55.029.7
30.0

63,664.5
30.0



70.029.7
114.6

62,266.7
95.2

69.167.9
48.1

58.5
11.5

43.5
9.1



7.986.9
8.7


305.4
189.8


Tons
10x6CuFt


Tons
1000 Gal

Tons
1000 Gal

Tons
1000 Gal



Tons
1000 Gal

Tons
1000 Gal

Tons
1000 Gal

1000 Gal
10x6CuFt

1000 Gal
10x6CuFt



Tons
1000 Gal


1000 Gal
1000 Gal


27.00
1.050.00


26.00
159.00

26.00
19.00

26.00
19.00



26.00
138.00

26.00
138.00

26.00
138.00

138.00
1,038.00

139.00
1.037.00



25.00
138.00


139.00
139.00


1,166.886
1.890


1.742.692
4.770

1,430,772
570

1.655,277
570



1,820,772
15.815

1.618,934
13.138

1.798.365
6,638

8.073
11.937

6.047
9,437 .



199,673
1,201


42,451
26.362


21.7
555.6


21.7
20.0

21.7
20.0

21.7
20.0



17.0
24.4

17.7
42.0

17.1
41.6

68.4
417.4

69.0
417.6



21.8
23.0


97.7
97.7


AP-42
AP-42


AP-42
AP-42

AP-42
AP-42

AP-42
AP-42



Sing 8tk Rep Cond
AP-42

Sing Stk Rep Cond
AP-42

Sing Stk Rep Cond
AP-42

Sing Stk Rep Cond
Sing Stk Rep Cond

Sing Stk Rep Cond
Sing Stk Rep Cond



AP-42
AP-42


AP-42
AP-42
Baseline
48
06/26/95
Five Emission Rate Target (Point Level)
Month (Ibs/IOxSBtu) RACT
1,024.2
469.4
468.9
0.5
2,016.0
727.5
727.2
0.3
597.4
697.1
0.3
09f.f
690.8
0.3

1,749.1
595.2
593.8
1.4
554.2
552£
2.0
591.9
590.9
1.0
4.4
2.0
2.4
3.4
1.5
1.9

87.1
87. 1
87.0
0.1

212.9
74.9
9.3
0.803
0.803


0.834
0.853


0.835


0.835



0.659
0.649


0.679


0.655


0.429


0.426



0.867
0.868



0.709
0.703
0.703
614.5
281.6


1.209.7
436.6


358.4


4J4.6



1.190.0
411.1


366.2


405.6


4.0


3.1



52.3
52.3



127.8
9.0
5.6
Phased PhaseJIl
460.9
2»r.2


907.2
327.4


268.8


3M.O



616.6
208.3


194.0


207.2


4.0


3.1



39.2
39.2



127.8
9.0
5.6
256.1
117.4


504.0
181.9


149.3


172.8



4424
148.6


138.6


148.0


4.0


3.1



214
2f.8



127.8
9.0
5.6

-------
'Detail Report - Five Month Data
Point-Segment Level Data
Design
Plant Capacity
Affected Point SCC/DescrlDtion (10x6 Btu/hr)
F
5-Month
Activity
Fac/Code
inal OTC NOx Baseline In
Pennsylvania
Heat Content
(10x6 Btu/ Heat Input
Fuel Use/Units SCC Unit) (10x8 Btu)
ventory
Stele Emission
Factor/Code Con.
(Ibs/SCC Unit) EH.
Baseline
Five Emission Rate
Month flbs/IOxe Btu)
017 Bucks Co - Inner Zone - Severe
0006 PHILADELPHIA ELECTRIC CO. •
Baseline 033 20100101 Distillate Oil
Baseline 034 20100101 Dlstittste OH
Baseline 035 20100101- Distmste OK
Baseline 036 20100101 Distillate Oil
Baseline 037 20100101 Distillate OH
Baseline 038 20100101 Distillate Oil
0055 UNITED STATES STEEL CORP.,
043
Affected 10200401 Residual Oil
Affected 10200601 Natural Gas
Affected 10200704 Process Gas
044
Affected 10200401 Residual Oil
Affected 10200601 Natural Gas
Affected 10200704 Process Gas
045
Affected 10200401 ' Residual Oil
Affected 10200601 Natural Gas
Affected 10200704 Process Gas
046
Affected 10200401 Residual Oil
Affected 10200601 Natural Gas
Affected 10200704 Process Gas
029 Chester Co - Inner Zone -
0023 PHILADELPHIA ELECTRIC CO. •
037
Affected 10100202 Bituminous Coal
Affected 10100401 Residual Oil
CROYDEN
562
562
562
562
562
562
THE
469



469



469



469



0.600 3
0.900 3
0.600 3
0.349 3
0.606 3
0.625 3


0.710 3
0.868 3
0.820 3

0.121 3
0.095 3
0.078 3

0.300 3
0.427 3
0.351 3

0.593 3
0.557 3
0.618 3
1,263.6 1000 Gal
587.4 1000 Gal
306.0 1000 Gal
395.0 1000 Gal
217.2 1000 Gat
1.094.2 1000 Gal


241.9 1000 Gal
482.3 10x6CuFt
3.781.9 10x6CuFt

111.2 1000 Gal
107.2 10x6CuFt
770.5 10x6CuFt

319.0 1000 Gal
555.9 10x6CuFt
4,311.8 10x6CuFt

463.2 1000 Gal
638.1 10x6CuFt
4.832.8 10x6CuFt
139.00
139.00
139.00
139.00
139.00
139.00


150.00
500.00
100.00

150.00
500.00
100.00

150.00
500.00
100.00

150.00
500.00
100.00
175.640
81.649
42.534
54.905
30.191
152,094


36,285
241,150
378,190

16,680
53.600
77,050

47.850
277,950
431,180

69.480
319.050
483,280
97.7 AP-42
97.7 AP-42
97.7 AP-42
97.7 AP-42
97.7 AP-42
97.7 AP-42


87.0 AP-42
137.3 Mul Stk Non-1 990
23.0 AP-42

66.5 AP-42
138.1 Mul Stk Non-1990
23.1 AP-42

67.1 AP-42
137.1 Mul Stk Non-1 990
23.0 AP-42

66.9 AP-42
137.3 Mul Stk Non-1 990
23.0 AP-42
2124
67.7
26.7
74.9
79.3
70.6
53.5
318.0
64.7
8.1
33.1
43.5
20.0
3.7
7.4
8.9
96.4
10.7
38.1
49.6
774.9
15.5
43.8
55.6
0.703
0.703
0.703
0.703
0.703
0.703
0.703
0.262
0360



0.263



0361



0.265



49
06/26/95
Target (Point Level)
PACT

127.8
37.0
77.2
9.0
77.6
6.4
32.7
248.9
66.6



75.3



77.3



69.5



Phase II

127.8
37.0
77.2
9.0
77.6
6.4
32.7
243.2
65.6



74.7



75.7



87.2



Phase III

127.8
37.0
173
9.0
11.6
6.4
32.1
182>4
49.2



77.7



56.6



65.4



Severe
• CROMBY
7.267


Affected 032 10100404 Residual Oil 7.930

0519 3
0.486 3
0.572 3

61.637.3 Tons
388.0 1000 Gal
8.380.8 1000 Gal

26.00
150.00
150.00

1,602,570
58.200
1,257.120

21.7 AP-42
67.0 AP-42
42.0 AP-42
857.8
667.6
668.8
13.0
176.0
0388
0.620


0.280
535.7
470.0


725.7
364.3
236.6


725.7
264.7
770.4


94.3
033 Clearfield Co - Outer Zone - Attainment
0021 PECO-SHAWVILLE
037
Affected 10100202 BMumtnous Coal
Affected 10100501 Distillate OH
032
Affected 10100202 Bituminous Coal
Affected 10100501 Distillate OH
033
Affected 10100212 Bituminous Coal
Affected 10100501 Distillate OH
034
Affected 10100212 Bituminous Coal

7,600


7,600


7,750


7,750



0.470 3
0.260 3

0.464 3
0.301 3

0.424 3
0.444 3

0.389 3


154,698.1 Tons
184.1 1000 Gal

150,219.3 Tons
139.8 1000 Gal

188.253.7 Tons
298.2 1000 Gal

152.413.0 Tons


24.00
137.00

24.00
137.00

24.00
137.00

24.00


3.712,754
25.222

3.605.263
19.153

4.518.089
40.653

3.657.912


29.3 Mul Stk Non-1 990
23.9 Mul Stk Non-1 990

29.2 Mul Stk Non-1990
24.3 Mul Stk Non-1 990

20.9 Mul Stk Non-1 990
24.1 Mul Stk Non-1 990

21.0 Mul Stk Non-1 990
8,037.0
2.2713
2,269.0
12
2.191.7
2.190.0
1.7
7,977.6
1.988.0
3.6
7.602.5
1.599.0
1.029
7.275


7-209


0.665


0.667

4,828.8
7.363.6


7.375.7


7.764.4


962.9

3,616.7
7.022.0


966.3


687.2


727.7

2,009.3
567.8


547.9


492.9


400.6


-------
Detail Report - Five Month Data
Point-Segment Level Data
Dmlgn S-Month
Plant Capacity Activity
Affected Point SCC/DetcrloHon (10i6Btu/hr) Fac/Code
Final OTC NOx Baseline Inventory
Pennsylvania
Heat Content Slate Emission
(10x6 Btu/ Heat Input Factor/Coda Con.
Fuel Use/Units SCCUnlt) (10x6 Btu) (Ibs/SCCUnlO En.
033 Clearf ield Co - Outer Zone - Attainment
0021 PECO-SHAWVILLE
034 1 7SO
Affected 10100501 Distillate Oil ' 0.317 3 291.8
035 Clinton Co - Outer Zone - Attainment
0008 INTERNATIONAL PAPER COMPANY
Affected 033 10800204 Bttumlnout Coal 256 0.383 3
Affected 034 10200204 Bttumlnout Coal 256 0.383 3

48.828.1
48.755.1
1000 Gal

Tons
Tons
137.00

25.00
25.00
39.977

1.220,703
1,218,878
24.0

13.7
13.7
MulStk Non-1 990

AP-42
AP-«2
Baseline
50
06/26/95
Five Emission Rate Target (Point Level)
Month (iba/IOxe Btu) RACT
8,037.0
1,602.5
3.5
8684
334.5
334.0
14)29
0.867
0348
0.548
0.548
4426.6
962.9
401.1
200.7
200.4
phase II
3,616.7
721.1
300.8
150.5
150.3
Phase in
2,0093
400.6
183.0
91.6
91.4
041 Cumberland Co - Outer Zone - Marginal
0045 METROPOLITAN EDISON COMPANY
Baiellne 031 20100201 Natural Gai 326 0.417 3
Baseline 032 20100201 Natural Gas 326 0.417 3
043 Dauphin Co - Outer Zone - Marginal
0013 HARRISBURG STEAM WORKS LTD.
Baseline 033 10100602 Natural Qas 209 0.116 3
045 Delaware Co - Inner Zone - Severe
0014 PHILADELPHIA ELECTRIC CO. - EDDYSTONE
031 2.604
Affected 10100212 Bituminous Coal 0.553 3
Affected 10100604 Natural Qas 0.544 3
032 2,708
Affected 10100212 Bituminous Coal 0.556 3
Affected 10100604 Natural Gas 0.580 3
033 3,997
Affected 10100404 Residual Otl 0.575 3
Affected 10100501 Distaste OH 0.497 3
Baseline 037 20100101 DistiasteOH 238 0.479 3
Baseline 039 20100101 DisHlate OB 238 0.518 3
Baseline 039 20100101 Distillate Oil 249 0.585 3
Baseline 040 20100101 Distillate Oil 249 0.732 3
041 3,997
Affected 10100404 Residual Oil 0.677 3
Affected 10100501 Distillate OH 0.337 3
0016 SCOTT PAPER CO.
034 277
Affected 10200601 Natural Gaa 0.485 3
035 799
Affected 10100101 Anthracite Coal 0.370 3

45.0
53.5


21.3



207.418.9
172.6

136.223.5
85.1

14,337.0
125.0
67.6
54.0
139.3
67.5

13.842.5
192.9


252.0

98.784.1

10x6 Cu Ft
10x6CuFt


10x6 Cu Ft



Tons
10x6CuFt

Tons
10x6CuFt

1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal

1000 Gal
1000 Gal


10x6 CuFt

Tons

1.037.00
1.037.00


1.030.00



26.00
1.032.00

26.00
1.028.00

149.00
140.00
140.00
140.00
140.00
140.00

149.00
140.00


1.050.00

15.00

46.665
55,480


21,939



5.392,891
178,123

3,541,811
87.483

2.1 36.21 3-
17,500
9,464
7,560
19.502
9,450

2,062.533
27.006


264.600

1,481.762

462.0
462.0


140.8



14.4
274.6

14.4
275.0

42.1
24.0
68.0
66.7
67.5
68.1

42.2
23.8


550.0

12

AP-42
AP-42






AP-42
AP-42

AP-42
AP-42

AP-42
AP-42
AP-42
AP-42
AP-42
AP-42

AP-42
AP-42


AP-42

Non-1990 Other CEMS
22.8
10.4
12.4

13
1.5

3,1183
1,517.1
1,493.4
23.7
992.5
980.8
11.7
303.5
302.0
1.6
2.3
1.8
4.7
2.3
294.3
292.0
2.3
1323
69.3
69.3
63.2
57.6
0448
0.446
0.446

0.137
0.137

0482
0.545


0.546


0.282


0.486
0.476
0.482
0.487
0.282


0.142
0.5/7

0.075

204
9.3
11.1

13
1.5

2469.7
1,231.2


805.7


21S.1


1.9
1.S
3.9
1.9
208.6


104.8
41.6

63.2

204
9.3
11.1

13
J.5

1,352.0
557. T


362.9


21S.1


1.9
1.5
3.9
1.9
208.6


89.7
26.5

63.2

204
9.3
11.1

13
1.5

1,0173
417.8


272.2


161.5


1.9
1.5
3.9
1.9
156.7


83.0
19.6

63.2


-------
Detail Report - Five Month Data
Point-Segment Level Data
Plant
Affected Point SCC/De*cr1otlon
Design 5-Month
Capacity Activity
(10x6 Btu/hr) Fac/Code
045 Delaware Co - Inner Zone - Severe
0016 SCOTT PAPER CO.
035 799
Affected 10100601 Natural Gas 0.465 3
0030 BP OIL, INC.
032 350
Affected 10200401 RetldualOil 0.155 3
Affected 30600104 Oat 0.318 3
033 3SO
Affected 10200401 Residual Oil 0.453 3
Affected 10200701 Process Gas 0.446 3
0049 CONGOLEUM CORP.
Affected 033 10200601 Natural Gas
047 Elk Co - Outer Zone -
0005 PENNTECH PAPERS, INC.
040
Affected 10200202 Bituminous Coal
Affected 10200401 Residual Oil
041
Affected 10200202 Bituminous Coal
Affected 10200401 Residual Oil
049 Erie Co - Outer Zone

300 0.667 3
Attainment

250
0.369 3
0.251 3
250
0.369 3
0.471 3
- Marginal
Final OTC NOx Baseline in
Pennsylvania
Heat Content
(10x6 Btu/ Heat Input
Fuel Use/Units SCO Unit) (10x6 Btu)
116.9
282.7
191.5
2.117.8
250.8

4.3



21.771.2
32.7

22.932.8
47.8

10x6 Cu Ft
1000 Gal
10x6CuFt
1000 Gal
10x6CuFt

10x6CuFt



Tons
1000 Gal

Tons
1000 Gal

1.030.00
158.00
1.500.00
134.00
1.003.00

1.020.00



26.00
151.00

26.00
151.00

120,407
44,667
287,250
283,785
251,552

4.386



566,051
4.938

596,253
7.218

ventory
State Emission
Factor/Code Con.
(Ibs/SCC Unit) Eff .
92.4
56.6
551.4
55.3
551.8

558.1



21.7
55.0

21.7
54.4

Non-1990 Other CEMS
AP-42
AP-42
AP-42
AP-42

AP-42



AP-»2
AP-42

AP-42
AP-42

0004 INTERNATIONAL PAPER CO.
Affected 037 10200204 Bituminous Coal
Affected 040 10200601 Natural Gas
0009 GENERAL ELECTRIC CO.
Affected 032 10200203 Bituminous Coal
Affected 035 10200204 Bituminous Coal
0016 PECO - FRONT STREET
Baseline 031 10100202 Bituminous Coal
Baseline 032 10100202 Bituminous Coal
Affected 033 10100212 Bituminous Coal
Affected 034 10100212 Bituminous Coal
276 0.374 3
075 0.417 3

416 0.311 3
260 0.266 3

226 0.703 3
226 0.703 3
597 0.416 3
587 0.416 3
13,414.9
262.3

23.487.2
13.616.3

1.623.5
1.661.7
41,335.5
41,341.1
Tons
10x6 Cu Ft

Tons
Tons

Tons
Tons
Tons
Tons
24.00
1,000.00

25.00
25.00

24.00
24.00
25.00
25.00
321,958
262,300

587,180
345.408

38.964
39.881
1.033,388
1,033,528
14.0
552.8

25.3
17.5

22.2
21.7
14.3
14.3
AP-42
AP-42

Non-1990 Other CEMS
Non-1 990 Other CEMS

AP-42
AP-42
AP-42
AP-42
Baseline
Ffv0 Enilvslon Rftto
Month (Ibt/IOxe Btu)
1323
63.2
5.4
188.6
60.8
8.0
52.8
127.8
58.6
692
1.2
1.2

4*7.2
237. 1
2362
0.9
250.1
248.8
1.3

166.4
93.9
72.5
417.7
296.7
121.0
628.0
18.0
18.0
296.0
296.0
0.142
0.075
0X35
0.365
0.478
0347
0.547

0.830
0.829


0.830



0370
0.583
0.553
OJ98
1.011
0.701
0385
0.924
0.903
0.573
0.573
51
06/26/95
Target (Point Level)
RACT Phase II Pfiase III
104.8
63.2
11X2
36.5
78.7
0.7
0.7

2923
f42.3


f50.f



99.8
56.3
43.5
250.6
178.0
72.6
486.7
>0.8
10.8
232.5
232.5
89.7
63.2
86.7
33.2
53.5
0.4
0.4

2194
fOS.7


112.6



74.9
42.3
32.fi
188.0
J33.5
54.5
288.0
70.9
fO.fi
J33.2
f33.2
83.0
63.2
6S.O
24.9
40.2
0.3
0.3

121.8
59.3


6215



43.8
24. f
f9.7
1044
74.2
30.3
176.6
10.8
10.8
77.5
77.5

-------
Detail Report - Five Month Data
Point-Segment Level Data
DtslQn 5-Mootfi
Plant Capacity Acllviey
Affecltd Point SCC/Detcrtotlon (10x8 Btuftir) Fac/Code
059 Greene Co - Outer Zone - Attainment
0006 WEST PENN POWER CO. - HATFIELD'S FERRY
031 5.034
Affected 10100202 BHumdioua Coal 0.432 1
Affected 10100501 Distillate Oil 0.417 3
032 5,034
Affected 10100202 Bituminous Coal 0.376 1
Affected 10100501 Distillate Oil 0.417 3
033 5.034
Affected 10100202 BHuminoua Coal 0.296 1
Affected 10100501 Distillate Oil 0.417 3
063 Indiana Co - Outer Zone - Attainment
0001 PECO-CONEMAUGH
031 7.800
Affected 10100212 Bituminous Coal 0.420 3
Affected 10100501 Distillate Oil 0.547 3
032 7.800
Affected 10100212 Bltumlnoua Coal 0.423 3
Affected 10100501 Distillate Oil 0.365 3
0002 PECO-SEWARD
032 374
Affected 10100202 Bltumlnoua Coal 0.367 3
Affected 10100501 Distillate Oil 0.427 3
033 374
Affected 10100202 Bltumlnoua Coal 0.415 3
Affected 10100501 Distillate OH 0.468 3
931 1,243
Affected 10100212 Bituminous Coal 0.441 3
Affected 10100501 Distillate Oil 0.540 3
0003 PECO - HOMER CITY
031 6,120
Affected 10100202 Bltumlnoua Coal 0.321 3
Affected 10100501 Distillate OH 0.122 3
02? 6.120
Affected 10100202 Bltumlnoua Coal 0.391 3
Affected 10100501 Distillate Oil 0.486 3
033 6,208
Affected 10100202 Bltumlnoua Coal 0.446 3
Affected 10100501 Distillate OH 0211 3
Final OTC NOx Baseline Inventory
Pennsylvania
Heat Content State Emission
(10x6 Btu/ Heat Input Factor/Coda Con.
Fuel Use/Urrita SCO Unit) (10x6 Btu) (Ibs/SCCUnlt) Eft.



569.960.0
0.0

526.544.0
0.0

308,289.0
0.0



802.905.6
417.6

1.020,947.0
1392


34.355.7
180.8

33.243.0
81.6

172.558.8
101.2


451.780.1
221.4

614.170.3
201.1

809.969.9
597.2



Tons
1000 Gal

Tons
1000 Gal

Tons
1000 Gal



Tons
1000 Gal

Tone
1 000 Gal


Tons
1000 Gal

Tons
1000 Gal

Tons
1000 Gal


Tons
1000 Gal

Tons
1000 Gal

Tons
1000 Gal



2720
141.00

27.30
141.00

27.30
141.00



25.00
139.00

25.00
139.00


24.00
137.00

24.00
137.00

24.00
137.00


25.00
139.00

25.00
139.00

27.00
137.00



15,502,912
0

14,429.251
0

6.416290
0



20.072.640
58,046

25.523.675
19.349


824.537
24.770

797.832
11.179

4,141.411
13,864


11294,503
30.775

15.354258
27.953

21.869.187
81.816



282
0.0

28.5
0.0

28.4
0.0



19.0
20.1

19.0
20.1


19.5
19.9

202
24.5

18.0
19.8


30.1
19.9

30.1
19.9

16.7
20.1



Non-1990 Other CEMS
Non-1 990 Other GEMS

Non-1990 Other CEMS
Non-1990 Other CEMS

Non-1990 Other CEMS
Non-1 990 Other CEMS



Non-1990 Other CEMS
Non-1990 Other CEMS

Non-1990 Other CEMS
Non-1990 Other CEMS


Non-1990 Other CEMS
Non-1990 Other CEMS

Non-1990 Other CEMS
Non-1990 Other CEMS

Non-1990 Other CEMS
Non-1990 Other CEMS


Non-1990 Other CEMS
Non-1 990 Other CEMS

Non-1990 Other CEMS
Non-1 990 Other CEMS

Non-1990 Other CEMS
Non-1990 Other CEMS

FNe
Month

19,955.0
8.049.8
8.049.0
0.8
7,520.4
7,520.0
0.4
4,384.8
4,384.0
0.8

17,355.6
7.640.2
7.636.0
42
9.715.4
9.714.0
M
2227J
336.0
335.0
1.8
336.0
335.0
1.0
f ,555.0
1,554.0
1.0
22.8152
0.793.2
8.791.0
22
9^35.0
9233.0
2.0
8.787.0
6.781.0
6.0
PaiaHna
Emission Rate
(lba/10x6Btu>

1.041
1.042


1.041


1.040



0.760
0.759


0.76f


0.768
0.795


O.fl29


0.748


0,938
T20f


1301


0.819




52
06/26/95
Target (Point Laval)
PACT

11,973.0
4,829.9


4.S12.2


2.630.9



10/415.6
4,585.8


5.829.8


1.J4JJ
207.9


202.0


933.4


15.091.9
4.076.8


S.S41.8


5.473.3


Phase II

8.979.8
3.622.4


3,384.2


1.973.2



7,810.0
3.438. 1


4.371.9


1,0023
151.6


151.2


699.8


10266.8
3.056.9


4.155.8


3.0543


Phase ill

4,988.8
2.012.5


1.880.1


1.096.2



4,338.9
».9»0.»


2.428.9


557.0
B42


84.0


388.8


5,7034
1,698.3


2.308.8


1,696.8


069 Lackawanna Co - Outer Zone - Marginal
0022 ARCHBALD POWER CORPORATION
Baseline 03f 10100101 Anthracite Coal 249 0.336 3

20.689.8

Tons

10.00

206.898

2.4

State Factor
2SJ
25.3
0245
0.24S
2S.3
25.3
25.3
25.3
254
25.3

-------
Detail Report - Five Month Data 1
Point-Segment Level Data
Design 5-Month
Plant Capacity Activity
Affected Point SCC/De«crtD«on (10x8 Btu/hr) Fac/Code
Final OTC NOX Baseline in1
Pennsylvania
Heat Content
(10x6 Btu/ Heat Input
Fuel Use/Units SCO Unit) (10x6 Btu)
071 Lancaster Co - Outer Zone - Marginal
0054 PP&L-HOLTWOOD
934 966
Affected 10100101 Anthracite Coal 0.417 3 132,324.9
Affected 10100s6l Distillate Oil 0.556 3 19.5
Affected 10100801 Coke 0.424 3 29.066.3
073 Lawrence Co - Outer Zone - Attainment
0025 PENN POWER CO. - NEW CASTLE
Affected 031 10100202 Bituminous Coal 495 0.417 3
Affected 032 10100202 Bituminous Coal 640 0.417 3
Affected 039 10100202 Bituminous Coal 7,029 0.417 3
Affected 034 10100202 Bituminous Coal 1.029 0.417 3
Affected 035 10100202 Bituminous Coal 1,325 0.417 3
079 Luzerne Co - Outer Zone - Marginal
0014 UGI CORP. - MUNLOCK POWER
Affected 031 10100101 Anthracite Coal 553 0.416 3
089 Monroe Co - Outer Zone - Marginal
SHAW MET EDISON SHAWNEE
Baseline 031 20100101 Distillate Oil 150 0.586 1
093 Montour Co - Outer Zone - Attainment
0003 PP&L- MONTOUR
03T 7,3/7
Affected 10100212 Bituminous Coal 0.385 3
Affected 10100501 Distillate Oil 0.407 3
032 7,239
Affected 10100212 Bituminous Coal 0.415 3
Affected 10100501 Distfllete OH 0.200 3
Affected 033 10100501 Distillate OH 269 0.468 3
Affected 034 10100501 Distillate OH 269 0.358 3

23,083.1
20.773.3
39.470.5
72,416.5
132,628.8


95,848.8


110.3



690.467.6
193.2

906,746.8
49.2
317.4
243.4
Tons
1000 Gal
Tone

Tons
Tons
Tons
Tons
Tons


Tons


1000 Gal



Tons
1000 Gal

Tons
1000 Gal
1000 Gal
1000 Gal
22.00
139.00
22.00

24.00
24.00
24.00
24.00
24.00


19.00


139.00



27.00
140.00

27.00
140.00
140.00
140.00
2,911,148
2.711
639.459

553,994
498,559
947,292
1,737.996
3.183.091


1.821,127


15,285



18.642,625
27.048

24.482.164
6.888
44,436
34,076
rentory
State Emission
Factor/Code Con.
(Ibs/SCC Unit) Etf.
23.2
20.5
23.2

21.8
21.8
21.7
21.7
21.7


18.0


81.6



20.9
23.8

26.4
24.4
23.9
23.8
Non-1990 5 Mo. CEMS
Non-1990 5 Mo. CEMS
Non-1 990 5 Mo. CEMS

AP-42
AP-42
AP-42
AP-42
AP-42


AP-42


Sing Slk Rep Cond



Non-1 990 Other CEMS
Non-1990 Other CEMS

MulStk Non-1 990
MulStk Non-1990
AP-42
AP-42
Ba
• •ihiti
IMIpTIV
Five Emission Rat
Month flbs/10x6 Btu
1,870.3
1.870.3
1.533.3
0.2
336.8
3,132.6
251. f
226.2
429.0
787.1
1.4392

862.6
862.6

4J5
4.5

19,219.2
7.2229
7,220.6
2.3
11,989.6
11,989.0
0.6
3.8
2.9
1.053
1.053
0.905
0.907
0.907
0.906
0.906
0.904

0.947
0.947

0.589
0.588

0.889
0.774


0.979


0.171
0.170

53
06/26/95
» Target (Point Level)
) PACT
1.122J
1.122.3
1379.6
150.7
13S.7
2S7.4
472.3
863.5

517.6
5J7.6

3.1
3.1

11,535.4
4,334.7


7.194.0


3.8
2.9
Phase II
841.6
841.6
1 ,409.7
113.0
101.8
193.1
3S4.2
647.6

3993
388.2

3.1
3.1

8,652.3
3.250.3


5.395.3


3.8
2.9
Phase ffl
467.6
467.6
783.2
62.8
56.6
107.3
196.8
359.8

215.7
2T5.7

3.1
3.f

4,809.0
1.805.7


2.997.4


3.3
2.6
095 Northampton Co - Outer Zone - Marginal
0010 PP&L -MARTINS CREEK
031 1815
Affected 10100201 Bituminous Coal 0.277 3
Affected 10100501 Distillate Oil 0.458 3
03i '.*'*
Affected 10100201 Bituminous Coal 0.385 3
Affected 10100601 Distillate Oil 0.375 3


103.366.7
248.6

114,167.4
142.9


Tons
1000 Gal

Tons
1000 Gal


27.00
140.00

27.00
139.00


2,790.901
34,804

3.063.060
19.863


32.5
24.1

24.8
23.8


MulStk Non-1 990
MulStk Non-1 990

MulStk Non-1 990
MulStk Non-1 990
5.8433
1.684.6
1.681.6
3.0
1.417.7
1,416.0
1.7
0.864
1.192


0.913


3.517.5
1.012.0


851.3


2,633.9
758. 1


638.0


1,595.6
421.2


354.4



-------
Detail Report - Five Month Data
Point-Segment Level Data
Design
Pbnt Capacity
Affected Point SCC/Descrlotlon (J0x8 Bhi/hrt
095 Northampton Co - Outer
0010 PP&L- MARTINS CREEK
033
Affected 10100404 Residual Oil
Affected 10100501 Distillate Oil
034
Affected 10100404 Residual Oil
Affected 10100501 Distillate OH
Baseline 035 10100501 Distillate OH
Affected 036 10100501 Distillate OH
Affected 037 10100501 Distillate Oil
Affected 038 10100501 Distillate Oil
Affected 039 10100501 Distillate Oil
Affected 040 10100501 Distillate Oil
001 1 MET EDISON CO. - PORTLAND
031
Affected 10100212 Bituminous Coal
Affected 10100501 Distillate Oil
032
Affected 10100212 Bituminous Coal
Affected 10100501 Distillate Oil
033
Affected 10100601 Natural Oat
034
Affected 10100601 Natural Oat
0048 BETHLEHEM STEEL CORP.
04 r
Affected Conf.
Affected Conf.
Affected Conf.
042
AfnMtOd Corn.
Affected Conf.
Affected Conf.
067
Affected Conf.
Affected Conf.
Affected Conf.
Zone

7.721


7.721


243
323
350
3SO
3SO
3SO

1.477


2,113


305

344


0



0



0



5-Month
Activity
Fac/Code
Final OTC NOx Baseline Inventory
• Pennsylvania
Heat Content State Entlaalon
(10x6 Btu/ Heat Input Factor/Code Con.
Fuel Use/Units SCO Unit) (10x6 Btu) (Iba/SCC Unit) EH.

Five
BfttMflnt
Emission Rate
(Ibt/10x8 Btu)
- Marginal


0.697 3
0.662 3

0.627 3
0.548 3
0.370 3
0.145 3
0.654 3
0.654 3
0.654 3
0.654 3


0.502 3
0.354 3

0.410 3
0.462 3

0.312 3

0.527 3


0.000 0
0.000 0
0.000 0

0.000 0
0.000 0
0.000 0

0.000 0
0.000 0
0.000 0


37.646.6 1000 Gal
35G.9 1000 Gal

33.308.7 1000 Gal
973.2 1000 Gal
32.8 1000 Gal
17.1 1000 Gal
1,476.0 1000 Gal
1,476.0 1000 Gal
1,476.0 1000 Gal
1,476.0 1000 Gal


136,718.5 Ton»
282.1 1000 Gal

174.418.0 Tons
314.7 1000 Gal

9.5 10x6CuFt

39.7 10x6CuFt


0.0
0.0
0.0

0.0
0.0
0.0

0.0
0.0
0.0


150.00
140.00

150.00
140.00
140.00
140.00
140.00
140.00
140.00
140.00


26.00
138.00

26.00
138.00

1,031.00

1.031.00


0.00
0.00
0.00

0.00
0.00
0.00

0.00
0.00
0.00


5,646,990
49,966

4,996.305
138,248
4,592
2,394
206,640
206.640
206,640
206,840


3,554,681
38,930

4,534,868
43.429

9,795

40,931


0
0
0

0
0
0

0
0
0


76.8 MulStk Non-1990
24.1 MulStk Non-1990

76.6 MulStK Non-1 990
24.0 MulStk Non-1 990
24.4 AP-42
23.4 AP-42
2.4 AP-42
2.4 AP-42
2.4 AP-42
2.4 AP-42


15.6 Sing Stk Rep Cond
24.1 AP-42

17.4 Sing Stk Rep Cond
24.2 AP-42

547.4 AP-42

549.1 AP-42


0.0
0.0
0.0

0.0
0.0
0.0

0.0
0.0
0.0
5.8435
1,445.8
1.441.5
4.3
1.287.6
1,275.9
11.7
0.4
0.2
1.8
1.8
1.8
1.8
2,601.2
1,080.5
1,063.1
3.4
f,52f.2
1,517/4
3.8
2.6
2.6
10.9
10.9
378.7
144.9
29.2
57.8
67.9
1S0.4
232
89.9
37.3
83.4
4.8
52.0
26.6
0.664
0.504


0.504


O.f74
0.167
0.017
0.017
0.017
0.017
0.633
0.594


0.097


O.S18

O.S28

0.000
0.231



0354



0327





54
06/26/95
Target (Point Level)
RACT

3,517.5
869.2


777.2


0.4
0.2
1.8
1.8
1.8
1.8
1,8354
603.2


t,024.f


f.0

0.5

287.1
110.6



112.2



64.3



Phase II

2,633.9
050.0


579.4


0.4
0.2
1.8
1.8
1.8
1.8
1.170.5
479.9


084.5


1.2

4.9

287.1
110.6



1123



64.3



Phase III

1,5954
427.3


384.9


0.4
0.2
1.8
1.8
1.8
1.8
653.6
209.5


380.3


0.7

3.f

242.1
95.2



92.4



54.5



097 Northumberland Co - Outer Zone - Attainment
0031 FOSTER WHEELER MT. CARMEL
Affected 031 10101001 Butane
624
0.333 3
83.434.1 Tons
7.00
584.039
0.7 Non-1 990 Other CEMS
27*
27.6
0.09S
0.095
27.6
27.6
27.6
27.6
27.6
27.0

-------
Detail Report - Five Month Data
Point-Segment Level Data
DMlgn
Plant Capacity
Aflectad Point SCC/Deseriotlon (10x6 Btu/hr)
\
5-Month
Activity
Fac/Code
101 Philadelphia Co - Inner Zone - Severe
1501 SUN REFINING AND MARKETING 1 OF 2
006 376
Affected 10200601. Natural OM 0.417 3
Affected 30600103 OK 0.417 3
007 310
Affected 10200601 Natural QM 0.417 3
Affected 30600103 Oil 0.417 3
030 260
Affected 10200601 Natural Gas 0.417 3
Affected 30600103 Oil 0.417 3
039 260
Affected 10200601 Natural Gas 0.417 3
Affected 30600103 Oil 0.417 3
1 551 ALLIED CHEMICAL CORP
050 294
Affected 10200401 RealdualOII 0.417 3
Affected 10200601 Natural Qa* 0.417 3
051 294
Affected 10200401 RealdualOII 0.417 3
Affected 10200601 Natural Oat 0.417 3
052 379
Affected 10200401 RealdualOII 0.417 3
Affected 10200601 Natural Gas 0.417 3
1566 CONTAINER CORP OF AMER
00» 273
Affected 10200202 Bituminous Coal 0.390 3
Affected 10200401 Residual Oil 0.390 3
4901 PECO ENERGY - DELAWARE
013 1.267
Affected 10100401 Residual Oil 0.457 1
Affected 10100501 Distillate OH 0.563 3
014 ',»*
Affected 10100401 Residual Oil 0.429 1
Affected 10100501 Distillate OH
Baseline 075 20100101 Distillate Oil
Baseline 016 20100101 Distillate Oil
Baseline Of 7 20100101 Distillate OH
Basellntf 018 20100101 Distillate OH
4902 PHILA THERMAL -SANSOM
Affected 001 10100401 Residual Oil
Affected 002 10100401 Residual Oil
Affected 003 10100401 Residual Oil

273
273
273
297

281
281
337
0.523
0.526
0.523
0.600
0.581

0.360
0.410
0.553
3
1
1
1
1

3
3
3
-mai OTC NUX Baseline irv
Pennsylvania
Heat Content
(10x6Btu/ Heat Input
Fuel Use/Units SCO Unit) (10x6 Btu)
369.2
493.8
572.9
1.032.5
228.8
2.055.8
228.8
2.055.8
351.7
37.5
71.3
136.3
1.875.4
284.2
18,564.0
574.5
5,981.0
106.5
6.989.0
118.3
51.0
68.0
81.0
108.0

2.123.1
1,871.7
645.5
10x6CuFt
1000 Gal
10x6CuR
1000 Gal
10x6CuFt
1000 Gal
10x6CuFt
1000 Gal
1000 Gal
10x6CuFt
1000 Gal
10x6CuFt
1000 Gal
10x6CuFt
Tons
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal
1000 Gal

1000 Gal
1000 Gal
1000 Gal
1.183.00
155.00
1.183.00
155.00
1,183.00
155.00
1,183.00
155.00
150.00
1,000.00
150.00
845.00
150.00
1,000.00
227.00
227.00
151.00
140.00
150.00
150.00
139.00
139.00
139.00
139.00

150.00
150.00
150.00
436,724
76,531
677,760
160.038
270.611
318,654
270,61 1
318.654
52.750
37.500
10.688
115.131
281.313
284,167
4,214.028
130,405
903.131
14,906
1,046.350
17.741
7.089
9.452
11.259
15,012

316,459
260,748
126.824
/entory
State Emission
Factor/Code Con.
flbs/SCCUnlt) Eft.
550.7
55.0
549.8
55.0
550.0
55.0
550.0
55.0
55.0
550.0
55.0
549.8
55.0
549.9
21.0
55.0
68.0
24.0
67.5
24.0
93.1
93.1
93.1
93.1

67.0
67.0
67.0
AP-42
AP-42

Sing Slk Rep Cond
Sing StK Rep Cond
Sing Stk Rep Good
Sing 8tk Rep Cond





Five Emission Rate
Month Oba/10x6 Btu)
540.0
1162
101.7
13.6
18S.9
1675
28.4
If 9.5
62.9
56.5
119.5
62.9
56.5
189.1
20.0
9.7
10.3
39.4
2.0
375
»29.7
51.6
78.1
210.7
2»0.7
194.9
15.8
456.1
204.5
2032
1.3
237.3
235.9
1.4
2.4
3.2
3.8
5.0
1965
7f.»
62.7
28.3
0427
0.449
0.444
0.405
0.405
0.484
0.443
0.627
0.459
0.097
0.097
0X50
0.446
0.446

0.670
0.670
0.670
0.670
0X47
0.447
0.447
0.447
55
06/26/95
Target (Point Level)
PACT Phase II Phase III
324.0
69. 7
111.6
71.7
71.7
113.5
»2.0
23.7
77.6
208.0
208.0
304.0
T36.7
»58.7

f.4
».9
2.3
3.0
132.2
47.6
42.7
19.0
253.0
5J.3
83.8
58.9
58.9
79.4
9.0
13.8
56.5
208.0
208.0
207.0
91.8
106.6

1.4
1.9
2.3
3.0
88.1
31.8
28.1
12.7
189.7
38.5
62.6
44.2
44.2
59.0
6.6
9.9
42.4
208.0
208.0
157.4
68.9
80.0

f.4
1.9
2.3
3.0
66.1
23.9
21. 1
9.5

-------
Detail Report - Five Month Data Final OTC NOx Baseline Inventory
Point-Segment Level Data Pennsylvania
DMlgn 5-Month Heat Content State Emission
Plant Capacity Activity (10x6 Btu/ Heat Input Factor/Cod* Con.
Affected Point SCC/D«lcrlDtton (10x8 Btu/hr) Fae/Code Fuel Use/Units SCCUnll) (10x6 Btu) Obs/SCCUnlt) Eft.
101 Philadelphia Co - Inner Zone - Severe
4902 PHILA THERMAL -SANSOM
Affected 004 10100401 Residual Oil 337 0.617 3 1.034.2 1000 Gal
4903 PHILA ELECTRIC CO
Baseline 037 20100101 Distillate OH 743 0.495 1 845.0 1000 Gal
Baseline 038 20100101 DtatJnate Oil 743 0.507 1 1.125.0 1000 Gal
4904 PECO ENERGY -SCHUYLKILL
003 1.623
Affected 10100404 Residual Oil 0.377 1 9.744.0 1000 Gal
Affected 10100501 Distillate Oil 0.447 3 S7.6 1000 Gal
Baseline 007 20100101 Distillate Oil 217 0.510 1 66.6 1000 Gal
Baseline 008 20100101 Distillate Oil 240 0.159 t 14.0 1000 Gal
4942 PHILA THERMAL - SCHUYLKILL
Affected 001 10100404 Residual Oil 775 0.270 3 3,407.9 1000 Gal
Affected 002 10100404 Residual Oil 775 0.147 3 1.521.1 1000 Gal
Affected 005 10100401 Residual Oil 757 0.147 3 1.654.3 1000 Gal
9702 U.S. NAVAL BASE
Affected 090 10200501 Distillate Oil 384 0.330 3 102.1 1000 Gal
Affected 099 10200501 Distillate Oil 317 0.667 3 14.0 1000 Gal
107 Schuylkill Co - Outer Zone - Attainment
0022 WHEELABRATOR FRACKVILLE ENERGY COMPANY
Affected 03! 10100101 Anthracite Coal 504 0.376 3 178.122.2 Tons
0023 WESTWOOD ENERGY PROPERTIES, INCORPORAT
Affected 031 10100101 Anthracite Coal 423 0.415 3 160.879.0 Tons
0024 SCHUYLKILL ENERGY RESOURCES, INC.
Affected 031 10100101 Anthracite Coal 1.184 0.565 3 416.106.4 Tons
0025 GILBERTON POWER COMPANY
03r 520
Affected 10100101 Anthracite Coal 0.406 3 95.936.2 Tons
032 520
Affected 10100101 Anthracite Coal 0.406 3 95.936.2 Tons
150.00
139.00
139.00
149.00
140.00
139.00
139.00
150.00
150.00
150.00
140.00
140.00
9.00
6.00
7.00
15.00
15.00
155.123
117,455
156.375
1,451.656
6.067
9.285
1,946
511,191
228,162
248.138
14,294
1.960
1.603.100
1,287,032
2.912.745
1.439.043
1.439.043
67.0
63.4 Sing Stk Rep Cond
63.4 Sing Stk Rep Cond
41.7 AP-42
24.0
93.1 Sing Stk Rep Cond
93.1 Sing Stk Rep Cond
42.0
42.0
67.0
20.0
20.0
1.2 1990 Other CEMS
16.0 AP-42
0.6 1990 Other CEMS
2.0 1990 Other CEMS
2.0 1990 Other CEMS
Baseline
Five Emission Rate
Month (Ibs/IOrtBtu)
19C.8
34.6
912
35.2
46.9
207.7
204.0
203.3
0.7
3.1
0.7
158.9
71.6
31.9
SS.4
1.2
1.0
0.1
108.8
108.8
1,447.9
7,447.9
175.0
17S.9
187.6
03.0
93.8
93.0
93.8
0X47
0.447
0.600
0.600
0.600
0.282
0260
0.670
0.670
0422
0260
0280
0.447
0.143
0.143
0.143
0.136
0.736
2£SO
2250
0.121
0.121
0.130
0.134
0.134
56
06/26/95
Target (Point Level)
PACT
132.2
23.3
54.6
23.5
31.3
148.1
745.9
1.9
0.4
111.2
51. 1
22.8
37.2
1.2
f.O
0.1
108.8
ro0.fi
868.7
868.7
175.9
175.9
187.6
93.0
93.6
phase II Phase ill
88.1
75.5
54.8
23.5
37.3
148.1
745.9
1.9
0.4
•8.7
5U
22.6
24.0
1.2
1.0
0.1
108.8
roe.a
651.6
65T.6
175.9
175.9
187.8
93.6
93.0
66.1
11.6
54.8
2*5
3T.3
111.8
709.5
7.9
0.4
74.1
30.3
77.7
T6.6
1.2
7.0
0.7
108.8
700.0
362.0
3620
175.9
T75.9
187.6
93.6
93.6

-------
Detail Report - Five Month Data
Point-Segment Level Data
Design
Plant Capacity
Affected Point SCC/DetcrlDtJon (10x6 Btu/hr)
109 Snyder Co - Outer Zone
0002 PP&L-SUNBURY
031
Affected 10100101 Anthracite Coal
Affected 10100202 Bituminous Coal
Affected 10100501 Distillate Oil
Affected 10100801 Coke
Affected 10200101 Anthracite Coal
032
Affected 10100101 Anthracite Coal
Affected 10100202 Bituminous Coal
Affected 10100501 Distillate Oil
Affected 10100801 Coke
Affected 10200101 Anthracite Coal
033
Affected 10100101 Anthracite Coal
Affected 10100202 Bituminous Coal
Affected 10100501 Distillate Oil
Affected 10100801 Coke
Affected 10200101 Anthracite Coal
034
Affected 10100101 Anthracite Coal
Affected 10100202 Bituminous Coal
Affected 10100501 Distillate Oil
Affected 10100801 Coke
Affected 10200101 Anthracite Coal
035
Affected 10100202 Bituminous Coal
Affected 10100501 Distillate Oil
036
Affected 10100202 Bituminous Coal
Affected 10100501 Distillate Oil
Baseline 037 20100102 Distillate Oil
Baseline 039 20100102 Distillate Oil
Baseline 039 20100101 Distillate Oil
Baseline 040 20100101 Distillate Oil
123 Warren Co - Outer Zone
0004 PECO -WARREN
03J
Affected 10100202 Bituminous Coal
Affected 10100501 Distillate Oil
032
Affected 10100202 Bituminous Coal
Affected 10100501 Distillate OH
033
Affected 10100202 Bituminous Coal
Affected 10100501 Distillate Oil
I
5-Month
Activity
Fac/Code
- Attainment
525
0.423 3
0.423 3
0.399 3
0.414 3
0.454 3
525
0.423 3
0.423 3
0.399 3
0.414 3
0.454 3
525
0.423 3
0.423 3
0.399 3
0.414 3
0.454 3
525
0.423 3
0.423 3
0.399 3
0.414 3
0.454 3
1,100
0.466 3
0.343 3
1.360
0.527 3

300
308
347
347
0.351 3
0.447 3
0.489 3
0.766 3
0.766 3
Final OTC NUX Baseline in
Pennsylvania
Heat Content
(10x« Btu/ Heat Input
Fuel Use/Units SCC Unit) (10x6 Btu)
8.494.9 Tons
6.108.7 Tons
18.0 1000 Gal
14.264.7 Tons
46,640.5 Tons
8.494.9 Tons
6.108.7 Tons
18.0 1000 Gal
14.264.7 Tons
46,640.5 Tons
8.487.7 Tons
6.108.6 Tons
18.0 1000 Gal
14.266.5 Tons
46.640.6 Tons
8,487.7 Tons
6.108.6 Tons
18.0 1000 Gal
14,266.5 Tons
46.640.6 Tons
136.129.0 Tons
21.2 1000 Gal
159,377.6 Tons
66.5 1000 Gal
5.1 1000 Gal
5.8 1000 Gal
104.9 1000 Gal
104.9 1000 Gal
24.00
26.00
139.00
30.00
19.00
24.00
26.00
139.00
30.00
19.00
24.00
26.00
139.00
30.00
19.00
24.00
26.00
139.00
30.00
19.00
26.00
139.00
27.00
139.00
139.00
139.00
139.00
139.00
203.878
158.826
2.502
427,941
886.170
203.878
158.826
2.502
427.941
886.170
203.705
158.824
2.502
427.995
886,171
203,705
158.824
2.502
427.995
886.171
3.S39.354
2.947
4,303.195
9,244
709
806
14,581
14.581
ventory
State Emission
Factor/Cod* Con.
(Ibs/SCC Unit) Efl.
20.4
23.4
22.2
27.1
15.6
20.4
23.4
22.2
27.1
15.6
17.3
19.8
22.2
22.9
13.2
17.3
19.8
22.2
22.9
13.2
23.0
18.9
25.2
24.1
470.6
448.3
68.6
68.6
Non-1990 5 Mo. CEMS
Non-1 990 5 Mo. CEMS
Non-1 990 5 Mo. CEMS
Non-1 990 5 Mo. CEMS
Non-1 990 5 Mo. CEMS
Non-1990 5 Mo. CEMS
Non-1 990 5 Mo. CEMS
Non-1 990 5 Mo. CEMS
Non-1 990 5 Mo. CEMS
Non-1990 5 Mo. CEMS
MulStk Non-1990
MulStk Non-1 990
MulStk Non-1 990
Mul Stk Non-1990
Mul Stk Non-1990
Mul Stk Non-1 990
Mul Stk Non-1 990
Mul Stk Non-1990
Mul Stk Non-1 990
Mul Stk Non-1 990
Mul Stk Non-1 990
Mul Stk Non-1 990
Non-1 990 5 Mo. CEMS
Non-1 990 5 Mo. CEMS
AP-42
AP-42
AP-42
AP-42
Baseline
Five Emission Rate
Month nbs/10x6 Btu)
6,222.0
7»4.7
66.8
71.4
0.2
193.1
363.2
7M.7
86.8
71.4
0.2
193.1
363.2
604.7
73.4
60.4
0.2
163.4
307.3
604.7
73.4
60.4
0.2
163.4
307.3
1.564.1
1,563.9
0.2
2.009.4
2.008.6
0.8
1.2
1.3
3.6
3.6
0.852
0.85?
0.851
0.720
0.720
0.883
0.931

3.385
3.226
0.494
0.494
57
06/26/95
Target (Point Level)
RACT Phase II Phase III
3,774.4
428.9
428.9
382.2
382L2
938.5
f.206.0

0.9
1.0
2.9
2.9
2,803.3
327.6
321.6
272.1
272.1
703.8
904.2

0.9
1.0
2.9
2.9
1,560.8
178.7
178.7
151.2
1513
391.0
502.4

0.9
1.0
2.9
2.9
- Attainment

256


256


256




0.412 3
0.417 3

0.416 3
0.417 3

0.425 3
0.417 3


22.750.4 Tons
7.5 1000 Gal

22,724.9 Tons
8.0 1000 Gal

22.832.0 Tons
8.5 1000 Gal


25.00
142.00

24.00
142.00

25.00
142.00


568.760
1.065

545,398
1.136

570.800
1.207


15.4
26.7

15.4
25.0

15.3
23.5


Non-1 990 Other CEMS


Non-1990 Other CEMS


Non-1990 Other CEMS

707.4
f75.t
175.0
0.1
J75.J
175.0
0.1
f75.f
175.0
0.1
0.610
0.61S


0.641


0.612


570.4
T42.3


136.S


142.6


318.3
78.8


78.6


78.8


176.9
43.8


43.8


43.8



-------
Detail Report - Five Month Data
Point-Segment Level Data
Plant
Affected Point SCC/Deterlotlon
OeslQn 5-Month
Capacity Activity
(10x8 Btu/hr) Fee/Code
Final OTC NOx Baseline Inventory
Pennsylvania
Heat Content State Emission
(10x6 Btu/ Heat Input Factor/Code Con.
Fiml Usn/bnll* SCO Unit) (10x6 Btu) (Ibs/SCCUnlt) Eff.
123 Warren Co - Outer Zone - Attainment
0004 PECO -WARREN
034 256
Affected 10100202 Bituminous Coal 0.436 3 23,606.8 Tons
Affected 10100501 Distillate Oil 0.417 3 6.5 1000 Gal
125 Washington Co - Outer Zone - Moderate
0014 WEST PENN POWER CO. - MITCHELL
034 2,546
Affected 10100202 Bituminous Coal 0.368 1 229.557.0 Tons
Affected 10100604 Natural Gas 0.397 3 0.0 10x6CuFt
0024 DUQUESNE LIGHT CO. - ELRAMA
031 f,090
Affected 10100202 Bituminous Coal 0.315 3 44.661.5 Tons
032 1.146
Affected 10100202 Bituminous Coal 0.338 3 46.200.0 Tons
033 1,156
Affected 10100202 Bituminous Coal 0.348 3 59,624.6 Tons
034 1,790
Affected 10100202 Bituminous Coal 0.462 3 138.700.0 Tons
129 Westmoreland Co - Outer Zone - Moderate
0007 MONESSEN INC.
Affected 037 10200707 Process Gas

930

0.419 3

1.092.9 10x6 Cu Ft
25.00
142.00
26.00
1.050.00
25.00
25.00
25.00
24.50

538.00
595.170
1.207
5.968,482
0
1.116,538
1,114.175
1.490,615
3.398.150

587.980
15.3 Non-1990 OthofCEMS
23.5
18.8 Non-1990 Other CEMS
0.0 Non-1990 Other CEMS
21.7 AP-12
21.7 AP-42
21.7 AP-42
21.7 AP-42

80.0 AP-42
Baseline
Five Emission Rate
Month (Ibs/IOrt Btu)
707.4
102.1
182.0
0.1
2,167.2
2, 1 57.2
2,156.0
1.2
3,138.2
484.?
484.1
S01.3
501.3
647.9
647.9
r.504.9
1,504.9
43.7
43.7
0.619
O.CJf
0.723
0.724
0.882
0.667
0.075
0.070
0.686
0.149
0.749
58
06/26/95
Target (Point Level)
RACT Phase II Phawill
570.4
148.9
1,4924
1,492.$
1,882.9
290.5
300.6
380.7
902.9
43.7
43.7
3164
81.9
970.7
970.7
1 ,412.2
217.8
225.6
297.6
677.2
43.7
43.7
176.9
45.5
639.3
539.3
784.S
121.0
125.3
162.0
376.2
43.7
43.7
131 Wyoming Co - Outer Zone - Marginal
0009 PROCTER & GAMBLE PAPER PRODUCTS CO.
Affected 035 20200203 Natural Gas
133 York Co - Outer Zone -
0016 GLATFELTER, P. H. CO.
03r
Affected 10200401 Residual Oil
Affected 30700104 Other
034
Affected 10200202 Bituminous Coal
Affected 10200401 Residual Oil
035
Affected 10200202 Bituminous Coal
Affected 10200401 Residual CHI
036
Affected 10200219 Bituminous Coal
575
0.395 3
1.654.8 10x6 Cu Ft
1.000.00
1,654,800
683.6 Non-1990 Other CEMS
565.6
565.6
0.684
0.604
339.S
339.5
254.5
254.5
141.4
T4T.4
Marginal

370


357


257


507



0.462 3
0.404 3

0.415 3
0.477 3

0.343 3
0.527 3

0.450 3


62.3 1000 Gal
59,480.5 Tons

36.039.8 Tons
39.4 1000 Gal

18.409.3 Tons
21.5 1000 Gal

59.290.0 Tons


150.00
11.00

27.00
150.00

27.00
150.00

27.00


9.345
654.286

973,075
5,910

497,051
3.225

1.600.830


54.6 AP-42
1.8 AP-42

21.7 AP-42
55.8 AP-42

21.7 AP-42
55.8 AP-42

7.9 AP-42
$81.6
55.2
1.7
53.5
392 f
391.0
1.1
200.3
199.7
0.6
233.9
233.6
0.471
O.T66


0.60?


0.602


0.292

570.3
54.5


235.3


120.2


160.3

481.4
54.5


176.5


90.2


160.3

318.1
49.6


96.0


50.1


120.2


-------
Detail Report - Five Month Data
Point-Segment Level Data
Plant
Affected Point

SCC/DescrlDtlon
1 33 York Co - Outer Zone •
0016 GLATFELTER, P. H. CO.
036
Affected 10200405 Residual Oil
0020 PP&L-BRUNNER ISLAND
03?
Affected 10100212 Bituminous Coal
Affected 10100501 Distillate OH
93T
Affected 10100212 Bituminous Coal
Affected 10100501 Distillate Oil
933
Affected 10100212 Bituminous Coal
Affected 10100501 Distillate Oil
TOLN MET
Baseline 03t
Baseline 032
EDISON TOLNA
20100101 Distillate Oil
20100101 Distillate ON
Design
Capacity
(10x6 Btu/hr)
Final OTC NOx Baseline Inventory
Pennsylvania
5-Month Heat Content State Emission
Activity
Fac/Code
• Marginal
507
0.148 3
3.726
0.376 3
0.411 3
3.349
0.402 3
0.330 3
7.140
0.458 3
0.406 3

150
ISO

0.734 1
0.760 1
(10x6 Btu/
Fuel Use/Units SCC Unit)
13.4 1000 Gal
378.098.3 Tons
373.6 1000 Gal
332.996.5 Tons
340.3 1000 Gal
747.666.2 Tons
375.5 1000 Gal

177.0 1000 Gal
139.6 1000 Gal
150.00
27.00
138.00
27.00
138.00
27.00
138.00

138.00
138.00
Heat Input
(10x6 Btu)
2.010
10.208.654
51.557
8.990.906
46.961
20.166.987
51.819

20,492
19.306
Factor/Cod* Con.
(Ibs/SCC Unit) EH.
44.8 AP-42
17.0 MulStk Non-1 990
24.1 MulStk Non-1 990
16.5 MulStk Non-1 990
24.1 MulStk Non-1 990
192 Non-19905Mo.CEMS
24.0 Non-1 990 5 Mo. CEMS

67.8 Sing SIX Rep Good
81.7 Sing Stk Rep Cond
Baseline
Five Emission Rate.
Month (Ibs/10x6 Btu)
881.6
233.9
0.3
13,148.9
3.219.7
3,215.2
4.5
2.744.0
2,739.9
4.1
7. 16SS
7,180.7
4.5
11.7
6.0
5.7
0.471
0.292
0.665
0.628
0.607
0.710
0388
0.588
0.589
59
06/26/95
Target (Point Level)
RACT Phase II Phase III
570.3
160.3
8,875.1
2.301.4
2.027.1
4.S46.6
8.0
4.1
3.9
481.4
160.3
5,917.0
1.448.9
1.234.S
3.233.3
8.0
4.1
3.9
318.1
120.2
3,287.2
804.9
686.0
1.796.3
8.0
4.;
3.9

-------
Detail Report - Five Month Data
Point-Segment Level Data

Plant
Affected Point SCC/DeacrlDtton
007 Providence Co - Inner


Datlgn
Capacity
(10x6 Btu/hr)


5-Month
Activity
Fac/Code
Final

OTC NOx Baseline Inventory
Rhode
Island
Heat Content

(10x6 Btu/
Fuel Use/Units SCO Unit)
Heat Input
(10x6 Btu)

State Emission
Factor/Coda
(Ibs/SCC Unit)


Con. Five
EN. Month

Baseline
Emission Rat*
flba/10x6 Btu)
Zone - Serious
0037 NARRAGANSETT ELECTRIC SOUTH
121
Affected 10100401 Residual Oil
Affected 10100601 Natural Gas
122
Affected 10100401 Residual Oil
Affected 10100601 Natural Gas
0039 NARRAGANSETT ELECTRO
006
Affected 10100401 Residual Oil
Affected 10100601 Natural Gas
007
Affected 10100401 Residual Oil
Affected 10100601 Natural Gas
012
Affected 10100401 RealdualOII
Affected 10100601 Natural Gas
670


670



546


546


546


STR. STATION

0.127 1
0.810 1

0.127 1
0.810 1


0.111
0.500

0.006
0.700

0.103
0.650

456.0
946.9

456.0
946.9


279.3
563.0

9.6
638.6

163.0
535.0

1000 Gal 150.00
10x6CuFt 1,032.00

1000 Gal 150.00
10x6 Cu Ft 1.032.00


1000 Gal 150.00
10x6CuFt 1.032.00

1000 Gal 150.00
10x6CuFt 1.032.00

1000 Gal 150.00
10x6CuFt 1.032.00

70.125
977,201

70.140
977,201


41.445
581.016

2,700
865,435

23,760
552,120

67.0 AP-42
550.0 AP-42

67.0 AP-42-
550.0 AP-42


67.0 AP-42
550.0 AP-42

67.0 AP-42
550.0 AP-42

67.0 AP-42
550.0 AP-42
5514
275.7
15.3
260.4
275.7
15.3
260.4
547.7
164.2
9.4
154.8
230.9
0.3
230.6
T52.6
5.5
147.1
0526
0.506


0.506


0.530
0.512


0.5/9


0.5f4






60
06/26/95

Target (Point Level)
PACT

213.0
106.5


106.5


208.3
63.3


66.9


66*


Phased

209.5
704.7


J04.7


206.6
62.2


66.8


57.6


Phase III

157.1
70.6


78.6


155.0
46.7


65. 1


43.2



-------
Detail Report - Five Month Data
Point-Segment Level Data
Plant
Aftected Point SCC/Descrlntlon

Design
Capacity
(10x6 Btu/hr)
007 Chittenden Co - Northern Zone
0043 BURLINGTON ELECTRIC
Affected 001 10100601 Natural Gas
842
Final (
}TC NOX Bas
;eiine in
Vermont
5-Month Heat Content
Activity (10x6 Btu/ Heat Input
Fac/Code Fuel Use/Units SCO Unit) (10x6 Btu)
- Attainment
0.723 1 496.8

10x6CuFt 1.050.00

521.640
iventory
State Emission
Factor/Code Con.
(Ibs/SCC Unit) Eft.

121.1 1990 Other OEMS


Five Emission Rate
Month (Iba/IOxB Btu)

30.1 0.115
30.1 0.115


61
06/26/95
Target (Point Level)
FACT

30.1
30. 1
Phase II

30.1
30.1
Phase III

30.1
30. 1

-------
Detail Report - Five Month Data
Point-Segment Level Data
Design 5-Month
Plant Capacity Activity
Affected Point SCC/Descrtotlon (|(^8Btu/hr) Fac/Code
153 Prince William Co - Inner
0002 VIRGINIA POWER
001
Affected 10100404 Residual Oil
Affected 10100501 Distillate Oil
00?
Affected 10100404 Residual Oil
Affected 10100501 Distillate OH
003
Affected 10100212 Bituminous Coal
Affected 10100501 Distillate Oil
004
Affected 10100212 Bituminous Coal
Affected 10100501 Distillate Oil
005
Affected 10100404 Residual Oil
Affected 10100501 Distillate Oil
Baseline 006 20100101 Distillate OH
Baseline OC7 20100101 Distillate Oil
Baseline 008 20100101 Distillate OH
Baseline 009 20100101 Distillate Oil
Baseline OJO 20100101 Distillate Oil
Baseline 011 20100101 Distillate OH
510 Alexandria - Inner Zone -
0003 PEPCO
007
Affected 10100212 Bituminous Coal
Affected 10100501 Distillate Oil
002
Affected 10100212 Bituminous Coal
Affected 10100501 Distillate Oil
003
Affected 10100212 Bituminous Coal
Affected 10100501 Distillate Oil
004
Affected 10100212 Bituminous Coal
Affected 10100501 Distillate Oil
005
Affected 10100212 Bituminous Coal
Affected 10100501 Distillate Oil
Final OTC NOx Baseline Inventory
Virginia
Heal Content Slat* Emission
(10x6 Btu/ Heat Input Factor/Coda Con.
Fuel Use/Units SCO Unit) (10x6 Btu) (Ibs/SCC Unit) EH.
Zone - Serious

925
1.000 3
1.000 3
923
1.000 3
1.000 3
1.129
0.527 3
0.527 3
2,332
0.450 3
0.450 3
8.118
0.810 3
0.810 3
264 0.797 3
264 0.916 3
264 0.696 3
264 0.924 3
264 0.908 3
264 0.930 3
Serious

970
0.563 2
0.505 2
970
0.555 2
0.396 2
961
0.430 2
0.536 2
961
0.472 2
0.235 2
961
0.440 2
0.300 2


180.6 1000 Oal
4.2 1000 Gal

201.5 1000 Gal
•7.2 1000 Gal

54.168.5 Tons
19.8 1000 Gal

204,229.0 Tons
56.7 1000 Gal

29.244.0 1000 Gal
283.7 1000 Gal
82.9 1000 Gal
127.3 1000 Gal
125.4 1000 Gal
129.3 1000 Gal
107.2 1000 Gal
125.6 1000 Gal



46.500.0 Tons
205.8 1000 Gal

61.800.0 Tons
168.0 1000 Gal

101,800.0 Tons
58.8 1000 Gal

110.500.0 Tons
16.8 1000 Gal

107.300.0 Tons
12.6 1000 Gal



146.00
140.00

148.00
140.00

25.00
140.00

25.00
140.00

148.00
140.00
140.00
140.00
140.00
140.00
140.00
140.00



25.74
136.94

25.66
136.96

25.74
136.82

25.73
137.38

25.75
137.06



26.758
588

29.822
1.008

1,354.213
2.772

5,105,725
7.938

4.328.112
39.718
11,606
17.822
17.556
18.102
15,008
17.584



1.196,943
28,182

1,585,637
23.010

2,620,532
8,045

2,843,607
2,308

2,763.020
1.727



42.0
20.0

42.0
20.0

14.4
20.0

14.4
20.0

42.0
20.0
97.7
97.7
97.7
97.7
97.7
97.7



13.4
20.0

13.3
20.0

16.0
20.0

16.0
20.0

16.0
20.0



AP-42
AP-42

AP-42
AP-42

AP-42
AP-42

AP-42
AP-42

AP-42
AP-42
AP-42
AP-42
AP-42
AP-42
AP-42
AP-42



MulStk Non-1 990
AP-42

MulStk Non-1990
AP-42

MutS* Non-1 990
AP-42

MulStk Non-1 990
AP-42

MulStk Non-1 990
AP-42

Five
Month

2,520.4
3.0
3.8
0.0
4.3
4.2
0.1
390.2
390.0
0.2
1.471.0
1.470.4
0.6
677.0
614.1
2.8
4.1
6.2
6.1
6.3
S.2
6.1

3,278.5
313.3
311.2
2.1
413.9
412.3
1.7
813.0
612.4
0.6
881.7
881.5
0.2
056.7
656.5
0.1
Baaellna
Emission Rate
flbS/IOrtBtu)

0.458
0.281


0.279


0.575


0.575


0.282


0.698
0.698
0.698
0.698
0.698
0.698

0.592
0.5/0


O.S13


0.619


0.619


0.620




62
06/26/95
Target (Point Level)
PACT

1,813.3
3.4


3.8


257.5


970.7


5*3.9


4.f
6.2
6.1
6.3
6.2
6.1

2,006.5
229.5


303.0


498.5


540.5


525. 1


Phase II

1.128.1
2.7


3.1


136.6


S14.9


436.8


4.1
62
6.1
6.3
S.2
6.1

1.176.3
122.S


160.9


284.5


308.6


299.8


Phase Ml

8514
2.1


2.3


101.8


383.5


327.6


4.1
6.2
6.1
6.3
5.2
6.1

850.4
91.9


120.6


2032


220.4


2142



-------
         APPENDIX C
MEMORANDUM OF UNDERSTANDING

-------
           Memorandum of Understanding
 Among the States of the Ozone Transport Commission
        on Development of a Regional Strategy
             Concerning the Control of
     Stationary Source Nitrogen Oxide Emissions

                       and

        O7C Stationary/Area Source Committee
Proposed Regional NOx Strategy for Stationary Sources
                   in support  of
          1994 State Implementation Plans
                September 27, 1994

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                      MEMORANDUM OF UNDERSTANDING
          AMONG THE STATES OF THE OZONE TRANSPORT COMMISSION
  ON DEVELOPMENT OF A REGIONAL STRATEGY CONCERNING THE CONTROL OF
                STATIONARY SOURCE NITROGEN OXIDE EMISSIONS

    WHEREAS,  the States of the Ozone Transport Commission (OTC) face a pervasive
 problem in their efforts to attain the National Ambient Air Quality Standard (NAAQS) for
 ozone; and

    WHEREAS,  a 1991 National Academy of Sciences study on ground-level  ozone
 indicates that a combination of reductions in emissions of volatile organic compounds
 (VOCs) and nitrogen oxides (NOx) will be necessary to bring the entire Ozone Transport
 Region (OTR) into attainment by the statutory attainment dates; and

    WHEREAS,  modeling and other studies confirm that NOx emission reductions  are
 effective in reducing ozone formation and help to reduce ozone transport; and

    WHEREAS, the States of the OTC are requiring major  stationary sources of NOx to
 implement reasonably available control technology (RACT); and

    WHEREAS, by November 15. 1994. the States must submit attainment demonstrations
 to EPA as State Implementation Plan (SIP) revisions; and

    WHEREAS, the implementation of RACT for the control  of NOx emissions will not be
 sufficient to enable all States in the OTR to reach attainment; and

    WHEREAS, the undersigned States seek to develop an  effective regional program to
 reduce NOx emissions, which would be implemented in conjunction with other measures
 to control  ozone precursors (including state-specific measures, regional measures and
 Federal measures required under the Clean Air Act); and

    WHEREAS, these measures together may enable EPA to approve the States' SIPs and
 refrain from imposing sanctions that could restrict economic growth throughout the OTR;
 and

    WHEREAS, information that the States  have collected in their emissions inventories
 shows that large boilers and other  large 'indirect heat exchangers  are the source of a
 substantial portion of the NOx emissions in the States, and will continue to be so after
they implement RACT;

    WHEREAS, the States intend to complete a reevahiation of  stationary source controls
 for 2003 and beyond in 1997. based on results of EPA-approved  models and other relevant
technical data;

    THEREFORE, the undersigned member States hereby agree to  propose regulations
 and/or legislation for the control of NOx emission from boilers and other indirect heat
exchangers with a mairin-mm gross heat input  rate of at least  250 million BTU per hour;
 and

-------
   FURTHERMORE, that the States agree to propose regulations that reflect the difference
in conditions in (i) the OTR's "Northern Zone" consisting of the northern portion of the OTR;
(ii) the OTR's "Inner Zone" consisting of the central eastern portion of the OTR; and (iii) the
OTR's "Outer Zone" consisting of the remainder of the OTR; and

   FURTHERMORE, that to establish a credible emissions budget, the States agree  to
propose regulations that requite enforceable specific reductions in NOx emissions from the
actual 1990 emissions set  forth in each  State's 1990  inventory submitted to EPA  in
compliance with § 182(a) (1)  of the Clean Air Act or in a similar emissions inventory
prepared for each attainment area (provided that for exceptional circumstances  that a
more  representative base year  may be  applied  to individual  sources  in a manner
acceptable to EPA) subject to public notice; and

   FURTHERMORE, that the States agree to develop a budget in a manner acceptable to
EPA based on the principles above no later than March 1.1995; and

   FURTHERMORE, if such a budget is not developed  by March 1.  1995. that the  1990
interim inventory used by EPA in its Regional Oxidant Model simulations for the 1994 OTC
Fall Meeting will be used for the budget; and

   FURTHERMORE, that the  States agree to propose  regulations that require subject
sources in the Inner Zone to reduce their rate of NOx emissions by 65 percent from base
year levels by May 1. 1999. or to emit NOx at a rate no greater than 0.2 pounds per million
BTU; and

   FURTHERMORE, that  the  States agree to  propose  regulations  that require subject
sources in the Outer Zone to reduce their rate of NOx emissions by 55 percent from base
year levels by May 1.1999. or to emit NOx at a rate no greater than 0.2 pounds per million
BTU; and

   .FURTHERMORE, that  the States agree to propose regulations  that require sources in
the Inner Zone and the Outer Zone to reduce their rate of NOx emissions by 75 percent
from base year levels by May 1. 2003. or to emit NOx at a rate no greater than 0.15 pounds
per million BTU; and

   FURTHERMORE, that the  States agree to propose  regulations that require subject
sources in the Northern Zone to reduce their rate of NOx emissions by 55  percent  from
base year levels by May 1. 2003, or to emit NOx at a rate no greater than 0.2 pounds per
million BTU; and

   FURTHERMORE, that  the States agree to develop a regionwide trading mechanism in
consultation with EPA; and

   FURTHERMORE, that in lieu of proposing the regulations described above, a State may
propose regulations that achieve an equivalent  reduction in stationary source  NOx
emissions in an equitable manner; and

-------
   FURTHERMORE, that the regulations for May 1. 2003 described above may be modified
if  (i) additional modeling and other scientific analysis shows that the regulations as
modified, together with regulations governing VOC emissions, will achieve attainment of
the ozone NAAQS across the OTR, and (ii) this Memorandum of Understanding is modified
to reflect those modeling results and other analysis no later than December 31, 1998; and

   FURTHERMORE, that the States agree to propose regulations that are otherwise
consistent  with the attached recommendations  of the OTC's  Stationary/Aiea Source
Committee; and

   FURTHERMORE,  that  the undersigned  States  agree  to  request  that  the  EPA
Administrator determine whether the SIPs of States outside the OTR contain adequate
provisions to prohibit the emission of air pollutants  in amounts that  will contribute
significantly to nonattainment of a National Ambient Air Quality Standard (NAAQS) within
the OTR as required under 42 U.S.C. Section 110(a)(2)(D).

-------
                               Figure 1

                  Northeast Ozone Transport Region
                      Ozone Nonattainment Areas
Pennsylvania
                New York
       Virginia
       Counties
                               Maine
                          New
                       Hampshire
                                                   Massachusetts
                                                   Rhode
                                                   Island
                                       Connecticut
     New Jersey

  Delaware
  Maryland
  ^
Washington, DC
                                                NonatUinimnt Classification

                                                    ~       Dan

-------
                                          Figure!

                        Northeast Ozone Transport Region
                                   Zones for Proposed
                      Regional NOx Stationary Source Strategy
                                                 Northern Zone
        Outer Zone
                                                            Inner Zone
The Inner Zone includes Merrimack County. New Hampshire.
                                                     loser Zone - All contiguous moderate and above i
                                                     areas except those located in Maine *
                                                     Outer Zone - Remainder of the OTR except the northern zone

                                                     Northern Zone • Maine, Vermont and New Hampshire (except
                                                     for its nyyttTBtf MM! above *vxi>tTainnvTTt areas),>nr* the
northeastern attainment portion of New York

The inner zone is based on «""«*'"e attainment designations
If an area is redesignated attainment, it remains in the inner zone
However, if contiguous marginal areas are 'bumped up* to
moderate status, they become a part of the inner zone

-------
Signed this 27th day of September,  19 £4   by the following:
CONNECTICUT
DELAWARE:
DISTRICT OF COLUMBIA:
MAINE:
MARYLAND:
MASSACHUSETTS:
NEW HAMPSHIRE
NEW JERSEY:C
NEW YORK:
PENNSYLVANIA:
RHODE ISLAND:

-------
             OTC STATIONARY/AREA SOURCE COMMITTEE
       PROPOSED REGIONAL NOx STRATEGY FOR STATIONARY
                                  SOURCES
                              IN SUPPORT OF
                  1994 STATE IMPLEMENTATION PLANS
 L Summary of the Regional Strategy

    A. General Description of the Strategy

 On March 10. 1992, the Ozone Transport Commission (OTC) adopted a Memorandum of
 Understanding (MOU) committing to Reasonably Available Control Technology (RA.CT) on
 major stationary sources of nitrogen oxides (NOx).  As  a  part of that MOU. the OTC
 anticipated 'additional  controls capable of meeting a performance standard  based on
 advanced control technology (to) be incorporated in 1994 SIP revisions for implementation
 by May 1999."

 In its 1994 Annual Meeting on May 10. 1994. the OTC reiterated its commitment to develop
 a strategy for additional controls on NOx for major stationary sources  for the 1994 SEP
 revisions. At that time  the OTC focused on its full meeting scheduled for September 27,
 1994, as the time to make a decision on this strategy.  An additional MOU documenting
 this plan was then developed and approved.

 This  paper  represents the strategy proposed  by the OTC Stationary/Area  Source
 Committee for adoption by the OTC as a part of its regional  strategy  for the 1994 SIP
 revisions. The strategy presented here would require further reductions in NOx emissions
 from large fossil fuel fired boilers and indirect heat exchangers and may limit emissions
 from smaller sources within the Ozone Transport Region in a two step process. Phase II
 (i.e. initial reductions beyond RACT) will require reductions by May 1. 1999 and a specific
 phase in reduction by May 1. 2003. Phase in would require further reductions as a default
 value unless  determined  by modeling and scientific evaluations that an alternative
 program is preferable to  achieve attainment  goals.   The default will ensure  that a
 reduction strategy is implemented in the event that the scientific efforts are inconclusive
 or that there is no consensus in the future on an alternative strategy.

 A regional emissions target will be set by calculating, on a unit by unit basis, either a pre-
 determined uniform emission limit or a pre-determined percentage emission decrease as a
 rate whichever is less stringent  for every affected unit.  A State  may implement this
 program in an alternate manner as long as the emission reduction targets for the State are
 met.  A trading program should be included as a necessary component of t*"g strategy.
 Work is currently  proceeding on  the development of an implementation mechanism  for
 such a program, which could include a NOx budget and tradable allowances.

 The Committee's report to the Commissioners on October  19. 1993.  indicated that the
 Committee  had,  in accordance with  the  Commissioners  request, assessed  the
technological  feasibility  of implementing additional NOx reductions  from large stationary

-------
sources.  The Committee concluded that current available technologies provide a feasible
and cost-effective means fox a 75 percent reduction from large boilers in aggregate.
   B. Key Components of the Regional Strategy

   1. Geographic Coverage
                                     Phase n
   Three zones:

   1) Inner - all contiguous moderate and above nonattainment areas except those
   located in Maine

   2) Outer - remainder of the OTR except the northern zone

   3) Northern - a northern tier covered by Maine. Vermont. New Hampshire (except for
   its moderate  and above nonattainment areas), and the northeastern attainment
   portion of New York - see attached map

                                  Phase m Default

   1) OTR-wide uniform applicability with exception for the northern zone

   2) Northern tier - Maine. Vermont. New Hampshire (except for its moderate  and
   above nonattainment areas), and the northeastern attainment portion of New York -
   see attached map
    2. Source Applicability
                         For Reduction Requirement Purposes
    *

   •  in phase n and phase m default, fossil fuel fired indirect heat exchangers 250
      mmBTU/Hr and greater heat input

   •  in phase HI, smaller combustion units, direct-fired process heaters and engines.
      and smaller indirect heat exchangers if necessary (to be determined in the future)

                              For Budgeting Purposes

   •  in phase n and phase m default, fossil fuel fired indirect heat exchangers 250
      mmBTU/Hr and greater heat input.

   •  in Phase n and in, other fossil fuel fired electric  generating sources 15 MW
      (approximately 150 mmBTU/Hr units) and greater.
    3. Timing - 5/1/99 and 5/1/03 final compliance dates for phase n and Phase
    respectively.

-------
    4. Seasonably - nonattainment ozone season only (5/1 to 9/30)

    5. Averaging - a seasonal limit with a daily consideration if needed

    6. Trading - allowed throughout the OTR to the extent consistent with the differences
    in zonal reduction requirements.


 C. Geographic Coverage - Limit (rates in Ibc NOx per mmBTU)

                                      Phase n

   Inner zone          0.2 rate or 60 to 75 percent range (65 percent recommended)
   Outer zone          0.2 rate or 50 to 75 percent range (55 percent recommended)
   Northern zone       RACT


                                  Phase m Default

   Inner zone          0.1 to .15 rate or 75 percent (.15 rate recommended)
   Outer zone          0.1 to .15) rate or 75 percent (.15 rate recommended)
   Northern zone       0.2 rate or 50 - 65 percent (55 percent recommended)


n. Discussion

A. General

Attainment will require a significant NOx emission reduction across the OTR to address
the. ozone problem. Attainment deadlines are rapidly approaching. However, to allow for
an opportunity for further evaluation and possible 'mid-course correction' in the context of
achieving attainment goals and new refinements to scientific evaluation techniques,  and
also due to other considerations as outlined in the following discussion of elements, it is
necessary to take a phased approach to controlling stationary source NOx.   Such an
approach would need to deliver reductions prior to the 1999 ozone season, the attainment
deadline for the OTR's serious nonattainment areas.  The approach would allow time for
additional developments in scientific information to be completed and used to amend if
necessary the phase m strategy to ensure that attainment goals are achieved.  However.
in order to meet SIP obligations,  the  strategy must  include provisions  to  ensure a
significant reduction program can be implemented in the event that the scientific results
are inconclusive, hence the recommendation for the default reduction.

The  phase n reduction outlined provides a significant near-term reduction. It requires
substantial control efforts resulting in significant emission reductions, but also provides a
developmental period necessary for trading programs to become operational, mature,  and
thereby providing a reasonable opportunity for a larger reduction and trading program to
succeed. An evaluation in advance of the phase m portion of the program will assure that
the pool of available capital and other assets will be used in the most effective  m«nn«»T m

-------
achieving attainment goals.  The default requirement is necessary to ensure that each
state has an adequate approvable SIP element for the 1994 submittals.

The  inclusion of the combined uniform limit or percent reduction  whichever is less
stringent for a particular unit addresses concerns about the ability of certain units to meet
a uniform fuel blind emission limit and simultaneously addresses concerns  about the
equity of a percent reduction for units which already have relatively low NOx emissions.

States may  apply the limits as unit  by unit reduction requirements or achieve  on an
aggregate basis an equivalent reduction utilizing alternative limit*  The limits can be met
by  using combinations of low  NOx burners. 'NOx control devices, fuel switching.
repowering and emissions trading.

Emissions from beyond the OTR are considered to impact the nonattainment areas  in the
region.  Efforts should therefore be made to determine  the significance of the impact of
these emissions and to seek the appropriate levels of control for the areas outside the OTR.

E. Diccuccion of Key Components

   1. Geographic Coverage - Coverage is extended across the OTR in both phases in a
manner that recognizes what is considered an urban  corridor of nonattainment  areas.
Consistent with the corridor concept and relative impact of other areas emissions on the
corridor, the northern far-downwind areas (see attached map) would only be included in
phase n at the RACT level Since it is less likely that reductions in the northern zone will
benefit the urban corridor, the decision for further control should be deferred until phase
m.

   2. Source Applicability - The fossil fuel fired 250 million BTU/hr heat input outpoint for
phase n applicability corresponds to boilers and other indirect heat  exchangers with a
potential to emit about 250 tons per year of NOx at a 50% capacity factor and 0.5 pounds of
NOx per  rnmBTU emission rate.   Stationary sources larger than *h
-------
 a uniform fuel blind emission limit and simultaneously addresses concerns about  the
 equity of a percent reduction for units which already have relatively low NOx emissions.

 As described earlier the emission reduction level contained in this strategy which takes
 the form of a pound per million BTU rate  limit  or a percent reduction (which  must be
 converted to its equivalent pound per million BTU rate limit) will be applied on a unit by
 unit basis. An appropriate base year related to the 1990 base year as determined by the
 OTC will be used to determine utilization rates in the calculation of the target reduction in
 a  manner  that  generally   follows   the  conceptual  outline  presented   by   the
 NESCAUM/MARAMA NOx Budget project.  Generally, it establishes an ozone season heat
 input as the utilization factor to be multiplied with the emission rate Kmit  Hie product of
 these  two factors is the reduction level for the unit involved. These unit levels will be
 summed to determine  the  total reduction from which states  win assign appropriate
 emission limits to their effected units in order to meet the reduction requirement.

    4. Tuning - Compliance with the phase n reduction is required by 5/99.  A decision on
 the phase ffl mid-course correction or default provision must occur in the  1997-1998 time
 frame  in order to ensure compliance by 5/03.   The timing provides  for  achieving  the
 reductions in the serious nonattainment areas by the statutory deadline and provides for
 implementation of further reductions to the extent necessary to achieve  the air quality
 standards in severe nonattainment areas.  The 5/03 compliance date would also provide
 the minimum three years of air quality data to demonstrate attainment by 2005.

    5. Seasonality - May 1 to September 30.  This is the most probable period for violating
 the ozone air quality standards in the OTR and would provide a common period for states
 to achieve the emission reductions. Year  round reductions, while useful for acid  rain
 mitigation  and other environmental issues,  are not necessary to achieve the ozone
 standard, and are beyond the OTC regional NOx strategy.

    6.  Averaging -  A cumulative seasonal limit with  a daily consideration  may be
 necessary.   The  form and stringency  of a daily consideration may  be  diminished  or
 eliminated contingent upon demonstrations  which indicate that actual daily emissions on
 the aggregate would  not exceed targeted levels.  Provided that modeling issues can be
 resolved (the models rely on daily tons per day limitations) this type of limit would be most
 conducive  to  implementing  the program, including trading programs, and  can  be
 demonstrated to result in daily area reductions equivalent to that which daily limits would
 provide.

    7. Emission Trading • Provisions should be made to allow for the  broadest  possible
emission trading within each zone and for appropriate trading between zones.  This  will
 permit  sources  to meet this  strategy's   emission  reduction  requirement more cost
 effectively.  Such a trading program should provide a consistent basis for meeting New
 Source Review offset requirements consistent with the Clean Air Act. A ratio reflective of
 the different zonal limits could apply for trades from the outer zone into the inner zone and
 vice versa.

-------
           APPENDIX D
DEFAULT OTC NOX BASELINE INVENTORY

-------
                                      Summary of Default OTC NOx Baseline Emission Inventory
                                    Average NOx Emission Rates by State for All Baseline Sources
State

Connecticut
Delaware
District of Columbia
Maine
Maryland
Massachusetts
New Hampshire '
New Jersey
New York
Pennsylvania
Rhode Island
Vermont
Virginia
Ozone Transport Region     227     615   921
Number of
Plants
15
9
2
14
20
25
6
26
50
52
3
2
3
: * Annual Ozone Season
Units SCCs
39
19
8
35
52
59
13
86
122
158
6
2
16
45
37
14
41
83
91
19
119
187
248
11
3
23
NOx (tons) Dally NOx (Ibs)
23,703
26,438
1,330
9,409
100,003
77,554
23,896
75,301
207,217
385,460
2,064
191
11,963
107,302
180,034
6,390
39.688
681,024
262,626
117,118
525,436
1,325,190
2,392,974
29,396
1,546
71,582
5 Month
5 Month Heat
5 Month
NOx Rate
NOx (tons) Input (10x6Btu) (lbs/10x6Btu)
10,055
11,827
742
4,081
44,864
32,602
8,341
34,711
87,816
158,532
1,143
138
5,789
52,959,125
37,954,981
4,693,401
21,764,676
135,911,118
134,333,902
22,062,952
85,512,521
385,392,110
459,241,888
4,400,130
500,692
22,103,011
0.380
0.623
0.316
0.375
0.660
0.485
0.756
0.812
0.456
0.690
0.520
0.549
0.524
944,529
5,740,306
400,640     1,366,830,507
This table summarizes heat input and average emission rates using the Default State Inventory.
This includes all baseline sources.
0.586
                                                                                                                            2/7/95

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                                      Summary of Default OTC NOx Baseline Emission Inventory
                                Average NOx Emission rates by Zone and State for All Baseline Sources
 Inner Zone
   Connecticut
   Delaware
   District of Columbia
   Maryland
   Massachusetts
   New Hampshire
   New Jersey
   New York
   Pennsylvania
   Rhode Island
   Virginia
Tota!

Outer Zone
   Delaware
   Maryland
   New York
   Pennsylvania
Total

Northern Zone
   Maine
   New York
   Vermont
Total
Ozone Transport Region     227     615   921
Number of:
Plants
15
7
2
16
25
6
26
25
16
3
3
144
Units SCCs
39
14
8
45
59
13
86
63
66
6
16
415
45
25
14
71
91
19
119
97
85
11
23
600
Annual Ozone Season
NOx (tons) Daily NOx (Ibs)
23.703
9.695
1,330
94.805
77.554
23.896
75.301
96,936
14,852
2.064
11,963
432,099
107,302
68,162
6,390
650,792
262,626
117,118
525,436
691,480
86,700
29,396
71,582
2,616,984
5 Month
NOx (tons)
10,055
4,541 -
742
42,711
32,602
8,341
34,711
41,870
7,037
1,143
5,789
189,541
5 Month Heat
5 Month
NOx Rate
Input (10x6Btu) (lbs/10x6Btu)
52,959,125
18,496,652
4,693,401
129,168,272
134,333,902
22,062,952
85,512,521
250,017,177
29,398,434
4,400,130
22,103,011
753,145,577
0.380
0.491
0.316
0.661
0.485
0.756
0.812
0.335
0.479
0.520
0.524
0.503
2
4
23
36
65
5
7
56
92
160
12
12
87
163
274
16,743
5,199
109,598
370,608
502,148
111,872
30,232
629,954
2,306,274
3,078,332
7,286
2,152
45,662
151,495
206,595
19,458,329
6,742,846
134,295,983
429,843,454
590,340,612
0.749
0.638
0.680
0.705
0.700
14
2
2
18
35
3
2
40
41
3
3
47
9,409
683
191
10,283
39,688
3,756
1,546
44,990
4,081
285
138
4,503
21,764,676
1,078,950
500,692
23,344,318
0.375
0.528
0.549
0.386
944,529
5,740,306
400,640
1,366,830,507
0.586
This table summarizes heat input and average emission rates using the Default State Inventory.
This includes all baseline sources.

-------
           APPENDIX E
INITIAL OTC NOX BASELINE INVENTORY

-------
                                   Summary of Initial State OTC NOx Baseline Emission Inventory (12/29 version)
                                                      Average NOx Emission Rates by State
Number of:
Plants
20
8
3
18
17
22
3
33
62
63
2
1
2
Annual Ozone Season
5 Month
5 Month Heat
5 Month •
NOx Rate
Units SCCs NOx (tons) Dally NOx (Ibs) NOx (tons) Input (10x6 Btu) (lbs/10x6Btu)
62
30
12
47
76
62
7
233
163
195
8
1
16
92
69
22
53
76
120
13
365
270
320
8
2
26
32,862
32,049
1,802
10,423
135,740
86,034
24,244
112,054
184,649
483,826
1,939
42
11,867
166,895
205,171
17,757
68,078
940,333
487,999
132,838
1 ,300,764
1,100,312
3,330,350
20.655
443
89,768
13,425
14,312
928
4,411
59,846
35,446
10,110
50,137
79,942
200,219
984
27
5,780
68,706,798
42,272,208
4,358,922
22,469,257
240,798,883
114,438,286
23,826,512
98,527,827
393,176,881
484,768,068
3,850,620
444,597
21,927,332
0.391
0.662
0.426
0.393
0.497
0.619
0.849
1.012
0.407
0.826
0.511
0.121
0.527
— Number of SCCs —
using missing
Total
92
58
22
53
76
119
13
361
270
320
8
2
26
AP-42
0
13
2
3
76
118
1
23
1
120
8
0
0
data
0
11
0
0
0
1
0
4
0
0
0
0
0
State

Connecticut
Delaware
District of Columbia
Maine
Maryland
Massachusetts
New Hampshire
New Jersey
New York
Pennsylvania
Rhode Island
Vermont
Virginia
Ozone Transport Region     254    912  1436   1,117,530
7,861,364      475,567    1,519,566,191
This table summarizes heat Input and average emission rates using the Initial State Inventory.
This includes all baseline sources (and may include sources which were later excluded from the baseline).
0.625   1420
365
16
                                                                                                                                        2/7/95

-------
                                      Summary of initial State OTC NOx Baseline Emission Inventory (12/29 version)
                                                    Average NOx Emission Rates by Zone and State
Number of Affected:
Plants
20
6
3
14
22
3
33
29
19
2
2
153
Units
62
22
12
68
62
7
233
101
61
8
16
652
SCCs
92
54
22
68
120
13
365
163
104
8
26
1035
Annual Ozone Season
NOx (tons) Dally NOx (Ibs)
32,862
14,431
1,802
128.672
86,034
24.244
112.054
85,852
21,289
1,939
11,867
521,046
166,895
99,222
17,757
890,066
487,999
132,838
1,300,764
519,849
197,366
20,655
89,768
3,923,179
5 Month
5 Month Heat
5 Month
NOx Rate
NOx (tons) Input (10x6Btu) (lbs/10x6Btu)
13,425
6,720
928
56,973
35,446
10,110
50,137
38,193
9,644
984
5,780
228,342
68,706,798
23,308,726
4,358,922
235,163,328
114,438,286
23,826,512
98,527,827
249,636,659
39,299,739
3,850,620
21,927,332
883,044,749
0.391
0.550
0.426
0.485
0.619
0.849
1.012
0.306
0.491
0.511
0.527
0.516
Number of SCCs 	
using missing
Total
92
43
22
68
119
13
361
163
104
8
26
1019
AP-42
0
12
2
68
118
1
23
0
46
8
0
278
data
0
11
0
0
1
0
4
0
0
0
0
16
 Inner Zone
   Connecticut
   Delaware
   District of Columbia
   Maryland
   Massachusetts
   New Hampshire
   New Jersey
   New York
   Pennsylvania
   Rhode Island
   Virginia
Total

Outer Zone
   Delaware
   Maryland
   New York
   Pennsylvania
Total

Northern Zone
   Maine
   New York
   Vermont
Total
Ozone Transport Region     254    912  1436     1,117,530
2
3
26
44
75
8
8
55
134
205
15
8
97
216
336
17,618
7,068
98,344
462,537
585,567
105,950
50,267
577,972
3,132,984
3,867,173
7,592
2,873
41,560
190,575
242,599
18,963,482
5,635,555
141,999,794
445,468,329
612,067,160
0.801
1.020
0.585
0.856
0.793
15
8
97
216
336
1
8
1
74
84
0
0
0
0
0
18
7
1
26
47
7
1
55
53
10
2
65
10,423
453
42
10,918
68,078
2,491
443
71,012
4,411
189
27
4,626
22,469,257
1,540,428
444,597
24,454,282
0.393
0.245
0.121
0.378
53
10
2
65
3
0
0
3
0
0
0
0
7,861,364
475,567    1,519,566,191
0.625   1420
This table summarizes heat Input and average emission rates using the Initial State Inventory.
This Includes all baseline sources (and may Include sources which were later excluded from the baseline).
365
16

-------
          APPENDIX F
FINAL OTC NOX BASELINE INVENTORY

-------
                                   Summary of Final OTC NOx Baseline Emission Inventory
                                 Average NOx Emission Rates by State for All Baseline Sources
State
Connecticut
Delaware
District of Columbia
Maine *
Maryland
Massachusetts
New Hampshire
New Jersey
New York
Pennsylvania
Rhode Island
Vermont
Virginia

Ozone Transport Region
260
                                      Annual Heat
                                   Input (10x6Btu)
                                      145,044,487
                                       96,855,010
                                        8,622,798
                                       54,088,610
                                      297,221,746
                                      327,316,770
                                       57,157,004
                                      222,873,917
                                      901,664,563
                                     1,232,673,622
                                        7,598,820
                                          721,560
                                       43,029,710
912  1,431     1,120,717     3,394,868,617
Number of:
Plants
21
9
4
18
16
27
3
35
53
69
2
1
2

Units
59
26
12
45
60
80
7
243
152
206
5
1
16
"
SCCs
84
49
18
51
88
141
13
381
241
328
10
1
26
Annual
NOx (tons)
26,201
29,496
1,123
10,443
120,108
97,865
36,423
107,862
197,288
480,036
1,941
42
11.890
                                               5 Month
                                             NOx (tons)
                                                 11,203
                                                 13,180
                                                    576
                                                  4,419
                                                 54,990
                                                 40,367
                                                 12,946
                                                 44,360
                                                 84,484
                                                199,639
                                                  1,099
                                                    30
                                                  5,799
           5 Month Heat
          Input (10x6Btu)
              61,284,609
              43,893,578
               4,315,427
              22,524,735
             139,601,865
             139,045,355
              21,688,403
              97,648,670
             394,796,337
             519,522,699
               4,161,143
                 521,640
              22,067,343
473,092    1,471,071,804
     5 Month
    NOx Rate
(lbs/10x6Btu)
       0.366
       0.601
       0.267
       0.392
       0.788
       0.581
       1.194
       0.909
       0.428
       0.769
       0.528
       0.115
       0.526

       0.643
This table summarizes heat input, emissions, and average emission rates using revised State data provided as of June 1,1995.
This summary includes all baseline sources.

-------
                                  Summary of Final OTC NOx Baseline Emission Inventory
                             Average NOx Emission Rates by Zone/State for All Baseline Sources
    State

 Inner Zone
    Connecticut
    Delaware
    District of Columbia
    Maryland
    Massachusetts
    New Hampshire
    New Jersey
    New York
    Pennsylvania
    Rhode Island
    Virginia
Total

Outer Zone
    Delaware
    Maryland
    New York
    Pennsylvania
Total

Northern Zone
    Maine
    New York
    Vermont
Total

Ozone Transport Region
Number of:
 Plants   Units
SCCs
21
8
4
13
27
3
35
30
18
2
2
163
1
3
22
51
77
18
1
1
20
59
22
12
53
80
7
243
108
61
5
16
666
4
7
43
145
199
45
1
1
47
84
41
18
79
141
13
381
163
98
10
26
1,054
8
9
77
230
324
51
1
1
53
Annual
NOx (tons)
26,201
12,927
1,123
111,592
97,865
36,423
107,862
97,304
18,525
1,941
11,890
523,652
16,570
8,515
99,301
461,511
585,897
10,443
683
42
11,168
Annual Heat
Input (10x6Btu)
145,044,487
57,017,631
8,622,798
279,436,332
327,316,770
57,157,004
222,873,917
566,037,458
91,454,368
7,598,820
43,029,710
1,805,589,295
39,837,379
17,785,414
331,933,025
1,141,219,254
1,530,775,072
54,088,610
3,694,080
721,560
58,504,250

5 Month
NOx (tons)
11,203
6,017
576
50,924
40,367
12,946
44,360
42,716
8,621
1,099
5,799
224,626
7,163
4,067
41,482
191,018
243,730
4,419
287
30
4,736

5 Month Heat
Input (10x6Btu)
61,284,609
26,673,862
4,315,427
131,038,110
139,045,355
21,688,403
97,648,670
253,049,312
40,861,491
4,161,143
22,067,343
801,833,725
17,219,716
8,563,755
140,195,511
478,661,208
644,640,190
22,524,735
1,551,514
521,640
24,597,889
5 Month
NOx Rate
(lbs/10x6Btu)
0.366
0.451
0.267
0.777
0.581
1.194
0.909
0.338
0.422
0.528
0.526
0.560
0.832
0.950
0.592
0.798
0.756
0.392
0.370
0.115
0.385
   260    912    1431
          1,120,717   3,394,868,617
473,092   1,471,071,804
0.643
This table summarizes heat input, emissions, and average emission rates using revised State data provided as of June 1,1995.
This summary includes all baseline sources.

-------
       APPENDIX G
EXCEPTIONAL CIRCUMSTANCES

-------
SummMy of Stationary/Area Soviet Committee Recommendations on
ucepiionaj uiiuiiimance rwquvns - reoruw
State FacllttyAJnft Requesting
Exceptional Circumstance
Delaware Delrnarva/EdgeMoorfS
Massachusetts Brayton PoknVUnM ff3
New Hampshire Merrimack StaAhiM 92
NewJeisey General Motois
New Jersey Bayway Refinery
New York Kodak Paik/UnN * 15
Pennsyivanla BP OWOH Refinery
Pennsylvania West Penn/HatfieU ff3
Pennsylvania Penetec/GPU - Homer City f 1
IftnWnln !Amtnt« fliHBMr
Virginia Virginia Power
Total Request:
NewJeisey VTneland UBBty
Pennsylvania Cheswlck
y It, 1933
Recoirnnendafion\
Comments on Claim
Yes
Yes
Yes
Yes/State Decision Pending
Yes/State Decision Pending
Yes
Yes
Yes
Yes
Yes
•
Determination Pending *
Determination Pending *
Pennsylvania Emma Determination Pending *
C«»IIMull |M|*
raciiny/unit
Actual 5 Month
1990 NOx (Tom)
1436.8
6922.0
7139^
0.0
423.3
4463.0
189.0
4217.0
6793.0
25212
34104.5
__
4538.0
3196.0
f •jilUfcj^fa^ia
racnflyfumt
Requested
Increase
80.0
963.0
1631.0
24.4
424.1
740.0
63.0
2846.0
543.0
332.0
7848.5
117.4
332.0
1794.0
f-m B-HTfc ili J»l*
rJCWiynJlm
Tcttf NOx
Request
1516.8
7885.0
8770^
24.4
847.4
5203.0
252.0
7063.0
7336.0
28532
41751.0
117.4
4870.0
4990.0
POSSUM exceptional circunuiuinuo, nowever, nci aoequaieiy oocuinenieo.
HoW for further consideration.
mm 	 A 	 • nrn •••<«•» fj§Bj.-^a • klllk.
Maryland Brandon snores utmy
Ein, 11 ^ni ML ui_n_ l_n_ inOrt nijA uuij JUI-M_JLBJ-B- jl I^IHJB f jll_n.
New source in 1990; uw not operate during SHIM

ran pftnod.


                                       Emissions estimated at 3576 tons for 5-month period.

-------
 Exceptional Circumstance Summary Tafcte Including Stationary/Area Source Recommendations -2/17/95

State

DE
MD
MO
MA
NH
NJ
NJ
NJ
NJ
NJ
>4Y
PA
PA
PA
PA
PA
PA
PA
PA



PA





VA
TOTAL

Facility/Unit Requesting)
^tmantlnnfnl SMiMBMiafcBMM*
exceptional dicunMance
OebnarvaCdge Moor #5
BQE HA Wagner #4
DemafvaAJrrit US
Biavton Point/Unit *3
Meirim**8taL/Un««2
Atlantic Electric
Vtneland UtiWy
JCP4L
General Motors
Bayway Reflnety
Kodak PsfWUnK* 15
ArcM>ax*Coaen.
Foster WheetoffCogsn.
SchuyMI Energy Res.
Wheefabrator
BPOa/Oil Refinery
PECO EneqjytfS fadMes
We*tPenn/HatfleMf3
PenelecfGPU - 3 faeHNtes:
Keystone Unit
FrontStreetfUnte7«8
Homer CRyAJntt 1
Duquesne Ught - 4 facttWes
Brunot Island facMy
PMMpefacfflty
^I«4k^**j4rf«
uneswncK
!•• 	 .
elrama
Virginia Power


Type of Circumstance Cfaimed

out of operation for 2-months
planned shutdown/50% norm, fuel usage
extended planned and forced outages
shift in outage period & startup problems
abnormal outage
2 faculties w abnormal operations
compliance testing
equipment outage
retooBngin1990
clanging ownership
abnormal outage/boiler tube replacement
equipment changes in 1990
equipment/startup problems
startup at 70% capacity/anticipate 90%
Operational probterm/Bmited capacity
#7 boiler 60 day maintanence outage
4 lower operation/2 higher than normal
extended outage/generation outside OTR

non-cummer outage
^^M ^bA«M*M«A
•Mjniowns
EPRI experimental

coM reserve
cold reserve
ower than avg. operations & more NUGs

KIWW man avp. operauons & more MUGS
abnormal cower demand & more NUGs
DE.MO.MA.NH.NJ.NY.PA & VA

RecommendatlonX
Comments on Claim
Yes
No; Insuff. intb.flustificafion
No; insuff. info./justlfica(ion
Yes
Yes
No; insuff. info.flurtificatk)n
Determination Pending *
No; insuff. *ifo./fu8fiflcatton
Yes/State Decision Pending
Yes/State Decision Pending
Yes
No: Insuff. inftxAntlflcalion
No: Insuff. info./justlflcatlon
No: Insuff. Info.flustifteatton
No; insuft. InfoJiustrncation
Yes
No; insuff. info./lustiricatlon
Yes

No; for info, purpose only
No; trwuff. hifo /lustiftcation
Yes

hio; Insuff. InfoJIustlficatlon
No: Insuff. kifoJlustincatton
Determination PenJna *

Determnstion penung
Yes: modifying tonnage

Summer (May-
FacilJtyAJrttt
Acauai HfwuNDx
1436.8
952.4
281.7
6922.0
71395
—
—
2892
0.0
423.3
4463.0
S.O
27.0
176.0
109.0
189.0
4688.0
4217.0

—
3610
6793.0

0.0
0.0
4538.0
44^A A
avxt.u
2521^
48402.8
•Sept/5-month)
FacffityrUrttt EC
n—*Jt\ iMn-^^A
Recfd. increas
80.0
723.0
184.6
963.0
16310
57.4
117.4
315.1
2' ,4
424.1
740.0
17.0
70.0
69.0
49.0
63.0
503.0
2846.0

_.
80.0
543.0

61S.O
3747.0
332.0

17M.O
332.0
16218.0
ronsofNOx
Facility/Unit
Total wnh EC
1516.8
1675.4
466.3
7885.0
8770.2
57.4
117.4
60Z3
24.4
847.4
5203.0
22.0
97.0
245.0
156.0
25ZO
5191.0
7063.0

_
116.0
7336.0

515.0
3747.0
4870.0

4900.0
28532
64620.8

State EC
Request
80.0

907.6
963.0
1631.0




936.4
740.0















4rtf£«9fl fi
lUtMO.U
332.0
16218.0
       * Possible exceptional droumstance, however, not adequately documented. Hold for further conside
Note:   Total for DE, MD, MA. NH, NJ, NY, PA & VA = 434644 tons NOx (cate'd as of 2/17/95)
       OTR Total {does not Include EC) = 467573 tons NOx (calc'd as of 2/17/95)
raton

-------
   APPENDIX H
10,000 TON RESERVE

-------
JUN 21 '95  03:21PM OZONE TRANSPORT COMMISSION                               P. 2/5



  OZONE TRANSPORT COMMISSION
  Cooncfeul, D*lmn, Mtloc, Muylud, MMtMhuMU, Nev Hu^Mbln, Nfw Jtrtey, New tek, Pnajlwu, Rhode Uud, Vbnnod,
  Bruce S. Cutout, Executive Dinrtor                                        Phooe (202) 508-3S40
                                                    _____ _ Fto; Q02)
     Ms. Mazy Nichols                                     June 15, 1905
     Assistant Administrator for Air and Radiation
     U.S. Environmental Protection Agency (ANR-443)
     401 M St., 8.W.
     Washington, DC 20460

     Dear Ms. Nichols:

        On March 1, 1095, I sant to you information relating to the baseline of nitrogen
     oxides (NOx) emissions data that the Osone Transport Commission. (OTC) developed
     in  response to its Memorandum of Understanding on stationary sources of NOx
     approved on September 27, 1994.  As a part of that transmittaL I indicated that the
     OTC planned  to modify the baseline with appropriate quality assurance-related
     adjustments, and could modify the baseline to accommodate unntsolved  issues.  I
     indicated at that time that these unresolved issues were not expected to exceed
     10,000 tons (for a five-month ozone season) across the Osone Transport Region (OTR).

        Since that transmittal, the OTC Stationary/Area Source Committee discussed all
     of these issues, including the potential reactivation of cold reservo units, and made
     recommendations to the OTC; the adjustments  associated with the 10,000 ton
     reserve and the treatment of cold reserve units were both limited to Phase n of the
     NOx MOU.  All of these recommendations were accepted by the  OTC at its Annual
     Meeting in Providence, Rhode Island, on June 13, 1995.

       Enclosed is a  summary of the  specific modifications made  by  the  OTC
     (Attachment 1). which  includ** a summary of the baseline by State.  I have »l*o
     enclosed a discussion (Attachment 2) of how specifically the adjustments were made
    and how a small number of cold reserve units will be treated.  Should there be any
     questions, feel free to call me at (202) 608-3840.
                                                     Sincerely yours,
                                                     Bruce 8. Carhart
                                                     Executive Director
    cc:  All OTC Members
          OTC Stationary/Area Source Committee Members
          Bill Backer. STAPPA/ALAPCO
          Jason Orumet, NESCAUM
          Jim Hambright, MARAMA

-------
                                         Summary of NOx Baseline Adjustments
                           Five Month NOx Emissions by State and Zone for All Baseline Sources
                                                   June 15,1995
State
Connecfcut
Delaware
OisL of Columbia
Maine
Maryland
Massachusetts

New rumpsniiv
New Jersey
New York
Pennsylvania
Rhode bland
Vermont
Virginia (No.)
Total:
Inner Zone
March 1
11,203
8.017
576

50.924
40.367
13.330
44.360
42,716
8.605
1,100

5,800
224,998
E/C
Adjust.

80



963
1.631
449

63


332
3,518
Q/A
Adjust.






(384)


16
(1)

(1)
(370)
Outer Zone
March 1
Baseline

7.163


4,067



42,071
189,854



243,155
E/C
Adjust








740
3,389



4,123
Q/A
Adjust.








(589)
1.164



575
Northern Zone
March 1
Basefine



4,419




287


30

4,738
BC
Adjiet.














Q/A
Adjust














10,000
Ton
Reserve
344
86
43
129
3,576
602
129
817
1.847
2.126
86
43
172
10,000
Phased
Basefine
11,547
13,346
619
4,548
58,567
41,932
14,706
45,626
87.072
205,217
1,185
73
6.303
490,741
  o
  UJ
  f\)
  s

Q/A = Emissions changes due to application of Quality Assurance procedures since February 28,1995
E/C = Exceptional Circumstances accepted by February 28,1995
rt-
rt
PI
O
                 NOTE - The 10,000 ton reserve expires at the end of Phase H.
                        leaving a Phase HI baseline of 480,741 tons.

-------
JUH £1  '95  03:22PM OZOIC TRANSPORT COMMISSION                                  P.4/5
                                                                     Attachment  2
   Summary of Adjustments to the NOx Baseline

     Consistent with the Stationary Source NOx MOU of September 27,1994, a NOx emission
   baseline has been developed and sent to EPA by March 1,1995, with the understanding that an
   additional 10,000 tons of NOx had been held in reserve for further consideration and that
   additional quality assurance adjustments were being made.  The 10,000 ton reserve was intended
   to be used to accommodate unresolved issues with the recognition that this reserve emissions
   would expire with the start of Phase n of the MOU.  Additional attention to quality assurance
   of the baseline was necessary to ensure the accuracy of the emissions data.  These
   determinations and adjustments were to be proposed by the OTC 1995 Annual meeting.

    The Stationary/Area Source Committee recommends the following uses of the reserve and
   adjustments to the baseline due to quality assurance refinements.

   Use of 10fOOO ton NOx Reserve in the QT.C Bg$gjinc

     In accordance with the OTC's decision at its February 28,1995 meeting, *U of the baseline's 10,000
   ton and cold reserve adjustments apply only to the 1999*2003 period. It is proposed that the 10,000 too
   NOx reserve be distributed according to the following criteria:

   *  Maryland - 3576 tons (Brandon Shores unit introduction to service in 1990)
   •  Pennsylvania • 2126 tons (Cheswick - 332 tons, and Elrama • 1794 toos requests for exceptional
     circumstances)
   *  Remaining portion of the reserve [(10,000 • (3576 + 2126) = 42_°JJ distributed to other States in the
     OTR.  Remaining OTR States receive a portion of the reserve according to their 1990 population as a
     percentage of the OTR States' total population less Maryland and Pennsylvania population.

     State               Tony
     Connecticut            344
     Delaware               86
     District of Columbia      43
     Maine                 129
     Massachusetts          602
     New Hampshire        129
     New Jersey            817
     New York            1847
     Rhode  Island            86
     Vermont               43
     Virginia (Northern)     172
     Sub Total:            4298

   Treatment of Cold Reserve Units in NOx Baseline

     A  limited adjustment to the baseline, independent of distribution  of  a  10,000 ton NOx reserve, is
   proposed for plants identified as being in "cold reserve" during  1990.  Allocation attributable to any
   adjustment for such a unit would not be tradable.  Only two candidate plants have been identified, both in

-------
JUN  21 '95   03:23PM OZONE TRPN5PORT COMMISSION                                    P.5/5
    Pennsylvania • Bnrnot Island and Phillips facilities.  Cold reserve units arc defined as plants operating
    before 1990, but not in 1990, and conform to the following criteria:

    *  Units in this status were to have been identified by the appropriate State by no later than
      May 24, 1995.
    *  Plant has continuously maintained regulatory status allowing its operation; and
    *  Plant assumes full operation prior to activation of Phase ffl of the MOU; and
    *  Plant conforms to Phase n emission reduction requirements.
    *  Annual statements that all regulatory requirements necessary to allow operation are being met
      could be required.
      The States and EPA have continued to apply quality assurance protocols to the NOx Baseline Data
    Base.  Through these efforts adjustments have been tracked and proposed for inclusion in the NOx
    Baseline Data Base.  As a result, there is a net  change of 205  additional tons (0.04% of the 3/1/95
    Baseline) proposed for inclusion as 1990 emissions (see attached table).

-------
     APPENDIX I
PROCEDURES DOCUMENT

-------
PROCEDURES FOR DEVELOPMENT OF THE OTC NO,
          BASELINE EMISSION INVENTORY

                  FINAL DOCUMENT
                      Prepared for:

                  Baseline Review Group
              Stationary/Area Source Committee
                Ozone Transport Commission
                      Prepared by:

             Emission Factor and Inventory Group
          Office of Air Quality Planning and Standards
             U.S. Environmental Protection Agency
              Research Triangle Park, NC 27711

               E.H. Pechan & Associates, Inc.
                  5537-C Hempstead Way
                   Springfield, VA 22151
                    December 20, 1994

-------
This document was approved by the Ozone Transport Commission Stationary/Area Source
Committee on December 15, 1994.

-------
                       TABLE OF CONTENTS


                                                            Page

ACKNOWLEDGEMENT	   1

L  INTRODUCTION	   2

II. PROCESS TO DEVELOP 1990 BASELINE INVENTORY	   4

III. QUALITY ASSURANCE	  14

IV. GUIDANCE ON REVISIONS TO ACTUAL 1990 OTC BASELINE NO, EMISSION
   INVENTORY  	  17

V. EXCEPTIONAL CIRCUMSTANCES	  20

APPENDICES

A. STATE INVENTORY CONTACTS

B. BASELINE REVIEW GROUP

C. AP-42 EMISSION FACTORS

D. ACID RAIN DIVISION EMISSION FACTORS

E. PENNSYLVANIA CEM DATA

F. FORM EIA-767 HEAT INPUT DATA BY STATE/PLANT

G. FORM EIA-767 HISTORICAL FUEL USE AND HEAT INPUT DATA BY BOILER

H. FORM EIA-759 UTILITY GENERATION SUMMARY BY PRIME MOVER

I.  INVENTORY CODES

J.  AFFECTED SCCs

-------
                             ACKNOWLEDGEMENT
    Several people contributed to the completion of this procedures document. State air
quality personnel contributing to this process are: Duane King of Maryland, Ray Papalski
of New Jersey, and Rob Sliwinski of New York. Contributors at EPA include David
Mobley, Chet Wayland, Barry Gilbert, and Roy Huntley. Contributors from E.H. Pechan
& Associates, Inc. include Erica Laich, Susy Rothschild, and Gregory Stella.

-------
I.   INTRODUCTION

    The objective of this effort is to compile and quality assure a data base, by March 1,
1995, of NO, emissions from fossil fuel fired boilers and indirect heat exchangers greater
than or equal to 250 MMBtu/Hr capacity and electric generating units greater than or
equal to 15 MW in the Northeast Ozone Transport Region (OTR).  Emissions for the
period May 1 through September 30,1990 (referred to as the five month summer season)
will also be compiled and will be used as a basis for emission reduction targeting and
trading.

    It is the States' responsibility to quality assure the inventory data and ensure that it
is submitted to EPA within the scheduled timeframe.  EPA is responsible for compiling
the integrated data base from the individual State submittals. The OTC Stationary/Area
Source Committee is coordinating policy issues. The Baseline Review Group represents
utilities and industries affected by the emission reduction targeting and environmental
concerns.  The Baseline Review Group may review and comment on inventory data and
the process to develop this data.  State and EPA personnel integral to this effort are
shown in Appendix A. Baseline Review Group members are shown in Appendix B.

    The schedule for the completion of the data base is shown in Figure 1. EPA has
developed the default data base which will be used in the event a State does not submit
their inventory data as required. The default OTC NOX data base is based on the Interim
1990 Emission Inventory which is used as the basis for ROM  modeling and EPA's
Emission Trends Report.

    All inventory data, including the default OTC NO, Inventory, will be available to all
interested parties through the OAQPS Technology Transfer Network:

        OAQPS TTN
        Phone (919) 541-5742
      •  CHIEF Bulletin Board
        Inventory DataBases/Programs
        Ozone Transport Commission  NOX

    Two data bases of NOX inventory data will be compiled in support of the development
of the NOX baseline for the OTR. The first data base will represent actual 1990 operation
for the five month summer season. The second data base will include data on sources
whose 1990 operating condition is deemed exceptional. This document describes the
process through which these data bases will be developed. This document also provides
guidance to the States and sources on quality assurance, selecting emission  factors,
developing the five month emission estimate, and determination of exceptional
circumstances.

    The second section of this document outlines the process through which the baseline
NO, inventory will be completed. Included in this section is a timeline and instructions
on submitting changes to the baseline inventory.  The third section of this document
addresses quality assurance checks on the 1990 Inventory.  The fourth section of the
guidance addresses changes to the actual 1990 inventory.  The last section of this
 document provides guidance on determining sources which are considered exceptional and
 outlines the data required for these sources.

-------
                                       Figure 1
                  Development of OTC NOX Emission Data Base
1.    OTC determines calculation approach, emission
      estimation approach, data elements, and format.
2.    States submit initial data (currently available) to EPA.
3.    EPA develops default data base from Interim
      Inventory and provides to States for review.
4.    EPA compiles initial data base and provides to States
      for review.
5.    OTC/EPA proposes quality assurance protocol and
      procedure for modifying data.
6.    States quality assure the initial and default data
      bases.
7.    Sources return comments to States.
8.    State data available for public review.
9.    States submit data revisions.
10.   EPA compiles final data base.
11.   States/OTC/Baseline Review Group conducts final
      data review.
12.   Calculate emission reduction targets.
13.   Manage trades.
Target Date
11/04

11/18
11/18

12/02

12/02

12/02-01/15

01/06
12/07-01/15
01/15
02/01
02/01 - 03/01

03/01
> 03/01
                                                                                                   ft*

-------
II.  PROCESS TO DEVELOP 1990 BASELINE INVENTORY

    The starting point for the actual 1990 OTC Baseline NO, Emission Inventory is the
SIP inventories and Enmiftl reporting of emissions from major point sources submitted to
EPA by each State. These inventories have undergone quality assurance by both the
States and, in some cases, the individual  sources (facilities). Therefore, minimal changes
are expected to the actual inventory data elements with the exception of providing data on
five month activity levels. All baseline data and any proposed changes will be subject to
review by any member of the Baseline Review Group, EPA, or State air pollution
personnel. All data will be considered public information which may be released by the
State to interested parties.

    A data base of exceptional circumstances will also be developed.  This is broadly
defined as sources which did not operate in 1990 or sources whose operation in 1990 was
atypical.  This data will be stored in a separate  data base from the actual 1990 OTC
Baseline NOX Emission Inventory. The goal of this data base is to provide information on
sources whose operation in 1990 varied significantly from normal operation which results
in a significant impact on the total NO, emission level for the entire OTR or for a
particular State.

    The States' original submittal to EPA is based on SIP and annual reporting data. A
number of data elements which are needed to establish the baseline and emission
reduction targets are therefore missing from this inventory. These include:

     •   Five month activity levels and emissions
     •   RACT emission limits and emissions (may be used in determining emission
        reduction targets)

     In addition, the  States must indicate which sources included in the data base are not
affected and add any missing sources which are considered affected sources. For the
purposes of establishing the baseline, an  affected source is any fossil fuel fired boilers and
indirect heat exchangers greater than 250 MMBtu/Hr capacity and electric generating
units greater than or equal to 15 MW.  This is discussed further under Section III
(Quality Assurance).

     Figure 2 lists the data elements included in the actual 1990 OTC Baseline NO,
Emission Inventory. This details which data elements  originate from in the initial State
inventories, which data elements are determined or calculated by EPA based on the State
data, which data elements must be provided by the States, and suggests which data
elements should be reviewed by the States. Monthly data is also requested for NOZ for
quality assurance of the five month data. Additional information on the development of
five month  activity levels is provided in Section IV.

     Figure  2 also includes  additional data elements requested from the States which are
 not integral to the development of the  baseline  NO, inventory. These data elements are
 included in the initial State submittals.  It is EPA's intent to develop a comprehensive
 1990 emission inventory from this data for use  in modeling efforts. This data will become
 publicly available when released by the States.

-------
                                    Figure 2
                  Actual 1990 OTC Emission Database Structure
Field Name
                                                                Source
PLANT LEVEL
AFFECTED
STATEjCODE
CNTY_CODE
PLANTJD
i ORISID
STATEABB
CNTYNAME
ZONE
CLASS
i UTILITY
PLANT
SIC
INV.YEAR
INVJTYPE
POINT LEVEL
POINT
i BOILER
HRSPERDAY
DAYSPERWK
HRSPERYR
DEC_FEB
MAR_MAY
JUN_AUG
SEP_NOV
2 ACTIV_5MO
2 METH_5MO
3 DSGN_CAP
SPACE_HEAT
3 CAP_UNITS
DSGNCON
« BOTTOM
4 FIRING
STACK LEVEL
STACK_TEMP
STACKJHT
PLUME_HT
STACK_FLOW
STACK_VEL
STACK_DIAM
LATITUDE
LONGITUDE
SEGMENT LEVEL
SCC_CODE
SULFUR
ASH
3 HEAT
2 HEAT.5MO
3 FUEL_PROC
3 FUEL_RATE
3 FUEL_SCC
2 FUEL_PROC5
HTINPUT
2 HTINPUT_5M
ACTIV_OSD
SEGCON

C
C
C
C
C
C
C
C
C
C
C
C
C
C

C
C
N
N
N
N
N
N
N
N
C
N
N
C
C
N
N

N
N
N
N
N
N
N
N

C
N
N
N
N
N
C
C
N
N
N
N
C

1
2
3
5
5
2
35
1
10
30
20
4
2
1

3
5
2
1
4
2
2
2
2
5
1
5
4
1
1
2
3

4
4
4
7
5
5
7
7

e
6
5
8
8
8
40
1
8
12
12
7
1


















0
0
0
0
0
0
0
3

0
1


0
0

0
0
0
0
1
2
4
4


3
2
2
2
1


1
0
0
5


Affected Unit (Y/N)
FIPS State Code
FIPS County Code
AFS Plant ID
ORISID
State Abbreviation
County Name
OTC Zone (Mnner / O-Outer / N-Northem)
Ozone Nonattainment Classification
Utility Name
Plant Name
SIC Code
Inventory Year
Inventory Type (A-Actual / (-Interim (default))

State Point ID
DOE Boiler ID
Hours Per Day
Days Per Week
Hours Per Year
Dec-Feb Activity
Mar-May Activity
Jun-Aug Activity
Sep-Nov Activity
5-Month Activity Factor
5-Month Activity Methodology
Design Capacity (MMBtu/hr)
Space Heat Percentage
Design Capacity Units
Point Level Confidentiality
Bottom Type
Firing Type

Stack Temperature (degrees F)
Stack Height (ft)
Plume Height (ft)
Stack Flow Rate (ft*3/min)
Stack Velocity (ft/sec)
Stack Diameter (ft)
Latitude (Decimal Degrees)
Longitude (Decimal Degrees)

Source Classification Code
% Sulfur Content
% Ash Content
Fuel Heat Content (MMBtu/SCC unit)
5-Month Fuel Heat Content (MMBtu/SCC unit)
Fuel Use (SCO units)
Fuel Use Units
Fuel Use Units Consistent With SCC Units (Y/N)
5-Month Fuel Use (SCC units)
Heat Input (MMBtu)
5-Month Heat Input (MMBtu)
Ozone Season Daily Activity Factor
Segment Level Confidentiality

EPA Determined/States to Provide
Base Inventory Data
Base Inventory Data
Base Inventory Data
EIA-767 Match
EPA Provided
EPA Provided
EPA Provided
EPA Provided
EIA-767 Match
Base Inventory Data
Base Inventory Data
Base Inventory Data
EPA Provided

Base Inventory Data
EIA-767 Match
Base Inventory Data
Base Inventory Data
Base Inventory Data
Base Inventory Data
Base Inventory Data
Base Inventory Data
Base Inventory Data
EPA Calculated/States to Provide
EPA Calculated/States to Provide
Base Inventory Data
Base Inventory Data
Base Inventory Data
Base Inventory Data
State to Provide
State to Provide

Base Inventory Data
Base Inventory Data
Base Inventory Data
Base Inventory Data
Base Inventory Data
Base Inventory Data
Base Inventory Data
Base Inventory Data

Base Inventory Data
Base Inventory Data
Base Inventory Data
Base Inventory Data/States to Convert
EPA Calculated/States to Provide
Base Inventory Data/States to Convert
Base Inventory Data/States to Provide
Base Inventory Data/States to Provide
EPA Calculated/States to Provide
EPA Calculated
EPA Calculated/States to Provide
Base Inventory Data
Base Inventory Data

-------
                                      Figure 2
                   Actual 1990 OTC Emission Database Structure
Field Name
Type Length  Decimal Description
                                                                    Source
POLLUTANT












t


2
s
s
2

2

2

2

2

2
6
2.6
e
2.6
LEVEL
CTRL_EQ_1
CTRL_EO_2
CTRLEO_EFF
EST_METH
EMF_AP42
EMF_UNIT
EMFJSTATE
EMF_5MO
EMF_HIER
COMMENT
RULE_EFF
EMISS_ANN
EMISS_5MO
EMISS_OSD
EMRATE
EMRAT_5MO
EMRAT_RACT
EMISS_RACT
EMIS5_RACT
EMISS_15
EMIS5_15
EMISS_20
EMIS5_20
EMISS_55
EMIS5_55
EMISS_65
EMIS5.65
EMISS_75
EMIS5_75
PHASE2
PHASE2_5MO
PHASES
PHASE3_5MO

C
c
N
C
N
C
N
N
C
C
N
N
N
N
N
N
N
' N
N
N
N
N
N
N
N
N
N
N
N
N
N
N
N

3
3
6
1
7
20
7
7
2
20
3
11
11
11
7
7
7
11
11
11
11
11
11
11
11
11
11
11
11
11
11
11
11



3

3

3
3


0
3
3
3
5
5
5
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3

Primary NOx Control Equipment
Seoonday NOx Control Equipment
NOx Control Efficiency
AIRS Estimation Method Code - NOx
AP-42 Emission Factor - NOx
AP-42 Emission Factor Units - NOx
State Provided Annual NOx Emission Factor
State Provided 5-Month NOx Emission Factor
Emission Factor Hierarchy Code - NOx
Emission Factor Comments - NOx
NOx Rule Effectiveness
Annual NOx Emissions (tons)
5-Month NOx Emission (tons)
Ozone Season Day NOx Emissions (tons)
Annual NOx Emission Rate Qbs/MMBtu)
5-Month NOx Emission Rate (Ibs/MMBtu)
Annual RACT NOx Emission Rate Obs/MMBtu)
Annual RACT NOx Emissions (tons)
5-Month RACT NOx Emissions (tons)
Annual 0.15 Ibs/MMbtu Limit NOx Emissions (tons)
5-Month 0.15 Ibs/MMbtu Limit NOx Emissions (tons)
Annual 0.20 Ibs/MMbtu Limit NOx Emissions (tons)
5-Month 0.20 Ibs/MMbtu Limit NOx Emissions (tons)
Annual 55% Reduction NOx Emissions (tons)
5-Month 55% Reduction NOx Emissions (tons)
Annual 65% Reduction NOx Emissions (tons)
5-Month 65% Reduction NOx Emissions (tons)
Annual 75% Reduction NOx Emissions (tons)
5-Month 75% Reduction NOx Emissions (tons)
Annual Phase II NOx Emissions (tons)
5-Month Phase II NOx Emissions (tons)
Annual Phase III NOx Emissions (tons)
5-Month Phase III NOx Emissions (tons)

Base Inventory Data
Base Inventory Data
Base Inventory Data
Base Inventory Data
EPA Provided
EPA Provided
State to Provide
State to Provide
State to Provide
State to Provide
Base Inventory Data
Base Inventory Data
EPA Calculated/States to Provide
Base Inventory Data
EPA Calculated
EPA Calculated
State to Provide
State to Provide
State to Calculate
EPA Calculated
EPA Calculated
EPA Calculated
EPA Calculated
EPA Calculated
EPA Calculated
EPA Calculated
EPA Calculated
EPA Calculated
EPA Calculated
EPA to Calculate with State Data
EPA to Calculate with State Data
EPA to Calculate with State Data
EPA to Calculate with State Data
ADDITIONAL POLLUTANT LEVEL DATA
(Not needed
VOC






CO







SO2




PM-10




for development of OTC
VC,TRL_EC_1
VCTRL_EO_2
VCTRLEC E-r
VEST_McTH
VRULE_EFr
EMISS.VOC
EMISS_VOSJ
CCTRL_EC_1
CCTRL_EG_2
CCTRLEG_EFF
CEST_METH
CRULE_EFF
EMISS_CO
EMISS_COSO
EMISS_CTWD
SCTRL_EG_1
SCTRL_EG_2
SCTRLEQ_EFF
SEST_METH
EMISS_SO2
PCTRL_EQ_1
PCTRL_EQ_2
PCTRLEO_EFF
PEST_METH
EMISS_PM10
C
C
N
C
N
N
N
C
C
N
C
N
N
N
N
C
C
N
C
N
C
C
N
C
N
NOx baseline, but
3
3
e
i
3
11
• i
n
3
6
1
3
11
11
11
3
3
6
1
11
3
2
6
1
11


3

0
3
3


3

0
3
3
3


3

3


3

3
requested for development of comprehensive OTC inventory)
Primary VOC Control Equipment
Seconday VOC Control Equipment
VOC Control Efficiency
AIRS Estimation Method Code - VOC
VOC Rule Effectiveness
Annual VOC Emissions (tons)
Ozone Season Day VOC Emissions (tons)
Primary CO Control Equipment
Seconday CO Control Equipment
CO Control Efficiency
AIRS Estimation Method Code - CO
CO Rule Effectiveness
Annual CO Emissions (tons)
Ozone Season Day CO Emissions (tons)
Typical Winter Day CO Emissions (tons)
Primary SO2 Control Equipment
Seconday SO2 Control Equipment
SO2 Control Efficiency
AIRS Estimation Method Code - SO2
Annual SO2 Emissions (tons)
Primary PM-10 Control Equipment
Seconday PM-10 Control Equipment
PM-10 Control Efficiency
AIRS Estimation Method Code - PM-10
Annual PM-10 Emissions (tons)
Base Inventory Data
Base Inventory Data
Base Inventory Data
Base Inventory Data
Base Inventory Data
Base Inventory Data
Base Inventory Data
Base Inventory Data
Base Inventory Data
Base Inventory Data
Base Inventory Data
Base Inventory Data
Base Inventory Data
Base Inventory Data
Base Inventory Date
Base Inventory Data
Base Inventory Data
Base Inventory Data
Base Inventory Data
Base Inventory Date
Base Inventory Data
Base Inventory Data
Base Inventory Data
Base Inventory Data
Base Inventory Data

-------
                                                                Figure 2
                                   Actual  1990 OTC Emission  Database Structure
    Field Name
                                                                                                               Source
MONTHLY DATA
7 FUEL.JAN
7 FUEL.FEB
7 FUEL.MAR
7 FUEL.APR
7 FUEL_MAY
7 FUELJUN
7 FUEL_JUL
7 FUEL.AUG
7 FUEL.SEP
7 FUEL_OCT
7 FUEL_NOV
7 FUEL_DEC
7 HEAT.JAN
7 HEAT_FEB
7 HEAT_MAR
7 HEAT_APR
7 HEAT.MAY
7 HEAT_JUN
7 HEAT_JUL
7 HEAT_AUG
7 HEAT_SEP
7 HEAT_OCT
7 HEAT_NOV
7 HEAT.DEC

N
N
N
N
N
N
N
N
N
N
N
N
N
N
N
N
N
N
N
N
N
N
N
N

8
8
8
8
8
8
8
8
8
8
8
8
8
8
8
8
8
8
8
8
8
8
8
8

1
1
1
1
1
1
1
1
1
1
1
1
2
2
2
2
2
2
2
2
2
2
2
2

January Fuel Use (SCO units)
February Fuel Use (SCO units)
March Fuel Use (SCO units)
April Fuel Use (SCO units)
May Fuel Use (SCO units)
Jon Fuel Use (SCO units)
Jury Fuel Use (SCO units)
August Fuel Use (SCO units)
September Fuel Use (SCO units)
October Fuel Use (SCO units)
November Fuel Use (SCO units)
December Fuel Use (SCC unto)
January Heat Content (MMBtu/SCC units)
February Heat Content (MMBtu/SCC units)
March Heat Content (MMBtu/SCC units)
April Heat Content (MMBtu/SCC units)
May Heat Content (MMBtu/SCC units)
June Heat Content (MMBtu/SCC units)
July Heat Content (MMBtu/SCC units)
August Heat Content (MMBtu/SCC units)
September Heat Content (MMBtu/SCC units)
October Heat Content (MMBtu/SCC units)
November Heat Content (MMBtu/SCC units)
December Heat Content (MMBtu/SCC units)

State Provided
State Provided
State Provided
State Provided
State Provided
State Provided
State Provided
State Provided
State Provided
State Provided
State Provided
State Provided
State Provided
State Provided
State Provided
State Provided
State Provided
State Provided
State Provided
State Provided
State Provided
State Provided
State Provided
State Provided
1  Stains should match Slate data with Form EIA-767 boiler data. This step wll b« completed after the data is released to the States and the puBBc.
   These data elements win therefore be blank in Version 1 of the State Inventories

2  States should provide source specific data where possible. For utilities, may be based on Form EIA-767 If appropriate matches are completed by States/EPA.
   The five month data will be initially calculated as follows:
   5 Month Activity Factor:      Summer season activity plus one-third of each ol spring and fall season activities
   Heat Content:              Annual value will be used
   Fuel Use:                  Annual fuel use multiplied by five month activity factor
   Heat Input                 Five month fuel use multipied by five month heat content
   Emissions                 Category annual emissions multiplied by five month activity factor

3  This data should be converted by the Slates to match SCO units for consistency.

4  This data should be provided by the States to EPA. If not provided, win be based on Interim Inventory where matches have been Identified.

5  RACT emissions and emission rates are to be provided by the States based on State RACT regulations

6  Phase 2 and Phase 3 emissions will be calculated by EPA when RACT emissions and emission rates are provided by the States

7  Monthly data needed for quality assurance ol 
-------
    The process that the sources follow for modifying the 1990 data (both the actual and
exceptional circumstances) should conform to the steps outlined in this document
whenever possible.  Three forms are included-two for the sources that will be submitted
along with appropriate documentation. The third form is a tracking form or log for the
State's use.  Please note that all data will be considered  public information.  Because the
schedule - from compilation of the initial default data base to production of the final base
- spans only two months as shown in Figure 1, it is especially important that a
concentrated effort be made to make informed and well-documented decisions regarding
the data to be accepted. Therefore, the following guidelines are proposed:

    1.  The Baseline Review Group, States, and EPA should provide as much
        information to the sources as possible so that the utilities and industry will be
        made aware of the existence of the review period, the procedures to be followed,
        and the time constraints in place. The sources should be clearly informed that if
        they do not avail themselves of the opportunity  to change the data within this
        time frame, the State will determine which methodology and data to use.
        Materials describing the process to be followed,  as well as appropriate forms (see
        Tables 1 and 2) to be submitted to the States for review, should also be easily
        available to the sources. Inventory data will be provided by EPA to the sources
        via the OAQPS CHIEF Bulletin  Board  (see Section I for details).

    2.  Utility/Industry Submittal  Responsibilities

        When an error in the actual data has been detected, the State representative
        should be contacted and provided with  a filled out Baseline Data Change Form
        (see Table 1) accompanied by documentation. The nature of the documentation
        depends upon the data element that needs modification.

        a.  If the error results from a typo, the correct information should be provided
            by including "official" utility/industry/State reports that indicate the  correct
            value.

        b.  If the error is  with the fuel quantity or quality, operating reports can be used
            to provide documentation.  If the fuel quantity or quality differs from that
            reported to EIA, the corrected values should be submitted to EIA.

         c.   If the error is  with the source classification code (SCO assigned to a fuel,
            operating reports, fuel processing reports, or reports from inspectors  in the
            field can be provided to show the correct information.

         d.  If a different emission factor than the one originally use to calculate
            emissions is desired, the source can provide data for a better emission factor
            method (as specified by the  emission factor hierarchy in this document) and
            include reports that support this thesis.

         e.  If exceptional circumstances are petitioned for, the documentation will  have
            to support the definitions delineated under the "exceptional circumstances"
            section of this document.
                                          8

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                                                Table 1
                            1990 State NOX Baseline Data Change Form
No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
Variable
Utility ORIS ID plant code
EPA ID
State ID plant Code
Plant Name
Boiler ID
Stack ID
Utility Name
Annual Emission Factor Value
Annual Emission Factor Units
Emission Factor Hierarchy Code
Annual Coal Use (k tons)
Annual Oil Use (k gal)
Annual Gas Use (MMcf)
Annual Coal Heat Content (MMBtu/SCC unit)
Annual Oil Heat Content (MMBtu/SCC unit)
Annual Gas Heat Content (MMBtu/SCC unit)
5 Mo Coal Use
5 Mo Oil Use
5 Mo Gas Use
5 Mo Coal Heat Content
5 Mo Oil Heat Content
5 Mo Gas Heat Content
State
Other
Original Value
























Proposed Value
























Value Accepted
























REFERENCE «_

NOTES:

COMMENTS:

RESOLUTION:
. (e.g., NH1 [State plus sequential number], corresponds to State Tracking Log)

-------
                                       Table 2
                1990 State NO, Exceptional Circumstances Submittal Form
No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
Variable
Utility ORIS ID plant code
EPA ID
State ID plant Code
Plant Name
Boiler ID
Stack ID
Utility Name
Annual Emission Factor Value
Annual Emission Factor Units
Emission Factor Hierarchy Code
Annual Coal Use (k tons)
Annual Oil Use (k gal)
Annual Gas Use (MMcf)
Annual Coal Heat Content (MMBtu/SCC unit)
Annual Oil Heat Content (MMBtu/SCC unit)
Annual Gas Heat Content (MMBtu/SCC unit)
5 Mo Coal Use
5 Mo Oil Use
5 Mo Gas Use
5 Mo Coal Heat Content
5 Mo Oil Heat Content
5 Mo Gas Heat Content
State
Other
Original Value
























Proposed Value
























Value Accepted
























REFERENCE #
REASONS FOR EXCEPTIONS:

COMMENTS:

RESOLUTION:

-------
3.   State Review Responsibilities

    After the Baseline Data Change Form or the Exception Data Submittal Form and
    accompanying documentation have been received by the State representative,
    there are several procedural items to consider.

    a.  The modification item should be logged in so that all requests and their
        status can be continually tracked on a Tracking Log (see Table 3).  The data
        change requests should be reviewed and evaluated with regard to its effect
        upon the State NOX emissions total in relation to the State SIP cap.

    b.  If the modification involves a typo, it should be straightforward to determine
        whether it is legitimate.

    c.  If a fuel quantity or quality modification is requested, there should be
        sufficient reports that, in conjunction with background knowledge, should
        allow the State to make an appropriate determination.  It is the States
        responsibility to match State inventory data with Form EIA-767 boiler data.
        These matches should be provided to EPA.  If the fuel quantity or quality
        used in the State inventory differs from that on Form EIA-767, the source
        should re-submit this information to EIA.

    d.  If a different emissions factor is applied for, it is incumbent upon the State
        reviewer to determine whether this alternate EF is representative of 1990
        and whether it has been previously approved (or should be presently
        approved) for use in calculating 1990 NO, emissions.  Past experience, good
        judgment, and consistency with regard to the emission factor hierarchy
        should be entered into the decision regarding data acceptance.  States should
        clearly indicate if an emission factor with a  lower rank on the hierarchy is
        utilized if data are available for a factor with a higher preference. For
        example, CEMS data for the summer of a year other than 1990 may be
        judged to be more representative of the 1990 five month summer period than
        actual  1990 CEMS data for the fall or winter. A justification indicating this
        should be provided to support the decision.

    e.  If exceptional circumstances have been applied for, the State will have to
        determine whether the criteria explicated in the "Exceptional Circumstances"
        section of this  document have been met.

    f.   The State should determine the deadline for source submittal of forms for
        data modifications.  It is strongly suggested that the sources in the State be
        notified that modifications to the data or additional data be considered if the
        supporting materials are clearly specified, complete, and authoritative, and if
        the submission occurs no later than  one week before the deadline for State
        submittal of the final data to EPA.

    g.  The State will determine the fuel use methodology based upon the five
        month  hierarchy and calculate the actual data values if no forms are
        submitted to the State. Default values have been calculated for the initial
        State inventories based on the seasonal thruput percentages (see Figure 2).
                                    11

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 Table 3
_ State Tracking Log
Dale
















Reference No.
















Source Name
















Data Mod (M) or
Exceptional
Circumstances (E)?
















Notes











•




Status

















-------
    h.  The State should inform the source in writing of the decision regarding data
        modification and reason for the decision. One way to provide the information
        is to send back a copy of the original Baseline Data Change Form submitted,
        with the status filled in.  Copies should be kept on record with the State.
        The State should also check the Tracking Log to ensure that all data
        modification requests are resolved.

    i.   The State, by January 15,1995, should submit to EPA original five month
        data and modifications as well as exceptional circumstances data. If
        substantial changes will be submitted, it is requested that these be
        submitted in electronic form as changes to the OTC format NO, data base
        which will be transferred to the States by December 2, 1994. Documentation
        should be available to the Baseline Review Group and the public upon
        request.

5.  Final Data Base Production

    The revised data base will  be produced by EPA by February 1,1995 after the
    States have submitted the  final data modifications and additions by January 15,
    1994. The period from February 1 to March 1 will be used for final review by the
    Baseline Review Group and approval/verification of each State and acceptance by
    the OTC Stationary/Area Source Committee.
                                    13

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in.     QUALITY ASSURANCE
    Data quality assurance is an integral part of developing the NO, baseline for trading.
Included in quality assurance are the elements of completeness as well as accuracy.  The
four steps listed below document the procedures that should be followed to ensure the
consistency, completeness and accuracy of the baseline.

    1.   Completeness of Affected Sources

    As stated in the MOU, States agree to "propose regulations and/or legislation for the
control of NO, emission from boilers and other indirect heat exchangers with a maximum
gross heat input rate of at least 250 million BTU per hour". Based on discussions with
the States in the OTC, the definition of the affected sources was determined to be
fossil-fuel fired boilers and indirect heat exchangers greater than or equal to 250 million
BTU's/hour and electric generating units greater than or equal to 15 megawatts. This
also includes any peaking units that might exceed this limit.  With this definition, fuels
such as wood, process gas (non fossil fuel derived), solid and liquid waste, bagasse, and
CO are eliminated as well as combustion devices in process heaters.

    At this time, no affected units appear to be covered with Source Classification Codes
(SCCs) beginning with numbers greater than 2. Appendix J contains the current list of
SCCs which have been determined to be affected according to the above definition
(sources with these SCCs must also meet the capacity requirements).  There may be
additional sources outside of these SCCs which should be covered in this baseline. These
should be flagged by individual States for EPA to include in the baseline (see Figure 2).
Therefore, it assumed that all sources meeting the criteria defined above will be included
in the 1990 NOX emission inventory to be used in establishing the NO, baseline for
trading under the MOU between the States in OTC. Any exceptions to this definition
should be cleared through  the OTC Stationary Source Committee prior to exclusion from
the baseline.

    2.   Comparisons

    In order to ensure that all sources are properly accounted for that meet the criteria
for affected sources described above, comparisons should be made between the State
baseline information and other compatible data bases.  This is only an attempt to verify
that individual sources in one data base are consistent with those sources in the NOZ
baseline and to indicate possible errors in plant identification codes or missing or
unreported data.  In general, if a source is in the NO, baseline inventory it should appear
in the other comparable data bases. The comparisons that are recommended are listed
below.

    1)  Comparison between the 1990 NOX baseline inventory and the 1990 State SIP
        inventory.

    2)  Comparison between the 1990 NOX baseline inventory and the 1990 DOE form
        767 data base (for utility sources only).
                                         14

-------
    3)  Comparison between the 1990 NOX baseline inventory and the 1990 EPA Interim
        Emission Inventory (default OTC Baseline Inventory). These data have been
        previously distributed to all OTC States for analyses.

    The above comparisons should primarily be made to ensure completeness and
accuracy of the 1990 NO, baseline estimates.  Any discrepancies between the baseline
data and any of the comparable datasets should be further examined to ensure that an
individual source was not accidentally omitted or that various data elements (throughput,
heat content, stack parameters, emission factor, etc.) were not accidentally entered
incorrectly.  In theory, the baseline data and the 1990 State SIP data should be very
similar for those sources meeting the affected source definition described above.

    In addition to the comparisons listed above, other comparisons should be made with
existing datasets to check for possible erroneous data values or outliers. This is especially
critical when examining the emission factor information.  The data comparisons
recommended for these types of checks are listed below.

    1)  Comparison between the 1990 NOX baseline inventory and the CEMS data for the
        Acid Rain program (for utilities only). These data are included in Appendix D.

    2)  Comparison between the 1990 NOX baseline inventory for an individual State
        with the same inventory for another State. Similar sources should be expected to
        contain similar data elements and this comparison might benefit both States in
        ensuring that a typographical error or miscalculation did not accidentally get into
        the data base.

    3.  Emission Inventory Quality Assurance System

    For those states with inventory data in AIRS format, the EPA's Emission Inventory
Quality Assurance System (EIQA) may be used to perform quality assurance edit checks
on critical data elements. This system performs range checks which are helpful in
identifying coding or unit errors which may be off by as much as one or more orders of
magnitudes.

    4.  Internally Consistent

    The last area that should be quality assured is the mathematical correctness of the
final emissions value. With so many data elements going  into the calculation of the
actual emissions value, it is just as important to QA the calculations as it is to QA the
individual data elements. As was discussed in the initial approach for developing the NOX
baseline inventory, the calculation approach is based on three fundamental equations.

    1)  EMISSION ESTIMATION

        Emissions = Activity * Emission Factor * Control  Factor

    Control Factor reflects the combined effects of control  device efficiency, rule
effectiveness, and rule penetration.
                                        15

-------
    2)   UTILIZATION

        Heat Input = Activity * Heating Value of Fuel

    3)   CAPACITY

        Design Capacity = Design Rating * Conversion Factor

    Each of these calculations should be checked for each source to ensure that the final
emission values have been calculated correctly.  Any erroneous data elements or
algorithms should be corrected and the emissions recalculated.
                                        16

-------
IV. GUIDANCE ON REVISIONS TO ACTUAL 1990 OTC BASELINE NOX
    EMISSION INVENTORY

    The starting point for the actual 1990 OTC Baseline NO, Emission Inventory will be
the SIP inventories and annual reporting of emissions from major point sources submitted
to EPA by each State. These inventories have undergone quality assurance by both the
States and, in some cases, the individual sources. Therefore, minimal changes are
expected to the actual inventory data elements with the exception of providing data on
five month activity levels. If a source believes that other data elements are in error (e.g.
the annual fuel use), documentation must be provided to the respective State supporting
any revisions. This data  will be subject to review by any member of the Baseline Review
Group and will be considered public information which may be released by the State to
interested parties.

    Included in Chapter II is a form to be completed by any source wishing to change
base year actual inventory data.  This form must be submitted to the State with
documentation supporting the proposed change.  The State will indicate the outcome of
the proposed change on the form and maintain all forms and supporting documentation as
outlined in Chapter II.  A copy of the form will be submitted to EPA so that the
appropriate changes may  be made in the final data base.  These forms and the supporting
documentation will be considered public information and must be available for review  by
the Baseline Review Group or other interested parties.

    1.   Five Month Activity Levels

    The five month period of May through September will be used as  the basis for the
NO, emission budget. Activity in the months of May through September may fluctuate
from the monthly average, particularly for batch or cyclic processes. The ideal situation is
for each source to provide actual monthly activity level data for this five month period.
The hierarchy thus established for determining the five month activity level (or fuel use)
is as follows:

        1)  Actual monthly fuel use data reported to the State by the source. If this  is
            provided, monthly fuel use for the entire year should be provided so that  the
            sum of the monthly fuel use can be checked against the reported annual fuel
            use.

        2)  Monthly fuel use from Form EIA-767 for utilities.  The 1990 monthly fuel
            use has been provided to the States and other interested parties.  There are
            potential difficulties associated with matching this boiler/fuel type data from
            Form EIA-767 to the State inventories. Data must be matched at the plant
            and boiler level. State data may be at the stack level rather than the boiler
            level.  EPA and the States will attempt to match this data. Any sources for
            which matches are not apparent will fall under one of the remaining steps in
            this hierarchy.

        3)  Seasonal thruput percentages provided in the SIP  inventory. Many of the
            sources have reported seasonal — spring (March-April-May), summer (June-
            July-August), fall (September-October-November),  winter (December-
            January-February) - thruput allocations or percentages.  In these cases, the
                                        17

-------
            five month fuel use will be determined by adjusting the annual fuel use by
            one-third of the spring thruput percentage plus the summer thruput
            percentage plus one-third of the fall thruput percentage.

        4)   If no other data are available, the five month fuel use will be determined by
            multiplying the 
-------
                                 Table 4
          Emission Factor Hierarchy and Associated Code
Code
1
2
3
4
5
6
7
8
9
10
11
Emission Factor Source
OEMS for May-Sept
1990
Other CEMS for 1990
OEMS for May-Sept
Other CEMS for non
Multiple Stack Tests
Multiple Stack Tests
Single Stack Test at
for non 1990 at representative conditions for 1990
1990 at representative conditions for 1990
at representative conditions for 1990
at representative conditions for non 1 990
representative conditions
AP-42 factors
Single Stack Test at
maximum load
State factors
Industry factors
The emission factor code should be added to the emission factor comment field (as
the first two characters) along with any additional comment (see Figure 2).

If a factor of lower preference within the hierarchy is chosen  when data of higher
preference are available, a justification for using this factor must be provided.
                                   19

-------
V.  EXCEPTIONAL CIRCUMSTANCES

    The MOU allows the use of a year other than 1990 for a base year inventory for
sources successfully demonstrating "exceptional circumstances."  Any source claiming
"exceptional circumstances" must show that operations in 1990 varied significantly from
normal operations. States will consider any claim of "exceptional circumstances" on a
case-by-case basis.

    A second data base will be developed to provide the information that will aid in
determining if a source's operation in 1990 varied significantly from normal operations.
Any recommended change to the emission baseline is the responsibility of the OTC
Stationary/Area Source Committee.

    The second data base will provide information on activity levels for each affected
source in the OTC, and how the actual 1990 information varies from an average. Note
that averages calculated from the  1985-1992 DOE data for utility sources and 1990-1993
data for industrial sources will be  used to flag sources that have indicated they may want
to apply for exceptional circumstances.
                                        20

-------
                            APPENDIX A
                      OTC-NOX Data  Contacts
NAME

Bill Simpson
Tehseen Khokhar
John Outten
Bob Boisselle
Duane King
Jerry Bernier
Andy Bodnarik
Ray Papalski
Rob Sliwinski
Joe White
Wick Havens
Doug McVay
Tom Ballou
Paul Wishinski

Barry Gilbert
Doug Grano
Tom Helms
Roy Huntley
Erica Laich
David Mobley
Chet Wayland
Praveen Amar
Joe Belanger
John Bachmann
David Conroy
Damien Ellis
David Foerter
Raymond Forde
James Hambright
Larry Montgomery
Carla Oldham
Nancy Pitblado
Doris Price
Susy Rothschild
ORG
CT
DC
DE
MA
MD
ME
NH
NJ
NY
PA
PA
RI
VA
VT
OAQPS
OAQPS
OAQPS
OAQPS
Pechan
OAQPS
OAQPS

NESCAUM
CT
OAQPS
ROI
ROII
OTC
ROIII
MARAMA
GAP
OAQPS
CT
OAP
Pechan
PHONE #
203 424-3419
202 645-6093
302 739-4791
617 292-5609
410 631-3231
207 287-2437
603 271-1370
609 633-7225
518 457-2823
717 787-2856
717 787-4310
401 277-2808 ext 7011
804 762-4406
802 241-3862
919 541-5238
919 541-3292
919 541-5527
919 541-1060
703 642-1120 ext 159
919 541-4676
919 541-4603
CC: list
617 367-8540
203 424 3027
919 541-5359
617 565-3254
212 264-9357
202 508-3840
215 597-8239
717 232-1961
202 233-9142
919 541-3347
203 424-3027
202 233-9067
703 642-1120 ext 128
FAX #

203 566-
202 645-
302 739-
617 556-
410 631-
207 287-
603 271-
609 633-
518 457-
717 772-
717 772-
401  277-
804 762
802 241-
    -6144
    -6102
    •3106
     1049
     3202
     7641
     1381
     6198
     0794
     2303
     2303
     2017
     4510
     2590
919
919
919
919
703
919
919
617
203
919
617
212
202
215
717
202
919
203
202
703
541-0824
541-0824
541-0824
541-0684
642-1258
541-0684
541-0684
742-
566-
541-
565-
264-
508-
597-
232-
233-
541-
566-
233-
642-
•9162
•6144
•2464
•4939
7462
•3841
3156
2018
9595
0824
6144
9595
1258
                               A-1

-------
                            APPENDIX B
               MEMBERS OF THE BASELINE REVIEW GROUP
Mr. David Darner, Chairman
United Illuminatin
157 Church Street
P.O. Box 1564
New Haven, CT 06506-0901
203-499-2560
203-499-3512  (fax)

Mr. Madison Milhous
Attn:  New York Power Pool
Manager, Electrical Planning
Long Island Lighting Company
175 E. Country Road
Hicksville, NY  11801

Ms. Sara Pierce-Sandner
Eastman Kodak Co.
Corporate Health, Safety and Environment
1100 Ridgeway Ave.
Rochester, NY  14652-6263

President
Council of Industrial Boiler Owners
6035 Burke Centre Pkwy. #360
Burke, VA  22015

Mr. Jim Murphy
Allegheny Power Service Corporation
800 Cabin Hill Drive
Greensburg, PA  15601

Mr. Bob Orchowski
Central Area Power Coordination Group
Environmental Affairs Unit
Duquesne Light Co.
Chamber of Commerce Bldg.
411 7th Ave, Fl 14-705
Pittsburgh, PA  15219

Mr. Daniel Steen
Ohio Edison Company
76 South Main Street
Akron, OH  44308
216-384-3704
216-384-5433 (fax)

                               B-1
                                                                        '-7

-------
Mr. Vince Brisini
Pennsylvania Electric Company
1001 Broad Street
Johnstown PA  15907
814-533-8811
814-533-8085  (fax)

Ms. Diana Mize
Office of Air Quality
Virginia Power, Innsbrook Tech. Ctr.
5000 Dominion Blvd.
Glen Allen, VA  23060

Mr. Ken Johnson
Electric Generation Association
Duke Energy Company, General Manager, Environmental Affairs and
Tech Mgmt, 400 S. Tyron  St., Suite  1800
Charlotte, NC ' 28285

Mr. Paul Billings
American Lung Association
1726 M St., NW, Suite  902
Washington, DC  20036-4502

Mr. David Hawkins
Natural Resources Defense Council
1350 New York  Ave., NW
Washington, DC 20005
                                B-2

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                                            APPENDIX C
                                       NOx EMISSION FACTORS
                                               for
                             EXTERNAL  and  INTERNAL COMBUSTION SOURCES
                                from AP-42, FOURTH ED., SUPP. A-F
FIRST LEVEL SCC DESCRIPTION (1-digit)
    SECOND LEVEL SCC DESCRIPTION (3-digit)
         Third Level SCC Description (6-digit)
SCC Code
NOx EF
EF Units
Rating   Fourth Level SCC Description
EXTERNAL COMBUSTION BOILERS
ELECTRIC GENERATION
Anthracite Coal
10100101 1.80000E+1 Ib/ton
10100102 9.20000 Ib/ton
Bituminous Coal
10100201 3.40000E+1 Ib/ton
10100202 2.17000E+1 Ib/ton
10100203 3.38000E+1 Ib/ton
10100204 1.37000E+1 Ib/ton
10100205 7.50000 Ib/ton
10100212 1.44000E+1 Ib/ton
10100217 1.30000E+1 Ib/ton
Subbituminous Coal
10100221 3.40000E+1 Ib/ton
10100222 2.17000E+1 Ib/ton
10100223 3.38000E+1 Ib/ton
10100224 1.37000E+1 Ib/ton
10100225 7.50000 Ib/ton
10100226 1.44000E+1 Ib/ton


Burned
Burned

Burned
burned
burned
burned
burned
burned
Burned

burned
burned
burned
burned
burned
burned


B
B

C
A
C
A
A
A
U

C
A
C
A
A
A


Pulverized Coal
Traveling Grate Overfeed Stoker

Pulverized Coal: Wet Bottom
Pulverized Coal: Dry Bottom
Cyclone Furnace
Spreader Stoker
Traveling Grate Overfeed Stoker
Pulverized Coal: Dry Bottom Tangential
Atmospheric Fluidized Bed Combustion

Pulverized Coal: Wet Bottom (Subbituminous)
Pulverized Coal: Dry Bottom (Subbituminous)
Cyclone Furnace (Subbituminous)
Spreader Stoker (Subbituminous)
Traveling Grate Overfeed Stoker (Subbit)
Pulverized Coal: Dry Bottom Tangentl (Subbit)
                                               C-1

-------
                                            APPENDIX C
FIRST LEVEL SCC DESCRIPTION (1-digit)
     SECOND LEVEL SCC DESCRIPTION  (3-digit)
          Third Level SCC Description  (6-digit)
SCC Code    NOx EF      EF Units             Rating   Fourth Level SCC Description
Lignite
10100301 1.11000E+1 Ib/ton
10100302 7.30000 Ib/ton
10100303 1.25000E+1 Ib/ton
10100304 5.80000 Ib/ton
10100306 5.80000 Ib/ton
Residual Oil
10100401 6.70000E+1 lb/1000 gal
10100404 4.20000E+1 lb/1000 gal
10100405 6.70000E+1 lb/1000 gal
10100406 4.20000E+1 lb/1000 gal
Distillate Oil
10100501 2.00000E+1 lb/1000 gal
10100504 6.70000E+1 lb/1000 gal
10100505 4.20000E+1 lb/1000 gal
Natural Gas
10100601 5.50000E+2 Ib/MM cu ft
10100602 1.40000E+2 Ib/MM cu ft
10100604 2.75000E+2 Ib/MM cu ft
Process Gas
10100701 5.50000E+2 Ib/MM cu ft
10100702 1.40000E+2 Ib/MM cu ft
Coke
10100801 2.10000E+1. Ib/ton
Liquified Petroleum Gas (LPG)
10101001 1.32000E+1 lb/1000 gal
10101002 1.24000E+1 lb/1000 gal
burned
burned
burned
burned
burned

Burned
Burned
Burned
Burned

Burned
Burned
Burned

Burned
Burned
Burned

Burned
Burned

Burned

Burned
Burned
C
C
C
C
C

A
A
A
A

U
A
A

A
A
A

U
U

A

C
C
Pulverized Coal
Pulverized Coal: Tangential Firing
Cyclone Furnace
Traveling Grate Overfeed Stoker
Spreader Stoker

Grade 6 Oil: Normal Firing
Grade 6 Oil: Tangential Firing
Grade 5 Oil: Normal Firing
Grade 5 Oil: Tangential Firing

Grades 1 and 2 Oil
Grade 4 Oil: Normal Firing
Grade 4 Oil: Tangential Firing

Boilers > 100 MBtu/Hr except Tangential
Boilers < 100 MBtu/Hr except Tangential
Tangentially Fired Units

Boilers > 100 MBTU/HR
Boilers < 100 MBTU/HR

All Boiler Sizes

Butane
Propane

-------
                                            APPENDIX
FIRST LEVEL SCC DESCRIPTION (1-digit)
     SECOND LEVEL SCC DESCRIPTION (3-digit)
          Third Level SCC Description (6-digit)
SCC Code    NOx EF      EF Units             Rating
Fourth Level SCC Description
INDUSTRIAL




.Anthracite Coal
10200101 1.80000E+1
10200104 9.20000
10200107 3.00000
Ib/ton
Ib/ton
Ib/ton
Burned
Burned
Burned
B
B
B
Pulverized Coal
Traveling Grate Overfeed Stoker
Hand-Fired
Bituminous Coal
10200201 3.40000E+1
10200202 2.17000E+1
10200203 3.38000E+1
10200204 1.37000E+1
10200205 7.50000
10200206 9.50000
10200210 7.50000
10200212' 1.44000E+1
10200217 1.30000E+1
10200219 1.50000E+1
Subbituminous
10200221 3.40000E+1
10200222 2.17000E+1
10200223 3.38000E+1
10200224 1.37000E+1
10200225 7.50000
10200226 1.44000E+1
10200229 1.50000E+1
Lignite
10200301 1.40000E+1
10200302 8.00000
10200303 1.70000E+1
10200304 6.00000
10200306 6.00000
10200307 1.20000E+1
Ib/ton
Ib/ton
Ib/ton
Ib/ton
Ib/ton
Ib/ton
Ib/ton
Ib/ton
Ib/ton
Ib/ton
Coal
Ib/ton
Ib/ton
Ib/ton
Ib/ton
Ib/ton
Ib/ton
Ib/ton

Ib/ton
Ib/ton
Ib/ton
Ib/ton
Ib/ton
Ib/ton
burned
burned
burned
burned
burned
burned
burned
burned
Burned
Burned

burned
burned
burned
burned
burned
burned
Burned

Burned
Burned
Burned
Burned
Burned
Burned
C
A
C
A
A
A
A
A
U
U

C
A
C
A
A
A
U

A
A
A
D
C
U
Pulverized Coal: Wet Bottom
Pulverized Coal: Dry Bottom
Cyclone Furnace
Spreader Stoker
Overfeed Stoker
Underfeed Stoker
Overfeed Stoker **
Pulverized Coal: Dry Bottom Tangential
Atmospheric Fluidized Bed Combustion
Cogeneration

Pulverized Coal: Wet Bottom (Subbituminous)
Pulverized Coal: Dry Bottom (Subbituminous)
Cyclone Furnace (Subbituminous)
Spreader Stoker (Subbituminous)
Traveling Grate (Overfeed) Stoker (Subbit)
Pulverized Coal: Dry Bottom Tangentl (Subbit)
Cogeneration (Subbituminous)

Pulverized Coal
Pulverized Coal: Tangential Firing
Cyclone Furnace
Traveling Grate Overfeed Stoker
Spreader Stoker
Cogeneration
                                               C-3

-------
                                            APPENDIX
FIRST LEVEL SCC DESCRIPTION  (1-digit)
     SECOND LEVEL SCC DESCRIPTION  (3-digit)
          Third Level SCC Description  (6-digit)
SCC Code    NOx EF      EF Units             Rating
Fourth Level SCC Description
Residual Oil
10200401 5.50000E+1
10200403 5.50000E+1
10200404 5.50000E+1
10200405 5.50000E+1

lb/1000 gal
lb/1000 gal
lb/1000 gal
lb/1000 gal

Burned
Burned
Burned
Burned

A
U
A
U

Grade 6 Oil
<10 MMBTU/hr **
Grade 5 Oil
Cogeneration
Distillate Oil
10200501 2.00000E+1
10200502 2.00000E-H
10200503 2.00000E-H
10200504 5.50000E-H
10200505 2.00000E+1
Natural Gas
10200601 5.50000E+2
10200602 1.40000E+2
10200603 1.00000E+2
10200604 1.40000E+2
Process Gas
10200701 1.40000E+2
Coke
10200802 1.40000E+1
10200804 1.40000E+1
lb/1000 gal
lb/1000 gal
lb/1000 gal
lb/1000 gal
lb/1000 gal

Ib/MM cu ft
Ib/MM cu ft
Ib/MM cu ft
Ib/MM cu ft

Ib/MM cu ft

Ib/ton
Ib/ton
Burned
Burned
Burned
Burned
Burned

Burned
Burned
Burned
Burned

Burned

Burned
Burned
A
U
U
A
U

A
A
A
U

U

U
U
Grades 1 and 2 Oil
10-100 MMBTU/hr **
<10 MMBTU/hr **
Grade 4 Oil
Cogeneration

Over 100 MMBTU/Hr
10-100 MMBTU/Hr
Less Than 10 MMBTU/Hr
Cogeneration

Petroleum Refinery Gas

All Boiler Sizes
Cogeneration
Liquified Petroleum Gas (LPG)
10201001 2.10000E+1
10201002 1.90000E+1
lb/1000 gal
lb/1000 gal
Burned
Burned
C
C
Butane
Propane
                                               C-4

-------
                                            APPENDIX C
FIRST LEVEL SCC DESCRIPTION (1-digit)
     SECOND LEVEL SCC DESCRIPTION (3-digit)
          Third Level SCC Description  (6-digit)
SCC Code    NOx EF      EF Units             Rating   Fourth Level SCC Description
COMMERCIAL/INSTITUTIONAL
' Anthracite Coal
10300101 1.80000E-H
10300102 9.20000
10300103 3.00000
Ib/ton
Ib/ton
Ib/ton
Burned
Burned
Burned
B
B
B
Pulverized Coal
Traveling Grate Overfeed Stoker
Hand-Fired
Bituminous Coal
10300203 3.38000E+1
10300205 3.40000E-H
10300206 2.17000E+1
10300207 7.50000
10300208 9.50000
10300209 1.37000E+1
10300211 , 7.50000
10300214 9.10000
10300216 1.44000E+1
10300217 1.30000E+1
Subbi tuminous
10300221 3.40000E+1
10300222 2.17000E+1
10300223 3.38000E+1
10300224 1.37000E+1
10300225 7.50000
10300226 1.44000E+1
Lignite
10300305 1.40000E+1
10300306 8.00000
10300307 6.00000
10300309 6.00000
Ib/ton
Ib/ton
Ib/ton
Ib/ton
Ib/ton
Ib/ton
Ib/ton
Ib/ton
Ib/ton
Ib/ton
Coal
Ib/ton
Ib/ton
Ib/ton
Ib/ton
Ib/ton
Ib/ton

Ib/ton
Ib/ton
Ib/ton
Ib/ton
burned
burned
burned
burned
burned
burned
Burned
burned
burned
Burned

burned
burned
burned
burned
burned
burned

Burned
Burned
Burned
Burned
C
C
A
A
A
A
U
E
A
U

C
A
C
A
A
A

A
A
D
C
Cyclone Furnace
Pulverized Coal: Wet Bottom
Pulverized Coal: Dry Bottom
Overfeed Stoker
Underfeed Stoker
Spreader Stoker
Overfeed Stoker **
Hand-Fired
Pulverized Coal: Dry Bottom Tangential
Atmospheric Fluidized Bed Combustion

Pulverized Coal: Wet Bottom < Subbi tuminous)
Pulverized Coal: Dry Bottom (Subbi tuminous)
Cyclone Furnace (Subbi tuminous)
Spreader Stoker (Subbi tuminous)
Traveling Grate Overfeed Stoker (Subbit)
Pulverized Coal: Dry Bottom Tangentl (Subbit)

Pulverized Coal
Pulverized Coal: Tangential Firing
Traveling Grate (Overfeed) Stoker
Spreader Stoker
                                                C-5

-------
                                            APPENDIX C
FIRST LEVEL SCC DESCRIPTION  (1-digit)
     SECOND LEVEL SCC DESCRIPTION  (3-digit)
          Third Level SCC Description  (6-digit)
SCC Code    NOx EF      EF Units             Rating   Fourth Level SCC Description
Residual Oil
10300401 5.50000E+1 lb/1000 gnl
10300402 5.50000E+1 lb/1000 gal
10300403 5.50000E+1 lb/1000 gal
10300404 5.50000E+1 lb/1000 gal
Distillate Oil
10300501 2.00000E+1 lb/1000 gal
10300502 2.00000E+1 lb/1000 gal
10300503 2.00000E+1 lb/1000 gal
10300504 5.50000E+1 lb/1000 gal
Natural Gas
10300601 5.50000E+2 Ib/MM cu ft
10300602 1.40000E+2 Ib/MM cu ft
10300603 1.00000E+2 Ib/MM cu ft
Liquified Petroleum Gas (LPG)
10301001 1.50000E+1 lb/1000 gal
10301002 1.40000E+1 lb/1 000 gal
SPACE HEATERS
Industrial
10500102 3.00000 Ib/ton
10500106 1.00000E+2 Ib/MM cu ft
10500110 2.00000E+1 lb/1 000 gal
Commercial-Institutional
10500202 3.00000 Ib/ton
10500206 1.00000E+2 Ib/MM cu ft
10500209 1.50000 Ib/ton
10500210 1.45000E+1 lb/1 000 gal

Burned
Burned
Burned
Burned

Burned
Burned
Burned
Burned

Burned
Burned
Burned

Burned
Burned


Burned
Burned
Burned

Burned
Burned
Burned
Burned

A
U
U
A

A
U
U
A

A
A
A

C
C


U
U
U

U
U
U
U

Grade 6 Oil
10-100 MMBTU/hr **
<10 MMBTU/hr **
Grade 5 Oil

Grades 1 and 2 Oil
10-100 MMBTU/hr **
<10 MMBTU/hr **
Grade 4 Oil

Over 100 MMBTU/Hr
10-100 MMBTU/Hr
Less Than 10 MMBTU/Hr

Butane
Propane


Coal **
Na'tural Gas
Liquified Petroleum Gas (LPG)

Coal **
Natural Gas
Wood
Liquified Petroleum Gas (LPG)

-------
                                            APPENDIX C
FIRST LEVEL SCC DESCRIPTION (1-digit)
     SECOND LEVEL SCC DESCRIPTION  (3-digit)
          Third Level SCC Description  (6-digit)
SCC Code    NOx EF      EF Units             Rating   Fourth Level SCC Description
INTERNAL COMBUSTION ENGINES
ELECTRIC GENERATION
Distillate Oil/Diesel
20100101
20100102

20100201
20100202
6.98000E-1
4.69000E+2
Natural Gas
4.40000E-1
4.41000
Ib/MM Btu
lb/1000 gal

Ib/MM Btu
Ib/MM cu ft
Burned
Burned

Burned
Burned
B
U

B
A
Turbine
Reciprocating

Turbine
Reciprocating





Kerosene/Naphtha Jet Fuel
20100901
20100902
6.78000E+1
4.69000E+2
lb/1000 gal
lb/1000 gal
Burned
Burned
U
U
Turbine
Reciprocating


INDUSTRIAL
Distillate Oil/Diesel
20200101
20200102
20200103
20200104

20200201
20200202
20200203
20200204
20200252
20200253
20200254

20200301
6.78000E+1
4.41000
6.78000E+1
4.69000E+2
Natural Gas
3.40000E-1
3.40000E+3
4.13000E+2
3.40000E+3
2.70000
2.30000
3.20000
Gasoline
1.63000
lb/1000 gal
Ib/MM Btu
lb/1000 gal
lb/1000 gal

Ib/MM BTU
Ib/MM cu ft
Ib/MM cu ft
Ib/MM cu ft
Ib/MM BTU
Ib/MM BTU
Ib/MM BTU

Ib/MM Btu
Burned
Burned
Burned
Burned

Burned
Burned
Burned
Burned
Burned
Burned
Burned

Burned
B
C
B
C

A
A
A
A
U
U
U

C
Turbine
Reciprocating
Turbine: Cogeneration
Reciprocating: Cogeneration

Turbine
Reciprocating **
Turbine: Cogeneration
Reciprocating: Cogeneration
Reciprocating: 2 -Cycle Lean
Reciprocating: 4 -Cycle Rich
Reciprocating: 4-Cycle Lean

Reciprocating









Burn
Burn
Burn


Large Bore Engine
20200401
20200402
20200403
3.10000
3.10000
1 .80000E+1
Ib/MM Btu
lb/1000 hp-hr
Burned

lb/100,000 brake hp-hrs
C
C
U
Diesel
Dual Fuel (Oil/Gas)
Cogeneration: Dual Fuel



                                                C-7

-------
                                            APPENDIX C
FIRST LEVEL SCC DESCRIPTION  (1-digit)
     SECOND LEVEL SCC DESCRIPTION  (3-digit)
          Third Level SCC Description  (6-digit)
SCC Code    NOx EF      EF Units             Rating   Fourth Level SCC Description
         Residual/Crude Oil
20200501   4.69000E+2  lb/1000 gal
         Kerosene/Naphtha Jet Fuel
20200901   6.78000E+1  lb/1000 gal
20200902   4.69000E+2  lb/1000 gal
    COMMERCIAL/INSTITUTIONAL
         Distillate Oil/Diesel
20300101
20300102

20300201
20300202

20300301
  4.41000
  6.78000E+1
Natural Gas
  3.40000E+3
  4.13000E+2
Gasoline
  1.63000
Ib/MM Btu
lb/1000 gal
Ib/MM
Ib/MM
cu
cu
ft
ft
Ib/MM Btu
                             Burned    U   Reciprocating

                             Burned    U   Turbine
                             Burned    U   Reciprocating
Burned    C   Reciprocating
Burned    B   Turbine

Burned    A   Reciprocating
Burned    B   Turbine

Burned    C   Reciprocating
                                               C-8

-------
                                      APPENDIX D
                              U. S. EPA — EMISSIONS TRACKING SYSTEM (ETS)
    Average Quarterly NO, Emission Rates from Quality Assured Hours as Reported by 19 Selected Plants
                                          Second Quarter, 1994
ATLANTIC CITY ELECTRIC CO (963)
      t
     B L ENGLAND (ORISPL 002378)


BALTIMORE GAS.fi ELECTRIC CO (1167)

     C P CRANE (ORISPL 001552)


DUQUESNE LIGHT CO (5487)

     CHESWICK (ORISPL 008226)

LONG ISLAND LIGHTING CO (11172)
       /
     NORTHPORT (ORISPL 002516)




     PORT JEFFERSON (ORISPL 002517)


METROPOLITAN EDISON CO  (12390)

     PORTLAND (ORISPL 003113)


NEW YORK STATE ELEC & GAS CORP  (13511)

    ' GREENIDGE (ORISPL  002527)

     MILLIKEN (ORISPL 002535)


NIAGARA MOHAWK POWER CORP  (13573)

     DUNKIRK  (ORISPL 002554)
•Unit/
Common
Stack ID
1
2
1
2
1
1 (OIL)
2 (OIL)
3 (OIL)
4 (OIL)
3 (OIL)
4 (OIL)
1
2
**6
**1
**2
CS0003
3
4
Total Unit
Operating
Time
( hours )
1442.00
1600.00
676.00
1323.00
1950.75
2184.00
2184.00
2184.00
2184.00
2104.50
2157.25
828.75
1724.00
1606.00
2149.50
1816.75
2184.00
1645.75
2180.00
Total Unit
Operating
Time for
QA'd Data
(hours)
1380.00
1546.00
672.00
1321.00
1928.75
1536.00
1806.00
1445.00
1505.00
1354.75
1944.00
802.75
1696.00
1552.00
2085.50
1655.25
1996.00
Average
QA'd NO,
Emission
Rate
(Ib/mmBtu)
0.931
0.995
1.185
1.440
0.437
0.146
0.180
0.171
0.117
0.175
0.245
0.337
0.353
0.505
0.393
0.575
0.458
Peak
QA'd NO,
Emission
Rate
(Ib/mmBtu)
1.407
1.489
1.813
2.127
0.819
0 . 500
0.443
0.428
0.387
0.435
0.426
0.588
21.4631
1.569
0.745
0.781
1.005
                                                     D-l
   1 erroneous value generated by monitor during unit etart-up.
Actual value is 0.695.

-------
                                           APPENDIX D
                              U. S. EPA ~ EMISSIONS TRACKING SYSTEM (ETS)
    Average Quarterly NOX Emission  Rates from  Quality Assured Hours as Reported by 19 Selected Plants
                                          Second Quarter, 1994
PENNSYLVANIA ELECTRIC CO (14711)

     CONEMAUGH (ORISPL 003118)


     SHAWVILLE (ORISPL 003131)
PENNSYLVANIA POWER & LIGHT CO {14715)

     BRUNNER ISLAND (ORISPL 003140)




     MARTINS CREEK (ORISPL 003148)



     SUNBURY (ORISPL 003152)


POTOMAC ELECTRIC POWER CO (15270)

     CHALK POINT (ORISPL 001571)



POTOMAC ELECTRIC POWER CO (15270)

     MORGANTOWN (ORISPL 001573)


PUBLIC SERVICE CO OF NH (15472)

     MERRIMACK (ORISPL 002364)
- Unit/
Common
Stack ID
1
2
CS1
1
2
3
4
CS102
1
2
3
CS102
1
2
3
4
CSE12
0001
0002
1
2
000001
000002
Total Unit
Operating
Time
( hours )
2038.25
2085.25
2083.25
1733.50
1907.50
1927.75
986.50
2053.25
2047.25
530.50
1922.75
1773.50
1494.00
1422.75
2050.25
1992.00
2184.00
2160.00
2160.00
1888.00
1888.00
1968.00
669.00
Total Unit
Operating
Time for
QA'd Data
(hours)
1949.25
1939.50
2051.25
1624.75
1776.50
2039.25
1894.25
1763.50
2019.00
1989.00
1873.00
1882.00
1882.00
1906.00
640.00
Average
QA'd NO.
Emission
Rate
(Ib/mmBtu)
0.666
0.397
0.732
0.471
1.017
0.385
0.814
0.662
0.459
0.989
0.994
0.887
0.366
1.204
1.735
Peak
QA'd NO,
Emission
Rate
(Ib/mmBtu)
0.816
0.662
0.913
0.678
1.222
0.747
1.071
1.042
1.545
1.360
2.536
1.389
1.848
1.603
3.152

-------
                                           APPENDIX D
                              U. S. EPA — EMISSIONS TRACKING SYSTEM (ETS)
    Average Quarterly NOK Emission Rates from Quality Assured Hours as Reported by 19 Selected Plants
                                          Second Quarter, 1994
                                         . Unit/
                                         Common
                                        Stack ID
          Total Unit
          Operating
            Time
           (hours)
            Total Unit
            Operating
            Time for
            QA'd Data
             (hours)
             Average
             QA'd NO.
             Emission
               Rate
            (Ib/mmBtu)
              Peak
           QA'd NO,
            Emission
              Rate
           (Ib/mmBtu)
WEST -PENN POWER -CO (20387)

     ARMSTRONG  (ORISPL 003178)


     HATFIELD'S PERRY (ORISPL 003179)
1
2

CS001
CS002
1
2
3
1855.00
 621.75

2184.00
2184.00
1969.25
2060.50
2184.00
1834.00
 621.75

2180.00
2177.00
0.944
0.975

0.794
0.802
1.240
1.200

1.290
1.110
                                               D-3

-------
                                      ."PPENDIX  D
                                                                                 November 16, 1994
                              SELECTED PHASE I LIST - REGIONS 1-3
    NOK Control Equipment Installed as of June 1994 (may not have been operational for entire 2nd Quarter)
    Atlantic City Electric Co
2378
B L England
1
2
Uncontrolled
Uncontrolled
Cyclone
Cyclone
  Baltimore Gas and Electric
1552
 C P Crane
1
2
Uncontrolled
Uncontrolled
Cyclone
Cyclone
      Duquesne Light Co
8226
 Cheswick
     LNCFS2
                Tangentially Fired
    Long Island Lighting Co
2516
 Northport
1
2
3
4
Other
Uncontrolled
Uncontrolled
Other
Tangentially Fired
Tangentially Fired
Tangentially Fired
Tangentially Fired
                                2517
        Port Jefferson
                3
                4
     Uncontrolled
     Uncontrolled
                Tangentially Fired
                Tangentially Fired
     Metropolitan Edison
3113
 Portland
1
2
Uncontrolled
LNCFS3
Tangentially Fired
Tangentially Fired
NY State Electric and Gas Corp
2527
Greenridge
     Uncontrolled
                Tangentially Fired
                                2535
          Milliken
                1
                2
     LNCFS3
     Uncontrolled
                Tangentially Fired
                Tangentially Fired
 Niagara Mohawk Power Corp
2554
  Dunkirk
3
4
Uncontrolled
Uncontrolled
Tangentially Fired
Tangentially Fired
   Pennsylvania Electric Co
3118
Conemaugh
1
2
Uncontrolled
LNCFS3
Tangentially Fired
Tangentially Fired

-------
                                   APPENDIX D
                                                                            Select Phase I List
                                                                            September 23, 1994
                                                                            Page 2
                               V

                             COt)B
                              3131
         Shawville
                 1
                 2
                 3
                 4
     LNB w/o OFA
     Uncontrolled
     Uncontrolled
     LNCFS3
                Dry Bottom Wall Fired
                Dry Bottom Wall Fired
                Tangentially Fired
                Tangentially Fired
Pennsylvania Power and Light
3140
Brunner Island
1
2
3
LNCFS3
LNCFS3
LNCFS3
Tangentially Fired
Tangentially Fired
Tangentially Fired
                              3148
       Martins Creek
                 1
                 2
     LNB w/ OFA
     LNB w/ OFA
                Dry Bottom Wall Fired
                Dry Bottom Wall Fired
                              3152
          Sunbury
                 3
                 4
     LNB w/OFA
     LNB w/ OFA
                Dry Bottom Wall Fired
                Dry Bottom Wall Fired
 Potomac Electric Power Co
1571
 Chalk Point
1
2
Uncontrolled
LNB w/OFA
Dry Bottom Wall Fired
Dry Bottom Wall Fired
                              1573
        Morgantown
                 1
                 2
     Low NO,
     Burner
     Low NO,
     Burner
                Tangentially Fired
                Tangentially Fired
  Public Service Co of NH
2364
  Merrimack
1
2
Uncontrolled
Uncontrolled
Cyclone
Cyclone
 West Pennsylvania Power Co
3178
  Armstrong
 1
 2
Uncontrolled
Uncontrolled
Dry Bottom WF
Dry Bottom WF
                                       D-5

-------
      APPENDIX D
                                                 Select Phase I List
                                                 September 23, 1994
                                                 Page3
3179
Hatfields Ferry
1
2
3
Uncontrolled
Uncontrolled
Uncontrolled
Cell Burner Wall Fired
Cell Burner Wall Fired
Cell Burner Wall Fired
         D-6

-------
            Appendix E
    Commonwealth of Pennsylvania
Department of Environmental Resources
     Bureau of Air Quality Control
1994

Company Name
AES-BV Partners
AES-BV Partners
AES-BV Partners
Cambria CoGen Co.
Cambria CoGen Co.
Cambria CoGen Co.
Cambria CoGen Co.
Continental Energy Assod
Continental Energy Assod
Continental Energy Assod
Continental Energy Assod
Duquesne Light Co.
Ebensburg Power Co.
Foster Wheeler Mt. Carmel
Foster Wheeler Mt Carmel
General Electric Co.
Gitoerton Power Co.
International Paper Co.
Merck, Sharp, and Dohme
Metropolitan Edison Co.
Metropolitan Edison Co.
Metropolitan Edison Co.
Metropolitan Edison Co.
Metropolitan Edison Co.
Northeastern Power Co.
Northern Consolidated Pow
Northern Consolidated Pow
Northern Consolidated Pow
Northern Consolidated Pow
P.H.GIatfelterCo.
P. H.GIatfelterCo.
P.H.GIatfelterCo.
PECO Enerav Co.

Location
Potter Twp
Potter Twp
Potter Twp
Ebensburg
Ebensburg
Ebensburg
Ebensburg
Hazleton
Hazleton
Hazleton
Hazleton
Elrama
Cambria Tw
Mt. Carmel
ML Carmel
Erie
Frackville
Erie
West Point
Portland
Portland
THus
Titus
Titus
Kline Twp.
North East
North East
North East
North East
Spring Gro
Spring Gro
Spring Gro
Eddystone
NOxCE

Source
Unit 2
Unit3
Unit 4
Unitl
Unitl
Unit 2
Unit 2
Rec. Boi
Rec. Boi
Turbine/
Turbine/
Units 1,
Boiler
Boiler
Boiler
Unit 2
Boilers
Boiler 2
Boiler &
Unitl
Unit 2
Unitl
Unit 2
Units
Boiler
Gas Turb
GasTurb
Gas Turb
GasTurb
Boiler 4
Boiler 5
Boiler 5
Unitl
Ws'on Co

SCC Code
10200202
10200202
10200202








10100202

10101201
10101201
10200204

10200204
20200203
10100201
10100201
10100212
10100212
10100212





10200202
10200219
10200219
10100212
nbustion

Pollparm
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX '
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
Units 250 MBtu o

Units
bs/MBtu
bs/MBtu
bs/MBtu
bs/MBtu
Ibs/hr
Ibs/MBtu
Ibs/hr
Ibs/MBtu
Ibs/hr
Ibs/hr
ppm
Ibs/MBtu
Ibs/MBtu
Ibs/MBtu
Ibs/hr
Ibs/MBtu
Ibs/MBtu
Ibs/MBtu
Ibs/MBtu
Ibs/MBtu
Ibs/MBtu
Ibs/MBtu
Ibs/MBtu
Ibs/MBtu
Ibs/MBtu
Ibs/hr
ppm
Ibs/hr
ppm
Ibs/MBtu
Ibs/MBtu
Ibs/hr
Ibs/MBtu

May
0.84
0.725
0.756
0.29
164.4
0.267
150.9
0.436
381.9
206.1
71
0
0.097
0.1
52.6
0.762
0.163
0
0
0.368
0.359
0.656
0.593
0.631
0.099
17.5
15
18.4
14
0.811
0.363
189.5
0.454
r Create

June
0.782
0.663
0.753
0.251
141.7
0.242
135.5
0
0
0
0
0
0.079
0.088
47.8
0.63
0.157
0
0
0.344
0.364
0.655
0.657
0.658
0.079
135
11
20.5
16
0.909
0.376
190.7
0.409


July
0.712
0.673
0.787
0.237
139
0.226
1245
0.336
336.1
205.9
73
0.573
0.071
0.095
55.8
0.674
0.148
0.184
0.06
0597
0.316
0.673
0.699
0.682
0.074
13.8
12
19.4
15
0.605
0.339
166.5
0.407

Aug
0.75
0.735
0.976
0.255
146.7
0.231
121.1
0.46
400.1
203.6
71
0.568
0.094
0.086
49.1
0
0.155
0.266
0
0.289
0.358
0.638
0.664
0.636
0.07
14.3
12
18.8
15
0.477
0.357
182.2
0.407

Sept
0.743
0.626
0.869
0.289
163.9
0.254
133.8
0.452
401.6
207.4
71
0.581
0.094
0.086
56.5
0
0.161
0.388
0
0.295
0.295
0.664
0.664
0.672
0.058
13
12
14.1
15
0.434
0.327
174.6
0
Average
May-Sept.)
0.765
0.684
0.828
0.264
151.1
0.244
133.1
0.337
303.9
164.6
71
0.574
0.087
0.091
52.4
0.689
0.157
0.168
0.06
0.319
0.338
0.657
0.655
0.656
0.076
14.3
12.5
18.3
15.2
0.647
0.352
180.7
0.419
                 E-1

-------
            Appendix  E
    Commonwealth of Pennsylvania
Department of Environmental Resources
     Bureau of Air Quality Control
1994NOxCE

Company Name
Panther Creek Partners
Panther Creek Partners
Panther Creek Partners
Panther Creek Partners
Pennsylvania Electric Co.
Pennsylvania Electric Co.
Pennsylvania Electric Co.
Pennsylvania Electric Co.
Pennsylvania Electric Co.
Pennsylvania Electric Co.
Pennsylvania Electric Co.
Pennsylvania Electric Co.
Pennsylvania Electric Co.
Pennsylvania Electric Co.
Pennsylvania Electric Co.
Pennsylvania Electric Co.
Pennsylvania Power Co.
Pennsylvania Power Co.
Pennsylvania Power Co.
Pennsylvania Power Co.
Pennsylvania Power Co.
Pennsylvania Power Co.
Pennsylvania Power and U
Pennsylvania Power and U
Pennsylvania Power and Li
Pennsylvania Power and U
Pennsylvania Power and U
Pennsylvania Power and U
Pennsylvania Power and U
Pennsylvania Power and U
Pennsylvania Power and U
Pennsylvania Power and U
Procter & Gamble Paper Pr

Location
Nesquehoni
Nesquehoni
Nesquehoni
Nesquehoni
Conemaugh
Conemaugh
Homer City
Homer City
Homer City
Keystone
Keystone
Seward
Shawville
Shawville
Shawville
Warren
Bruce Mans
Bruce Mans
Bruce Mans
Newcastle
Newcastle
Newcastle
Brunner Is
Brunner Is
Holtwood
Martin's C
Montour
Montour
Sunbury
Sunbury
Sunbury
Sunbury
Mehoopany

Source
Boiler 1
Boiler 1
Boiler 2
Boiler 2
Unitl
Unit 2
Unitl
Unit 2
Unit 3
Unitl
Unit 2
Units 12
Unitl
Unit 2
Units 3,
Units 1,
Unitl
Ms -on Combustion Units 250 MBtu or Create

SCC Code




10100202
10100202
10100202
10100202
10100202
10100202
10100202
10100202
10100202
10100202
10100202
10100202
10100202
Unit 2 10100202
Units
Unit 3
Unit 4
Units
Unit3
Units 1,
Unit 17
Units 1,
Unitl
Unit 2
Unitl
Unit 2
Unit 3
Unit 4
Turbine
10100202
10100202
10100202
10100202
10100202
10100201
10100101
10100201
10100202
10100202
10100101
10100101
10100101
10100101
20200203

Pollparm
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX

Units
Ibs/MBtu
Ibs/hr
Ibs/MBtu
Ibs/hr
Ibs/MBtu
Ibs/MBtu
Ibs/MBtu
Ibs/MBtu
Ibs/MBtu
Ibs/MBtu
Ibs/MBtu
Ibs/MBtu
Ibs/MBtu
Ibs/MBtu
Ibs/MBtu
Ibs/MBtu
Ibs/MBtu
Ibs/MBtu
Ibs/MBtu
Ibs/MBtu
Ibs/MBtu
Ibs/MBtu
Ibs/MBtu
Ibs/MBtu
Ibs/MBtu
Ibs/MBtu
bs/MBtu
bs/MBtu
bs/MBtu
bs/MBtu
bs/MBtu
bs/MBtu
bs/MBtu

May
0.105
49.6
0.111
47.1
0.658
0.387
0
0.622
0.602
0.607
0.628
0.632
0.48
1.031
0.721
0.623
0
0.747
0.429
0.583
0.528
0.638
0.806
0.364
1.093
0.669
0.841
0
0.938
0.725
0.397
0.976
2.907

June
0.102
49.3
0.112
49.6
0.651
0.394
0
0.734
0.582
0.562
0.508
0.657
0.484
0.998
0.706
0.641
0.198
0.785
0.382
0.612
0.556
0.618
0.78
0.357
1.246
0.634
0.875
0.462
0.939
0.756
0.447
0.943
2.599
f

July
0.106
51.4
0.098
43.8
0.642
0.407
0.723
0.746
0.615
0.498
0.419
0.675
0.484
1.021
0.686
0.605
0.17
0.742
0.361
0.57
0.519
0.559
0.783
0.392
1.442
0.579
0.869
0.456
1.043
0.585
0.423
1.03
0

Aug
0.106
52.6
0.1
49.6
0.636
0.416
0.705
0.777
0.579
0.588
0.425
0.633
0.5
0.97
0.663
0.632
0.228
0.722
0.349
0.559
0.531
0.567
0.792
0.414
1.201
0.341
0.822
0.396
0.978
0.632
0.421
0.906
0

Sept
0.111
59.3
0.099
53.8
0.584
0.408
0.77
0.887
0.6
0.588
0.399
0.6
0.488
0.928
0.557
0.574
0.267
0.71
0.373
0.543
0.512
0.609
0.738
0.416
1.018
0.428
0.833
0.381
1.005
0.822
0.435
0.982
0
Average
(May-Sept.)
0.106
52.4
0.104
48.8
0.634
0.402
0.733
0.753
0.596
0.569
0.476
0.639
0.487
0.99
0.667
0.615
0.216
0.741
0.379
0.573
0.529
0.598
0.78
0.389
1.2
0.53
0.848
0.339
0.981
0.704
0.425
0.967
2.753
                E-2

-------
            Appendix  E
    Commonwealth of Pennsylvania
Department of Environmental Resources
     Bureau of Air Quality Control
1994 NOx CEMs on Combustion Units 250 MBtu c

Company Name
Procter & Gamble Paper Pr
Schuylkill Energy Resourc
Scott Paper Co.
Scrubgrass Generating Co.
Scrubgrass Generating Co.
West Penn Power Co.
West Penn Power Co.
West Penn Power Co.
Westwood Energy Propertle
Wheelabrator Frackville

Location
Mehoopany
North Maha
Chester
Kennerdell
Kennerdel!
Hatfield
Hatfield
Mitchell
Joliette
Frackville

Source
Turbine
Boiler
Unit 10
Boiler 1
Boiler 2
Units 1,
Units H2
Unit 33
Unitl
Boiler

SCC Code
20200203
10100101
10100101


10100202
10100202
10100202
10100101
10100101

Pollparm
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX
NOX

Units
Ibs/hr
Ibs/MBtu
Ibs/MBtu
Ibs/MBtu
Ibs/MBtu
Ibs/MBtu
Ibs/MBtu
Ibs/MBtu
Ibs/MBtu
Ibs/MBtu

May
57.8
0.084
0.073
0.17
0.194
0.795
0.813
0.727
0.135
0.143
>r Greater

June
53.8
0.09
0.061
0.15
0.158
0.731
0.802
0.698
0.107
0.13

July
0
0.089
0.05
0.151
0.147
0
0
0
0
0.124

Aug
0
0.115
0.057
0.158
0.155
0
0
0
0
0.129

Sept
0
0.068
0.056
0.135
0.13
0
0
0
0
0.132
Average
(May-Sept.)
55.8
0.089
0.059
0.1.53
0.157
0.763
0.807
0.713
0.121
0.132
                 E-3

-------
UTILITY
                                               Appendix F
                                    Comparison of 1990 and Average Heat Input
PLANT
Five Month Heat Input (MMBtu)
1990 Actual         Average
         Percent from
         Average
CONNECTICUT
CONNECTICUT LIGHT & POWER CO
UNITED ILLUMINATING CO
CONNECTICUT LIGHT & POWER CO
CONNECTICUT LIGHT & POWER CO
CONNECTICUT LIGHT & POWER CO
UNITED ILLUMINATING CO
UNITED ILLUMINATING CO
WALLINGFORD TOWN OF
CONNECTICUT LIGHT & POWER CO
NORWALK HARBOR
BRIDGEPORT HARBOR
MID-CONN/S. MEADOW
MIDDLETOWN
DEVON
ENGLISH
NEW HAVEN HARBOR
PIERCE
MONTVILLE
7004488
15836201
690545
6399355
6173799
143379
9515005
6680
4877069
50646521
6691340
13779466
596525
6996179
4921394
186329
8429914
11046
4469351
46081544
4.7%
14.9%
15.8%
-8.5%
25.4%
-23.1%
12.9%
-39.5%
9.1%
9.9%
DELAWARE
DOVER CITY OF (DE)
DELMARVA POWER & LIGHT CO
DELMARVA POWER & LIGHT CO
DELMARVA POWER & LIGHT CO
MCKEE RUN
DELAWARE CITY
EDGE MOOR
INDIAN RIVER
2388835
2840810
12141801
17219486
34590932
2224264
2749957
14555065
17766611
37295897
7.4%
3.3%
-16.6%
-3.1%
•7.3%
DISTRICT OF COLUMBIA
POTOMAC ELECTRIC POWER CO
BENNING
     3729606
    3729606
 2628648
2628648
 41.9%
41.9%
MAINE
MAINE PUBLIC SERVICE CO
CENTRAL MAINE POWER CO
CENTRAL MAINE POWER CO
BANGOR HYDRO-ELECTRIC CO
CARIBOU
WILLIAM FWYMAN
MASON STEAM
GRAHAM STATION
15087
11039343
91672
94854
11240956
20385
8210422
78240
142568
8451615
-26.0%
34.5%
17.2%
-33.5%
33.0%
Based on 1985 through 1992 Form EIA-767 Fuel Use
and Heat Content Data.
                   F-1

-------
 UTILITY
                                                 Appendix F
                                     Comparison of 1990 and Average Heat Input
PLANT
Five Month Heat Input (MMBtu)
1990 Actual          Average
            Percent from
            Average
 MARYLAND
 BALTIMORE GAS & ELECTRIC CO
 BALTIMORE GAS & ELECTRIC CO
 BALTIMORE GAS & ELECTRIC CO
 POTOMAC ELECTRIC POWER CO
 DELMARVA POWER & LIGHT CO
 POTOMAC ELECTRIC POWER CO
 POTOMAC ELECTRIC POWER CO
 POTOMAC EDISON CO
 BALTIMORE GAS & ELECTRIC CO
 BALTIMORE GAS & ELECTRIC CO
 BALTIMORE GAS & ELECTRIC CO
HERBERT A WAGNER
BRANDON SHORES
RIVERSIDE
MORGANTOWN
VIENNA
DICKERSON
CHALK POINT
R P SMITH
C P CRANE
GOULD STREET
WESTPORT
    17167117
    17150005
    5204887
    30451547
    1448016
    14625493
    31165924
    1952116
    8277970
    1561861
    2169211
  131174147
  14581798
  20381966
   2629931
  26797962
   2044073
  14532882
  29172744
   2221811
   6657885
   894270
   1019666
120934988
 17.7%
-15.9%
 97.9%
 13.6%
-29.2%
  0.6%
  6.8%
-12.1%
 24.3%
 74.7%
112.7%
 8.5%
MASSACHUSETTS
CANAL ELECTRIC CO
MONTAUP ELECTRIC CO
COMMONWEALTH ELECTRIC CO
NEW ENGLAND POWER CO
TAUNTONCITYOF
NEW ENGLAND POWER CO
HOLYOKE WATER POWER CO
WESTERN MASSACHUSETTS ELEC CO
HOLYOKE GAS & ELECTRIC CO
BOSTON EDISON CO
CAMBRIDGE ELECTRIC LIGHT CO
CAMBRIDGE ELECTRIC LIGHT CO
BOSTON EDISON CO
CANAL
SOMERSET
CANNON STREET
BRAYTON POINT
CLEARY FLOOD
SALEM HARBOR
MOUNT TOM
WEST SPRINGFIELD
CABOT-HOLYOKE
MYSTIC
BLACKSTONE STREET
KENDALL SQUARE
NEW BOSTON
21239578
3910615
539696
34973070
1027186
19576214
4762286
2014935
53168
21369349
172613
1213510
19143053
129995273
24743720
4610201
635844
34249402
792620
18720747
4343387
2096554
55887
18232302
174046
1416093
17213060
127283863
-14.2%
-15.2%
-15.1%
2.1%
29.6%
4.6%
9.6%
-3.9%
-4.9%
17.2%
-0.8%
-14.3%
11.2%
2.1%
Based on 1985 through 1992 Form EIA-767 Fuel Use
 and Heat Content Data.
                                                    F-2

-------
 UTILITY

 NEW HAMPSHIRE
 PUBLIC SERVICE CO OF NH
 PUBLIC SERVICE CO OF NH
 PUBLIC SERVICE CO OF NH
                                                 Appendix F
                                     Comparison of 1990 and Average Heat Input
PLANT
MERRIMACK
SCHILLER
NEWINGTON
Five Month Heat Input (MMBtu)
1990 Actual          Average
    9298123
    3850678
    8531869
   21680670
 10297516
  3129841
  8496983
21924340
           Percent from
           Average
 -9.7%
23.0%
 0.4%
-1.1%
 NEW JERSEY
 PUBLIC SERVICE ELECTRIC&GAS CO
 PUBLIC SERVICE ELECTRIC&GAS CO
 ATLANTIC CITY ELECTRIC CO
 VINELANDCITYOF
 PUBLIC SERVICE ELECTRIC&GAS CO
 PUBLIC SERVICE ELECTRIC&GAS CO
 JERSEY CENTRAL POWER&LIGHT CO
 PUBLIC SERVICE ELECTRIC&GAS CO
 JERSEY CENTRAL POWER&LIGHT CO
 JERSEY CENTRAL POWER&LIGHT CO
 PUBLIC SERVICE ELECTRIC&GAS CO
 ATLANTIC CITY ELECTRIC CO
 PUBLIC SERVICE ELECTRIC&GAS CO
NEW YORK
NIAGARA MOHAWK POWER CORP
NEW YORK STATE ELEC & GAS CORP
NIAGARA MOHAWK POWER CORP
JAMESTOWN CITY OF
NEW YORK STATE ELEC & GAS CORP
NIAGARA MOHAWK POWER CORP
CONSOLIDATED EDISON CO-NY INC
ROCHESTER GAS & ELECTRIC CORP
ROCHESTER GAS & ELECTRIC CORP
LONG ISLAND LIGHTING CO
LONG ISLAND LIGHTING CO
BERGEN
BURLINGTON
B L ENGLAND
HOWARD DOWN
HUDSON
KEARNY
GILBERT
MERCER
WERNER
SAYREVILLE
SEWAREN
DEEPWATER
LINDEN
ALBANY
GOUDEY
DUNKIRK
S A CARLSON
JENNISON
C R HUNTLEY
HUDSON AVENUE
ROCHESTER 3
ROCHESTER 7
E F BARRETT
GLENWOOD
7522149
1000256
8345870
603672
19182351
1048472
1066962
11941398
415264
3180352
4349221
5487062
6364965
70507994
9423055
1071459
9222836
819538
16990360
1202205
1331905
12007153
470657
3855303
4170784
5245211
7853537
73664003
-20.2%
-6.6%
-9.5%
-26.3%
12.9%
-12.8%
-19.9%
-0.5%
-11.8%
-17.5%
4.3%
4.6%
-19.0%
•4.3%
    11130920
     3598869
    16211098
     1342533
     1949703
    20765186
     3587545
     1842985
     6633046
    11623544
     5836596
  9674675
  3292802
 14998809
  1142201
  1912920
 17701534
  2157899
  1938041
  5681130
 10750046
  5141742
 15.1%
 9.3%
 8.1%
 17.5%
 1.9%
 17.3%
 66.3%
 -4.9%
 16.8%
 8.1%
 13.5%
Based on 1985 through 1992 Form EIA-767 Fuel Use
and Heat Content Data.
                   F-3

-------
 UTILITY
                                                 Appendix F
                                     Comparison of 1990 and Average Heat Input
 PLANT
Five Month Heat Input (MMBtu)
1990 Actual          Average
          Percent from
          Average
 CONSOLIDATED EDISON CO-NY INC
 CONSOLIDATED EDISON CO-NY INC
 CONSOLIDATED EDISON CO-NY INC
 CONSOLIDATED EDISON CO-NY INC
 NEW YORK STATE ELEC & GAS CORP
 CENTRAL HUDSON GAS & ELEC CORP
 CENTRAL HUDSON GAS & ELEC CORP
 NIAGARA MOHAWK POWER CORP
 POWER AUTHORITY OF STATE OF NY
 CONSOLIDATED EDISON CO-NY INC
 LONG ISLAND LIGHTING CO
 CONSOLIDATED EDISON CO-NY INC
 CONSOLIDATED EDISON CO-NY INC
 ORANGE & ROCKLAND UTILS INC
 ORANGE & ROCKLAND UTILS INC
 NEW YORK STATE ELEC & GAS CORP
 LONG ISLAND LIGHTING CO
 LONG ISLAND LIGHTING CO
 NEW YORK STATE ELEC & GAS CORP
 NEW YORK STATE ELEC & GAS CORP
EAST RIVER
WATERSIDE
59TH STREET
74TH STREET
SOMERSET
DANSKAMMER
ROSETON
OSWEGO
CHARLES POLETTI
RAVENSWOOD
FAR ROCKAWAY
ASTORIA
ARTHUR KILL
BOWLINE POINT
LOVETT
HICKLING
NORTHPORT
PORT JEFFERSON
MILLIKEN
GREENIDGE
8522764
8772012
1424839
2312977
21206019
13272883
24722958
24347913
11461433
34802770
2740456
28761292
9983685
25370744
9590405
2818909
32267311
8778701
9490271
3723658
368894025
7603936
5640199
964080
1721695
19644583
10920618
23062027
14871792
12551297
28031229
2539636
24090495
9945458
20679305
8211344
2598088
30960714
8912442
8158829
4052500
319552066
12.1%
55.5%
47.8%
34.3%
7.9%
21.5%
7.2%
63.7%
-8.7%
24.2%
7.9%
19.4%
0.4%
22.7%
16.8%
8.5%
4.2%
-1.5%
16.3%
-8.1%
15.4%
PENNSYLVANIA
DUQUESNE LIGHT CO
PENNSYLVANIA ELECTRIC CO
WEST PENN POWER CO
PENNSYLVANIA POWER CO
METROPOLITAN EDISON CO
PENNSYLVANIA ELECTRIC CO
PHILADELPHIA ELECTRIC CO
PENNSYLVANIA ELECTRIC CO
PHILADELPHIA ELECTRIC CO
PENNSYLVANIA ELECTRIC CO
WEST PENN POWER CO
CHESWICK
KEYSTONE
ARMSTRONG
BRUCE MANSFIELD
TITUS
WILLIAMSBURG
CROMBY
SHAWVILLE
EDDYSTONE
FRONT STREET
HATFIELD'S FERRY
   14674157
   45583307
    9729304
   57589014
    5415698
     229890
    2920807
   15860472
   13766334
    2125432
   37013588
14953730
47295706
 9871909
56132730
 5034801
  433036
 4405607
15737206
15168139
 2531154
40275697
 -1.9%
 -3.6%
 -1.4%
 2.6%
 7.6%
-46.9%
-33.7%
 0.8%
 -9.2%
-16.0%
 -8.1%
Based on 1985 through 1992 Form EIA-767 Fuel Use
 and Heat Content Data.
                                                    F-4

-------
UTILITY
                                                Appendix F
                                    Comparison of 1990 and Average Heat Input
PLANT
Five Month Heat Input (MMBtu)
1990 Actual          Average
            Percent from
            Average
PENNSYLVANIA ELECTRIC CO
PENNSYLVANIA ELECTRIC CO
PENNSYLVANIA ELECTRIC CO
PENNSYLVANIA POWER & LIGHT CO
PENNSYLVANIA POWER CO
UGI CORP
PENNSYLVANIA POWER & LIGHT CO
METROPOLITAN EDISON CO
PENNSYLVANIA POWER & LIGHT CO
PHILADELPHIA ELECTRIC CO
PHILADELPHIA ELECTRIC CO
PENNSYLVANIA POWER & LIGHT CO
PENNSYLVANIA ELECTRIC CO
DUQUESNE LIGHT CO
WEST PENN POWER CO
PENNSYLVANIA POWER & LIGHT CO
CONEMAUGH
HOMER CITY
SEWARD
HOLTWOOD
NEW CASTLE
HUNLOCK POWER
MONTOUR
PORTLAND
MARTINS CREEK
DELAWARE
SCHUYLKILL
SUNBURY
WARREN
ELRAMA
MITCHELL
BRUNNER ISLAND
45065347
48127800
5831774
2557955
6995337
1870785
39534957
8274798
17350831
2100227
1384331
11703134
2285973
7135985
5626601
36051785
446805623
44928512
46195819
5969319
1898842
7398052
1823188
38330188
6846787
22037536
1824915
1349016
11120249
2363128
8834218
5082870
35263525
453105879
0.3%
4.2%
-2.3%
34.7%
-5.4%
2.6%
3.1%
20.9%
-21.3%
15.1%
2.6%
5.2%
-3.3%
-19.2%
10.7%
2.2%
•1.4%
RHODE ISLAND
NEW ENGLAND POWER CO
NEW ENGLAND POWER CO
MANCHESTER STREET
SOUTH STREET
     2071237
     2125844
    4197081
    1616354
    1327554
   2943908
 28.1%
 60.1%
42.6%
VERMONT
BURLINGTON CITY OF
J C MCNEIL
      496800
     496800
    294586
    294586
 68.6%
68.6%
VIRGINIA
VIRGINIA ELECTRIC & POWER CO
POTOMAC ELECTRIC POWER CO
POSSUM POINT
POTOMAC RIVER
OZONE TRANSPORT REGION

Based on 1985 through 1992 Form EIA-767 Fuel Use
and Heat Content Data.
    10959467
    11073011
   22032478

 1295992106
   13035493
   10348298
  23383791

1237545128
-15.9%
  7.0%
•5.8%

 4.7%
                   F-5

-------
                                                         Appendix G
                                        Form EIA-767 Fuel Use and Heat Input Data by Boiler
ORIS
ID     Utility Nam*

CONNECTICUT
544    CONNECTICUT LIGHT* POWER CO
544    CONNECTICUT LIGHT & POWER CO
544    CONNECTICUT LIGHT & POWER CO
544    CONNECTICUT LIGHT & POWER CO
544    CONNECTICUT LIGHT A POWER CO
544    CONNECTICUT LIGHT & POWER CO
544    CONNECTICUT LIGHT & POWER CO
544    CONNECTICUT LIGHT & POWER CO
546    CONNECTICUT LIGHT & POWER CO
546    CONNECTICUT LIGHT & POWER CO
546    CONNECTICUT LIGHT & POWER CO
548    CONNECTICUT LIGHT & POWER CO
548    CONNECTICUT LIGHT & POWER CO
562    CONNECTICUT LIGHT & POWER CO
662    CONNECTICUT LIGHT & POWER CO
562    CONNECTICUT LIGHT & POWER CO
562    CONNECTICUT LIGHT & POWER CO
563    CONNECTICUT LIGHT & POWER CO
563    CONNECTICUT LIGHT & POWER CO
563    CONNECTICUT LIGHT & POWER CO
563    CONNECTICUT LIGHT & POWER CO
563    CONNECTICUT LIGHT & POWER CO
563    CONNECTICUT LIGHT & POWER CO
568    UNITED ILLUMINATING CO
568    UNITED ILLUMINATING CO
568    UNITED ILLUMINATING CO
568    UNITED ILLUMINATING CO
569    UNITED ILLUMINATING CO
569    UNITED ILLUMINATING CO
6156  UNITED ILLUMINATING CO
6156  UNITED ILLUMINATING CO
6635  WALLINQFORD TOWN OF
6635  WALLINQFORD TOWN OF
6635  WALLINGFORD TOWN OF
Plant Name
DEVON
DEVON
DEVON
DEVON
DEVON
DEVON
DEVON
DEVON
MONTVILLE
MONTVILLE
MONTVILLE
NORWALK HARBOR
NORWALK HARBOR
MIDDLETOWN
MIDDLETOWN
MIDDLETOWN
MIDDLETOWN
MID-CONN/S. MEADOW
MID-CONN/S. MEADOW
MID-CONN/S. MEADOW
MID-CONN/S. MEADOW
MID-CONN/S. MEADOW
MID-CONN/S. MEADOW
BRIDGEPORT HARBOR
BRIDGEPORT HARBOR
BRIDGEPORT HARBOR
BRIDGEPORT HARBOR
ENGLISH
ENGLISH
NEW HAVEN HARBOR
NEW HAVEN HARBOR
PIERCE
PIERCE
PIERCE
DOE         Five Month Fuel Us* (SCO unite)  Five Month Heat Input (MMBtu)
Boiler                        % from                    % from
ID     Fuel   1990    Average   Average    1990     Average   Average
3
4A
4B
5A
SB
6
7
8
5
5
6
1
2
1
2
3
4
11
11
12
12
13
13
BHB1
BHB2
BHB3
BHB3
EB13
EB14
NHB1
NHB1
1
2
3
OH
01
oil
oil
oil
oil
ol
ol
gas
ol
ol
ol
ol
ol
ol
ol
ol
coal
gas
coal
gas
coal
gas
ol
ol
coal
d
d
d
gas
ol
ol
ol
ol
4452.0
1083.6
1083.6
1062.6
1062.6
4699.8
15262.8
12117.0
1297.4
2625.0
20785.8
22012.2
24255.0
2671.2
7110.6
24948.0
8047.2
15800.0
0.5
5300.0
0.5
5400.0
0.5
10117.8
22167.6
413900.0
29.4
373.8
571.2
1972.5
49375.2
0.0
21.0
25.2
3747.0
1166.9
1166.9
1078.0
1078.0
3997.8
11263.9
11272.3
1013.5
2030.2
20746.4
22042.1
22478.4
3330.0
8898.8
20755.4
9502.5
7800.0
1.5
4566.7
1.5
6600.0
1.4
7881.3
20173.1
368525.0
697.2
525.0
714.0
1350.6
47774.0
34.7
34.3
18.9
18.8
•7.1
-7.1
-1.4
•1.4
17.6
35.5
7.5
28.0
29.3
0.2
-0.1
7.9
•19.8
-20.1
20.2
-15.3
102.6
-66.7
16.1
-66.7
-18.2
-64.3
28.4
9.9
12.3
-95.8
•28.8
-20.0
46.1
3.4
-100.0
-38.8
33.3
673201
163831
163831
160709
160709
710757
2308362
1832399
1336322
397292
3143455
3331966
3672522
399857
1064998
3733325
1201175
410800
515
137800
515
140400
515
1528483
3349108
10954173
4439
56703
86676
2037089
7477918
0
3036
3644
564041
175876
175875
162576
162543
602052
1696608
1696803
1043866
304413
3116759
3312886
3378453
496822
1328048
3099025
1416760
203194
1501
118994
1501
172000
1373
1186892
3040542
9758217
104885
78900
107429
1393968
7210193
5011
4967
2738
19.4
-6.8
-6.8
•1.1
-1.1
18.1
36.1
8.0
28.0
30.5
0.9
0.6
8.7
•19.5
-19.8
20.5
-15.2
102.2
-65.7
15.8
•65.7
•18.4
-62.5
28.8
10.1
12.3
-95.8
•28.1
•19.3
46.1
3.7
-100.0
-38.9
33.1
                                                             G-1

-------
                                                        Appendix G
                                        Form EIA-767 Fuel Use and Heat Input Data by Boiler
OR1S
ID    Utnity Name

DELAWARE
502   DELMARVA POWER & LIGHT CO
592   DELMARVA POWER A LIGHT CO
592   DELMARVA POWER AUGHT CO
592   DELMARVA POWER & LIGHT CO
592   DELMARVA POWER ALIGHT CO
592   DELMARVA POWER & LIGHT CO
592   DELMARVA POWER AUGHT CO
592   DELMARVA POWER AUGHT CO
593   DELMARVA POWER AUGHT CO
593   DELMARVA POWER A LIGHT CO
593   DELMARVA POWER AUGHT CO
593   DELMARVA POWER A LIGHT CO
593   DELMARVA POWER A LIGHT CO
593   DELMARVA POWER A LIGHT CO
594   DELMARVA POWER A LIGHT CO
594   DELMARVA POWER AUGHT CO
594   DELMARVA POWER AUGHT CO
594   DELMARVA POWER A LIGHT CO
594   DELMARVA POWER A LIGHT CO
594   DELMARVA POWER A LIGHT CO
594   DELMARVA POWER A LIGHT CO
594   DELMARVA POWER A LIGHT CO
599   DOVER CITY OF (DE)
599   DOVER CITY OF (DE)
590   DOVER CITY OF (DE)
599   DOVER CfTY OF (DE)
599   DOVER CITY OF (DE)
599   DOVER CITY OF (DE)

DISTRICT OF COLUMBIA
603   POTOMAC ELECTRIC POWER CO
603   POTOMAC ELECTRIC POWER CO
Plant Name
DELAWARE CITY
DELAWARE CITY
DELAWARE CITY
DELAWARE CITY
DELAWARE CITY
DELAWARE CITY
DELAWARE CITY
DELAWARE CfTY
EDGE MOOR
EDGE MOOR
EDGE MOOR
EDGE MOOR
EDGE MOOR
EDGE MOOR
INDIAN RIVER
INDIAN RIVER
INDIAN RIVER
INDIAN RIVER
INDIAN RIVER
INDIAN RIVER
INDIAN RIVER
INDIAN RIVER
MCKEE RUN
MCKEE RUN
MCKEE RUN
MCKEE RUN
MCKEE RUN
MCKEE RUN
BENNING
BENNING
DOE
Boiler
ID
B1
B1
B2
B2
B3
B3
B4
B4
3
3
4
4
5
5
1
1
2
2
3
3
4
4
1
1
2
2
3
3
15
16
Fuel
gas
oil
gas
dl
gas
01
gas
01
coal
ol
coal
ol
gas
ol
coal
ol
coal
ol
coal
ol
coal
ol
gas
ol
gas
d
gas
ol
ol
ol
Five Month
Fuel UM (SCO units) Five Month
% front
1990 Average Average
531.6
176.4
662.0
117.6
473.9
373.8
813.7
155.4
90800.0
172.2
126900.0
1260.0
1355.1
31722.6
69600.0
46.2
81200.0
126.0
170400.0
483.0
338100.0
323.4
333.2
0.0
198.9
0.0
110.5
11382.0
13788.6
12247.2
506.2
412.8
523.5
417.0
489.6
528.0
591.2
909.0
82676.0
429.5
161400.0
524.5
1805.5
36350.2
82162.5
453.6
85762.5
288.8
160288.0
561.8
346400.0
496.7
139.9
593.8
102.5
273.0
116.4
11494.9
8664.1
9680.0
5.0
-57.3
26.5
-71.8
-3.2
-29.2
37.6
-82.9
9.8
-59.0
-21.4
140.2
-24.0
-12.7
•15.3
•80.8
-5.3
-56.4
6.3
•14.0
•2.4
•34.0
138.2
-100.0
04.0
-100.0
-5.1
-1.0
59.1
26.5
Heat Input (MMBtu)
%from
1990 Average Average
578682
26641
711839
17702
517934
56299
008359
23354
2393005
25610
3340499
189295
1404288
4789104
1810444
6316
2116819
17373
4453713
67048
8702920
44853
344473
0
205538
0
114250
1724574
1977741
1751865
574054
61847
593054
62495
554001
70260
673408
136331
2221128
63898
4336706
78530
1871165
5483725
2127304
61454
2220011
39346
4149785
76747
9023226
67837
144382
90091
105819
41409
120539
1740072
1241091
1386657
0.8
•56.9
20.0
-71.7
-6.7
-29.0
34.9
•82.9
7.7
•59.9
•23.0
141.0
•25.0
-12.7
-14.9
-89.7
•4.7
-55.8
7.3
•12.6
-3.5
•33.9
138.6
•100.0
94.2
•100.0
-5.2
-0.9
59.2
26.3

-------
                                                         Appendix G
                                         Form EIA-767 Fuel Use and Heat Input Data by Boiler
ORIS
ID     Utility Nam*

MAINE
1470   BANQOR HYDRO-ELECTRIC CO
1470   BANQOR HYDRO-ELECTRIC CO
1470   BANGOR HYDRO-ELECTRIC CO
1486   CENTRAL MAINE POWER CO
1496   CENTRAL MAINE POWER CO
1496   CENTRAL MAINE POWER CO
1507   CENTRAL MAINE POWER CO
1507   CENTRAL MAINE POWER CO
1507   CENTRAL MAINE POWER CO
1507   CENTRAL MAINE POWER CO
1513   MAINE PUBLIC SERVICE CO
1513   MAINE PUBLIC SERVICE CO

MARYLAND
1552   BALTIMORE GAS & ELECTRIC CO
1552   BALTIMORE GAS & ELECTRIC CO
1552   BALTIMORE GAS & ELECTRIC CO
1552   BALTIMORE GAS & ELECTRIC CO
1553   BALTIMORE GAS & ELECTRIC CO
1554   BALTIMORE GAS & ELECTRIC CO
1554   BALTIMORE GAS & ELECTRIC CO
1554   BALTIMORE GAS & ELECTRIC CO
1554   BALTIMORE GAS & ELECTRIC CO
1554   BALTIMORE GAS & ELECTRIC CO
1554   BALTIMORE GAS & ELECTRIC CO
1554   BALTIMORE GAS & ELECTRIC CO
15S4   BALTIMORE GAS & ELECTRIC CO
1559   BALTIMORE GAS & ELECTRIC CO
1559   BALTIMORE GAS & ELECTRIC CO
1559   BALTIMORE GAS & ELECTRIC CO
1559   BALTIMORE GAS & ELECTRIC CO
1559   BALTIMORE GAS & ELECTRIC CO
1559   BALTIMORE GAS & ELECTRIC CO
1559   BALTIMORE GAS & ELECTRIC CO
1559   BALTIMORE GAS & ELECTRIC CO
1559   BALTIMORE GAS & ELECTRIC CO
1559   BALTIMORE GAS & ELECTRIC CO
1560   BALTIMORE GAS & ELECTRIC CO
1560   BALTIMORE GAS & ELECTRIC CO
1564   DELMARVA POWER & LIGHT CO
Plant Name
GRAHAM STATION
GRAHAM STATION
GRAHAM STATION
MASON STEAM
MASON STEAM
MASON STEAM
WILLIAM F WYMAN
WILLIAM FWYMAN
WILLIAM F WYMAN
WILLIAM F WYMAN
CARIBOU
CARIBOU
C P CRANE
C P CRANE
C P CRANE
C P CRANE
GOULD STREET
HERBERT A WAGNER
HERBERT A WAGNER
HERBERT A WAGNER
HERBERT A WAGNER
HERBERT A WAGNER
HERBERT A WAGNER
HERBERT A WAGNER
HERBERT A WAGNER
RIVERSIDE
RIVERSIDE
RIVERSIDE
RIVERSIDE
RIVERSIDE
RIVERSIDE
RIVERSIDE
RIVERSIDE
RIVERSIDE
RIVERSIDE
WESTPORT
WESTPORT
VIENNA
DOE
Boiler
ID
3
4
5
3
4
5
1
2
3
4
1
2
1
1
2
2
3
1
1
2
2
3
3
4
4
1
1
2
2
3
3
4
4
5
5
3
4
8
Fuel
01
01
d
ol
oil
oil
d
oH
01
ol
ol
ol
coal
ol
coal
d
d
gas
d
coal
gas
coal
gas
gas
ol
gas
d
gas
d
gas
d
gas
d
gas
d
d
d
d
Five Month Fuel Uee (SCO unite)
% from
1990 Average Average
75.6
168.0
382.2
205.8
239.4
163.8
2851.8
2499.0
8253.0
59850.0
50.4
50.4
136300.0
138.6
172300.0
180.6
10428.6
1881.1
0.0
136000.0
151.2
300100.0
276.2
11.3
22965.6
9.4
6699.0
23.0
5405.4
14.1
4746.0
1265.9
29.4
17.3
8706.6
5863.2
8647.8
9643.2
138.6
288.0
521.4
217.6
179.8
122.6
2618.7
2847.6
10875.4
38334.5
48.7
86.5
108575.0
115.0
141300.0
111.0
5966.6
1353.7
1944.6
118100.0
137.3
296063.0
118.1
32.8
18251.1
10.2
3339.0
19.7
2449.1
35.5
2710.6
498.4
1638.0
18.5
3804.7
2825.0
3995.8
12886.3
-45.6
-41.7
-26.7
-5.4
33.1
33.6
8.9
-12.2
-24.1
56.1
3.5
-41.7
25.5
20.5
21.9
62.7
74.8
39.0
-100.0
15.2
10.1
1.4
133.9
-65.5
25.8
-7.8
100.6
16.8
120.7
•60.3
75.1
154.0
-98.2
-6.5
128.8
107.5
116.4
•25.2
Five Month Heat Input (MMBtu)
Strom
1990 Average Average
11460
25461
57933
30979
36036
24657
428833
376110
1241914
6992486
7544
7543
3633282
19134
4600601
24953
1561861
1955656
0
3531666
157330
7792541
287320
11748
3430856
9768
1000626
23898
807083
14675
708854
1317523
4414
17996
1300050
876404
1292807
1448016
20832
43304
78432
32748
27050
18442
393818
428304
1635140
5753160
7342
13042
2878700
15963
3749762
15382
894270
1412828
291033
3052742
143082
7676450
123124
34375
2730425
10645
499110
20632
366247
37180
405737
520122
245794
19334
568849
422113
597553
1943573
-45.0
-41.2
-26.1
-5.4
33.2
33.7
8.9
-12.2
•24.0
56.3
2.8
-42.2
26.2
19.9
22.7
62.2
74.7
38.4
-100.0
15.7
10.0
1.5
133.4
•65.8
25.7
•8.2
100.5
15.8
120.4
•60.5
74.7
153.3
•98.2
-6.9
128.5
107.6
116.4
-25.5
                                                             G-3

-------
                                                         Appendix G
                                        Form EIA-767 Fuel Use and Heat Input Data by Boiler
ORIS
ID    Uffltty Name

1570  POTOMAC EDISON CO
1570  POTOMAC EDISON CO
1570  POTOMAC EDISON CO
1570  POTOMAC EDISON CO
1571  POTOMAC ELECTRIC POWER CO
1571  POTOMAC ELECTRIC POWER CO
1571  POTOMAC ELECTRIC POWER CO
1571  POTOMAC ELECTRIC POWER CO
1571  POTOMAC ELECTRIC POWER CO
1671  POTOMAC ELECTRIC POWER CO
1571  POTOMAC ELECTRIC POWER CO
1571  POTOMAC ELECTRIC POWER CO
1572  POTOMAC ELECTRIC POWER CO
1572  POTOMAC ELECTRIC POWER CO
1572  POTOMAC ELECTRIC POWER CO
1572  POTOMAC ELECTRIC POWER CO
1572  POTOMAC ELECTRIC POWER CO
1572  POTOMAC ELECTRIC POWER CO
1573  POTOMAC ELECTRIC POWER CO
1573  POTOMAC ELECTRIC POWER CO
1573  POTOMAC ELECTRIC POWER CO
1573  POTOMAC ELECTRIC POWER CO
602   BALTIMORE GAS & ELECTRIC CO
602   BALTIMORE QAS & ELECTRIC CO
602   BALTIMORE QAS & ELECTRIC CO
602   BALTIMORE QAS & ELECTRIC CO

MASSACHUSETTS
1588  BOSTON EDISON CO
1588  BOSTON EDISON CO
1588  BOSTON EDISON CO
1588  BOSTON EDISON CO
1588  BOSTON EDISON CO
1589  BOSTON EDISON CO
1589  BOSTON EDISON CO
1589  BOSTON EDISON CO
1589  BOSTON EDISON CO
1594  CAMBRIDQE ELECTRIC LIGHT CO
1594  CAMBRIDQE ELECTRIC LIGHT CO
1594  CAMBRIDQE ELECTRIC LIGHT CO
1594  CAMBRIDGE ELECTRIC LIGHT CO
 Plant Nam*

 R P SMITH
 R P SMITH
 R P SMITH
 R P SMITH
 CHALK POINT
 CHALK POINT
 CHALK POINT
 CHALK POINT
 CHALK POINT
 CHALK POINT
 CHALK POINT
 CHALK POINT
 DICKERSON
 DICKERSON
 DICKERSON
 DICKERSON
 DICKERSON
 DICKERSON
 MORQANTOWN
 MORQANTOWN
 MORGANTOWN
 MORGANTOWN
 BRANDON SHORES
 BRANDON SHORES
 BRANDON SHORES
 BRANDON SHORES
MYSTIC
MYSTIC
MYSTIC
MYSTIC
MYSTIC
NEW BOSTON
NEW BOSTON
NEW BOSTON
NEW BOSTON
BLACKSTONE STREET
BLACKSTONE STREET
BLACKSTONE STREET
BLACKSTONE STREET
DOE
Five Month Fuel UM (SCC unit*)
Boiler
ID
11
11
9
9
1
1
2
2
3
3
4
4
1
1
2
2
3
3
1
1
2
2
1
1
2
2
4
5
6
7
7
1
1
2
2
11
11
12
12
Fuel
coal
d
cod
oR
cod
oil
coal
oil
gas
d
gas
d
coal
d
coal
ol
coal
cl
coal
d
coal
oil
coal
d
coat
d
d
d
d
gas
d
gas
d
gas
d
gas
d
gas
d
1990
75200.0
88.2
1300.0
16.8
346500.0
344.4
347000.0
357.0
3723.8
28782.6
2188.5
19236.0
193200.0
88.2
196400.0
92.4
191400.0
105.0
600000.0
520.8
587200.0
970.2
671000.0
453.6
0.0
0.0
19051.2
16073.4
13944.0
11576.4
9681.0
6712.5
11558.4
8315.5
12234.6
40.9
54.6
51.8
67.2
Average
81400.0
66.7
7337.5
28.4
344838.0
264.6
351550.0
307.7
1777.6
32036.5
2435.4
20761.7
189800.0
205.3
184650.0
170.6
194275.0
160.7
497888.0
1245.3
545038.0
1812.3
650163.0
609.0
400800.0
613.2
15541.1
12010.4
15461.3
7114.1
28476.0
5563.9
24667.1
5044.1
17267.8
39.5
61.8
44.2
50.4
Sfrom
Average
-7.6
32.2
•82.3
•40.8
0.5
30,2
•1.3
16.0
109.6
•10.2
•10.1
•7.3
1.9
•67.0
6.4
•45.8
•1.6
-34.7
20.5
•58.2
7.7
-46.6
3.2
-25.5
-100.0
-100.0
22.6
33.6
•9.8
62.7
-66.0
20.6
•63.1
64.9
-29.1
3.6
•11.7
17.2
33.3
Five Month Meet Input (MMBtu)

1990
1903788
12436
33523
2369
8839094
47188
8854003
48971
3889180
4311308
2288039
2888053
4861778
12153
4929743
12726
4794639
14455
15310043
77606
14919328
144570
17087339
62666
0
0
2889795
2421266
2099861
12517190
1461248
6938843
1751322
8594540
1858348
40900
8301
51800
10210

Average
2025947
9402
182465
3997
8695355
36504
8865020
42433
1861669
4791004
2S52712
3112653
4862652
28397
4675371
23596
4920640
22226
12585162
184898
13757387
270516
16444957
84467
10188711
84736
2329640
1799992
2318312
7509370
4274988
5745284
3693483
5202038
2572255
39457
9235
44200
7546
%from
Average
-6.0
32.3
-81.6
-40.7
1.7
29.3
•0.1
16.4
108.9
•10.0
•10.4
-7.2
0.0
•57.2
6.4
-46.1
-2.6
•35.0
21.7
-58.0
8.4
-46.6
3.9
-25.8
-100.0
-100.0
23.2
34.5
•9.4
66.7
•65.8
20.8
•62.6
65.2
•27.8
3.7
•10.1
17.2
35.3

-------
ORIS
ID     Utility Nam*

1594   CAMBRIDGE ELECTRIC LIGHT CO
1594   CAMBRIDGE ELECTRIC LIGHT CO
1594   CAMBRIDGE ELECTRIC LIGHT CO
1594   CAMBRIDGE ELECTRIC LIGHT CO
1595   CAMBRIDGE ELECTRIC LIGHT CO
1595   CAMBRIDGE ELECTRIC LIGHT CO
1595   CAMBRIDGE ELECTRIC LIGHT CO
1595   CAMBRIDGE ELECTRIC LIGHT CO
1595   CAMBRIDGE ELECTRIC LIGHT CO
1595   CAMBRIDGE ELECTRIC LIGHT CO
1599   CANAL ELECTRIC CO
1599   CANAL ELECTRIC CO
1606   HOLYOKE WATER POWER CO
1606   HOLYOKE WATER POWER CO
1613   MONTAUP ELECTRIC CO
1613   MONTAUP ELECTRIC CO
1613   MONTAUP ELECTRIC CO
1613   MONTAUP ELECTRIC CO
1616   COMMONWEALTH ELECTRIC CO
1616   COMMONWEALTH ELECTRIC CO
1616   COMMONWEALTH ELECTRIC CO
1616   COMMONWEALTH ELECTRIC CO
1616   COMMONWEALTH ELECTRIC CO
1616   COMMONWEALTH ELECTRIC CO
1619   NEW ENGLAND POWER CO
1619   NEW ENGLAND POWER CO
1619   NEW ENGLAND POWER CO
1619   NEW ENGLAND POWER CO
1619   NEW ENGLAND POWER CO
1619   NEW ENGLAND POWER CO
1619   NEW ENGLAND POWER CO
1626   NEW ENGLAND POWER CO
1626   NEW ENGLAND POWER CO
1626   NEW ENGLAND POWER CO
1626   NEW ENGLAND POWER CO
1626   NEW ENGLAND POWER CO
1626   NEW ENGLAND POWER CO
1626   NEW ENGLAND POWER CO
1642   WESTERN MASSACHUSETTS ELEC CO
1642   WESTERN MASSACHUSETTS ELEC CO
1642   WESTERN MASSACHUSETTS ELEC CO
                                                        Appendix G
                                       Form EIA-767 Fuel Use and Heat Input Data by Boiler
Plant Name

BLACKSTONE STREET
BLACKSTONE STREET
BLACKSTONE STREET
BLACKSTONE STREET
KENDALL SQUARE
KENDALL SQUARE
KENDALL SQUARE
KENDALL SQUARE
KENDALL SQUARE
KENDALL SQUARE
CANAL
CANAL
MOUNT TOM
MOUNTTOM
SOMERSET
SOMERSET
SOMERSET
SOMERSET
CANNON STREET
CANNON STREET
CANNON STREET
CANNON STREET
CANNON STREET
CANNON STREET
BRAYTON POINT
BRAYTON POINT
BRAYTON POINT
BRAYTON POINT
BRAYTON POINT
BRAYTON POINT
BRAYTON POINT
SALEM HARBOR
SALEM HARBOR
SALEM HARBOR
SALEM HARBOR
SALEM HARBOR
SALEM HARBOR
SALEM HARBOR
WEST SPRINGFIELD
WEST SPRINGFIELD
WEST SPRINGFIELD
DOE
Boiler
ID
5
5
6
6
1
1
2
2
3
3
1
2
1
1
7
7
8
a
1
1
2
2
3
3
1
1
2
2
3
3
4
1
1
2
2
3
3
4
1
2
3
Fuel
gas
ol
gas
ol
gas
ol
gas
ol
gas
ol
ol
ol
coal
ol
coal
ol
coal
d
gas
ol
gas
ol
gas
ol
coal
ol
coal
ol
coal
ol
ol
coal
ol
coal
ol
coal
ol
ol
ol
ol
gas
Five Month Fuel Us* (SCO unite)
%from
1990 Average Avenge
37.5
33.6
13.7
33.6
236.7
319.2
144.5
142.8
665.9
651.0
68212.2
73038.0
182900.0
75.6
75400.0
1667.4
59800.0
898.8
97.6
159.6
97.6
159.6
238.0
390.6
292500.0
403.2
313300.0
130.2
380700.0
1684.2
60685.8
103600.0
147.0
106400.0
310.8
141900.0
390.6
68426.4
277.2
1087.8
1535.7
50.1
72.6
10.5
14.4
220.7
385.2
223.0
348.6
653.1
1293.6
74467.5
89809.1
163338.0
45.0
65937.5
1165.5
96237.5
1093.6
98.3
272.4
98.3
274.8
250.1
709.8
260838.0
508.7
266050.0
1680.5
447863.0
969.2
53076.4
90262.5
189.5
97662.5
194.8
163038.0
336.0
63010.0
1210.2
1455.6
1232.5
-25.1
-53.7
30.5
133.3
7.2
-17.1
-35.2
-59.0
2.0
-49.7
-8.4
-18.7
12.0
68.0
14.4
43.1
-37.9
-17.8
-0.7
-41.4
-0.7
-41.9
-4.8
-45.0
12.1
-20.7
17.8
-92.3
•15.0
73.8
14.3
14.8
-22.4
8.9
69.5
-13.0
16.3
8.6
-77.1
-25.3
24.6
Five Month Heat Input (MMBtu)
Sfrom
1990 Avenge Avenge
37500
5094
13700
5108
236700
47341
144500
21192
665900
97877
10260896
10978682
4751784
10502
1969373
246072
1562840
132330
97600
23946
97600
23946
238000
58604
7600383
56516
8149090
19166
9864211
234109
9049595
2682245
22178
2755167
46933
3671865
58929
10338897
41627
163876
1560726
60086
10830
10529
2164
220657
57483
223043
62061
669424
193425
11216381
13527339
4337942
6223
1739666
171619
2537954
160962
98271
40982
98300
41351
250129
106810
6833754
74766
6972790
249201
11729421
139657
7943195
2353185
28308
2542946
29233
4248790
60325
9467959
181496
218478
1236610
-25.1
•53.0
30.1
136.0
7.3
-17.6
-35.2
-59.3
•0.5
-49.4
-8.5
-18.8
9.5
68.8
13.2
43.4
-38.4
-17.8
-0.7
•41.6
-0.7
-42.1
-4.8
•45.1
11.2
•24.4
16.9
•92.3
-15.9
67.6
13.9
14.0
-21.7
8.3
60.5
-13.6
17.1
9.2
-77.1
-25.0
26.2
                                                            0-5

-------
                                                            Appendix G
                                          Form EIA-767 Fuel Use and Heat Input Data by Boiler
ORIS
ID    Utility Nairn

1642  WESTERN MASSACHUSETTS ELEC CO
1682  TAUNTON CITY OF
1682  TAUNTON CFTY OF
1682  TAUNTON CFTY OF
9864  HOLYOKE GAS & ELECTRIC CO
9864  HOLYOKE GAS & ELECTRIC CO
9864  HOLYOKE GAS & ELECTRIC CO
9864  HOLYOKE GAS & ELECTRIC CO
9864  HOLYOKE GAS & ELECTRIC CO
9864  HOLYOKE GAS & ELECTRIC CO
9864  HOLYOKE GAS & ELECTRIC CO
NEW HAMPSHIRE
2364  PUBLIC SERVICE CO OF NH
2364  PUBLIC SERVICE CO OF NH
2364  PUBLIC SERVICE CO OF NH
2364  PUBLIC SERVICE CO OF NH
2367  PUBLIC SERVICE CO OF NH
2367  PUBLIC SERVICE CO OF NH
2367  PUBLIC SERVICE CO OF NH
2367  PUBLIC SERVICE CO OF NH
2367  PUBLIC SERVICE CO OF NH
2367  PUBLIC SERVICE CO OF NH
2367  PUBLIC SERVICE CO OF NH
2367  PUBLIC SERVICE CO OF NH
8002  PUBLIC SERVICE CO OF NH

NEW JERSEY
2378  ATLANTIC CITY ELECTRIC CO
2378  ATLANTIC CITY ELECTRIC CO
2378  ATLANTIC CITY ELECTRIC CO
2384  ATLANTIC CITY ELECTRIC CO
2384  ATLANTIC CITY ELECTRIC CO
2384  ATLANTIC CITY ELECTRIC CO
2384  ATLANTIC CITY ELECTRIC CO
2384  ATLANTIC CITY ELECTRIC CO
2384  ATLANTIC CITY ELECTRIC CO
2384  ATLANTIC CITY ELECTRIC CO
2384  ATLANTIC CITY ELECTRIC CO
2384  ATLANTIC CITY ELECTRIC CO
2384  ATLANTIC CITY ELECTRIC CO
 Plant Name

 WEST SPRINGFIELD
 CLEARY FLOOD
 CLEARY FLOOD
 CLEARY FLOOD
 CABOT-HOLYOKE
 CABOT-HOLYOKE
 CABOT-HOLYOKE
 CABOT-HOLYOKE
 CABOT-HOLYOKE
 CABOT-HOLYOKE
 CABOT-HOLYOKE
MERRIMACK
MERRIMACK
MERRIMACK
MERRIMACK
SCHILLER
SCHILLER
SCHILLER
SCHILLER
SCHILLER
SCHILLER
SCHILLER
SCHILLER
NEWINGTON
BL ENGLAND
B L ENGLAND
BL ENGLAND
DEEPWATER
DEEPWATER
DEEPWATER
DEEPWATER
DEEPWATER
DEEPWATER
DEEPWATER
DEEPWATER
DEEPWATER
DEEPWATER
DOE
Boiler
ID
3
8
9
9
5
5
6
6
7
8
8
1
1
2
2
1
2
4
4
5
5
6
6
1
1
2
3
1
1
4
7
7
8
8
8
9
9
Fuel
OH
off
gas
01
gas
ofl
gas
OH
gas
gas
dl
coal
OH
coal
oil
01
01
coal
01
coal
01
coal
01
OH
coal.
coal
oi
gas
oi
ol
coal
ol
coal
gas
oil
coal
01
Five Month
FuelUae(SCCunKe)
%from
1990 Average Average
1650.6
730.8
874.7
105.0
3.1
0.0
36.9
33.6
0.7
5.2
4.2
127400.0
4.2
223100.0
16.8
1155.0
1155.0
10600.0
5531.4
10400.0
5913.6
13400.0
5220.6
55150.2
120200.0
144600.0
10844.4
807.8
2255.4
1549.8
27400.0
928.2
76600.0
1.4
58.8
49300.0
428.4
3386.3
605.9
730.5
921.4
4.7
27.0
22.7
79.2
1.9
6.7
40.3
127238.0
5.8
260275.0
11.6
539.7
537.6
19587.5
2997.2
18150.0
2570.4
26912.5
2973.1
54108.6
116675.0
152275.0
15529.5
820.8
2691.2
452.8
34850.0
1164.5
71687.5
30.7
36.6
38475.0
884.1
-51.3
20.6
19.7
-88.6
-34.0
-100.0
62.6
•57.6
•63.2
•22.4
-89.6
0.1
-27.6
-14.3
44.8
114.0
114.8
-46.9
84.6
•42.7
130.1
•50.2
75.6
1.9
3.0
•5.0
•30.2
•1.6
•16.2
242.3
•21.4
•20.3
6.9
•05.4
60.7
28.1
-51.5
Five Month
Heat Input (MMBtu)
%from
1990 Average Average
248706
109620
901816
15750
3205
0
38132
5092
723
5376
640
3382391
581
5912818
2333
179668
179668
279636
859547
273098
916567
352106
810290
8531869
3042662
3663828
1639380
840470
335327
229235
688726
137561
1934768
1452
8718
1247064
63721
509966
90835
752252
137596
4817
4069
23280
11946
2009
6915
6056
3385402
800
6900709
1605
83671
83350 .
528119
462505
484455
306038
716221
458002
8380246
2086008
3801682
2330888
860726
403003
67171
884430
174326
1844626
31818
5480
075184
132100
-51.2
20.7
19.9
-88.6
-33.5
-100.0
63.8
-57.4
•64.0
•22.3
•89.4
•0.1
-27.4
•14.4
45.4
114.7
115.6
•47.1
85.8
-43.6
130.9
•50.8
76.9
1.8
1.9
•5.9
-20.0
•1.2
•17.0
241.3
•22.1
-21.1
4.0
•05.4
50.1
27.9
-51.8

-------
                                                          Appendix G
                                         Form EIA-767 Fuel Use and Heat Input Data by Boiler
ORIS
ID     Utility Nam*                     Plant Name

2385  JERSEY CENTRAL POWER&UGHT CO  WERNER
2390  JERSEY CENTRAL POWER&UGHT CO  SAYREVILLE
2390  JERSEY CENTRAL POWER&UGHT CO  SAYREVILLE
2390  JERSEY CENTRAL POWER&LIGHT CO  SAYREVILLE
2390  JERSEY CENTRAL POWER&LIGHT CO  SAYREVILLE
2390  JERSEY CENTRAL POWER&LIGHT CO  SAYREVILLE
2390  JERSEY CENTRAL POWER&LIGHT CO  SAYREVILLE
2390  JERSEY CENTRAL POWER&LIGHT CO  SAYREVILLE
2390  JERSEY CENTRAL POWER&LIGHT CO  SAYREVILLE
2390  JERSEY CENTRAL POWER&LIGHT CO  SAYREVILLE
2390  JERSEY CENTRAL POWER&UGHT CO  SAYREVILLE
2393  JERSEY CENTRAL POWER&LIGHT CO  GILBERT
2393  JERSEY CENTRAL POWER&LIGHT CO  GILBERT
2393  JERSEY CENTRAL POWER&LIGHT CO  GILBERT
2393  JERSEY CENTRAL POWER&LIGHT CO  GILBERT
2393  JERSEY CENTRAL POWER&LIGHT CO  GILBERT
2393  JERSEY CENTRAL POWER&UGHT CO  GILBERT
2393  JERSEY CENTRAL POWER&UGHT CO  GILBERT
2393  JERSEY CENTRAL POWER&LIGHT CO  GILBERT
2393  JERSEY CENTRAL POWER&LIGHT CO  GILBERT
2393  JERSEY CENTRAL POWER&UGHT CO  GILBERT
2398  PUBLIC SERVICE ELECTRIC&GAS CO  BERGEN
2398  PUBUC SERVICE ELECTRIC&GAS CO  BERGEN
2398  PUBLIC SERVICE ELECTRIC&GAS CO  BERGEN
2399  PUBUC SERVICE ELECTRIC&GAS CO  BURLINGTON
2403  PUBLIC SERVICE ELECTRIC&GAS CO  HUDSON
2403  PUBUC SERVICE ELECTRIC&GAS CO  HUDSON
2403  PUBLIC SERVICE ELECTRIC&GAS CO  HUDSON
2404  PUBUC SERVICE ELECTRIC&GAS CO  KEARNY
2404  PUBUC SERVICE ELECTRIC&GAS CO  KEARNY
2406  PUBLIC SERVICE ELECTRIC&GAS CO  LINDEN
2406  PUBUC SERVICE ELECTRIC&GAS CO  LINDEN
2406  PUBLIC SERVICE ELECTRIC&GAS CO  LINDEN
2408  PUBLIC SERVICE ELECTRIC&GAS CO  LINDEN
2406  PUBLIC SERVICE ELECTRIC&GAS CO  LINDEN
2406  PUBLIC SERVICE ELECTRIC&GAS CO  LINDEN
2406  PUBLIC SERVICE ELECTRIC&GAS CO  LINDEN
2406  PUBLIC SERVICE ELECTRIC&GAS CO  LINDEN
2406  PUBLIC SERVICE ELECTRIC&GAS CO  LINDEN
2406  PUBLIC SERVICE ELECTRIC&GAS CO  LINDEN
2408  PUBLIC SERVICE ELECTRIC&GAS CO  MERCER
DOE
Boiler
ID
04
02
03
05
05
06
06
07
07
08
08
01
01
02
02
03
03
04
05
06
07
1
1
2
7
1
2
2
7
8
11
11
12
12
13
13
2
2
4
4
1
Five Month Fuel UM (SCO unHa)
%from
Fuel
01
oR
oH
gas
ofl
gas
ofl
gas
OK
gas
ofl
gas
ofl
gas
ofl
gas
ofl
ofl
ofl
ofl
ofl
gas
ofl
gas
ofl
gas
coal
gas
ofl
ofl
gas
ofl
gas
ofl
gas
ofl
gas
ofl
gas
ofl
coal
1990 Average Average
2801.4
50.4
12.6
43.1
4.2
156.8
21.0
640.1
3607.8
1018.4
4800.6
46.1
382.2
30.3
252.0
323.3
2116.8
441.0
441.0
457.8
403.2
4209.3
0.0
3074.9
6657.0
5547.4
484400.0
578.2
3179.4
3964.8
1.9
14586.6
1.9
14586.6
0.0
2759.4
3.2
4502.4
1.1
6690.6
222200.0
3177.6
72.6
37.3
96.3
23.1
149.4
35.7
1495.8
1900.0
1452.0
1750.4
67.2
301.9
48.8
236.8
415.9
2961.5
507.7
453.1
383.3
525.5
4133.7
3293.3
4166.4
7156.8
4709.8
373600.0
1625.2
4086.6
4087.1
1.6
14518.9
1.6
11452.4
0.5
11564.7
4.0
10470.1
0.0
5084.6
211900.0
-11.8
-30.6
-66.2
-55.2
-81.8
5.0
•41.2
-57.2
89.9
•29.9
174.3
-31.4
26.6
-37.9
6.4
•22.3
•28.5
•13.1
-2.7
19.4
•23.3
1.8
•100.0
-26.2
-7.0
17.8
29.7
-64.4
•22.2
-3.0
18.8
0.5
18.8
27.4
•100.0
•78.1
-20.0
-57.0
22.2
31.6
4.9
Five Month Heat Input (MMBtu)
%from
1990 Average Average
415264
7201
1835
44521
626
161963
3078
660642
535531
1051399
713556
47553
57217
31256
37732
333662
317216
61298
61309
63656
56063
4347531
0
3174618
1000256
5723598
12862184
596569
466659
681813
1959
2150008
1959
2150008
0
408129
3298
662691
1134
985779
6092170
470657
10492
5449
99185
3399
153867
5226
1541613
281055
1496899
259430
69180
45341
50215
35591
429178
443994
70309
62291
53025
72781
4264102
482949
4298550
1071459
4903997
9875357
1684706
600973
601232
1597
2147156
1648
1692880
515
1709781
4085
1549262
876
752283
5746233
-11.8
-31.4
-66.3
-55.1
-81.6
5.3
-41.1
-57.1
90.5
-29.8
175.0
-31.3
26.2
-37.8
6.0
-22.3
-28.6
-12.8
-1.6
20.0
-23.0
2.0
-100.0
-26.1
•6.6
16.7
30.2
-64.6
•22.3
-3.2
22.7
0.1
18.9
27.0
•100.0
•76.1
-18.9
-57.2
29.5
31.0
6.0
                                                              G-7

-------
                                                          Appendix G
                                         Form EIA-767 Fuel Use and Heat Input Data by Boiler
ORIS
ID    UtHHy Name

2408  PUBLIC SERVICE ELECTRIC&GAS CO
2408  PUBLIC SERVICE ELECTRIC&QAS CO
2408  PUBLIC SERVICE ELECTRIC&GAS CO
2411  PUBLIC SERVICE ELECTRIC&GAS CO
2411  PUBLIC SERVICE ELECTRIC&GAS CO
2411  PUBLIC SERVICE ELECTRIC&GAS CO
2411  PUBLIC SERVICE ELECTRIC&GAS CO
2411  PUBLIC SERVICE ELECTRIC&GAS CO
2411  PUBLIC SERVICE ELECTRIC&GAS CO
2411  PUBLIC SERVICE ELECTRIC&GAS CO
2411  PUBLIC SERVICE ELECTRIC&GAS CO
2434  VINELANDCfTYOF
2434  VINELANDCITYOF
2434  VINELANDCITYOF
2434  VINELANDCITYOF
2434  VINELANDCfTYOF
2434  VINELANDCfTYOF

NEW YORK
2480  CENTRAL HUDSON GAS & ELEC CORP
2480  CENTRAL HUDSON GAS & ELEC CORP
2480  CENTRAL HUDSON GAS & ELEC CORP
2480  CENTRAL HUDSON GAS & ELEC CORP
2480  CENTRAL HUDSON GAS & ELEC CORP
2480  CENTRAL HUDSON GAS & ELEC CORP
2480  CENTRAL HUDSON GAS ft ELEC CORP
2480  CENTRAL HUDSON GAS ft ELEC CORP
2490  CONSOLIDATED EDISON CO-NY INC
2490  CONSOLIDATED EDISON CO-NY INC
2491  POWER AUTHORITY OF STATE OF NY
2491  POWER AUTHORITY OF STATE OF NY
2493  CONSOLIDATED EDISON CO-NY INC
2493  CONSOLIDATED EDISON CO-NY INC
2493  CONSOLIDATED EDISON CO-NY INC
2493  CONSOLIDATED EDISON CO-NY INC
2493  CONSOLIDATED EDISON CO-NY INC
2493  CONSOLIDATED EDISON CO-NY INC
2496  CONSOLIDATED EDISON CO-NY INC
2500  CONSOLIDATED EDISON CO-NY INC
2500  CONSOLIDATED EDISON CO-NY INC
2500  CONSOLIDATED EDISON CO-NY INC
 Plant Name

 MERCER
 MERCER
 MERCER
 SEWAREN
 SEWAREN
 SEWAREN
 SEWAREN
 SEWAREN
 SEWAREN
 SEWAREN
 SEWAREN
 HOWARD DOWN
 HOWARD DOWN
 HOWARD DOWN
 HOWARD DOWN
 HOWARD DOWN
 HOWARD DOWN
DANSKAMMER
DANSKAMMER
DANSKAMMER
DANSKAMMER
DANSKAMMER
DANSKAMMER
DANSKAMMER
DANSKAMMER
ARTHUR KILL
ARTHUR KILL
CHARLES POLETTI
CHARLES POLETTI
EAST RIVER
EAST RIVER
EAST RIVER
EAST RIVER
EAST RIVER
EAST RIVER
HUDSON AVENUE
RAVENSWOOD
RAVENSWOOD
RAVENSWOOD
DOE
Rve Month Fuel Uee (SCC unite)
Boiler
ID
1
2
2
1
1
2
2
3
3
4
4
10
10
4
7
8
9
1
1
2
2
3
3
4
4
20
30
001
001
50
50
60
60
70
70
100
10
10
20
Fuel
gas
coal
gas
gas
d
gas
d
gas
d
gas
d
coal
d
d
d
d
d
gas
d
gas
d
coal
gas
coal
gas
d
d
gas
d
gas
d
gas
d
gas
d
d
gas
d
gas
1990
618.1
172900.0
434.2
725.5
214.2
1008.2
336.0
915.4
285.6
1373.4
529.2
0.0
1848.0
100.8
268.8
659.4
1138.2
1654.9
0.0
1465.2
0.0
154700.0
8.2
223800.0
53.0
31655.4
35880.6
10095.4
7257.6
380.1
13700.4
1180.6
11881.8
1380.3
11600.4
24276.0
6886.0
2948.4
6179.0
Average
427.2
182150.0
871.8
508.8
381.7
933.9
1034.8
819.4
689.3
1221.9
1828.6
16828.6
632.1
162.0
247.2
456.0
1152.6
1017.6
1204.9
977.8
731.3
120233.0
64.8
222567.0
75.5
21959.2
30976.1
10697.0
11564.2
186.9
14132.5
1011.1
11369.9
1570.7
6575.1
14242.2
5972.9
1019.0
5912.7
% from
Average
44.7
•5.1
•50.2
42,6
•43.9
8.0
-67.5
11.7
•58.6
12.4
•71.1
•100.0
192.4
-37.8
8.7
44.6
•1.2
62.6
-100.0
49.8
•100.0
28.7
•87.3
0.6
-29.8
44.2
15.8
-6.6
-37.2
103.4
-3.1
16.8
4.5
-12.1
76.4
70.5
15.3
189.3
4.5
Five Month Heel Input (MMBtu)

1990
636703
4765183
447342
748192
31513
1039783
49432
944017
42017
1416411
77856
0
277747
15139
40381
99176
171229
1710616
0
1514408
0
4077903
8484
5906676
54796
4681642
5302043
10405892
1055541
392882
2017868
1220203
1754043
1426230
1711538
3587545
7116156
437010
6386513

AVMV00
440477
4919852
900591
524471
56175
962894
152129
844734
101407
1260305
288669
434692
94845
24396
37179
68512
173463
1048972
179802
1009023
109028
3143511
66897
5835286
78038
3248442
4673981
10663879
1687418
192624
2089784
1043189
1682324
1622018
973998
2105478
6165159
150729
6102366
% from
Average
44.5
-3.1
-50.3
42.7
-43.9
8.0
•67.5
11.8
-58.6
12.4
•71.0
•100.0
192.8
-37.9
8.6
44.8
•1.3
63.1
-100.0
50.1
-100.0
29.7
•87.3
1.2
-29.8
44.1
15.9
•4.2
•37.4
104.0
-3.4
17.0
4.3
•12.1
75.7
70.4
15.4
189.9
4.7
                                                             o-a

-------
                                                          Appendix G
                                         Form EIA-767 Fuel Use and Heat Input Data by Boiler
ORIS
ID    Utility Name

2500  CONSOLIDATED EDISON CO-NY INC
2500  CONSOLIDATED EDISON CO-NY INC
2500  CONSOLIDATED EDISON CO-NY INC
2502  CONSOLIDATED EDISON CO-NY INC
2502  CONSOLIDATED EDISON CO-NY INC
2502  CONSOLIDATED EDISON CO-NY INC
2502  CONSOLIDATED EDISON CO-NY INC
2502  CONSOLIDATED EDISON CO-NY INC
2502  CONSOLIDATED EDISON CO-NY INC
2502  CONSOLIDATED EDISON CO-NY INC
2502  CONSOLIDATED EDISON CO-NY INC
2502  CONSOLIDATED EDISON CO-NY INC
2502  CONSOLIDATED EDISON CO-NY INC
2502  CONSOLIDATED EDISON CO-NY INC
2502  CONSOLIDATED EDISON CO-NY INC
2503  CONSOLIDATED EDISON CO-NY INC
2503  CONSOLIDATED EDISON CO-NY INC
2503  CONSOLIDATED EDISON CO-NY INC
2503  CONSOLIDATED EDISON CO-NY INC
2503  CONSOLIDATED EDISON CO-NY INC
2503  CONSOLIDATED EDISON CO-NY INC
2504  CONSOLIDATED EDISON CO-NY INC
2504  CONSOLIDATED EDISON CO-NY INC
2504  CONSOLIDATED EDISON CO-NY INC
2511   LONG ISLAND LIGHTING CO
2511   LONG ISLAND LIGHTING CO
2511   LONG ISLAND LIGHTING CO
2511   LONG ISLAND LIGHTING CO
2513  LONG ISLAND LIGHTING CO
2513  LONG ISLAND LIGHTING CO
2514  LONG ISLAND LIGHTING CO
2514  LONG ISLAND LIGHTING CO
2514  LONG ISLAND LIGHTING CO
2514  LONG ISLAND LIGHTING CO
2516  LONG ISLAND LIGHTING CO
2516  LONG ISLAND LIGHTING CO
2516  LONG BLAND LIGHTING co
2516  LONG ISLAND LIGHTING CO
2517  LONG ISLAND LIGHTING CO
2517  LONG ISLAND LIGHTING CO
2517  LONG ISLAND LIGHTING CO
Plant Name

RAVENSWOOD
RAVENSWOOD
RAVENSWOOD
WATERSIDE
WATERSIDE
WATERSIDE
WATERSIDE
WATERSIDE
WATERSIDE
WATERSIDE
WATERSIDE
WATERSIDE
WATERSIDE
WATERSIDE
WATERSIDE
59TH STREET
59TH STREET
59TH STREET
59TH STREET
59TH STREET
59TH STREET
74TH STREET
74TH STREET
74TH STREET
E F BARRETT
E F BARRETT
E F BARRETT
E F BARRETT
FAR ROCKAWAY
FAR ROCKAWAY
GLENWOOD
GLENWOOD
GLENWOOD
GLENWOOD
NORTHPORT
NORTHPORT
NORTHPORT
NORTHPORT
PORT JEFFERSON
PORT JEFFERSON
PORT JEFFERSON
DOE         Five Month Fuel UM (SCO units)  Flv» Month Heat Input (MMBtu)
Boiler                        %from                     %from
ID      Fuel   1990     Average  Avaraga   1990     Avaraga   Average
20
30
30
51
51
52
52
61
61
62
62
80
80
90
90
110
111
112
113
114
115
120
121
122
10
10
20
20
40
40
40
40
60
50
1
2
3
4
1
2
3
01
gas
ofl
gas
ol
gas
ol
gas
ol
gas
ol
gas
ol
gas
ol
ol
ol
ol
ol
ol
ol
ol
ol
ol
gas
ol
gas
ol
gas
ofl
gas
ol
gas
ol
ol
ol
ol
ofl
ol
ol
ol
0.0
13279.0
48090.0
171.3
0.0
164.6
0.0
1105.7
0.0
1086.1
0.0
2895.2
407.4
2909.8
680.4
0.0
1764.0
1738.8
1789.2
2188.2
2188.2
2028.6
6241.2
7329.0
5480.2
823.2
5557.0
764.4
2497.4
1100.4
2778.4
373.8
2763.8
420.0
49408.8
59056.2
63525.0
42197.4
2394.0
2175.6
28240.8
929.8
8725.7
43779.8
525.8
14.2
534.7
15.8
616.9
58.8
781.0
66.2
1184.0
101.9
1614.7
143.3
998.2
1406.5
1423.8
1075.2
1029.0
857.3
4032.0
4103.4
3501.2
4975.8
267.2
5358.3
297.2
2394.2
490.8
2432.8
203.4
2488.6
382.8
47939.9
53262.3
56715.8
47891.6
2889.1
2957.3
26835.9
-100.0
52.2
9.8
•67.4
-100.0
-69.2
•100.0
79.2
-100.0
39.1
•100.0
144.5
299.8
80.2
374.8
-100.0
25.4
22.1
66.4
112.7
155.2
-49.7
52.1
109.3
10.1
206.1
3.7
157.2
4.3
124.2
14.2
83.8
11.1
9.7
3.1
10.9
12.0
•11.9
•17.1
•26.4
5.2
0
13730991
7132100
177006
0
170091
0
1142703
0
1122463
0
2991920
60331
3006676
100822
0
261103
257708
264646
320691
320691
300799
925439
1086739
5654125
122311
5733531
113577
2577278
163178
2866888
55440
2851976
62292
7441116
8893035
9566110
6367050
360600
327776
4254044
137684
8998817
6476474
543180
2081
552468
2310
637097
8654
806974
9742
1222950
16008
1668563
21159
147084
208064
210662
159160
150202
125679
596249
607269
518177
5136296
39479
5530387
43885
2466932
72704
2503903
30011
2562214
66417
7216180
8022661
8541993
7179881
432941
443521
4039892
-100.0
52.6
10.1
•67.4
-100.0
-69.2
-100.0
79.4
•100.0
39.1
•100.0
144.6
302.0
80.2
376.5
-100.0
25.5
22.3
66.3
113.5
155.2
-49.6
52.4
109.7
10.1
209.8
3.7
158.8
4.5
124.4
14.5
84.7
11.3
10.4
3.1
10.8
12.0
•11.3
-16.7
-26.1
5.3
                                                              Q-9

-------
                                                        Appendix G
                                        Form EIA-767 Fuel Use and Heat Input Data by Boiler
ORIS
ID    Utility Name

2517  LONG ISLAND LIGHTING CO
2526  NEW YORK STATE ELEC A GAS CORP
2526  NEW YORK STATE ELEC A GAS CORP
2526  NEW YORK STATE ELEC & GAS CORP
2526  NEW YORK STATE ELEC & GAS CORP
2526  NEW YORK STATE ELEC A GAS CORP
2526  NEW YORK STATE ELEC A GAS CORP
2527  NEW YORK STATE ELEC A GAS CORP
2527  NEW YORK STATE ELEC A GAS CORP
2527  NEW YORK STATE ELEC A GAS CORP
2527  NEW YORK STATE ELEC A GAS CORP
2527  NEW YORK STATE ELEC A GAS CORP
2527  NEW YORK STATE ELEC A GAS CORP
2528  NEW YORK STATE ELEC A GAS CORP
2529  NEW YORK STATE ELEC A GAS CORP
2529  NEW YORK STATE ELEC A GAS CORP
2529  NEW YORK STATE ELEC A GAS CORP
2531   NEW YORK STATE ELEC A GAS CORP
2531   NEW YORK STATE ELEC A GAS CORP
2531   NEW YORK STATE ELEC A GAS CORP
2531   NEW YORK STATE ELEC A GAS CORP
2535  NEW YORK STATE ELEC A GAS CORP
2535  NEW YORK STATE ELEC A GAS CORP
2535  NEW YORK STATE ELEC A GAS CORP
2535  NEW YORK STATE ELEC A GAS CORP
2539  NIAGARA MOHAWK POWER CORP
2539  NIAGARA MOHAWK POWER CORP
2539  NIAGARA MOHAWK POWER CORP
2539  NIAGARA MOHAWK POWER CORP
2539  NIAGARA MOHAWK POWER CORP
2539  NIAGARA MOHAWK POWER CORP
2539  NIAGARA MOHAWK POWER CORP
2539  NIAGARA MOHAWK POWER CORP
2549  NIAGARA MOHAWK POWER CORP
2549  NIAGARA MOHAWK POWER CORP
2549  NIAGARA MOHAWK POWER CORP
2549  NIAGARA MOHAWK POWER CORP
2549  NIAGARA MOHAWK POWER CORP
2549  NIAGARA MOHAWK POWER CORP
2554  NIAGARA MOHAWK POWER CORP
2554  NIAGARA MOHAWK POWER CORP
 Plant Name

 PORT JEFFERSON
 GOUDEY
 GOUDEY
 GOUDEY
 GOUDEY
 GOUDEY
 GOUDEY
 GREENIDGE
 GREENIDGE
 GREENIDGE
 GREENIDGE
 GREENIDGE
 GREENIDGE
 HICKLING
 HICKLING
 HICKLING
 HICKLING
 JENNISON
 JENNISON
 JENNISON
 JENNISON
 MILLIKEN
 MILLIKEN
 MILLIKEN
 MILLIKEN
 ALBANY
 ALBANY
 ALBANY
 ALBANY
 ALBANY
 ALBANY
 ALBANY
 ALBANY
 C R HUNTLEY
 C R HUNTLEY
 C R HUNTLEY
 C R HUNTLEY
C R HUNTLEY
C R HUNTLEY
DUNKIRK
DUNKIRK
uut
Boiler
ID
4
11
11
12
12
13
13
4
4
5
5
6
6
1
2
3
4
1
2
3
4
1
1
2
2
1
1
2
2
3
3
4
4
63
64
65
66
67
68
1
2
Fuel
ol
coal
ol
coal
ol
coat
oil
coal
d
coal
ol
coal
ol
coal
coal
coal
coal
coal
coal
coal
coal
coal
ol
coal
ol
gas
d
gas
d
gas
ol
gas
ol
coal
coal
coal
coal
coal
coal
coal
coal
rive Nionin
riMi wee iai>v* urm»;
Sfrofn
1990 Average Average
25477.2
25000.0
25.2
24900.0
25.2
89100.0
37.8
10600.0
50.4
9000.0
37.8
130800.0
63.0
26100.0
26500.0
38400.0
39500.0
25600.0
26100.0
21700.0
21300.0
193000.0
12.6
197100.0
4.2
2085.1
2856.0
2011.1
5262.6
2058.7
3599.4
2147.4
4985.4
114900.0
95200.0
95800.0
85800.0
217100.0
192300.0
88100.0
104400.0
26540.3
23187.5
70.4
23100.0
69.3
85325.0
36.8
26887.6
54.6
26200.0
40.4
113271.0
53.6
26328.6
26257.1
32257.1
33828.6
22114.3
24042.9
21957.1
22585.7
162113.0
16.8
170025.0
25.7
1803.4
4142.8
1993.7
3078.0
1961.1
1382.3
1951.3
3694.2
79087.5
83650.0
89137.5
79037.5
163625.0
185038.0
101488.0
100988.0
-4.0
7.8
-64.2
7.8
-63.6
4.4
2.7
-60.6
•7.7
•66.6
•23.5
16.6
17.5
•0.9
0.9
10.0
16.8
15.8
8.6
•1.2
•6.7
19.1
•26.0
16.9
•83.7
16.6
•31.1
0.9
71.0
6.0
160.4
10.0
36.0
46.3
13.8
7.5
8.6
32.7
3.9
-13.2
3.4
nvemonin
DMI input immDiu;
%from
1990 Average Average
3836281
646523
3444
644006
3444
2296286
5166
263329
6931
223766
5199
3215779
8664
662922
573272
829478
853237
525193
535487
448809
440214
4692791
1742
4795157
581
2162834
431068
2085904
793964
2134624
543170
2227198
752160
3006426
2494140
2506038
2245566
5565896
4947121
2324492
2751522
3996089
577350
7670
575499
7758
2120225
4300
669860
6024
662263
6608
2810670
6462
576053
574324
707158
741652
466629
607342
463103
476845
3983961
1308
4170885
2676
1862002
621727
2056929
460761
2025394
207109
2013763
653812
2075042
2199564
2341147
2078036
4214266
4793480
2636064
2622101
-4.0
12.0
-55.1
11.9
-55.6
8.3
20.1
-60.7
15.1
-66.7
•7.3
14.4
34.1
•2.1
•0.2
17.3
15.1
12.8
5.5
•3.1
•7.7
17.8
33.2
15.0
-78.3
16.2
•30.7
1.4
72,3
5.4
162.3
10.6
35.8
44.9
13.4
7.0
8.1
32.1
3.2
•11.8
4.9

-------
                                                        Appendix G
                                        Form EIA-767 Fuel Use and Heat Input Data by Boiler
ORIS
ID     Utility Name

2554  NIAGARA MOHAWK POWER CORP
2554  NIAGARA MOHAWK POWER CORP
2594  NIAGARA MOHAWK POWER CORP
2594  NIAGARA MOHAWK POWER CORP
2594  NIAGARA MOHAWK POWER CORP
2594  NIAGARA MOHAWK POWER CORP
2594  NIAGARA MOHAWK POWER CORP
2594  NIAGARA MOHAWK POWER CORP
2625  ORANGE & ROCKLAND UTILS INC
2625  ORANGE & ROCKLAND UTILS INC
2625  ORANGE & ROCKLAND UTILS INC
2625  ORANGE & ROCKLAND UTILS INC
2629  ORANGE & ROCKLAND UTILS INC
2629  ORANGE & ROCKLAND UTILS INC
2629  ORANGE & ROCKLAND UTILS INC
2629  ORANGE & ROCKLAND UTILS INC
2629  ORANGE & ROCKLAND UTILS INC
2629  ORANGE & ROCKLAND UTILS INC
2629  ORANGE & ROCKLAND UTILS INC
2629  ORANGE & ROCKLAND UTILS INC
2640  ROCHESTER GAS & ELECTRIC CORP
2640  ROCHESTER GAS & ELECTRIC CORP
2642  ROCHESTER GAS & ELECTRIC CORP
2642  ROCHESTER GAS & ELECTRIC CORP
2642  ROCHESTER GAS & ELECTRIC CORP
2642  ROCHESTER GAS & ELECTRIC CORP
2642  ROCHESTER GAS & ELECTRIC CORP
2642  ROCHESTER GAS & ELECTRIC CORP
2642  ROCHESTER GAS & ELECTRIC CORP
2642  ROCHESTER GAS & ELECTRIC CORP
2682  JAMESTOWN CfTY OF
2682  JAMESTOWN CfTY OF
2682  JAMESTOWN CITY OF
2682  JAMESTOWN CITY OF
2682  JAMESTOWN CITY OF
2682  JAMESTOWN CITY OF
2682  JAMESTOWN CITY OF
6082  NEW YORK STATE ELEC & GAS CORP
6082  NEW YORK STATE ELEC & GAS CORP
8006  CENTRAL HUDSON GAS* ELEC CORP
8006  CENTRAL HUDSON GAS & ELEC CORP
Plant Name

DUNKIRK
DUNKIRK
OSWEGO
OSWEGO
OSWEGO
OSWEGO
OSWEGO
OSWEGO
BOWLINE POINT
BOWLINE POINT
BOWLINE POINT
BOWLINE POINT
LOVETT
LOVETT
LOVETT
LOVETT
LOVETT
LOVETT
LOVETT
LOVETT
ROCHESTER 3
ROCHESTER 3
ROCHESTER 7
ROCHESTER 7
ROCHESTER 7
ROCHESTER 7
ROCHESTER 7
ROCHESTER 7
ROCHESTER 7
ROCHESTER 7
S A CARLSON
S A CARLSON
S A CARLSON
S A CARLSON
S A CARLSON
S A CARLSON
S A CARLSON
SOMERSET
SOMERSET
ROSETON
ROSETON
DOE
Boiler
ID
3
4
3
4
5
5
6
6
1
1
2
2
1
2
3
3
4
4
5
5
12
12
1
1
2
2
3
3
4
4
10
11
11
12
12
9
9
1
1
1
2
Fuel
coal
coal
gas
ofl
gas
ofl
gas
oil
gas
ol
gas
ol
gas
gas
gas
ol
coal
gas
coal
gas
coal
ol
coal
ol
coal
d
coal
ol
coal
d
coal
coal
ol
coal
ol
coal
ol
coal
ol
ol
ol
Five Month Fuel U*e (SCO units)
%from
1990 Average Average
226700.0
196200.0
2024.0
10495.8
62.1
72395.4
64.8
63886.2
684.0
58451.4
12711.2
18950.4
0.0
13.5
1180.8
0.0
177400.0
234.6
116800.0
452.2
69400.0
12.6
45500.0
63.0
52000.0
42.0
66700.0
37.8
84600.0
12.6
0.0
17900.0
0.0
18300.0
0.0
17100.0
0.0
807000.0
71.4
89628.0
73206.0
183450.0
191313.0
773.5
3272.9
49.2
49179.4
71.3
41729.6
3222.3
40994.6
8445.6
17222.1
8.7
17.6
733.2
42.S
116700.0
1263.2
127800.0
1207.1
75016.7
29.9
37225.0
79.8
53937.5
43.1
61600.0
32.6
61400.0
21.0
4566.7
13166.7
5.6
14233.3
8.4
30957.1
18.6
752975.0
238.9
77775.1
65279.5
23.6
2.6
161.7
220.7
26.2
47.2
•9.1
53.1
-78.8
42.6
50.5
10.0
-100.0
-23.3
61.0
-100.0
52.0
-81.4
-8.6
-62.5
-7.5
-67.9
22.2
•21.1
-3.6
-2.6
8.3
16.0
37.8
•40.0
•100.0
35.9
-100.0
28.6
-100.0
•44.8
-100.0
7.2
-70.1
15.2
12.1
Five Month Heat Input (MMBtu)
%from
1990 Average Average
5973259
5161825
2088913
1578172
64089
10954039
66890
9595810
708380
8692283
13153079
2817002
0
13959
1221780
0
4609010
242771
3034975
467910
1841245
1740
1209411
8694
1379563
5797
1773237
5217
2249387
1740
0
450862
0
460948
0
430723
0
21196271
9748
13605427
11117531
4765185
4971883
798075
491327
50737
7409990
73526
6258559
3328782
6081391
8722290
2546843
8943
18157
757078
6373
3015301
1305279
3328758
1247396
1996634
4130
981716
11013
1425383
5942
1626366
4493
1623320
2899
116324
333910
789
361164
1184
790737
2622
19618817
25766
11768260
9877270
25.4
3.8
161.7
221.2
26.3
47.8
-9.0
53.3
-78.7
42.9
50.8
10.6
•100.0
•23.1
61.4
•100.0
52.9
•81.4
-8.8
-62.5
-7.8
•57.9
23.2
•21.1
-3.2
-2.4
9.0
16.1
38.6
-40.0
-100.0
35.0
-100.0
27.6
-100.0
-45.5
•100.0
8.0
•62.2
15.6
12.6
                                                            G-11

-------
                                                           Appendix G
                                          Form EIA-767 Fuel Use and Heat Input Data by Boiler
 ORIS
 ID    Utility Name

 8906  CONSOLIDATED EDISON CO-NY INC
 8906  CONSOLIDATED EDISON CO-NY INC
 8906  CONSOLIDATED EDISON CO-NY INC
 8906  CONSOLIDATED EDISON CO-NY INC
 8906  CONSOLIDATED EDISON CO-NY INC
 8906  CONSOLIDATED EDISON CO-NY INC
 8906  CONSOLIDATED EDISON CO-NY INC
 8906  CONSOLIDATED EDISON CO-NY INC
 8906  CONSOLIDATED EDISON CO-NY INC
 8906  CONSOLIDATED EDISON CO-NY INC

 PENNSYLVANIA
 3098  DUQUESNE LIGHT CO
 3098  DUQUESNE LIGHT CO
 3098  DUQUESNE LIGHT CO
 3098  DUQUESNE LIGHT CO
 3098  DUQUESNE LIGHT CO
 3098  DUQUESNE LIGHT CO
 3098  DUQUESNE LIGHT CO
 3098  DUQUESNE LIGHT CO
 3113  METROPOLITAN EDISON CO
 3113  METROPOLITAN EDISON CO
 3113  METROPOLITAN EDISON CO
 3113  METROPOLITAN EDISON CO
 3115  METROPOLITAN EDISON CO
 3115  METROPOLITAN EDISON CO
 3116  METROPOLITAN EDISON CO
 3115  METROPOLITAN EDISON CO
 3115  METROPOLITAN EDISON CO
 3118  PENNSYLVANIA ELECTRIC CO
 3118  PENNSYLVANIA ELECTRIC CO
 3118  PENNSYLVANIA ELECTRIC CO
 3118  PENNSYLVANIA ELECTRIC CO
 3121  PENNSYLVANIA ELECTRIC CO
 3121  PENNSYLVANIA ELECTRIC CO
3121  PENNSYLVANIA ELECTRIC CO
3121  PENNSYLVANIA ELECTRIC CO
3121  PENNSYLVANIA ELECTRIC CO
3121  PENNSYLVANIA ELECTRIC CO
3121  PENNSYLVANIA ELECTRIC CO
3121  PENNSYLVANIA ELECTRIC CO
 Plant Name

 ASTORIA
 ASTORIA
 ASTORIA
 ASTORIA
 ASTORIA
 ASTORIA
 ASTORIA
 ASTORIA
 ASTORIA
 ASTORIA
ELRAMA
ELRAMA
ELRAMA
ELRAMA
ELRAMA
ELRAMA
ELRAMA
ELRAMA
PORTLAND
PORTLAND
PORTLAND
PORTLAND
TITUS
TITUS
TITUS
TITUS
TITUS
CONEMAUGH
CONEMAUGH
CONEMAUGH
CONEMAUGH
FRONT STREET
FRONT STREET
FRONT STREET
FRONT STREET
FRONT STREET
FRONT STREET
FRONT STREET
FRONT STREET
DOE
Five Month Fual UM (SCC unite)
Boiler
ID
10
10
20
20
30
30
40
40
50
50
1
1
2
2
3
3
4
4
1
1
2
2
1
1
2
2
3
1
1
2
2
10
10
7
7
8
8
9
9
Fuel
gas
oil
gas
ofl
gas
ofl
gas
oil
gas
ofl
coal
ofl
coal
ofl
coal
ofl
coal
ofl
coal
ofl
coal
ofl
coal
ol
coal
ofl
coal
coal
ofl •
coal
ofl
coal
ofl
coal
ofl
coal
ofl
coal
Ol
1990
3906.7
3297.0
4151.6
2784.6
6933.2
6094.2
1922.5
14401.8
4322.4
19521.6
47300.0
21.0
46200.0
25.2
61900.0
29.4
138700.0
67.2
136700.0
344.4
174400.0
21.0
70100.0
210.0
62300.0
4.2
69700.0
797700.0
663.6
1019200.0
151.2
41400.0
25.2
1600.0
8.4
1600.0
8.4
41400.0
25.2
Average
2951.0
1169.2
3331.5
1097.8
5163.6
4363.8
2976.1
14502.6
3457.8
16960.7
57012.5
67.7
53787.5
63.0
89312.5
71.4
164888.0
128.1
99300.0
245.7
159738.0
170.6
65250.0
146.0
60012.5
74.0
64562.5
862938.0
370.1
950975.0
187.4
39057.1
21.0
4871.4
11.4
4700.0
11.4
39214.3
21.0
Nfrom
Average
32.4
182.0
24.6
153.7
34.3
39.7
-35.4
•0.7
25.0
15.1
-17.0
-69.0
-14.1
-60.0
-30.7
-58.8
•15.0
-47.5
37.7
40.2
9.2
•87.7
7.4
43.8
3.8
•94.3
8.0
-7.6
79.3
7.2
•19.3
6.0
20.0
•67.2
•26.3
•66.0
-26.3
5.6
20.0
Five Month Heat Input (MMBtu)

1990
4035640
488206
4288776
412609
7161545
903759
1985031
2126180
4464619
2894927
1144154
2883
1117307
3454
1496561
4030
3358385
9211
3613695
47867
4610421
2915
1868636
28057
1659427
582
1857996
19741723
92107
25210530
20987
1018797
3498
39259
1162
39259
1162
1018797
3498

Average
3047625
172798
3438908
162352
5330749
645794
3073941
2143191
3569518
2505618
1376938
9217
1297948
8570
2148027
9725
3966323
17470
2607082
33889
4182331
23485
1718263
20182
1580556
10232
1697066
21324991
51296
23525112
25999
960872
2911
120134
1580
115906
1580
964500
2911
%from
Average
32.4
182.5
24.7
154.1
34.3
39.9
-35.4
-0.8
25.1
15.5
•16.9
-68.7
-13.9
•59.7
-30.3
-58.6
-15.3
-47.3
38.6
41.2
10.2
•87.6
8.8
44.0
6.0
-94.3
9.6
•7.4
79.6
7.2
-19.3
6.0
20.2
-67.3
-26.5
-66.1
-26.5
6.6
20.2
                                                             G-12

-------
                                                           Appendix G
                                         Form EIA-767 Fuel Use and Heat Input Data by Boiler
ORIS
ID    Utility Nam*

3122  PENNSYLVANIA ELECTRIC CO
3122  PENNSYLVANIA ELECTRIC CO
3122  PENNSYLVANIA ELECTRIC CO
3122  PENNSYLVANIA ELECTRIC CO
3122  PENNSYLVANIA ELECTRIC CO
3122  PENNSYLVANIA ELECTRIC CO
3130  PENNSYLVANIA ELECTRIC CO
3130  PENNSYLVANIA ELECTRIC CO
3130  PENNSYLVANIA ELECTRIC CO
3130  PENNSYLVANIA ELECTRIC CO
3130  PENNSYLVANIA ELECTRIC CO
3130  PENNSYLVANIA ELECTRIC CO
3131   PENNSYLVANIA ELECTRIC CO
3131   PENNSYLVANIA ELECTRIC CO
3131   PENNSYLVANIA ELECTRIC CO
3131   PENNSYLVANIA ELECTRIC CO
3131   PENNSYLVANIA ELECTRIC CO
3131   PENNSYLVANIA ELECTRIC CO
3131   PENNSYLVANIA ELECTRIC CO
3131   PENNSYLVANIA ELECTRIC CO
3132  PENNSYLVANIA ELECTRIC CO
3132  PENNSYLVANIA ELECTRIC CO
3132  PENNSYLVANIA ELECTRIC CO
3132  PENNSYLVANIA ELECTRIC CO
3132  PENNSYLVANIA ELECTRIC CO
3132  PENNSYLVANIA ELECTRIC CO
3132  PENNSYLVANIA ELECTRIC CO
3135  PENNSYLVANIA ELECTRIC CO
3135  PENNSYLVANIA ELECTRIC CO
3136  PENNSYLVANIA ELECTRIC CO
3136  PENNSYLVANIA ELECTRIC CO
3136  PENNSYLVANIA ELECTRIC CO
3136  PENNSYLVANIA ELECTRIC CO
3138  PENNSYLVANIA POWER CO
3138  PENNSYLVANIA POWER CO
3138  PENNSYLVANIA POWER CO
3138  PENNSYLVANIA POWER CO
3138  PENNSYLVANIA POWER CO
3138  PENNSYLVANIA POWER CO
3138  PENNSYLVANIA POWER CO
3138  PENNSYLVANIA POWER CO
Plant Name

HOMER CITY
HOMER CITY
HOMER CITY
HOMER CITY
HOMER CITY
HOMER CITY
SEWARD
SEWARD
SEWARD
SEWARD
SEWARD
SEWARD
SHAWVILLE
SHAWVILLE
SHAWVILLE
SHAWVILLE
SHAWVILLE
SHAWVILLE
SHAWVILLE
SHAWVILLE
WARREN
WARREN
WARREN
WARREN
WARREN
WARREN
WARREN
WILLIAMSBURG
WILLIAMSBURG
KEYSTONE
KEYSTONE
KEYSTONE
KEYSTONE
NEW CASTLE
NEW CASTLE
NEW CASTLE
NEW CASTLE
NEW CASTLE
NEW CASTLE
NEW CASTLE
NEW CASTLE
DOE         Five Month Fuel U*e(SCC unite) Five Month Heat Input (MMBtu)
Boiler                        % from                    % from
ID      Fuel  1990     Average  Average   1990     Average  Average
1
1
2
2
3
3
12
12
14
14
15
15
1
1
2
2
3
3
4
4
1
1
2
3
3
4
4
11
11
1
1
2
2
1
1
2
2
3
3
4
4
coal
oil
OK*
oH
coal
oH
cod
01
cod
01
cod
oil
cod
01
cod
oil
cod
01
cod
oH
cod
oil
cod
cod
01
cod
01
cod
oi
cod
ol
cod
ol
cod
ol
cod
ol
cod
ol
cod
ol
462500.0
58.8
619600.0
277.2
812100.0
210.0
33800.0
189.0
34600.0
121.8
171100.0
138.6
154400.0
100.8
149300.0
84.0
188900.0
348.6
156500.0
260.4
21500.0
0.0
23700.0
23800.0
8.4
23400.0
8.4
9400.0
8.4
1047700.0
256.2
826200.0
953.4
23100.0
46.2
20800.0
46.2
39500.0
42.0
72500.0
54.6
601250.0
292.4
515925.0
221.0
725525.0
431.6
37537.5
150.7
37125.0
123.9
169625.0
139.7
146900.0
116.0
139588.0
123.4
176900.0
309.8
173913.0
368.0
21733.3
4.9
21666.7
22133.3
7.0
23533.3
7.0
14633.3
11.2
1023650.0
251.6
902838.0
546.0
17637.5
35.7
18837.5
28.4
71850.0
33.6
74375.0
35.7
•23.1
•79.9
20.1
25.4
11.9
-51.3
•10.0
25.4
•6.8
•1.7
0.9
-0.8
5.1
•13.1
7.0
•31.9
6.8
12.5
•10.0
•29.2
•1.1
•100.0
9.4
7.5
20.0
•0.6
20.0
•35.8
•25.0
2.3
1.9
•8.5
74.6
31.0
29.4
10.4
62.7
•45.0
25.0
•2.5
52.9
11329669
8134
15205291
38440
21517156
29110
814456
25915
833714
16700
4121985
19004
3747953
13815
3622678
11517
4584773
47787
3796240
35709
531345
0
586139
588089
1126
578148
1126
228746
1145
25392424
35560
20022992
132331
555950
6385
501805
6388
955071
5804
1748887
7548
14752154
40510
12693531
30593
18619334
59699
908040
20760
898018
17084
4106196
19221
3598480
16005
3419414
16993
4331497
42666
4261470
50681
532240
676
531053
542483
961
676495
961
359324
1539
25081590
34886
22103548
75682
428178
4909
458462
3900
1748848
4624
1808967
4914
-23.2
-79.9
19.8
25.6
15.6
-51.2
•10.3
24.8
•7.2
-2.2
0.4
•1.1
4.2
•13.7
5.9
-32.2
5.8
12.0
•10.9
•29.5
-0.2
-100.0
10.4
8.4
17.2
0.3
17.2
•36.3
•25.6
1.2
1.9
•9.4
74.9
29.8
30.1
9.5
63.8
•45.4
25.5
-3.3
53.6
                                                              Q-13

-------
                                                           Appendix G
                                         Form EIA-767 Fuel Use and Heat Input Data by Boiler
 ORIS
 ID     Utility Nam*

 3138   PENNSYLVANIA POWER CO
 3138   PENNSYLVANIA POWER CO
 3140   PENNSYLVANIA POWER & LIGHT CO
 3140   PENNSYLVANIA POWER & LIGHT CO
 3140   PENNSYLVANIA POWER & LIGHT CO
 3140   PENNSYLVANIA POWER & LIGHT CO
 3140   PENNSYLVANIA POWER A LIGHT CO
 3140   PENNSYLVANIA POWER & LIGHT CO
 3145   PENNSYLVANIA POWER & LIGHT CO
 3145   PENNSYLVANIA POWER ALIGHT CO
 3148   PENNSYLVANIA POWER & LIGHT CO
 3148   PENNSYLVANIA POWER & LIGHT CO
 3148   PENNSYLVANIA POWER & LIGHT CO
 3148   PENNSYLVANIA POWER ALIGHT CO
 3148   PENNSYLVANIA POWER & LIGHT CO
 3148   PENNSYLVANIA POWER ALIGHT CO
 3149   PENNSYLVANIA POWER A LIGHT CO
 3149   PENNSYLVANIA POWER A LIGHT CO
 3149   PENNSYLVANIA POWER A LIGHT CO
 3149   PENNSYLVANIA POWER A LIGHT CO
 3152   PENNSYLVANIA POWER A LIGHT CO
 3152   PENNSYLVANIA POWER A LIGHT CO
 3152   PENNSYLVANIA POWER A LIGHT CO
 3152   PENNSYLVANIA POWER A LIGHT CO
 3152   PENNSYLVANIA POWER A LIGHT CO
 3152   PENNSYLVANIA POWER A LIGHT CO
 3152   PENNSYLVANIA POWER A LIGHT CO
 3152   PENNSYLVANIA POWER A LIGHT CO
 3152   PENNSYLVANIA POWER A LIGHT CO
 3152   PENNSYLVANIA POWER A LIGHT CO
 3152   PENNSYLVANIA POWER A LIGHT CO
 3152   PENNSYLVANIA POWER A LIGHT CO
 3159  PHILADELPHIA ELECTRIC CO
 3159  PHILADELPHIA ELECTRIC CO
 3159  PHILADELPHIA ELECTRIC CO
 3160  PHILADELPHIA ELECTRIC CO
3160  PHILADELPHIA ELECTRIC CO
3161   PHILADELPHIA ELECTRIC CO
3161   PHILADELPHIA ELECTRIC CO
3161   PHILADELPHIA ELECTRIC CO
 3161   PHILADELPHIA ELECTRIC CO
 Plant Name

 NEWCASTLE
 NEW CASTLE
 BRUNNER ISLAND
 BRUNNER ISLAND
 BRUNNER ISLAND
 BRUNNER ISLAND
 BRUNNER ISLAND
 BRUNNER ISLAND
 HOLTWOOD
 HOLTWOOD
 MARTINS CREEK
 MARTINS CREEK
 MARTINS CREEK
 MARTINS CREEK
 MARTINS CREEK
 MARTINS CREEK
 MONTOUR
 MONTOUR
 MONTOUR
 MONTOUR
 SUNBURY
 SUNBURY
 SUNBURY
 SUNBURY
 SUNBURY
 SUNBURY
 SUNBURY
 SUNBURY
 SUNBURY
 SUNBURY
 SUNBURY
 SUNBURY
 CROMBY
 CROMBY
 CROMBY
 DELAWARE
DELAWARE
EDDYSTONE
EDDYSTONE
EDDYSTONE
EDDYSTONE
DOE         Five Month Fuel Uae (SCC unKa)  Five Month Heat Input (MMBtu)
Boiler                        % from                    % from
ID     Fuel   1990     Average  Average   1990     Average  Average
5
5
1
1
2
2
3
3
17
17
1
1
2
2
3
4
1
1
2
2
1A
1A
1B
1B
2A
2A
2B
2B
3
3
4
4
1
1
2
71
81
1
1
1
2
coal
off
coal
ofl
coal
oil
coal
off
cosl
on
coal
ofl
coal
ofl
ofl
ofl
coal
ofl
coal
ofl
coal
Ofl
coal
ofl
coal
ofl
coal
ofl
coal
ofl
coal
ofl
coal
ofl
ofl
ofl
ofl
coal
gas
ol
coal
132600.0
46.2
331400.0
281.4
377000.0
441.0
744400.0
264.6
133700.0
16.8
129400.0
298.2
120500.0
172.2
38434.2
33822.6
692200.0
537.6
907700.0
138.6
62000.0
25.2
62000.0
25.2
62000.0
25.2
62000.0
25.2
137600.0
21.0
164600.0
63.0
61500.0
399.0
8391.6
6820.8
7056.0
208000.0
77.1
331.8
135500.0
120463.0
47.8
285750.0
281.9
396663.0
319.2
729538.0
223.7
99371.4
21.0
120275.0
241.0
131550.0
256.2
51394.4
52563.0
730663.0
600.6
792725.0
367.0
66025.0
15.2
66025.0
15.2
66025.0
16.2
66025.0
15.2
124875.0
22.1
142150.0
79.3
92400.0
254.6
10503.2
7100.1
5049.5
185750.0
57.0
619.5
175138.0
10.1
-3.3
16.0
-0.2
-5.0
38.2
2.0
18.3
34.5
-20.0
7.6
23.7
-8.4
-32.8
•2S.2
-35.7
-5.3
•10.5
14.5
-62.2
•6.1
65.8
•6.1
65.8
•6.1
65.8
•6.1
65.8
10.2
-6.0
16.8
-20.6
-33.4
66.7
•20.1
-3.9
39.7
12.0
35.3
•46.4
-22.6
3201110
6389
8180885
39159
9320759
61264
18412848
36870
2555617
2338
3331092
41612
3112042
24078
5759434
5082573
17031456
74888
22409298
19316
1061382
3502
1061382
3502
1081382
3502
1061382
3502
3363575
2918
4068357
8748
1606560
55515
1258732
1032068
1068159
5223921
79583
48769
3558093
2928677
6575
7132424
39087
9885630
44242
18131143
30997
1895928
2915
3081477
33547
3346808
35683
7691582
7868440
18315710
83434
19880083
50962
1118683
2116
1118683
2114
1118683
2116
1118683
2115
3088131
3084
3534854
11011
2433785
35634
1589623
1066057
758858
4835195
COfififi
OOvQO
90042
4587609
9.3
-2.8
14.7
0.2
-5.7
38.5
1.6
18.9
34.8
-19.8
8.8
24.0
•7.0
•32.5
•25.1
•35.4
•7.0
•10.2
12.7
-62.1
-5.1
65.6
-5.1
65.7
-5.1
65.6
-5.1
65.6
8.9
•4.8
15.1
•20.6
-34.0
55.8
-20.8
-3.2
40.8
8.0
35.7
•45.8
•22.4

-------
                                                         Appendix G
                                        Form EIA-767 Fuel Use and Heat Input Data by Boiler
ORIS
ID     Utility Name

3161   PHILADELPHIA ELECTRIC CO
3161   PHILADELPHIA ELECTRIC CO
3161   PHILADELPHIA ELECTRIC CO
3161   PHILADELPHIA ELECTRIC CO
3161   PHILADELPHIA ELECTRIC CO
3161   PHILADELPHIA ELECTRIC CO
3169  PHILADELPHIA ELECTRIC CO
3176  UGICORP
3176  UGICORP
3178  WEST PENN POWER CO
3178  WEST PENN POWER CO
3178  WEST PENN POWER CO
3178  WEST PENN POWER CO
3179  WEST PENN POWER CO
3179  WEST PENN POWER CO
3179  WEST PENN POWER CO
3179  WEST PENN POWER CO
3179  WEST PENN POWER CO
3179  WEST PENN POWER CO
3181   WEST PENN POWER CO
3181   WEST PENN POWER CO
6094  PENNSYLVANIA POWER CO
6094  PENNSYLVANIA POWER CO
6094  PENNSYLVANIA POWER CO
6094  PENNSYLVANIA POWER CO
6094  PENNSYLVANIA POWER CO
6094  PENNSYLVANIA POWER CO
8226  DUQUESNE LIGHT CO
8226  DUQUESNE LIGHT CO

RHODE ISLAND
3236  NEW ENGLAND POWER CO
3236  NEW ENGLAND POWER CO
3236  NEW ENGLAND POWER CO
3236  NEW ENGLAND POWER CO
3236  NEW ENGLAND POWER CO
3236  NEW ENGLAND POWER CO
3238  NEW ENGLAND POWER CO
3238  NEW ENGLAND POWER CO
3238  NEW ENGLAND POWER CO
3238  NEW ENGLAND POWER CO
Plant Name

EDDYSTONE
EDDYSTONE
EDDYSTONE
EDDYSTONE
EDDYSTONE
EDDYSTONE
SCHUYLKILL
HUNLOCK POWER
HUNLOCK POWER
ARMSTRONG
ARMSTRONG
ARMSTRONG
ARMSTRONG
HATFIELD'S FERRY
HATFIELD'S FERRY
HATFIELD'S FERRY
HATFIELD'S FERRY
HATFIELD'S FERRY
HATFIELD'S FERRY
MITCHELL
MITCHELL
BRUCE MANSFIELD
BRUCE MANSFIELD
BRUCE MANSFIELD
BRUCE MANSFIELD
BRUCE MANSFIELD
BRUCE MANSFIELD
CHESWICK
CHESWICK
MANCHESTER STREET
MANCHESTER STREET
MANCHESTER STREET
MANCHESTER STREET
MANCHESTER STREET
MANCHESTER STREET
SOUTH STREET
SOUTH STREET
SOUTH STREET
SOUTH STREET
DOE         Five Month Fuel UM (SCO unto)  Five Month Heat Input (MMBtu)
Boiler                        % from                   % from
ID     Fuel   1990    Average   Average    1990     Avenge  Average
2
2
3
3
4
4
1
6
6
1
1
2
2
1
1
2
2
3
3
33
33
1
1
2
2
3
3
1
1
12
12
6
6
7
7
121
121
122
122
gas
ol
gas
01
gas
oil
01
coal
oH
coal
oil
coal
oil
coal
01
coal
oil
coal
oil
coal
gas
coal
oil
coal
ol
coal
ol
coal
gas
gas
ol
gas
ol
gas
oH
gas
OK
gas
oil
89.2
609.0
226.8
14385.0
153.0
13918.8
9206.4
96200.0
16.8
204800.0
29.4
189300.0
29.4
576800.0
63.0
526800.0
37.8
318000.0
105.0
229600.0
12.2
691400.0
214.2
893900.0
193.2
801400.0
411.6
591300.0
45.0
843.0
8.4
563.3
277.2
531.2
163.8
948.1
546.0
948.1
546.0
56.6
594.3
168.1
16857.2
146.9
17567.6
6496.9
93371.4
34.2
201750.0
25.7
195800.0
32.6
530800.0
37.8
501950.0
39.4
524825.0
44.1
205288.0
13.4
693038.0
349.1
809225.0
356.5
818850.0
511.4
598125.0
94.8
396.9
1079.4
420.8
1688.4
418.2
925.6
578.6
1967.0
529.9
1790.6
57.6
2.5
34.9
-14.7
4.2
-20.8
41.7
3.0
-50.9
1.5
14.4
-3.3
-9.8
8.7
66.7
5.0
•4.1
-39.4
138.1
11.8
-9.0
-0.2
-38.6
10.5
•45.8
•2.1
•19.5
•1.1
-52.5
112.4
•99.2
33.9
-83.6
27.0
-82.3
63.9
-72.2
78.9
-69.5
92076
86807
234099
2176576
157846
2108564
1384331
1868452
2333
5049284
4073
4671875
4072
15020243
8884
13722075
5330
8242251
14805
5613791
12810
16684276
29354
21471161
26512
19321200
56511
14627897
46260
871719
1270
582280
41911
549292
24765
980486
82436
980486
82436
58242
85950
173113
2529535
151237
2634744
974071
1818395
4793
5005451
3563
4858387
4508
13716442
5330
12976114
5552
13566041
6218
5068761
14109
16711698
47998
19496166
48933
19757738
70198
14861085
97469
410336
162433
431868
253711
432054
139241
596965
295839
546778
269220
58.1
1.0
35.2
-14.0
4.4
-20.0
42.1
2.8
-51.3
0.9
14.3
-3.8
•9.7
9.5
66.7
5.7
-4.0
-39.2
138.1
10.8
•9.2
-0.2
-38.8
10.1
•45.8
•2.2
-19.5
-1.6
•52.5
112.4
-99.2
34.8
•83.5
27.1
-82.2
64.2
•72.1
79.3
-69.4
                                                             G-15

-------
ORIS
ID    Utility Nam*
                                                           Appendix G
                                          Form EIA-767 Fuel Use and Heat Input Data by Boiler
Plant Name
DOE
Boiler
ID
Fuel
Five Month Fuel UM (SCO unto)
                % front
1990     Average  Average
Five Month Heat Input (MMBIu)
                Sfrom
1990      Average  Average
VERMONT
589   BURLINGTON CITY OF
589   BURLINGTON CRY OF

VIRGINIA
3788  POTOMAC ELECTRIC POWER CO
3788  POTOMAC ELECTRIC POWER CO
3788  POTOMAC ELECTRIC POWER CO
3788  POTOMAC ELECTRIC POWER CO
3788  POTOMAC ELECTRIC POWER CO
3788  POTOMAC ELECTRIC POWER CO
3788  POTOMAC ELECTRIC POWER CO
3788  POTOMAC ELECTRIC POWER CO
3788  POTOMAC ELECTRIC POWER CO
3788  POTOMAC ELECTRIC POWER CO
3804  VIRGINIA ELECTRIC & POWER CO
3804  VIRGINIA ELECTRIC & POWER CO
3804  VIRGINIA ELECTRIC & POWER CO
3804  VIRGINIA ELECTRIC & POWER CO
3804  VIRGINIA ELECTRIC & POWER CO
3804  VIRGINIA ELECTRIC & POWER CO
3804  VIRGINIA ELECTRIC & POWER CO
J C MCNEIL
J C MCNEIL
POTOMAC RIVER
POTOMAC RIVER
POTOMAC RIVER
POTOMAC RIVER
POTOMAC RIVER
POTOMAC RIVER
POTOMAC RIVER
POTOMAC RIVER
POTOMAC RIVER
POTOMAC RIVER
POSSUM POINT
POSSUM POINT
POSSUM POINT
POSSUM POINT
POSSUM POINT
POSSUM POINT
POSSUM POINT
1
1
2
2
3
3
4
4
5
5
1
2
3
3
4
4
5
01
gas
coal
ol
coal
OR
cod
ol
coal
oft
coal
oil
d
OR
coal
oR
coal
oR
on
0.0
496.8
46500.0
205.8
61800.0
168.0
101800.0
68.8
110500.0
16.8
107300.0
12.6
184.8
210.0
54100.0
21.0
204200.0
54.6
29534.4
177.8
478.7
50612.5
176.4
53975.0
180.1
93887.5
66.2
98912.5
53.6
101813.0
45.7
623.7
941.9
72837.5
23.6
218800.0
63.0
36975.8
-100.0
3.8
•8.1
16.7
14.5
•6.7
8.4
•11.2
11.7
-68.7
5.4
•72.4
•70.4
•77.7
•25.7
-11.0
•6.7
-13.3
•20.1
0
496800
1196943
28182
1585637
23010
2620532
8045
2843607
2308
2763020
1727
27263
31012
1364983
2940
5134916
7644
4390709
24584
478650
1305314
24349
1390659
24852
2414664
9124
2544743
7386
2620908
6300
92874
140173
1858874
3308
5573034
8820
5474934
-100.0
3.8
-8.3
15.7
14.0
•7.4
8.5
•11.8
11.7
-68.8
5.4
•72.6
•70.6
-77.9
•26.6
-11.1
•7.9
•13.3
-19.8
                                                             G-16

-------
                     Appendix H
Form EIA-759 Electric Generation by State and Prime Mover
Generation (MW-houra) ——
Prim*
Mover
Connecticut
ALL
FFSTM
HYDRO
NUCLEAR
OTHER
District of Columbia
ALL
FFSTM
OTHER
Delaware
ALL
FFSTM
OTHER
Massachusetts
ALL
FFSTM
HYDRO
NUCLEAR
OTHER
Maryland
ALL
FFSTM
HYDRO
NUCLEAR
OTHER

1965

25252092
12232591
281404
12721397 •.
16700

114540
95710
18830

8470439
8456386
14053

37285155
29661209
1220428
6132633
270885

32310201
20669849
1523744
9925976
190632

1986

50919196
31816018
377275
18691995
31908

170028
153716
16312

6410875
8399462
11413

37904482
33318893
1331584
2420249
833756

50587512
35698072
1876510
12840456
172474

1987

53830477
32848065
350050
20592597
39765

237799
214905
22894

8512680
8491093
21587

36957949
33337451
1333828
1136125
1150545

46369721
34311671
1612024
10093465
352561

1988

58714407
36011308
338571
22285679
78849

472997
420659
52338

8952776
8929743
23033

36973555
33292244
1339518
1116886
1224907

52188433
38734653
1327499
11768164
358117

1989

53961719
33870022
412942
19611926
66829

651326
591604
59722

8457882
8255034
202848

43413689
37652340
1466452
3014854
1280043

38680807
33570097
1777964
2820531
512215

1990

52028000
31688000
511000
19819000
10000

366000
346000
20000

7098000
6833000
265000

42891000
35326000
1640000
5069000
856000

33058000
29059000
2299000
1403000
297000

1991

34648000
21944000
360000
12321000
23000

178000
167000
11000

6979000
6527000
452000

37674000
31535000
1322000
3927000
890000

42849000
33266000
1286000
8015000
282000

1992

42177000
24902000
378000
16888000
9000

83000
68000
15000

6267000
5998000
269000

38889000
32180000
1412000
4742000
555000

50299000
37514000
1825000
10687000
273000

1993

50622000
28403000
368000
21843000
8000

198000
191000
7000

8308000
7408000
900000

33866000
27729000
1356000
4339000
442000

55822000
41392000
1659000
12316000
455000
1990
% Difference
from Average

10.9%
12.4%
36.2%
8.3%
-68.3%

33.3%
38.5%
-19.3%

-10.6%
-11.3%
10.5%

11.6%
8.1%
18.8%
43.0%
2.7%

-26.0%
-14.0%
36.2%
-84.2%
-7.6%
                          H-1

-------
                     Appendix H
Form EIA-759 Electric Generation by State and Prime Mover
Generation (MW-houra) —
Prlma
Mover
Maine
ALL
FFSTM
HYDRO
NUCLEAR
OTHER
Now Hampshire
ALL
FFSTM
HYDRO
NUCLEAR
OTHER
New Jersey.
ALL
FFSTM
HYDRO
NUCLEAR
OTHER
New York
ALL
FFSTM
HYDRO
NUCLEAR
OTHER

1965

9142333
2065536
1717823
5354401
4573

6037685
5058853
975457
0
3375

34878726
16147344
247166
17769857
714359

114237677
60285620
29399628
24092442
459987

1986

17135307
8853022
2033399
6241746
7140

6118226
5006282
1104406
0
7538

44264864
28309141
289234
14822390
844099

135562871
81146575
31553445
22125694
737157

1987

12390802
6636?94
1703212
4042900
839S

6047368
5143392
896337
0
7639

62717038
37852617
312130
22721609
1830682

142491618
89280491
29438206
22939269
833652

1988

14548519
7945487
1569244
5017194
16594

6997526
6005821
967684
0
24021

64730268
38774688
221652
23992489
1741439

150746171
99551359
25673760
24215952
1305100

1989

18567655
9930330
1681074
6941696
14555

712531.1
6017705
1088677
0
18929

64830695
39579758
261136
23093009
1896792

155805273
104496643
26022872
23046361
2239397

1990

13928000
6953000
2111000
4861000
3000

14891000
9330000
1476000
4081000
4000

60751000
35641000
150000
23850000
1110000

154625000
102212000
27857000
23743000
813000

1991

14281000
6792000
1815000
5672000
2000

17323000
10254000
1070000
5998000
1000

57343000
33002000
146000
22851000
1344000

143209000
92263000
24638000
25714000
594000

1992

13702000
6622000
1720000
5358000
2000

21323000
12490000
964000
7869000
0

53286000
30895000
138000
21691000
762000

138466000
86340000
27660000
24160000
306000

1993

13820000
6499000
1576000
5740000
5000

23633000
13564000
1002000
9047000
0

59703000
33588000
123000
25010000
982000

135538000
78891000
29262000
26903000
482000
1990
% Difference
from Average

-1.7%
0.4%
19.3%
•11.1%
-57.3%

22.4%
15.2%
39.2%
36.1%
-45.9%

8.8%
9.3%
-28.5%
9.6%
-11.0%

9.5%
15.8%
-0.3%
-1.5%
-5.8%
                        H-2

-------
                                                               Appendix H
                                         Form EIA-759 Electric Generation by State and Prime Mover
Generation (MW-houra) — —
Prime
Mover
Pennsylvania
ALL
FFSTM
HYDRO
NUCLEAR
OTHER
Rhode Island
ALL
FFSTM
HYDRO
OTHER
Vermont
ALL
FFSTM
HYDRO
NUCLEAR
OTHER

1985

136814630
107620486
2385380
26541375
267389

547278
538995
0
8283

3905409
46385
852571
2999400
7053

1986

188927074
145941605
2735501
39907502
342466

724049
711916
0
12133

5208104
2159931
974604
2058425
15144

1987

182388383
144181073
2603004
35242138
362168

836678
822880
0
13798

8170872
3692340
925095
3536409
17028

1988

193068666
152044820
2423047
38120770
480029

764006
741935
0
22071

9163215
4214259
809234
4113833
25889

1989

196210057
153112198
2919306
39463648
714905

496118
477999
0
18119

8367959
3795572
948000
3606775
17612

1990

225326000
163757000
3461000
57828000
280000

592000
583000
0
9000

8607000
3776000
1214000
3616000
1000

1991

203310000
148147000
2361000
52639000
163000

154000
144000
0
10000

8492000
3917000
843000
3728000
4000

1992

228167000
164826000
3054000
60194000
93000

110000
102000
0
8000

8431000
3891000
804000
3735000
1000

1993

227539000
165071000
2891000
59439000
138000

55000
45000
0
10000

7671000
3457000
839000
3372000
3000
1990
% Difference
from Average

13.8%
9.6%
25.4%
27.1%
-11.3%

24.5%
25.9%
0.0%
-27.3%

13.9%
17.4%
33.1%
5.8%
-90.2%
Ozone Transport Region
ALL
FFSTM
HYDRO
NUCLEAR
OTHER
408996165
262878964
38603601
105537481
1976119
545932588
381516633
42275958
119108457
3031540
560951385
396812272
39173886
120304512
4660715
597320539
426666976
34670209
130630967
5352387
596568491
431349302
36578423
121598800
7041966
614161000
425504000
40719000
144270000
3668000
566440000
387958000
33841000
140865000
3776000
601200000
405628000
37955000
155324000
2293000
616775000
406258000
39076000
168009000
3432000
8.2%
8.7%
6.9%
7.7%
-6.3%
FF STM . Fossil Fuel Steam
                                                                    H-3

-------
                            Appendix I
                         Inventory Codes

Five Month Activity Methodology  (METH_5MO)

     1    =    Based on monthly  fuel use provided by  the  source
     2    =    Based on Form EIA-767 monthly fuel use
     3    =    Based on seasonal throughput percentages  (1/3  of
               spring plus summer plus 1/3 of fall)
     4    =    5/12 of annual

Design Capacity Units (CAP_DNITS)

     Blank=    Assumed MMBtu/hr
     1    =    MMBtu/hr
     2    =    Megawatts
     3    =    Kilowatts
     4    =    Thousand Ibs steam/hr
     5    =    Boiler horsepower
     6    =    Horsepower
     A    =    1000 gallons
     B    =    Barrels
     C    =    1000 Barrels
     M    =    Tons/hr
     N    =    Tons/day
     P    =    Pounds/hr

Note:     A,  B, and C are volume units used for storage tanks and
should not be used for affected sources.

Firing Type (FIRING)

      0   =    no data
      1   =    front (wall)
      2   =    opposed
      3   =    tangential
      4   =    spreader stoker
      5   =    cyclone
      6   =    arch
      7   =    concentric
      8   =    duct burner
      9   =    AFB
     10   =    rear (wall)
     11   =    side (wall)
     12   =    vertical
                               1-1

-------
Bottom Type (BOTTOM)

     0    =    no data
     1    =    wet
     2    =    dry

AIRS Estimation Method  (EST_METH)

1 -  Emissions user-calculated based on source test or other
     emissions measurements.
2 -  Emissions user-calculated based on material balance using
     engineering knowledge of the process.
3 -  Emissions user-calculated based on ap-42 emission factor.
4 -  Emissions user-calculated by best guess/engineering
     judgement.
5 -  Emissions user-calculated based on a state or local agency
     emission factor.
6 -  New construction,  not yet operational.  Emissions are zero.
7 -  Source closed; operation ceased.  Emissions are zero.
8 -  Emissions computer-calculated based on standard emission
     factor.
9 -  Emissions computer-calculated based on user-supplied
     emission factor.
A -  Emissions computer-calculated based on apportionment of neds
     point  level emissions estimates to the segment level by
     ratio  of computer-calculated emissions based on standard
     emission factors in the af-geo-emissions-table maintained in
     the airs geo-common subsystem.
B -  Emissions computer-calculated based on apportionment of neds
     point  level emissions estimates to the segment level by a
     default procedure.  Insufficient data were available to
     permit use of method A.

Emission Factor Hierarchy Code  (EMF_HIER)

       1    =    CEMS for May-Sept 1990
       2    =    Annual CEMS for  1990
       3    =    CEMS for May-Sept for non 1990
       4    =   Annual CEMS for  non 1990
       5    =   Multiple stack tests at representative conditions
               for  1990
       6    =   Multiple stack tests at representative conditions
               for  non  1990
       7    =   Single stack test at representative conditions
       8    =   AP-42 factor
       9    =   Single stack test at maximum load
      10    =   State factor
      11    =   Industry factor
                                1-2

-------
                                             Appendix .1
                     SCCs Initially Marked M Affected In tb« State OTC NOx Databaa*
SCO
10100101
10100102
10100201
10100202
10100203
10100204
10100205
10100212
10100217
10100221
10100222
10100223
10100224
10100225
10100226
10100301
10100302
10100303
10100304
10100306
10100401
101 00402
10100404
10100405
10100406
10100501
10100504
10100505
10100601
10100602
10100603
10100604
10100801
10101001
10101002
10200101
10200102
10200104
10200107
10200201
10200202
10200203
10200204
10200205
10200206
10200210
10200212
10200213
10200217
10200219
10200221
10200222
10200223
10200224
10200225
10200226
10200229
10200301
10200302
10200303
10200304
10200306
10200307
 Description
 Ext Comb Boaeis;Etec.Geo/AnthraciteCoal;Po*verized Coal
 Ext Comb Boters;Etec. Gen.jAnthracte CoeJ;Traveing Grata
 Ext Comb BoHecs;Elec. Gea;Bttumlnou5 CoeJ;Pulverized Coal: Wet
 Ext Comb Betters f tec. Gen.;Bttumlnous CoaJ;Pulverized Coal: Dry
 Ext Comb Boters;Etec. Gen.;Bftuminous Coal;Cyctone Furnace
 Ext(>>inbBoilersflec.Gen.;BitumirK>U6Coal<-SpraaderStokar
 Ext Comb Boters;Etec. Gen. Bituminous Coat.Traveing Grate
 Ext Comb BoBersftec. Gen.;Bituminou6 CoaljPufcwrizad Coal: Dry
 Ext Comb Boiters;Elec. Gen.;BituminouB Coal ;AJn»6pr*rte FUdteed Bed Comb.
 Ext Comb Bo»ere;Etec. Gen.^ubbiUminous CoaJiPutarteed Coal: Wet
 Ext Comb Boitersf tec. Gea^ubbttuminous(^>al;Pu»v»rtzed Coal: Dry
 Ext O>rnb Botere;Elec. Gen.^ubb«urryrKX« Coal^yckxw Furnace
 ExtCcfnbBcierB^ec. Gen.^ubom»rtrwus<5oaJ^eaderS»oker
 Ext Comb Boters;Etec. Gea^ubbttuminouE Coal;Tnming Grate
 Ext Comb BoflercEtoc. GeagubbHumlnom CoatPutverized Coal: Dry
 ExtCo«TABo*ers;Etec. Gen.iigniteiPuVortzedCoal
 Ext Comb BoHersflec. Gen.;Uonte:Pulv»rlred Coal: Tangential Firing
 Ext Comb Boiters;Etec. Gen.;Ugnite;Cyctone Furnace
 Ext Comb Boiters;Bec. Gen.;Ugnite;Trave&ng Grate
 Ext Comb Boitersftec. Gen.;Ugnte;Spreader Stoker
 Ext Comb BoBers;Elec. Gen.;Residual Ofl;Grade 6 OB: Normal Firing
 Ext Comb Boitere;Etec. Gen. ;ReskJoa) Oil
 Ext Comb BoNers;Etec. Gen.;Residual OH.-Grade 6 OS: Tangential Firing
 Ext Comb BoHers;Etec. Gen.;Residual OI;Grade 5 OK: Normal Firing
 Ext Comb Boitere;Etec. Gen.;ResidualOI,<3rade 5 Oil: Tangential Firing
 ExtCombBoflers;Etec. Gen.fMs«ateOil;Gractes1and20fl
 Ext Comb Boiters;Etec. Gen.;D«sffllate Ol^rade 4 Oi: Normal Firing
 Ext Comb Boiters;Etec. Gen.;DJstiHat8 Oil;Grade 4 Oil: Tangential Firing
 Ext Comb Boiters;Etec. Gen.;Natural Gas;Boitere > 100 MBtuAHr except Tang.
 Ext Comb Boilers;Etec. Gen.;Natural Gas;Boiters < 100 MBtu/Hr except Tang.
 Ext Comb Bolters ftec. Gen. Datura! Gas
 Ext Comb Boilers :Etec. Gen. Datura! Gas;Tangentially Fired Units
 Ext Comb Boiters;Etec. Gen.;Coke;AJI Botor Sizes
 Ext Comb BoJlers;Etec. Gen.;Lk)uifted Petro (LPG);Butane
 Ext Comb Boiters;Etec. Gen.Uqiafied Petro (LPG) propane
 Ext Comb Boiters;lndustriaJ^nflracrte Coal;Purverized Coal
 Ext Comb Boilers ;lndustria) Anthracite Coal
 Ext Comb Bo«ers;lndustrial Anthracite Coal;Travefing Grate
'Ext Comb Boiters;lndustriaI;Anthracite CoaJ;Hand-Rred
 Ext Comb Boilers;lndustrial;Bituminous Coal;Putverized Coal: Wet Bottom
 Ext Comb Boiters;lndustria);Bituminous Coaf;Pulverized Coal: Dry Bottom
 Ext Comb Boilefs;lndustriaJ;Bituminous Coal;Cydone Furnace
 Ext Comb Boiters;lndustrial;Bituminous CoaJiSpreader Stoker
 Ext Comb Boiters;lndustrial:Bituminous Coalpverfeed Stoker
 Ext Comb Boilers;lnoustrial;Bituminous Coal;Underteed Stoker
 Ext Comb Boiere;lnd;Subbituminous CoaJ^>verfeed Stoker"
 ExtCcus(^
 Ext Comb Boters;lndustnal;Bituntinous Coal;Wet Slurry
 Ext Comb Bo«ere^ndustrial;BrlumirKXJS(^>alAtrnospheric FMdized Bed Comb.
Ext Comb BoRers.ln
st
                     al.-Subbiturninous Coal^urvertzed Coal: Wet Bottom
 Ext Comb Bdkm;lndustriaJ,-Subbituminous Coal.Purverired Coal: Dry
 ExtC<»rnbBoflers^rKlus«al^ubDituminousCoal;(^ctoneFurrace
 Ext Comb Baters;lndustrial;Subbiturninous Coal^preader Stoker
 Ext Comb BoUers.lndustial^ubbituminous Coal;Trave8ng Grate
 Ext Comb Boilers;lrxJustrial;Subbituminous Coal;Purverized Coal: Dry
 Ext Comb Boflers^ndusWal^uboituminous Coal;Cogeneration
 Ext Comb BoHers;lndustial^Jgnite;Pulverized Coal
 Ext Comb Boiters^ndustrial;Lignfte;Putverized Coal: Tangential Firing
 Ext Comb Boterc;lndustrial;Ugnte;Cyctone Furnace
 Ext Comb Boiters^ndustrial;LJgnrte;Traveling Grate (Overfeed) Stoker
 Ext Comb Boilers;lndustrial;IJgnite;Spreader Stoker
 Ext Comb Boilere;ladustrid;Ugnite;Cogeoeration
                                                J-1

-------
                                            Appendix J
                    SCC« teM*y M«fc*d M Affected In th* StM* OTC NOx DaUbM*
SCC
10200401
10200402
10200403
10200404
10200405
10200406
10200501
10200502
10200503
10200504
10200505
10200601
10200602
10200603
10200604
10200801
10200802
1 0200804
10201001
1 020 1 002
10300101
10300102
10300103
10300205
10300206
10300207
10300208
10300209
10300211
 10300214
 10300216
 10300217
 10300221
 10300222
 1 0300223
 10300224
 10300225
 10300226
 10300305
 10300306
 10300307
 10300309
 10300401
 10300402
 10300403
 10300404
 10300501
 10300502
 10300503
 10300504
 10300601
 10300602
 10300603
 10301001
 10301002
 10500102
 10500105
 10500106
 105001 10
 10500202
 10500205
 10500206
 10500210
Description
ExtCombBorters;lrxkistrial;ResidualCH;Grade6Oil
Ext Comb BoHers-lnd;ReskJual OI;10-100MMBTU/HR "
Ext Comb Boitors-lnd;Rasktual Oi;<10MMBTU/HR "
Ext Comb Boiterc;lndustrial;Residual Oi;Grade 5 Oil
Ext Comb Boiterc;lndu6trial;Re6idual OijCogeneration
Ext Comb BoUers;lndustrW;Rttiduai Oil
Ext Comb Botere-lnd;DisJaa*B OI;10-100MMBTU/HR "
Ext Comb Bo8ere-lnd;D«s*aJe O1;<10MMBTU/HR "
ExtCombBotors;lndu6trU^>istilateOI.<>rade40il
Ext Comb Boters;lndustriai;Dfc«ale Oi^oaaneratkm
Ext Comb Boters;lndustrial;Nalur* GasiOvef 100 MB*j/Hr
Ext Comb Botere;lndustrid;NalurjfHhracite Coal;Putverized Coal
Ext Comb Boilers;Co(nmerdal/lnsttul;Anftraote Coal;Trav0fing Grate
Ext Comb Boiters;Commefcialrtns6tJt^nlhfacrt8 Coal;HafxJ-F»Bd
Ext Comb Boilers;CommefX3aWns«ittJt;Bituminous CoaI;Putveri2ed Coal: Wet
Ext Comb Boiters;Commercial/tnstitLJt;Bituminous Coal;PuK^efized Coal: Dry
Ext Comb Bolefs;C>jmmerciaMr*stitJt;Bituminous Coalpverfeed Stoker
Ext Comb Boiters;CommefciaLV«stitirt.;Bitumlnous Coal.Urxterieed Stoker
Ext Comb Bolers;Commerciaiansti«Jt;Bituminous Coat;Spreader Stoker
Ext Comb Boiters-Comm^nstitur;Bi»uminous Coal^)verteed StokeT'
Ext Comb BoJlers;Commercial/lnstitut;Bi(uminous Coal;HanrJ-Fired
Ext Comb Boiters;Commerciai/lnstitut3ituminous Coal;Pulveri2ed Coal: Dry
Ext Comb Boilers;Commyiretitut;Bituminous Coal^tmos. Fluidized Bed Comb.
Ext Comb Boilers;ComrnerciaI/lnstJmrnerdaMnstmjt9is«ateOi;Grade4Oil
 Ext Comb Bo9ere;CommerctaHnstitut^4a»jfal GasjOver 100 MMBtu^Hr
 Ext Comb Boiters;CommerciaMnstitut;Natural Gas;Lass Than 10 MMBtVHr
 Ext Comb Boiters;CommeraaUlnsttut;LkjU6ed Petro (LPG)^utane
 Ext Comb Bo»ers^ommeraaVlnstitut;Lkiurfied Petro (LPG);Propane
 Ext Comb Boilers-Space Heaiers;lndusfrial;Coal
 Ext Comb Boiters,-SpaceHeaters;lnckistrialpistiBate Oil
 Ext Comb Boilers;Space Heaters;lndustrial;Natural Gas
 Ext Comb Boiters;Space Heaters:lndustrial;Uqur6ed Petroleum Gas (LPG)
 Ext Comb Boilers-Space Heaters;Commercial/lnstitutional;Coal
 Ext Comb Boilers;Space Heatefs;CommefciaJ-lnstitut)onal:D«stillate Oil
 Ext Comb Bo»ers;Space Heaters^ofmnercial-lnstitut)onal:r4atural Gas
 Ext Comb Boilers;Space Heaters;Commercial-lr«s(Jtutional;(LPG)
                                                 J-2

-------
                     SCC* Initially Marked i
                                                          Appendix J
                                                       i Affected In the State OTC NOx Database
 SCC
 20100101
 20100102
 20100201
 20100202
 20100901
 20100902
 20200101
 20200102
 20200103
 20200104
 20200201
 20200202
 20200203
 20200204
 20200301
 20200401
 20200402
 20200403
 20200501
 20200901
 20200902
 20201001
 20201002
 20300101
 20300102
 20300201
 20300202
 20300203
 20300204
 20300301
20301001
20301002
28888801
28888802
28888803
 Description
 Int Comb Engines;Etec. Gen. ;Dtst (late Oil (Diesel) ;Turfaine
 Int Comb Engines;Bec. Gen. pistillate Oil (DieseO Reciprocating
 Int Comb Engines;Elec. Gen.^atural Gas;Turotrte
 Int Comb Engines f tec. Gen.;Natural Gas;Redproca«ng
 Int Comb Engine6;Etec. Gen.;Kero6ene/Naph1ha (Jet Fuel);Turbine
 kit Comb Engines;Eiec. Gen.;KBrosene/Naphtha (Jet FuelJiRedprocating
 kit Comb Engina6;lndustriaJ;DiEtBate Ol (Diesel) ;Redprocafing
 kit Comb Engkw6;lndustrial^>i6tilata Oi (Diesel);Turbine: Cogeneratkxi
 ktfCombEngin«;lncHist;Distil.C*(Die^;Redprcude Ofl;Redprocating
Int Comb Engines;lndustrial;Kerosene^4aphtha (Jet Fuel);Turbine
kit Comb Engines ;lndustrial;Kerosene^laphlha (Jet Fuel);Redprccating
Int Comb Engines;lndustrial;Uquified Petro (LPG);Propane: Reciprocating
Int Comb Engines ;lndustrial;IJpumecl Petro (LPG);Butane: Reciprocating
Int Comb Engines;(^)mmercial/lnstituL;Distillate Oil (Dtesel);Reciprocating
Int Comb Engines;CommerdaWnstitut;Distillate Oil (Diesel) ;Turbine
Int Comb Engines ^ommerdal/tnstituL Datura! Gas;Rectproca6ng
Int Comb Engines;Commerdal/1nstituL;NaUjral Gas;Turbine
Int Comb Engines;Commercial/lnsl)tut^latural Gas Turbine: Degeneration
Int Comb Engines£ommerdal/lnstitLit;Natural Gas;Cogeneration
Int Comb Ertgines;Comrnerctal/1nstJtut,-Gasoline;Reciprocating
Int Comb Engines A>mmefcial/lnstitut;(LPG);Propane: Reciprocating
Int Comb Engines;Commerdal/lnstitiitXLPG);Butane: Reciprocating
Int Comb Engines;Fugitive Emiss.;Other Not dassified.Specify in Comm.s
Int Comb Engines;Fugitive Emiss.^Dther Not Classified ;Specify in Comm.s
Int Comb Engines;Fugit7ve Emiss.^Dthef Not Classified^pecify in Comm.s
                                                 J-3

-------
      APPENDIX J
LIST OF FILES ON EPA TTN

-------
                        APPENDIX J
               LIST OF FILES ON EPA TTN
The following files are available through the OAQPS Technology Transfer Network:

   OAQPS TTN
   Phone (919) 541-5742
   CHIEF Bulletin Board
   Inventory Data Bases/Programs
   Ozone Transport Commission - NO,
Name
OTC_JUN1.ZIP
NOXTABLE.WP5
OTCJNV5.ZIP
OTC_NWSR.ZIP
OTCJNV4.ZIP
OTCJNV3.ZIP
OTCINV1A.ZIP
ECS131_1.ZIP
OTCJNV1 .ZIP
NOXRATE.ZIP
PROCEDUR.ZIP
OTC_DAT2.ZIP
OTCSTATE.ZIP
OTCBASE.ZIP
Date
6/02/95
5/03/95
3/22/95
3/02/95
2/21/95
2/08/95
2/06/95
2/06/95
1/27/95
1/09/95
12/29/94
12/29/94
12/09/95
11/21/95
Description
OTC NO, baseline inventory as of 6/1/95
Status report of changes to Feb 16th OTC NOX
Baseline Inventory as of 4/22/95
Revised baseline inventories for all States
Summary of new source submrttals as of March 1 , 1 995
in spreadsheet format
Updated baseline inventories as of 2/20/95
Updated baseline inventories as of 2/9/95
Update baseline inventories as of 2/6/95
Summary of exceptional circumstance submittals
Revised State inventories as of 1/27/95
NOK emission rate summaries for default OTC NOX
Baseline Inventory
Procedures Document
Update Initial State Inventories
Initial State Inventories
Default OTC NOX Baseline Inventory
                              J-l

-------
J-2

-------
                                    TECHNICAL REPORT DATA
                             (Piease read Instructions on the revene before completing)
1. REPORT NO.
     EPA-454/R-95-013
                              2.
                                                             3. RECIPIENT'S ACCESSION NO.
4. TITLE AND SUBTITLE

   1990  OTC NO  Baseline  Emission Inventory
                                                             5. REPORT DATE
                          July 1995
                                                             6. PERFORMING ORGANIZATION CODE
7. AUTHOR(S)
                                                             I. PERFORMING ORGANIZATION REPORT NO
9. PERFORMING ORGANIZATION NAME AND ADDRESS

   E. H. Pechan & Associates,  Inc.
   5537-C  Hempstead Way
   Springfield, VA  22151
                                                             10. PROGRAM ELEMENT NO.
              11. CONTRACT/GRANT NO.
12. SPONSORING AGENCY NAME AND ADDRESS
              13. TYPE OF REPORT AND PERIOD COVERED
   Office Of  Air Quality Planning And Standards (MD 14)
   U. S. Environmental Protection Agency
   Research Triangle Park, NC   27711
              14. SPONSORING AGENCY CODE
15. SUPPLEMENTARY NOTES
   EPA Project  Officer:  Roy  Huntley
16. ABSTRACT

      The states  of the Ozone  Transport Commission (OTC) agreed to develop  a regional
   strategy for the control of NO  emissions  from stationary  sources.  As part of this
   strategy,  the  OTC Stationary/Area Source Committee proposed a regional NO  strategy
   that required  NO  reductions beyond reasonably available control technology (RACT) ii
   two phases.  Botn phases have emission reduction goals that are calculated as percent
   reductions from 1990, the baseline year.   This report documents the NO   emissions
   from 1990  for  the OTC states.                                            x
 7.
                                KEY WORDS AND DOCUMENT ANALYSIS
                  DESCRIPTORS
b.lDENTIFIERS/OPEN ENDED TERMS  C. COS AT I Field/Group
   Ozone Transport  Commission
   Emission Trading
   NO
     v
   Baseline Emission  Inventories
18. DISTRIBUTION STATEMENT
                                               19. SECURITY CLASS (ThisReport)
                            21. NO. OF PAGES
                                 242
                                               20. SECURITY CLASS (Thispage)
                                                                           22. PRICE
EPA Form 2220-1 (R«v. 4-77)   PREVIOUS EDITION is OBSOLETE

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