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
-------
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
-------
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
-------
IV
-------
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.
-------
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
-------
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
-------
VU1
-------
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
-------
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.
-------
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.
-------
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.
-------
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
-------
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
-------
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
-------
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
-------
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
-------
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
-------
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
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APPENDIX J
LIST OF FILES ON EPA TTN
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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
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J-2
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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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