SURVEY OF UTILITY PCWERPLANT
EMISSIONS AND FUEL DATA
Prepared for
Division of Stationary Source Enforcement
U.S. Environmental Protection Agency
October 1980
ICF INCORPORATED 1850 K Street Northwest,
Suite 950, Washington, D. C 20006
-------
SURVEY OF UTILITY POWERPLANT EMISSIONS
AND FUEL DATA
Prepared for
Division of Stationary Source Enforcement
U.S. Environmental Protection Agency
October, 1980
ICF
INCORPORATED
-------
TABLE OF CONTENTS
Page
Introduction i
Chapter One - powerplant Data: Equipment, Emissions Standards,
and Fuel Consumption
Methodology and Data Conventions 1
Universe of Powerplants 1
Capacity Ratings . 1
Location 2
County Attainment Status 2
Emissions Standards 2
Averaging Time 3
Boiler Data 3
Control Equipment 4
1979 Fuel Consumption 4
Estimated Actual Emissions 5
Powerplant Summaries, by State
Chapter Two - Survey of State Enforcement Agencies
ICF
INCORPORATED
-------
INTRODUCTION
This report presents the results of ICF's survey of utility powerplant
fuel consumption and compliance with state air pollution control regulations
currently specified fuel consumption and in individual State implementation
Plan regulations. This volume contains two chapters.
Chapter One includes the results of the major data
collection effort, showing powerplant equipment,
emissions standards, 1979 fuel consumption and 1979
estimated emissions by powerplant and unit.
Chapter TWO presents the responses of state air
pollution control officials to questions concerning
state enforcement practices for determining and/or
ensuring compliance with the air pollution control
regulations.
A separate volume, titled Review of Calculated and Allowable Emissions for
Existing utility Steam Powerplants, contains ICF's calculations of each
powerplant1s actual annual emissions, estimated based on 1979 fuel
consumption; allowable emissions, calculated by applying the state's specified
emissions rates to the total quantity of fuel consumed in 1979; and the ratio
of actual to allowable emissions.
ICF
INCORPORATED
-------
Chapter One
-------
CHAPTER ONE
POWERPLANT DATA: EQUIPMENT, EMISSIONS STANDARDS,
AND FUEL CONSUMPTION
METHODOLOGY AND DATA CONVENTIONS
The powerplant data assembled in this chapter were compiled from several
sources. The sections below identify the reference used for entries in each
category and discuss the decision rules used to choose among conflicting
sources of informaton.
Universe of Powerplants
As agreed to in the original work statement, the powerplants included in
this chapter represent oil, gas, and coal-fired steam turbines greater than or
equal to 25 jviw. Where fuel consumption data were available for smaller units
these units have also been included. No combined cycle, gas turbine, or
internal combustion units have been included in this listing.
Capacity Ratings
Every effort was made to associate nameplate and net dependable boiler
capacities with the turbine capacities reported in the DOE Generating unit
Reference File (GURF). The GURF ratings were always used when a "unit"
corresponded directly to one boiler and one turbine generator set. Where the
correspondence was not direct but fuel consumption by individual boilers was
obscured by a common feeder, the GURF unit ratings were used. In cases where
more than one boiler was associated directly with one turbine, the numbering
convention refers to the boiler initially and the turbine (i.e., GURF
reference) second, where the correspondence was not direct (i.e., more than
one turbine associated with a boiler and vice versa), the total capacity
shown reflects/the GURF estimate of nameplate and net dependable turbine
capacity, but the unit numbering corresponds to the boilers.
ICF
INCORPORATED
-------
-2-
Location
The plant locations were taken directly from FPC Form 67, when available.
For those plants not filing a Form 67, the National Coal Association's Steam
Electric Plant Factors, 1975 was used to identify the city and the DOE
Inventory of Powerplants in the united States, December 1979 was used to
identify the county.
County Attainment Status
The status of counties with regards to attainment of the national ambient
air quality standards for sulfur dioxide, nitrogen oxides, and particulates is
based on an EPA/OAQPS publication referred to as "Counties Not Meeting the
NAAQS for One or More Pollutants." The effective date of the publication used
in this assessment is 6/19/80.
The conventions used to designate the county attainment status are as
follows:
attainment of primary and secondary standards
X non-attainment of primary standard in entire county
XX non-attainment of secondary standard in entire county
X-P non-attainment of primary standard in part of county
XX-P non-attainment of secondary standard in part of county.
Emissions standards
The reported emissions standards for S02, NOX, and TSP reflect ICF's
best judgement concerning the currently enforced standard. These standards
were arrived at based on:
SO2 and TSP emissions limitations reported by
utilities on FPC Form 67.
SO2, NOX and TSP standards established by the
latest version of the State Implementation Plan
Verification/clarification by state enforcement
officials as to the correct standard.
Standards established in terms other than emissions per million Btu have been
converted when possible, or designated with the appropriate terms otherwise.
ICF
INCORPORATED
-------
3
One exception to this procedure was made for the State of Ohio. For all
Ohio utility plants, information obtained by ICF as part of the EPA Section
125 study was used to supplement or override the standards reported on either
Form 67 or the State regulations.
It should be recognized that the "currently enforced" emissions standard
remains a moving target in many instances. Negotiations over standards are
continuing in several states, causing utility perceptions of the correct limit
to differ from the published standard. The lag times between submission of a
proposed charge and official state approval, as well as state submissions of
revised standards and EPA approval, can also create a difference between the
official standard and the currently enforced standard. Chapter TWO identified
the approval status of the standards used in this report by listing the
effective dates of the regulations according to both the State and EPA.
It should also be noted that state officials gave considerably more
attention to verifying the S02 standards than to either the TSP or NOX
standards. Where standards varied according to actual (versus design) heat
input, as was true in some states for particulate emissions, state officials
made relatively no effort to verify the utility's estimate of the emissions
limitation. AS a result, while the S02 standards can be considered as
officially verified for the most part, the TSP limitations primarily reflect
the utility's submission on FPC Form 67, and the NOX limits reflect iCF's
reading of the State's emissions regulations.
Averaging Time
The averaging times associated with the emissons standards reflect the
averaging period specified in the state reguations as verified by state
enforcement officials. The state's actual enforcement procedure is recorded
where it differs from what is written in the regulations. in some cases the
averaging time listed is the implicit time construed from the regulations;
i.e., where standards are based on heat input rates and the heat input rates
are calibrated on a per hour basis, a one hour averaging time was assumed.
Boiler Data
Data on the boiler bottom and firing method were obtained for all
coal-fired boilers from 1979 FPC Form 67. Other sources including Form 67
Boiler Data for 1976 and PEDCO utility FGD Survey were used to verify the Form
67 information.
The firing method is shown for those oil and gas-fired units for which it
was available. The primary source of this data was the Form 67 Boiler Data
for 1976.
ICF
INCORPORATED
-------
4
Control Equipment
Information on the type and design removal efficiency of existing
equipment for controlling particulate and SC>2 emissions was obtained from
PPC Form 67. The information was verified using the GURF file and PEDCO
Utility FGD Survey. NO adjustment to the specified removal efficiencies has
been made to account for coincident removal of other pollutants (i.e., of
S02 by particulate controls or of particulates by desulfurization controls),
or for the portion of flue gas that is actually treated.
The abbreviations used in this category represent the following types of
equipment:
Particulate Controls:
Sulfur Controls:
MC
ESP
BH
PS
LS
LSS
DA
Vent.
MO
WL
CH
L/AF
GC
AC
NaS
NaCS
Mechanical Collectors
Electrostatic Precipitators
Baghouse
Particulate Scrubbers
Lime Scrubbers
Limestone Scrubber
Dual Alkali Scrubber
Venturi Scrubbers
Magnesium Oxide Scrubbers
Wellman Lord Scrubbers
Calcium Hydroxide Scrubbers
Lime/Alkaline Flyash
Baffled Gravitational Chamber
Aqueous Carbonate
Sodium Scrubber
Sodium Carbonate Scrubber
1979 Fue1 Consumption
Estmated 1979 fuel consumption by unit and by plant were taken from FPC
Form 67. Where a common feeder serves more than one boiler it has been so
noted. Quality characteristics of the fuels were only available on a
plant-wide basis.
In many cases, the quantity of fuel consumed by the individual units does
not add to the plant total, implying either that the reported total represents
deliveries rather than burn or that the plant total includes consumption by
units other than steam turbines, whenever possible, total consumption has
been adjusted to account for known differences.
ICF
INCORPORATED
-------
-5-
Estimated Actual Emissions
The estimated actual emissions shown in Chapter One were computed by the
utilities and submitted on FPC Form 67. These estimates can be compared to
the ICF calculations, prepared using EPA-approved formulae from AP-42;
Compilation of Air Pollutant Emissions Factors, which appear in the companion
volume to this report. That volume, titled Review of Calculated and Allowable
Emissions for Existing utility Steam powerplants, also contains ICF's
estimates of allowable emissions, based on the currently enforced emissions
standards, and the ratio of actual to allowed emissions.
ICF
INCORPORATED
-------
(Dc.l
Unit
Utilitv/Powerplant Number
ALABAMA
Alabama Electric
McWilliams 1
2
3
Total
Tomb'igbee 1
2
3
Total
Alabama Power Company
Barry 1
2
,3
4
5
Total
Cnickasaw 3
Gadsden 1
' '2
'/.. ' Total
Gaston 1
2
3
4
5
ixdme
Plate
Capacity
(MW
7.
7.
25.
40.
75.
235.
235.
545.
153.
153 .
272.
403.
788.
1,770.
40.
60.
60.
. 120.
272.
272.
272.
244.
952.
«e i
Depend
Capac
,t^ . Currently Enforced Emissions Limits-'
able county Attainment "
ity Location Status
SO.,
NO l
TSP
a
Averaging Boiler Data
Period Bottom
Firing
) (MW) City County SO, NO TSP (lbs/10 Btu) (lbs/10 Btu) (lbs/10 Btu)
5
5
0
0
0
0
0
0
1
1
0
8
8
8
0
0
0
0
0
0
0
a
0
8
8
22
38
70
210
210
490
147
147
265
372
741
1,674
47
68
68
136
272
272
272
244
864
.0 Gantt Covington -
.0
.0
.0
.0 Leroy Washington -
.0
.0
.0
.5 Bucks Mobile -
,5
.3
.5
.9
.7
.0 Chickasaw Mobile - - -
.0 East Gadsden Etowah - - X-P
.0
.0
.0 Wilsonville Shelby
.0
.0
.8
.0
4
4
4
4
1
1
1
1
1
1
1
1
4
4
4
4
4
4
4
.0
.0
.0
.0
.2-C/0.8-O
.2-C/0.8-0
.8
.8
.8
.8
.8
.8
.0
.0
.0
.0
.0
.0
.0
None
None
None
None
U.7-C/0.3-0
0.7-C/0.3-0
None
None
None
None
None
None
None
None
None
None
None
None
None
.17
.17
.17
.12
.10
.10
.12
. 12
.12
.12
.12
.12
.12
.12
.12
.12
.12
.12
.12
24 hr. Dry
Dry
Dry
24 hr. Dry
Dry
Dry
24 hr. Dry
Dry
Dry
Dry
Dry
24 hr. Dry
24 hr. Dry
Dry
24 hr. Dry
Dry
Dry
Dry
Dry
Stoker
Stoker
Pulverizer
Pulverizer
Pu Iver i zer
Pulver izer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulv/Tan
Pu Iver i zer
Pulver izer
Pulver izer
Pu Iver i zer
Pulverizer
Pulverizer
Pulverizer
Total 2,012.8
1,924.8
I/ Emissions limits apply to all fossil fuels
o
Tl
z
o
o
3)
s
3)
5
m
O
-------
1979 Fuel Consumption Estimated Actual
Control Equipment
! Unit
>L Uti 1 ity/Powerplant Number
i \BAMA
[ Alabama Electric
Mcwilliams . 1
2
3
f Tombigbee
' 3
Alabama Power Company
Barry 1
2
. 3
, 4
; s
Chickasaw 1..' 3
Gasden 1
2
',
1
1 Gaston . ' .: 1
' 2 '
3
4 .
; 5
Part iculates
Eouio.
MC
MC
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
. MC
ESP
ESP
' ESP
ESP
ESP
ESP
ESP
Eff.
90.
90.
99.
99.
99.
99.
99.
99.
99.
99.
99.
85.
99.
99.
99.
99.
98.
98.
99.
(») Eauif
0
0
3
3
3 LSS
3 LSS
5
0
3
2
6
0
7
7
0
0
8
e
s
so- io3
. * Eff. (%) " 1
1 .
8.
72.
85.0 273.
85.0 200.
545.
104.
118.
592.
709.
1.184.
2,708.
176.
163.
340.
726.
- 662.
681.
720.
2,031.
4,821.
Coal
'ons BtU/lb. Sulf. (%) Ash (%)
9
4
6
9 11,682 1.17 12.88
0
0
2
3 11,518 1.32 14.07
0
3
3
2
3
1 11,758 .84 13.6 .
4
7
1 12,236 2.02 13.03
9
2.
1
0 !'
3
5 11,823 1.83 13.31
Barrels
4.
21.
21.
47.
0.
0,
14.
98.
74.
187.
4.
0.
0.
1.
3.
6.
4.
3.
9.
27.
6
8
2
7
3
5
3
4
0
5
6
9
9
8
3
2
9
2
6
2
Oil ' Gas 3
/gal. (%) 10 MCF BtU/Ft.3 S02 NO TSP
88.2
97.2
1.5
186.9 1,026 - - .04
130,500 0.4 5.0 4.9 Q.S
3,628.4
3,047.1
_
_
_
136,957 0.14 6,675.5 1.127 36.4 26.1 3.0
136,795 0.17 28.6 1,191 000
26.6
24.0
136,464 0.25 50.6 1,033 11.0 6.1 0.1
137,585 0.35' 141.2 43.5 10.7
; Chickasaw Units 1,2 - retired
O
Tl
o
o
71
o
O
73
m
o
-------
(Id)c.l
Utili ty/PowerpIant
ALABAMA (Cont'd).
Alabama Power Company
Gotgas
Greene County
Miller
Tennessee Valley Authority
widows Creek (A) '
Widows Creek (B)
Colbert (A)
Colbert (B)
Unit
Number
5
6
7
8
9
10
Total
1
2
Total
1
1
2
3
4
5
6
Total
7
8
Total
1
2
3
4
Total
Plate
Capacity
(MW)
69
125.
125
187
190
788
1,485
299
269
568
705
141
141
150
141
141
141
855
575
550
1,125
200
223
223
223
869
.0
.0
.0
.5
.4
.8
.7
.2
.2
.4
.5
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
Capacity Location Status
so.
NO
TSP '
(MW) City County SO, NO TSP (lbs/10 Btu) (lbs/10 Btu) (lbs/10 Btu)
59
107
109
162
162
677
1,276
267
273
541
662
130
127
130
127
127
127
768
532
532
1,064
200
200
200
200
800
.0 Parrish Walker -
.0
.0
.0
.0
.0
.0
.7 Demopolis Greene -
.4
.1
.0 Graysville Jefferson - - X-P
.0 Stevenson Jackson X-P - X-P
.0
.0
.0
.0
.0
.0
.0 Stevenson Jackson X-P - X-P
.0
.0
.0 Tuscumbia Colbert XX-P
.0
.0
.0
.0
4
4
4
4
4
4
4
4
1
1
1
1
1
1
1
0
0
4
4
4
4
.0
.0
.0
.0
.0
.0
.0
.0
.2-C/0.8-0
.6
.6
.6
.6
.6
.6
.9
.9
.0
.0
.0
.0
None
None
None
None
None
None
None
None
0.7-C/0.3-0
None
None
None
None
None
None
None
None
None
None
None
None
.12
.12
.12
.12
.12
.12
.12
.12
.1
.12
.12
.12
.12
.12
.12
.12
.12
.12
.12
.12
.12
Averaqinq Boiler Data
Period Bottom
24 he. Dry
Dry
Dry
Dry
Dry
Dry
24 hr. Dry
Dry
24 hr. Dry
24 hr. Dry
Dry
Dry
Dry
Dry
Dry
24 hr. Dry
Dry
24 hr. Dry
Dry .
Dry
Dry
Firing
Pu Iver i zer
Pulverizer
Pulverizer
Pulverizer
Pulver izer
Pulverizer
Pu Iver i zer
Pulverizer
Pu Iver i zer
Pulver i zer
Pulverizer
Pulverizer
Pulvec izer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pu Iver i zer
Pulverizer
Pulverizer
550.0
500.0
Tuscumbia
Colbert
4.0
.12
24 hr.
Dry
PuIverizer
o
TI
o
o
3
TJ
O
33
m
O
-------
(If)c.l
1979 Fuel Consumption
Control Equipment
Utility/Poverplant
ALABAMA (Cont'd)
Alabama Power Company
Gorgas
Greene County
Miller
TVA
Widow's Creek (A)
Widow's Creek (B)
Colbert (A)
,
Colbert (B)
I/ Widow's Creek unit 7
O
n
1 Z
o
o
3D
TJ
§
m
o
Unit
Number E
5
6
7
8
9
10
1
2
1
1
2
3
4
5
6 .
8 '
1
2
3
4
5
retrofit planned
Particulates SO,
quip.
ESP
ESP .
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP/Vent
ESP
ESP
ESP
ESP
ESP
in 1981
Eff. (%) Equip-. Eff. (%)
99.5
99.8
99.6
99.4
99.6
99.4
99.3
99.3
99.1
99.6
99.6
99.6 - . -
99.6
99.6
99.6
95.0 LSS 83.4
. 90.0/S9.S LSS 80.0
97.0
97.0
97.0 - . " -
97.0
99.5
coal uii Cas ,
103 1(J3 Suit. . 1 ^missions UU Tons)
" Tons ""Vlb. Sul£. (%) Ash (%) " Barrels ""* /qal. (%) lu HCF UCU/Ft 3 so NO T«p
85.7 2.7
208.0 4.3
192.4 3.8
427.2 4.7
400.8 . 3.7
1,010.6 38.8
2,324.7 11,965 1.6 13.29 58.0 137,069 .44 5g 5 4
446.8 5.4
338.2 11.5
785.0 12,206 1.68 11.77 16.9 137,166 .42 ,,
^1.1 14.2 2.4
1,073.8 12,615 .68 9.85 50.3 137,393 .38 ' 11 7 19 5 8 5
252.5
263.6
266.3
276.2
278.4
256.0
1,593.0 11,920 0.8 14.5 22.6 137,500 0.1 0.7 23.8 14 3
1,151.9
804.6
1,956.5 11,660 3.1 14.9 34.1 137,600 0.1 ' 13-9 U8 2 2Q ?
449.2 .
299.5 |:
508.4
577.9
1,835.0 11,500 2.2 12.4 12.4 137,300 0.2 3 Q ?5 5 lg s
612.9 11,630 1.9 11.9 7.7 137,300 0.2 0 6 22 3 5 5
-------
(2)
Unit
Utility/Powerplant Number
ARIZONA
Ar i zor.a Electric Power Coop
Apache
2
3
Total
Arizona Public Service
.Cholla 1
2
Total
Ocotillo 1
2
Saguaro 1
; 2
Total
West Phoenix 4
5
, ' 6
Total
Yucca (Yuma-Axis) * 1
Salt River Agricultural
Improvement Project
Agua Fria '1
2
3
Total
Name
Plate
Capacity
(MW)
194.7
204.0
120.0
263.0
383.0
110.0
110.0
220.0
125.0
100.0
225.0
35.0
13.0
68.0
116.0
75.0
113.6
113.6
163.2
390.4
I/ (£) indicates figure derived from SIP formula
2/ Cholla Plant 11 - TSP allowable emission stated as
3/ Oculillo HI 6 »2 - TSP allowable emission stated as
4/ West Phoenix Plant - TSP allowable emission stated
5/ No S02 standard for gas. TSP standards
0
-n
z
0
o
30
-o
O
3D
m
o
,_, _ . Currently Enforced Emissions LindtsS/
Capacity Location Status 2: x r- ^ Averaging
(MB) City County SO, NOJ( TSP (lbs/10 Btu) (lbs/10 Btu) (lbs/10 Btu) Period
Cochise Cochise X-P X 3 hr.
166.5 0.8 Coal/oil 0.7 0.1
175.0 0.8 Coal/oil 0.7 0.1
116.0 Joseph City Navajo - - XX 1.0 Coal/oil None 0.1982/ 3 hr.
235.0 0.8 Coal/oil O.T-c/0.3-0 0.167
351.0
114.9 Tempe Maricopa - - X 1.0 Oil None O.l3/ 3 hr.
113.0 1.0 Oil None 0 . l5/
227.9
110.0 Red Rock Final X-P - X 1.0 oil None .2 3 hr.
94.0 1.0 Oil None .2
204.0
33.0 Phoenix Maricopa - - X 1.0 Oil None -27(f)i/V 3 hr.
13.0 1.0 Oil None.' .33(f)
67.0 1.0 Oil None .23 (f )
113.0
75.0 Yuma Yuma - - X 1.0 Oil None .2 3 hr.
113.0 Glendale Maricopa - - X 1.0 Oil None .2(£) 3 hr.
113.0 ' ' 1.0 Oil None .2(£)
182.0 1.0 Oil None " .18(f)
408.0 ' '
756 lb./hr.; both HI & 2 allowed 920 Ibs./hr. after 1981
133 lb./hr.
as 401 lb./hr.
Boiler Data
Bottom Firing
Wet Pulverizer
Wet Pulverizer
Dry Pulverizer
Dry Pulverizer
N/A Tangential
Tangential
N/A Tangential
Tangential
N/A Front
Front
Front
K/A Tangential
"/A Front
"rent
Opp.Wall
apply to all fuels.
^
*"
'
.
-------
1979 Fuel Consumption
Estimated Actual 1979
L't ill ty/Powerplant
:JO:IA (Cont'd.)
Arizona Electric Power Coop
Apache
Arizona Public Service
Cholla
Ocotillo
Saguaro
west Phoenix
fucca (Yuma-Axis)
lalt River Agricultural
Improvement Project
Ag u a Fr i a
Unit
Number
2
3
1
2
1
2
1
2
' 4
5
6
1
- 1
. - 2
' 3
Control Equipment
Particulates SO
Equip. Elf. (%) Equip. ."" Eff. (%)
ESP 99.6 " LSSl/ 85.0
ESP 99.6 LSSl/ 85.0
Vent/MC 99.2/75.0 LSS2/ 92.0
Vent/MC 99.0/75.0 LSS.?/ 75.0
- - - -
-
_
- - - -
_
_
_
- _
_
t
' -
.
<
, _
_
_
. -
Coal
10 Tons BtU/lb. Sulf. (%) Ash (%) 10 Barrels
481.8 9
39716 6
879.4 10,072 0.46 . 13.99 16
479.2
895.9 11
1,375.1 10,047 0.41 12.77 11
503
538
58
141
470
430
B55
1,756
.4
.6
.0
.1
.1
.6
.6
.4
.6
.6
.8
.5
.9
Oil '. Gas . . ,3
BtU /gal. (%) 10MCF BtU/Ft.3 SO, NO TSP
137,789 0.35 . ' 0.43 12. B 0.5
26.9
-
139,139 0.35 26.9 923 est. 2.1 11.0 3.5
149,700 0.76 5,974.6 1065 0.56 12.7 0.017
149,895 0.79 3,990.7 1056 1.3 9.0
145,097 0.41 713.2 1057 0.3 0.7
148,540 0.77 2,526.0 1046 0.16 0.5
1,901.1
2,059.4
2,585.9
148,070 0.88 6,546.5 1062 4.2 3.4 .13
Line Stone Scrubbers on Apache Plant have Particulate Design Removal Efficiencies of 99.5% for'units 2 and 3.
Limestone Scrubbers on Cholla Plant have Particulate Design Removal Efficiencies of 80% for Unit 1 and 99.7% for unit 2.
O
TI
o
o
3
TJ
O
m
O
-------
(2d)
Utility/Powerplant Number
ARIZONA (Cont'd.)
Salt Rivet Agricultural
Improvement Project
Coronado 1
Kyrene . 1
2
Total
Mavajo 1
2
3
Total
Tucson Gas & Electric
Irving ton . 1
2
3
4
Total
Del-loss Petrie 1
2
3
4
Name
Plate
(MH)
411
34
73
108
803
803
803
2,409
109
109
114
173
495
13
12
23
58
.0
.5
.5
.0
.0
.0
.0
0
.0
.0
.0
.0
.0
.0
.0
.0
.0
Net
Dependable County
(MW) City County SO.,
350
35
75
110
750
750
750
2250
81
81
104
156
422
15
13
24
46
.0 St. John's Apache
.0 Tempe Maricopa
.0
.0
.0 Page Coconino
.0
.0
.0
.0 Tucson Pima X-P
.0
.0
.0
.0
.0 Tucson Pima X-P
.0
.0
.0
Bnicsions LimitsS/
SO
2 t
NO TSP jl.bs/lo"Btu)
- XX 0
XI
1
XI
1
1
XI
1
1
1
XI
1
1
1
.8 Coal/Oil
.0 Oil/Oil
.0 Oil/Oil
.0 Coal/Oil
.0 Coal/Oil
.0 Coal/Oil
.0-Oil
.0-Oil
.0-Oil
.0-Oil
.0-Oil
.0-011
.0-Oil
.0-Oil
NO
TSP
(lbs/10 btu) (lbs/10 Btu) Period
0.7
None
None
None
None
0.7-c/O 3-o
None
None
None
None
None
None
None
None
0.1 3 hr.
.26(£)1/ 3 hr.
.22(f)
.13(£) 3 hr.
.13(f)
1
.22(£)3/ 3 hr.
.22(£)
.20 (f)
19(f)
.32(f) 3 hr.
.33(£)4/
.29(f)
25(f)
Bottom Firing
Dry
N/A
N/A
Dry
Dry
Dry
N/A
N/A
N/A
N/A
N/A
N/A
N/A
Pulver izer
Front
Front
Pulver izer
Pulverizer
Pulverizer
Tangential
Tangential
Tangential
Front
Front
Front
Front-
Total
106.0
98.0
I/ (f) indicates figure derived from SIP formula
2/ Navajo Plant - S02 emissions limited to 21,270 Ibs./hr.
3_/ Irvington Plant - TSP .41% by weight
4/ Deiaoss Petrie Plant - TSP .49% by weight
5/ No S01
' Standard for gas. TSP standards apply to all fuels.
o
Tl
z
o
o
3
T»
O
3
5
m
o
-------
<2e)
1979 Fuel Consumption
Ut ill ty/Powerplant
ARIZONA (Cont'd.)
Salt River Agricultural
Improvement Project
Coronado
Kyrene
Navajo
Tucson Gas & Electric
Irvi ng ton
DeMoss Petrie
Unit
Number
1
1
2
1
2
3
1
2
3
4
1
2 '
Control Equipment Coal
Particulates so,, 3 3
Equip. Eff. (») Equip. " Eff. (%) "ions """"ib. Sulf. (%) Ash (») "Barrels
ESP 99.7 LSS 82.5 145.1 10,656 .59 13.76 135.3
- - - - 12.8
- - - - 90.7
103.5
ESP . 99.5 - - 2,435.
ESP 99.5 - - 2,369.7 38.0
ESP 99.5 - - 2,642.9 ' 17.3
7,448.2 10,820 0.43 9.45 85.2
- - - - 38.2
- - - - 162.9
- - - - 185.1
- - - - 535.1
921.3
- - ' - - . .2
- .1
91.2
142.0
Oil
Bt" /qal. "itf" "lO3
MCT
140,251 0.42
410
1,184
146,760 0.69 1)595
137,171 0.5/less
2,635
3,345
3,011
146,464 0.92 14)334
4
2
956
2,432
146,618 0.92 3,396
- ~ Emissions (10 Ton.^j
BtU/Ft 3 SO HO
0.9 .79 .17
.5
.7
.2 1,055 0.25 .54 .C;
60.9 67.0 5.6
.4
.1
.1
7? 1,055 2.74 30.08 .06
.6
.5
.6
.9
.5 1,055 .42 6.94 .01
o
o
o
a
-o
O
m
-------
Utility/Powerplant
ARKANSAS
Arkansas Electric Corp.
Fitzhugh
Bailey
McClellan
Arkansas Power & Light
Cecil Lynch
Hamilton Moses
Harvey Couch^/
Lake Catherine
Robert E. Ritchie
Jonesboro Water & Light
Jonesboro
Unit
Number
1
1
1
1
2
3
Total
1
2
Total
1
2
Total
1
2
3
4
' Total
1
2
Total
4
5
6
Total
Fiate
Capacity
(MW)
60.0
120.0
136.0
34.0
69.0
156.0
259.0
69.0
69.0
138.0
31.0
156.0
187.0
46.0
46.0
113.0
552.0
757.0
359.0
545.0
904.0
8.0
8.0
12.0
28.0
Capacity Location Status 2
(MW)"
59.0
122.0
134.0
28.0
59.0
130.0
217.0
63.0
63.0
126.0
27.0
124.0
151.0
45.0
44.0
97.0
485.0
671.0
295.0
517.0
812.0
8.0
8.0
12.0
28.0
City County SO, NO TSP (lbs/10 Btu)
Ozark Franklin - - *
Augusta Woodruff - *
Schumaker Ouachita - *
North Little Pulaski - *
Rock *
*
Forrest City St. Francis - *
*
Stamps Lafayette - *
*
Hot Springs Hot Springs - *
A
*
*
Helena Phillips - . *
i *
Jonesboro Craighead - *
*
*
^Qx TJiE ' Averaging
(lbs/106Btu) (lbs/106Btu) Period
None * *
None * *
None * *
None * *
None *
None *
None * *
None *
None * *
None *
None * *
None *
None *
None *
None * *
None *
None * *
None *
None *
Boiler Data
Bottom
N/A
H/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
H/A
N/A
N/A
H/A
N/A
Wet
N/A
N/A
N/A
Firing
Front
Front
Front
Front
Front
Front
Front
Front
Front
Front
Front
Front
Front
Tangential
Cyclone
Tangential
N/A
H/A
N/A
Southwestern Electric Power
Flint Creek
512.3
528.0 Gentry
Benton
1.2b/
0.7
0.1
30 days
* S02: 0.2 ppm SC>2 for any 30 min. ambient for single source.
TSP: 75 mg/m3 for any 24 hours, or 150 mg/m^ for any 30 min. ambient standard for single source.
a/ Couch unit 1 retiring after 1982.
b/ Flint Creek S02 limit changes to 1.1 Ibs. SO2/106 Btu in 1982.
O
o
o
30 .
TJ
O
30
Wet
Pulverizer
m
O
-------
(3b)c.l
1979 Fuel Consumption
Estimated Actual 197'j
t
1
j!
1
\
J
i
1
[
1
p
t
ji
1
1
I
I
s
1,
1
i
1
1
i
{
I
*
j
i
Utility/Powerplant
ARKANSAS (Cont'd)
Arkansas Electric Corp.
Fitzhugh!/
Ba i leyl/
ClennanJL/
Arkansas Power & Light
Cecil 'Lynch
Hamilton Moses
Harvey Couch
Lake Catherine
Robert E. Ritchie
Jonesboro Water & Light
JonesborojL/
Southwestern Electric Power
Flint CreeK
I/ Consumption data from Cost
2/ Sulfur content from Cost &
O
Tl
z
.0
o
31
o
O
3)
m
O
Control Equipment Coal
Unit Particulates SO, 3
Number Equip. Eff. (») Equi-p. " Eff. (%) Tons /lb. Sulf. (») Ash (»)
1
1
1
1
2
3
1
2
1 .
2
1 .
2
3 ;
4 ..
1
2 :
"
4
5
6
1 ESP 99.6 .. 1,451.2 8,393 0.35 5.4
s Quality of Fuels for Electric Utility Plants - 1979.
Quality of Fuels for Electric Utility Plants - 1979.
,
Oil Gas
"barrels Btu A,al. "I"' ^MCP BtU/Ft.3
114.1 149,552 2.23 266.2 1,014
278.1 149,806 2.29 904.6 1,013
700.0 149,988 2.80 31.° 1.056
112.4 514.6
131.3 1,183.2
-
243.7 142,220 0.3 1,697.8 1,018
287.4
187.6
475.0 149,446 1.1
661.7
107.3 5,632.8
107.3 147,712 0.9 6,294.5 1,056
93.8 795.1
111.8 934.5
92.0 1,734.9
1,898.3 7,942.3
2,195.9 151,308 1.0 11,406.9 1,016
979.4 5,778.'3
2,688.9 3.517.6
3,668.3 149,684 1.1 9,295.9 1,016
"
4.2 145,044 1.0 113.5 1,016
30.2 140,000 0.62/
'- ' (103Ton-l
SO NO TSf
Not Available
Not Available
Hot Available
.02 .54 .01
1.80 2.09 .04
.31 1.34 .03
3.74 3.29 .56
13.7 9.9 0.2
Hot Available
10.16 21.83 1.88
-------
c.i
Util ity/Powe_r plant
MFORHIA
Eurbank Public Service Co.
Magnolia
01 ive
City of Glendale Public
Service Department
Grayson
Imperial Irrigation District
El Cenuo
Pacific Gas & Electric
Avon
Unit
Number
1
2
3
4
1
2
Total
1A/B
2
3
4
. 5
Total
1
2
3 ',
4
Total
VI
2/1
3/1
Total
Name
Plate
Capacity
(MW)
10.0
10.0
23.0
34.0
77.0
45.0
60.0
105.0
20.0
20.0
23.0
50.0
50.0
163.0
23.0
35.0
50.0
82.0
190.0
40.0
40.0
Net
Dependable County Attainment
Capacity . Location Status
(MW) City County SO, NO TSP
10.0 Burbank Los Angeles - - -
10.0
21.0
28.0
69.0
46.0 Burbank Los Angeles -
53.0
99.0
20.0 Glendale Los Angeles - -
22.0
21.0
47.0
49.0
159.0
22.0 El Centro Imperial - -
30.0
48.0
80.0
180.0
i
46.0 Martinez Contra Costa XX
46.0
Currently Enforced Emissions Limits
so..
NO
(lbs/10 Btu) (lbs/106Btu)
.25
.25
.25
.25
.25
.25
.25
.25
.25
.25
.25
.25
.5
.5
.5
.5
.5
.5
.5
% S
% S
% S
» S
% S
% S
% S
% S
% S
% S
% S
% S
% S
% S
% S
% S
% S-oil
% S-oil
% S-oil
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
TSP
(lbs/l'05Btu)
11.0 ibs/hr
11.0 Ibs/hr
11.0 Ibs/hr
11.0 Ibs/hr
11.0 Ibs/hr
11.0 Ibs/hr
11.0 Ibs/hr
All units:
.027 1DS./103
Stack Gas
0.3 grains/SCF
0.3 grains/SCF
0.3 grains/SCF
0.3 grains/SCF
0.15 grains/SCF
0.15 yrains/SCF
0.15 grains/ECF
Averaging Boiler Data
Period Bottom Firing
Not specified
Front
Front
Front
Front
Front
Front
Front
o
in
o
o
a>
i
m
O
-------
J,
r
1
{
s
I
!
f
V
1
f,
1
;
-
Control Equipment Coal
Unit Participates SO2 1Q3 Dtu
lity/Powerplant Number Equip. Eff. (%) Equip. * Eff. (%) * Tons " "/lb. Sulf. (%) Ash (%
lift (Cont'd)
mK Public Service Company
Kjnolia 1 MC 40.0
2 MC 40.0
3 MC 40.0
4 KC 40.0
1 ive 1 MC 23.0
2
of Glendale Publ ic
Service Department
;ruyson 1A/B
2 ;
3
4 FC/BH 98.0
5
rial Irrigation District
:i Centre 1
.2 "
.3'.
4.
ific Gas 6 Electric
\von 1/1
2/1
3/1
L/ Total consumption, Burbank Public Service Co.
o
-n
o
o
3J
' -0
O
DO
$
m
O
1979 Fuel Consumption Estimated Actual 1979
Oil Gas . . ..3
I 10 Barrels Bt" /gal. "»?' "^CF Btu/Ft.3 S02 NO TSP
T T
214.3 ' 446.9
1 1
529.4 1,125.0
807.0 I/ 147,168 .24 1,572.2 I/ 1,081 .63 2.08 .14
322.8 149,000 .24 1,457.1 1,065 0.3 518.0
21.7 300.3
151.5 370 9
296.3 652.7
497.0 ' 805.7
966.5 150,919 1.26 2,289.6 1,045 4.15 2.85 0.2
70.8 149,066 0.5 3,630.0 . 1,109 0.1 0.4
-------
(5c)c.l
Unit
Ut il i ty/Powerplant Number
COLORADO
Central Telephone & Utilities
Clark 3_/ 1
2
Total
Pueblo 3/ 4
5
6
Total
City of Colorado Springs
George Birdsall 1
2
3
Total
Martin Drake ' . 4/1,3,4
5/5
6/6
: 7/7
. Total
Colorado Ute Association
Craig .2
Hayden - ' 1
2
Total
riate
Capa~; ^~~
city
(MW)
16
22
38
7
7
15
30
19
19
25
63
20
50
75
132
277
380
190
275
465
.5
.0
.5
.5
.5
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.4
.4
uepenaaoie
Capacf"~ * *""
icy L/ucaciun
(MW) City County
19
24
43
7
8
i5.
34
17
17
23
57
21
52
80
132
285
380
183
261
444
.0 Fremont
.0
.0
.0 Pueblo Pueblo
.0
.0
.0
.0 Colo. Springs El Paso
.0
ii
.0
.0 Colo. Springs El Paso
.0
.0
.0
.0
.0 Craig Moffat
.0 Hayden Routt
0 i
.0
Bouncy Hccainmenc r^
Status 2 ,. ~
SO., NO TSP (lbs/10 Btu)
- - 1.8
1.8
X-P 1.5 oil
1.5 oil
1.5 oil
X-P 1.5 oil
1.5 oil
1.5 oil
X-P None
1.2 coal
1.2 coal
1.2 coal
0.8 oil/1.2 coal
0.8 oil/1.2 coal
0.8 oil/1.2 coal
NO
^ ^
TSP
f.
2/ .
Averag ing
Boi ler
(lbs/10 Btu) (Ibs/lO'Btu) Periorl HoK-^p
None
None
None
None
None
None
None
None
None
None
None
None
0. 3-o/0. 7-c
None
0.3-0/0. 7-c
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
.13
.12
.16
.16
.14
.13
.13
.12
.10
.10
.10
.10
.10
.10
.10
SO?
2 2 hr.
for whole
state
oil/gas 2 he.
oil/gas
oil/gas
oil/gas
oil/gas 2 hr.
oil/gas
2 hr.
oil/gas 2 hr.
oil/gas 2 hr .
oil/gas
Dry
Dry
Dry
Dry
Dry
N/A
N/A
N/A
wet
Wet
Wet
Dry
Dry
Dry
Data
Firing
Stoker
Stoker
Stoker
Stoker
Pulverizer
Front
Front
Front
Front .
Pulverizer
Pulver izer
Pulverizer
Pulveri zer
Pulverizer
Pulverizer
I/ State has no SO, ,..-...
.-' * limit for units burning gas.
2/ The Colorado State Regulation formula for existing plants with heat rates beetween 1 and 500 million BTU/hour is particulate limit = 0.5 (heat rate
BTU/HR) (0.26). This formula was used to determine limits for all plants which did not report TSP limits on Form 67. TSP limits apply to coal, oil and gas.
3/ Consumption data from: Cost & Quality of Fuels for Electric Utility Plants - 1979.
O
o
a
-o
O
a
m
o
-------
.1
1979 Fuel Consumption
Estimated Actual 1979
Control Equipment Coal Oil Gas
Unit Particulates SO, 3 1Q3 Dtu Suif. 1Q3 DCu -j
tility/Powerplant Number Equip. Eff. («) Equip. '-Eft. (%) Tons /lb. Sulf. (4) Ash (%) Barrels /qal. ,(4) MCF /Ft.
ADO (Cont'd)
ntral Telephone s Utilities
Clark 1 - - -
2 - - - -
182.3 9,711 0.5 Not Available
Pueblo 4 - -
5
6 * ~ ~ ~ _ -
3T71 142,030 0.12 2,057.8 852
ity of Colorado Springs
George Birdsall 1 - - - - 3.3 719.3
2 - - - - 2.9 401.7
} 3 3.9 1,058.4
1 - 10.7 148,142 0.46 2,179.3 987
B - -
If
>\ Martin Drake ' _. ,
'f 4/1,3,4 ----- 34.1
| 5/5 MC/ESP 85.0/96.0 - 198.2 15.2
1 6/6 : BH/MC 99.9/86.0 - 281.0 20.4
S 7/7 'ESP 99.4 453.5 36.7
1 ' 932.8 10,489 0.47 8.2 108.9 998
S
8
!. olorado ute Association
f. Craig ' '2 ' ESP 99.5 DA 95.0 249.9 9,900.0 0.45 7.55 9.1 130,000 0.2
ij Hayden 1 ESP 99.6 - - 651.1 5.0
ij 2 ESP 99.6 - - 985.3 3.3
3 ' 1,636.4 10,684 0.48 10.13 8.4 130,000 0.2
&us-ion- U03Tons
SO, NO TSP
trace 1.1 0
8.77 14.01 0.28
2.2 0.87 0.23
15.7 5.36 1.03
0
y
s
z
8
"
0
-------
(4z.4)c.l
Control Equipment
Coal
1979 Fuel Consumption
Ut ility/Powecplant
CALIFORNIA (Cont'd).
Southern California Edison
Unit
Number
11-17/1
11-17/2
11-17/3
11-17/4
5/5
6/6
7/7
8/8
Particulates
Eff. (%)
10
Btu .
Eff. (%) Tons /lb. Sulf. (%) Ash
103 Btu ' Sul£-
Barrels /gal. (i)
46.0
Gas
1,920.2
J
1,435.8
10'
MCF
1,143.5
15,501.0
27,856.0
Btu/Ft.3
Estimated Actual 1'j,
Emissions (10 Tonr.)
SO, NO
3,425.4 146,066 0.22 44,500.5 1,047 2.46 6.11 O.J.
San Bernardino
385.5 145,096 0.23 5,906.3 1,045 0.29 0.63 O.C-:
o
Tl
z
o
o
a
-o
O
m
a
-------
Utility/Pouerplant
CALIFORNIA (Cont'd)
Southern California Edison
Redondo
San Bernardino
Unit
Number
11-17/1
11-17/2
11-17/3
11-17/4
5/5
6/6
7/7
8/8
Total
1
2
Total
Name
Plate
Capacity
(MW)
66
69
66
69
156
163
495
495
1,569
65
65
130
.0
.0
.0
.0
.3
.2
.0
.0
.5
.0
.0
.0
Net
Depend,
Capac
itv Location Status
Currently Enforced Emissions Limits
soi
2 r
NOK
^ » Averaging Boiler Data
(MW) City County SO, NO TSP (lbs/10 Btu) (lbs/10 Btu) i (lbs/10 Btu) Period Bottom Firing
74
74
70
74
175
175
480
480
1602
63
63
126
.0 Redondo Beach Los Angeles -
.0
.0
.0
.0
.0
.0
.0
.0
.0 Loma Linda San Bernardino - - -
.0
.0
.25
.25
.25
.25
.25
.25
.25
.25
.25
.25
% S
% S
% S
% S
% S
% S
% S
% S
% S
% S
None
None
None
None
None
None
None
None
None
None
.1/SCFD Not Specified
. 1/SCFD
.1/SCFD
. 1/SCFD
.1/SCFD
. 1/SCFD
. 1/SCFD
.1/SCFD
.1/SCFD
.1/SCFD
Front
Front
Front
Front
Front
Front
Opp. Wall
Opp. Wall
Tangential
Tangential
o
n
o
o
a
TJ
o
3
5
m
o
-------
(4x)c.l
Ut i 1 i ty/Powerpla nt
CALIFORNIA (Cont'd)
Southern California Edison
El Segundo
Et iwanda
Highgrove
Huntington Beach
Long Beach ' .- .
Mandalay
Ormond Beach
Number
1
2
3
4
Total
1
2
3
4
Total
1
2
3
4
Total
1
2
3
' 4
\ Total
/ 10
11
Total
1
2
Total
1
2
Name
Plate
(MW)
156.0
156.0
342.0
342.0
996.0
123.0
123.0
333.0
333.0
912.0
35.0
35.0
50.0
50.0
170.0
218.0
218.0
218.0
218.0
872.0
90.0
90.0
180.0
218.0
218.0
436.0
806.4
806.4
Net
Dependable
(MW)
175.0
175.0
335.0
335.0
1020.0
132.0
132.0
320.0
320.0
904.0
32.0
33.0
44.0
45.0
154.0
215.0
215.0
215.0
225.0
870.0
50.0
50.0
100.0
215.0
215.0
430.0
750.0
750.0
Currently Enforced Emissions Limits
City County SO, NO TSP (lbs/10 Btu)
El Segundo Los Angeles - - - .25
.25
.25
.25
Etiwanda San Bernardino - - .25
.25
.25
.25
Colton San Bernardino - - .25
.25
.25
.25
Huntington Beach, Orange - .25
.25
.25
.25
San Pedro Los Angeles - - .25
.25
Oxnard Ventura - - - .5
.5
Oxnard Ventura - - - .5
.5
% S
% S
% S
% S
% S
% S
% S
% S
% S
% S
« S
% S
% S
% S
% S
% S
% S
% S
% S
% S
% S
% S
NO
(lbs/10 Btu)
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
TSP
(lbs/106btu)
.1/SCFD
.1/SCFD
.1/SCFD
.1/SCFD
.1/SCFD
.1/SCFD
.1/SCFU
.1/SCFD
.1/SCFD
.1/SCFD
. 1/SCFD
.1/SCFD
.1/SCFU
.1/SCFD
.1/SCFD
.1/SCFD
.1/SCFD
.1/SCFD
.1/SCFD
.1/SCFD
.1/SCFD
.1/SCFD
Averaging Boiler Data
Period Bottom Firing
Not Specified
Front
Front
Tangential
Tangential
Tangential
Tangential
Tangential
Tangential
Front
Front
Front
Front
Front
Front
Opp. Wall
Opp. Wall
I/
I/
Front
Front
Opp. Wall
Opp. Wall
Total 1,612.8
1,500.0
I/ Not available
o
Tl
z
o
o
00
-o
O
3D
m
o
-------
(4z)c.l
1979 Fuel Consumption
Estimated Actual I 57
Ut ility/Powerplant
CALIFORNIA (Cont'd)
Southern Cal i f ifornia
El Segundo
; Etiwanda
1
1 Highgrove
i
s
[ Huntington Beach
i
it
s
ft
if
| Long Beach
i
I
|! Mandalay
In
1
IS
i] Ormond Beach
u
Control Equipment Coal
Unit Participates SO., .-3
Number Equip. Eff. (%) Equip. ' E£f. (%) Tons /lb. Sulf. (%) Ash (%
Edison
1
2
3
4
1
2
3
4
1
2
3
- 4
1
2
3 '
4
10 '
. ' 11 .,
1 ''
2
1
2
Oil Gas 3
1 10 Barrels Bt" /gal. m 10 MCF Btu/Ft.J so, NO T3:-
5,302.9 146,396 0.23 16,403.4 1,054 4.0 4.78 .4Z
5,866.6 145,310 0.20 14,899.8 1,046 3.79 4.34 .46
66.8 145,503 0.23 1,203.2 1,045 .04 .24 .01
4,114.6 144,538 0.20 16,583.0 1,047 2.63 5.05 .33
425.7 122,015 0.4 6,002.6 * 1,047 .03 .08 .03
2,380.0 145,238 0...21 10,205.0 1,054 2.02 2.6 .19
9,423.0 145,701 0.23 3,057.0 1,079 6.74 5.48 .71
*Long Beach Gas total includes consumption by boilers 9 and 10 (combined cycle units).
o
n
o
o
JO
o
§
m
o
-------
(It)c.l
Unit
Ut i 1 i ty/Powerplant Number
CALIFORNIA
Southern California Edison
Alamitos 1
2
3
4
5
6
Total
Cool Water 1
2
31-32 *
!.
41-42 *
Name
Capacity
(MM)
163.0
163.0
333.0
333.0
495.0
495.0
1,982.0
65.3
81.6
-
-
Net
Capacity Location Status
(MK) . City County SO, NO TSP
x
175.0 Long Beach Los Angeles - - -
175.0
320.0
320.0
480.0
480.0
1950.0
65.0 Daggett San Bernardino -
81.0
-
-
Currently
SO,
(lbs/10 Btu)
.25 %
.25 %
.25 %
.25 %
.25 %
.25 %
0.5 % S
0.5 % S
0.5 % S
0.5 % S
Enforced Emissions
NO
(lbs/106Btu) (ib
S None
S None
S None .
S None
S None
S None
None
None
None
None
Limits
TSP .
s/106t)tu)
.1/SCF
. 1/SCF
. 1/SCF
.1/SCF
.1/SCF
.1/SCF
.1/SCF
.1/SCF
.01/SCFU &
11 IbS./hr.
.01/SCFD i
11 Ibs./hr.
Period Bottom Firing
Not Specified rront
Front
Tangential
Tangential
Opp. Wall
Cpp Wall
Tangential
Tangential
Total 146.9
146.0
* N/A-Turbine
o
Tl
o
o
3
0
O
3D
5
m
o
-------
1979 Fuel Consumption
Estimated Actual \
-------
<4p)c.l
Unit
Util i ty/Powerplant Number
CALIFORNIA (Cont'd)
Los Angeles Dept. of Wtr. & Pwr.
Valley 1
2
3
4
Total
San Diego Gas & Electric
Enc i na 1
2
3
4
5
Total
Silver Gate 1,2/1
; 3,4/2
5/3
6/4
South Day 1
, 2
3
, 4
' 't Total
Station B 21, 23-28/21
31-33/22
24
25
Total
Name
Plate
Capacity
(MW)
100
100
172
172
545
110
110
110
306
320
956
40
69
69
69
247
136
136
201
240
713
15
15
28
35
93
.0
.0
.8
.8
.6
.0
.0
.2
.0
.0
.2
.0
.0
.0
.0
.0
.0
.0
.6
.3
.9
.0
.0
.0
.0
.0
Net
Depend;
Capac
(MW
94
101
171
160
526
able County Attainment
ity Location Status
Currently Enforced Emissions Limits
S°2 .
NO^
). City County SO., NO TSP (lbs/10 Btu) (lbs/10 Btu)i
.0 Sun Valley Los Angeles - - -
.0
.0
.0
.0
.
100.0 Carlsbad San Diego -
102
102
287
292
883
38
64
64
64
230
140
142
198
220
700
17
18
28
41
104
.0
.0
.0
.0
.0
.0 San Diego San Diego -
.0
.0
.0
.0
.0 Chula San Diego -
.0 Vista
.0
.0
.0
.0 San Diego San Diego -
.0
.0
.0
.0
?$S- . Averaging Boiler Data
(lbs/10 Btu) Period Bottom Firing
Not- Snprifipd
.25
.25
.25
.25
.5
.5
.5
.5
.5
.5
.5
.5
.5
.5
.5
.5
.5
.5
.5
.5
.5
% S
% S
% S
% S
% S
% S
% S
% S
% S
% S
« S
% S
% S
% S
% S
% S
% S
% S
% S
i S
% S
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
.1/SCF
.1/SCF
.1/SCF
.1/SCF
. 1/SCF
. 1/SCF
.1/SCF
.1/SCF
.1/SCF
.1/SCF
.1/SCF
.1/SCF
.1/ECF
.1/SCF
.1/SCF
.1/SCF
.1/SCF
. 1/SCF
.1/SCF
.1/SCF
.1/SCF
,
Front
Front
Front
Front
Front
Front
Front
Opp. Wall
H/A
Front
Front
Front
Front
Front
Front
Opp . We
ill
Tangential
Front
Front
Front
Front
o
3
TJ
O
3
m
O
-------
(4r)c.l
1979 Fuel Consumption
Unit
Ut ili ty/Powerplant Number
CALIFORNIA (Cont'd)
Los Angeles Dept. of wtr.6 Pwr.
Valley 1
2
3
4
San Diego Gas ft Electric
Encina- 1
2
3
4
. 5
i Silver Gate . 1/1
2/1
3/2
4/2
5/3
6/4
South Bay 1 '
2 '
3 '
' '.: 4 -
- ' '
Station B 21
22
24
25
I
\
|
|
! Tl
1 o
o
33
i o
* ?
Control Equipment Coal
Pacticulates SO, 3 1()3
Equio- Eff. (%) Equip. ' Eff. (%) Tons /lb. Sulf. (4) Ash (») Barrels
MC 7.0 . 272.0
MC 7.0 ' 297.0
MC 7.0 587.0
MC 7.0 317.0
1,471.0
679.0
792.0
1,030.0
710.0
3,152.0
7,362.0
4.0
1
9.0
- . ^ 35*0
26.0
73.0
463.0
490.0
1,120.0
1,135.0
3,209.0
i-
11.0
'
'
f
Oil Gas
BtU /»!. ^ ' 103MCF BtVt.3
884.0
1,292.0
1,890.0
1,779.0
144,761 0.2 5,845.0 1,048
1,657.0
2,410.0
1,032.0
2,891.0
16.0
148,452 0.43 8,006.0 1,048
160.0
1
556.0
1
725.0
742.0
140,095 0.19 2,183.0 1,047
4,571.0
6,184.0
, 4,471.0
352.0
147,333 0.43 15,578.0 1,047
139,500 0.17 372.8 1,047
-
. _
Estimated Actual l'^7
3
F3n issions (10 To n i^ i
SO, NO T;,;>
0.9 1.1 0.1
10.3 5.0 1.1
-
4.5 2.2 0.2
.7 -
-------
(4l)c.l
Unit
Utility/Powerplant Number
CALIFORNIA (Cont'd)
Pacific Gas & Electric
Potrero 1/1,2 I/
2/1,2
3/1,2
3-1/3
j Total
City of Pasadena Water & Power
Broadway 1
2
3
Total
Glenarm 14/G8
15/G8
16 /G9
17/G9
Total
Los Angeles Dept of water & Pwc.
1 Harbor 1
2'
3 '
4 ,'
' ; . s ,
Total
Haynes ' . 1
2
3
4
5
6
Total
Scattergood 1
2
3
Total
Name
Plate
Capacity
(MW)
Net
Dependable County Attai
Capaci
(MW)
ty - Location status
City County SO, NO
Currently Enforced Emissions Limits
nment
TSP (lbs/10
NO
6Btu) (lbs/10 Btu)
TSP
Boiler Data
(lbs/10 Btu) Period Bottom Firing
Not Specified
100
217
317
46
50
75
171
25
40
65
65
65
86
86
86
388
230
230
230
230
343
343
1,606
163
163
496
823
.0
.9
.9
.0
.0
.0
.0
.0
.0
.0
.0
.0
.4
.2
.2
.8
.0
.0
.0
.0
.0
.0
.0
.2
.2
.8
.2
116.
207.
323.
45.
45
71.
161
14
45
59
78
79
92
92
94
435
222
232
220
227
344
344
1589
179
179
284
642
0 San Francisco San Francisco - -
0
0
0 Pasadena Los Angeles - -
0
0
0
0 Pasadena Los Angeles
0
0
0 Los Angeles Wilmington -
0
0
0
0
0
0 Long Beach Los Angeles
0
0
0
0
0
0
0 Playa Del Ray Los Angeles - -
0
0
0
0.5 %
0.5 S
0.5 t
0.5 S
.25
.25
.25
.25
.25
.25
.25
.25
.25
.25
.25
.25
.25
.25
.25
.25
.25
.25
.25
.25
.25
S-Oil
S-Oil
S-Oil
S-Oil
% S
% S
% S
% S
% S
% S .
% S
% S
% S
% S
% S
% S
* S
% S
% S
% S
% s
% s
% s
% s
% s
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
.15 gr./SCFD
.15 gr./SCFD
.15 gr/SCFD
.15 gr./SCFD
.1/SCF
.1/SCF
.1/SCF
.1/SCF
.1/SCF
.1/SCF
. 1/SCF
.1/SCF
.1/SCF
.1/SCF
.1/SCF
.1/SCF
.1/SCF
.1/SCF
.1/SCF
.1/SCF
.1/SCF
.1/SCF
.1/SCF
.1/SCF
.1/SCF
Front
Front
Front
Front
Front
Front
Opp . wall
Front
Front
Front
Front
Front
Front
Front
Front
Front
Front
Front
Opp.
Opp.
Opp.
Opp.
Front
Wall
Wall
Wall
Wall
Front
Tangential
I/ Potreio boilers 1,2,3 associated with turbines 1 (50 MW) and 2 (50MW).
o
Tl
z
o
o
3J
TJ
O
3
m
O
-------
tnjc.l
1979 Fuel Consumption
Control Equipment Coal
Unit Particulates SO, 3
Utility/Powerplant Number Equip. Eff. (%) Equip. ' E££. (%) Tons /lb. Sulf. (%) Ash (%
CALIFORNIA (Cont'd)
Pacific Gas s Electric
Potrero 1/1,2
2/1,2
3/1,2
3-1/3
City of Pasadena water & Power
Broadway 1 MC 94.0
2 MC 94.0
3 MC 92.0
Glenarra 14/G8 MC 94.0
15/G8 MC 94.0
16/G9 MC 94.0
17/G9 MC 94.0
Los Angeles Dept. of wtr . & Pwr.
Ha r bor 1 '
2
3
4 '
, ' 5 ''
''.;
Haynes 1 .
2 j. '
3 - -
4
5
6
*"
Scattergood 1 MC 7.0
2 MC 7.0
3
Oil
103 Btu , . Sulf'
) Barrels /gal. («)
60.1
48.9
64.2
332.8
506.0 147,784 0.4
317.8
281.6
178.4
777.8 147,600 0.3
108.0
169.0
306.0
321.0
376.0
1,276.0 145,774 0.2
1,790.0
1,839.0
67.0
727.0
1,014.0
1,173.0
8,636.0 145,026 0.2
1,102.0
717.0
1,817.0 144,412 0.2
Gas
103MCF
. 721.0
530.0
730.4
6,601.5
8,583.0
528.8
516.7
22.9
1,068.4
6.6
|
1.0
1
7.6
160.0
42.0
137.0
73.0
143.0
i 556.0
424.0
1,090.0
20.0
666.0
1,625.0
2,586.0
4,387.0
2,310.0
1,427.0
16,321.0
20,059.0
BtU/Ft.3
1,051
1,045
V
1,050
1,047
1,049
Estimated Actual 197
Emissions (10 Ton;:;
SO
2-
NO
0.8 2.1 O.i
1.2 1.0 0.1
0.9 3.3 0.4
6.3 5.8 0.9
1.1 7.9 0.3
I/ Not available
o
Tl
z
o
o
30
TJ
O
a
m
O
-------
(4h)c.l
Ut illty/Powerplant
CALIFORNIA (Cont'd)
Pacific Gas & Electric
Mocro Boy
Moss Landing
Oleum
Pittsburg
Unit
Number
1
2
3
4
Total
1/1
2/1
3/2
4/2
5/3
6/3
7/4
8/5
6-1/6
.7-1/7
Total
1/1
2/1
3/1
'4/2
,5/2
6/2
' Total
;l
2
3
4
5
6
7
Name
Plate
Capacity
(MW)
169
169
359
359
1,056
108
110
108
113
.0
.0
.0
.0
.0
.0
.0
.0
.0
113.0
812
812
2176
40
40
80
156
156
156
156
326
326
751
.0
.0
.0
.0
.0
.0
.3
.3
.2
.2
.4
.4
.1
Net
Dependable County Attai
Capac"'"" * "~" r*>--'
(MW
163
163
338
338
1002
116
115
117
117
117
739
739
2060
41
46
87
153
163
153
163
325
325
720
iiy ixjudtiun OLUUU^
) " City County SO, NO
.0 Morro Bay San Luis 'Obispo -
.0
.0
.0
.0
.0 Moss Landing Monterey
.0
.0
.0
.0
.0
.0
.0
.0 Martinez Contra Costa
.0
.0
.0 Pittsburg Contra Costa - -
.0 ;,
.0 v
.0
.0
.0
.0
Currently Enforced Emissions Limits
nment so.
TSP (Ibs
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
NO
f 6
/10 Btu) (lbs/10 Btu) (Ibs/
.5
.5
.5
.5
.5
.5
.5
.5
.5
.5
.5
.5
.5
.5
.5.
.5
.5
.5
.5
.5
.5
.5
.5
.5
.5
.5
.5
% S
% S
t S
% S
% S
% S
% S
* S
% S
% S
% S
% S
% S
% S
% S-Oil
* S-Oil
I S-Oil
% S-Oil
% S-Oil
% S-Oil
% S-Oil
% S-Oil
% S-Oil
% S-Oil
% S-Oil
% S-Oil
% S-Oil
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
'0.3
0.3
0.3
0.3
.15
.15
.15
.15
.15
.15
.15
.15
.15
. .15
.15
.15
.15
.15
.15
.15
.15
'SP
106Btu) Period 1
Boiler Data
Bottom Firing
gr/SCFD Not Specified Front
yr./SCFD
gr./SCFD
gr./ SCFD
gr./SCFD
gr ./ SCFD
gr./SCFD
gr v' SCFD
gr./SCFD
gr./SCFD
gr./SCFD
gr./SCFD
gr./SCFD
gr./SCFD
gr./SCFD
gr./SCFD
gr./SCFD
gr./SCPD
gr J SCFD
gr./SCFD
gr./SCFD
.15 gr./SCFD
.15
gr./SCFD
.15 gr./SCFD
.15
.15
.15
gr./SCFD
gr./SCFD
gr./SCFD
Front
Front
Front
Front
Front
Front
Front
Front
Front
Front
Front
Opp. Wall
Opp. Wall
Front
Front
Front
Front
Front
Front
Front
Front
Front
Front
Opp . Wall
Opp. Wall
Tanannt-i ^1
Total 2,028.9
2,002.0
o
Tl
o
o
3
TJ
O
3
m
D
-------
(4JJC.1
Control Equipment Coal
Unit Particulates S0_ ,-3
Utility/Powerplant Number Equip. Eff. (%) Equip. " Eff. (%) Tons /lb. Sulf. (4) Ash (%
CALIFORNIA (Cont'd)
Pacific Gas & Electric
Mor to Bay 1
2
3
4
Moss Landing 1/1
2/1
3/2
4/2
5/3
6/3
7/4
8/5
6-1/6
7-1/7 Vent. I/
Oleum 1/1
2/1
3/1 .
4/2
5/2
6/1
'.
Pittsburg 1
2 .
3
4
5
6
7
1979 Fuel Consumption
Oil
103 Btu i
) Barrels /gal.
566.7
524.2
1,696.2
1,866.0
4,653.0 147,812
804.4
206.0
370.2
2,484.9
3,032.1
6,897.6 145,877
931.7
914.1
898.8
865.1
1,043.6
1,385.3
1,435.4
7,474.0 147,487
Gas
Sm' . lo3MCF Btu/Ft.3
3,719.5
5,249.2
9,114.6
8,915.3
0.5 26,998.5 '1,083
10,134.1
3,970.8
3,786.4
24,802.3
15,378.8
0.4 58,072.3 1,083
6,875.0 1,097
4,630.5
3,890.2
4,482.9
3,405.3
4,844.3
6,185.4
11,554.9
0.5 38,993.6 1,040
Estimated Actual ly?
Emissions (10 Tons)
SO NO TSP
7.7 8.8 0.5
11.4 14.5 0.8
0.4
12.4 18.4 0.8
I/ Removal efficiency not available.
O
Tl
o
o
.3)
-0
O
3)
m
o
-------
(4d)c.l
Unit
Utili ty/Powerplant Number
CALIFORNIA (Cont'd)
Pacific Gas 6 Electric (Cont'd)
Contra Costa 1/1
2/1
3/2
4/2
5/3
6/3
7/4
8/5
9/6
10/7
Total
Humooldt Bay 1
2
Total
Hunter's Point 3/2
4/2
5/3
6/3
7/4
Total
Kern ' " 1/1
2/1
3/2
4/2
Total
Martinez 1
* SIP changes to 200 ppm in 1982 for all 4
Name
Plate
Capai ' '
city
(MW)
110
110
110
113
113
359
359
1,274
51
51
102
108
108
156
372
66
100
166
40
units
0
.0
.0
.0
.0
.0
.0
.0
.2
.2
.4
.0
.0
.0
.0
.0
.0
.0
.0
Net
Dependable County Attai
Capac.' ' " "--.
icy ideation otacutj
(MW) City County SO, NO
116
116
116
115
115
340
340
1258
52
53
105
107
107
163
377
74
106
180
46
.0 Antioch Contra Costa
.0
.0
.0
.0
.0
.0
.0
.0 Eureka Humboldt
.0
.0
.0 San Francisco San Francisco -
.0
.0
.0
.0 Bakersfield Kern
.0
».'
.0
.0 Martinez Contra Costa - -
Currently Enforced Emissions
"ment SO.. NO
* f. !
TSP (lbs/10 Btu) (lbs/10"Btu)
Oil-0.5 % S
Oil-0.5 % S
Oil-O.5 % S
Oil-0.5 % S
Oil-0.5 % S
Oil-0.5 % S
Oil-0.5 5 S
Oil-0.5 % S
Oil-0.5 % S
Oil-0.5 % S
- 1,000 ppm-exhaust
1,000 ppm-exhaust
0.5 % S-Oil
0.5 % S-Oil
0.5 * S-Oil
0.5 % S-Oil
0.5 % S-Oil
- *2,000 ppm-exhaust
*2,000 ppm-exhaust
2,000 ppm-exhaust
*2,000 ppm-exhaust
0.5 % S-Oil
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
Limits
TSP
e.
Averaq inq
(lbS/10"BtU) Cori^rf"
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
.15
.15
.15
.15
.15
.15
.15
.15
.15
.15
.1
.1
.15
.15
.15
.15
.15
.1
.1
.1
.1
gr./
gr./
gr./
gr./
gr./
gr./
gr./
gr./
gr /
gr/
gc ,
gr-/ E
gr./
gr./
gr ./
gr./
gr./
gt.j
gr./
gr./
gr./
boiler Data
Bottom Firing
Not Specified
SCFD
SCFD
SCFD
SCFD
SCFD
SCFD
SCFU
SCFD
SCFU
SCFD
ECF
;CFD
SCFD
SCFD
SCFD
SCFD
SCFD
SCF
SCF
SCF
SCF
.15gr/SCFD
Front
Front
Front
Front
Front
Front
Front
Front
Opp.Wall
Opp.Wall
Front
Front
Front
Front
Front
Front '
Front
Front
Front
Front
Front
Front
O
Tl
o
o
TJ
O
m
o
-------
<4£>c.l
1979 Fuel Consumption
Estimated Actual I
Control Equipment Coal
Unit Particulates SO, 1Q3
Utility/Powerplant Number Equip. Eff. (%) Equip. ' Eff. (%) Tons /lb. Sulf. (%) Ash (%
CALIFORNIA (Cont'd)
Pacific Gas t, Electric
Contra Costa 1/1
2/1
3/2
4/2
5/3
6/3
7/4
8/5
9/6
10/7
Humboldt Bay 1
2
Hunter's Point ' 3/2
4/2
5/3
6/3
7/4
Kern 1/f.
2/1
'. 3/2
' 4/2 '
Martinez 1
103
) Barrels
126.2
144.6
147.9
174.5
194.0
138.6
i8b.7
346.8
1,252.7
1,434.7
4,246.6
137.8
166.8
304.6
156.8
160.4
170.8
171.7
391.8
1,051.4
42.4
49.6
45.4
45.7
183.0
247.3 1
Oil ' Gas
Bt" )q.l. ''"Si' "'MCP ""/Ft.3
2,463.2
2,8-10.8
3,161.9
2,632.3
2,607.1
2,851.3
4,259.2
4,710.5
13,861.2
11,912.7
147,739 0.5 51,300.1 1,035
' 2,126.8
2,786.6
151,392 1.4 4,913.4 1,015
2,373.4
2,593.7
2,800.8
2,982.9
6,940.9
150,845 0.3 17,321.7 1,051
2,369.4
1,931.2
2,449.4
1,823.2
149,723 1.2 8,573.2 1,081
/ 151,094 1/-0.69 I/ 2,810.7 I/ 1,054 I/
3
Emissions (10 Tcr.
so NO r
7.0 9.8 0.
1.4 1.5 0.
1.7 4.1 0.
0.6 3.7
Not Available
Source: DOB, EIA Cost and Quality of Fuels for Electric Utility Plants - 1979.
O
Tl
o
o
a
o
O
m
O
-------
(5d)c.l
Ut i1i ty/Powe rpla nt
COLORADO (Cont'd)
Colorado Ute Association
Nucla
Utilities Bd. of City at Lamar
La mar
Public Service of Colorado
Arapa hoe
Cameo
Unit
Number
; m ifff-"-"'
Total
Total
Total
Total
Name Net
Plate
12.6
12.6
12.6
37.8
2.0
3.0
5.0
25.0
35.0
46.0
46.0
46.0
113.0
251.0
25.0
50.0
75.0
125.0
125.0
171.0
381.0
802.0
Capacity Location Status 2
(MW) City County SO, NO
12
12
12
36
2
3
6
28
39
45
45
45
101
236
24
52
76
104
107
156
339
706
.0 Nucla Montrose
.0
J)_
.0
.0 Prowers
.0
.0
.0
.0
.0 Denver Denver - X-P
.0
.0
.0 .
.0
.0 Palisade Mesa - -X
.0
.0
.0 Denver Adams
.0
.0
.0 j
.0
TSP (lbs/10 Btu)
1
1
1
.8
.8
.a
None
None
None
None
X 1
1
1
1
0.8 oil/ 1
1
1
1
1
1
.2
.2
.2
.2
.2
.2
.2
.2
.2
.2
coal
coal
coal
coal
coal
coal
coal
coal
coal
coal
N0x
TSP
==£ Averaging
(lbs/106Btu) (lbs/10bBtu) Period
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
.0
0
13 2 he.
.13
.13
.23
.21
.ia
.12
.1
.1
2 hr.
coal/gas 2 hr.
coal/gas
.1 coal/gas
.1 coal/gas
.11
.1
.1
.1
.1
.1
oil/gas 2 hr-
coal/gas
coal/gas 2 nr_
coal/gas
coal/gas
coal/gas
Boiler Data
Bottom Firing
Dry
Dry
Dry
N/A
N/A
H/A
H/A
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Stoker
Stoker
Stoker
N/A
H/A
N/A
Front
N/A
N/A
t!/A
N/A
Pulverizer .:
Pulverizer
N/A
N/A -'
Pulverizer
Pulverizer
o
z
o
o
.3
-o
O
33
m
o
-------
1979 Fuel Consumption
Estimated Actual 1979
li Control Equipment
1
Unit
Utility/Powerplant Number
1!
{ TOORADO (Continued)
fi Colorado Ute Association
!Nucla 1
2
3
Utilities Bd . of City of Lamar
Laroar 1
2
3
;
4
. .,
. :
i| Public Service of Colorado
1978 data: Arapahoe 1
2
3
4
1978 data: Cameo 2/ . 1
~ . ; 2
1978 data: Cherokee 1
2
3
4
Particul
ates
Equip. Eff.
BH
BH
BH.
-
-
-
-
MC/ESP
MC/ESP
' . MC/ESP
MC/ESP
; MC
, MC/ESP
MC/ESP
MC/ESP
MC/ESP
MC/ESP
99.
99.
99.
-
-
-
-
75.
75.
75.
so.
(%) Equip". Eff. (%)
4
4
4
-
-
-
-
0/99.0
0/95.7
0/95.7
Total 99.2 I/ -
99.
75.
75.
75
75.
75
8 - -
0/98.3
0/92.4 - . -
0/95.5
0/85.3 - . -
0/87.0 PS 16.0
Coal
103 Btu 103
Tons /lb. Sulf. (%) Ash (%) Barrels
37
49
28
115
200
146
40
329
716
3
152
155
371
376
467
954
2,170
.7
.9
.1
.7 11,420 0.82 13.79
.5
.1
.5
.8
.9 10,818 0.45 8.9
.0 1.6
.0
.0 11,987 0.55 . 9.1 1.6
.5
.8
.1
.7
.7 10,870 0.46 9.05
Oil
Btu Sul£- io3
/gal. (%) MCF
1,236.
217.
148.
54.
645.
1,066.
1,771.
356.
137,204 0.29 2,128.
189.
99.
276.
347.
912.
Gas
BtU/Ft.3
5 '967
0
2
9
9
0 996
9
4
3 1,016
1
5
9
3
7 990
3
SO, NO 1'SP
1.90 0.37 .01
4/ 4/ 4/
5.51 6.7 0.68
16.3 16.8 2.12
Includes particulate scrubber.
Uaghouse installed in Unit 2, 1979
Units 1,3, and 4 have particulate scrubbers-also combined efficiencies for total equipment at each unit: 99.3%, 99.0%, 99.3%.
Hot available
o
o
o
3
-Q
O
m
O
-------
Utility/Powerplant
COLORADO (Cont'd)
Public Service Co. of Colorado
Comanche
Unit
Number
Total
Name Net
Plate Dependable
Capacity Capacity
(MW) (MW)
383.0
350.0
733.0
325.0
335.0
660.0
Location
City
County
County Attainment
Status
SO.
Currently Enforced Emissions Limits
Pueblo
SO,
NO
TSP
6 6
(lbs/10 Btu) (Ibs/lO.Btu)
(lbs/10 Btu)
Averaging
Period
Boiler Data
0.8 oil/ 1.2-coal None
0.8 oil/ 1.2-coal None
0.1 c/o/gas
0.1 c/o/gas
2 hra.
Dry Pulverizer
Dry Pulverizer
Valmont I/
11-14
21-24
5
Total
282.0
247.0
Boulder
Boulder
1.2-coal None
1.2-coal None
1.2-coal None
0.11 gas/coai
0.11 gas/coal
0.1 gas/coal
Dry Pulverizer
Wet Pulverizer
Dry Pulverizer
Total
40.0
75.0
115.0
39.0
68.0
107.0
0.8-oil
0.8-oil
None
None
0.19 oil/gas
0.1 oil/gas
2 hrs.
Dry
N/A
I/ Capacity data not available by unit.
Boilers 11 and 21 associated w/turbine 1 at 33 MW.
Boilers 12 and 22 associated w/turbine 2 at 25 MW.
Boilers 13 and 23 associated w/turbine 3 at 25 MW.
Boilers 14 and 24 associated w/turbine 4 at 25 MW.
Boiler 5 associated w/turbine 5 at 174 MW.
o
Tl
z
o
o
3>
-O
O
3D
J
m
O
-------
Utility/Powecplant
Control Equipment
Unit Particulates so
Number Eg u i p. Eff. f%)
COLORADO (Cont'd)
Public Service of Colorado
Comanehe I/ 1
2
1978 data: Valmont
1973 data: Zuni
11-14
21-24
5
MC/ESP 75.0/96.6 PS 40^0
MC 75.0
MC/ESP 37.0/81.3
1979 Fuel Con
10 Tons Bt"/lb. Sulf. ,%,
I/ Consumption data from: Cost & Quality of Fuels for Electric Utility Plants - 197
2,734.1 8461 0.34 N/A
10,703 0.72 7.5
148.7
235.2
Oil
Estimated Actual ;
Emissions (10 Tci.
/gal.
>' 10MCF Bt"/Ft.3 SO
19.6 135,417 0.28 9.5
1,796.6 985
2_
Not Available
2,622.0
4,418.6 995 4.95 4.86 0
3,051.1
3,887.5
383.9 148,488 0.93 6,938.6 993 1.23 2.2
o
o
o
DO
TJ
O
m
O
-------
(6)0
{
r. Ut i 1 i ty/Powerpla nt
1
/f CONNECTICUT
| Connecticut Light & Power
ji Devon
1
$
f
Jj
9
'i
Number
2A
3
4A
4B
5A
5B
6
7
8
Total
Name
Plate
(MW)
25.0
66.0
45.0
1
45.0
66.0
104.0
104.0
455.0
Net
Dependable
(MW)
25.
68.
50.
48.
68.
107.
107.
473.
City
0 Milford
0
0
0
0
0
0
0
.... . Currently Enforced Emissions Limits-'
County SO., NO TSP (lbs/10
New Haven - - X 0.5
0.5
0.5
0.5
0.5
0.5
0.5
0.5
0.5
Btu)
% S
* S
% S
% S
% S
% S
% S
% S
% S
NO
(lbs/10 Btu)
0.3
0.3
0.3
0.3
0.3
0.3
0.3
0.3
0.3
TSP
j
(lbs/10
0.
0.
0.
0.
0.
0.
0.
0.
0.
r ' Averaging
Btu) Period
2 Absolute for
2 for all limits
2 in state.
2
2
2
2
2
2
Boil
Bottom
N/A
N/A
N/A
N/A
N/A
11/A
N/A
H/A
N/A
er Data
Firing
Front
Front
Front
Front
Front
Fror.t
Fron t
Tangent i.al
Tangential
l# I/ All limits apply to oil consumptions
O
Tl
o
o
3
-0
O
DO
5
m
O
-------
1979 Fuel Consumption
Control Equipment
Oil
Ut ility/Powerplant
CONNECTICUT (Cont'd)
Connecticut Light & Power
Devon
Unit
Number
2A
3
4A
48
5A
58
6
7
8
Part iculates
Suit". (%)
ESP
ESP
ESP
ESP
. ESP
ESP
ESP
ESP
ESP
98.0
95.0
95.0
95.0
86.0
86.0
98.0
98.0
98.0
10
Parrels
44.0
232.0
44.2
44.2
30.6
30.6
247.5
618.1
505.B
1,797.0
Btu
Estimated Actual I'j'l'i
Emissions (10 Tens)
-2-
NO
147,970
0.4
2.56
1.56 0.10
o
T!
z
o
o
.30
TJ
O
DO
m
O
-------
(6d)c.l
Utility/Powerolant
CONNECTICUT (Cont'dl
Connecticut Light & Power
Montville I/
Norwalk Harbor
Hartford Electric Light Co.
Middletown
United Illuminating Co.
Bridgeport Harbor
English
.. . . /
New Haven Harbor
steel Point 2/
Unit
Number
^
2
3
4
5
6
Total
1
2
Total
1
±
2
3
4
Total
1
2
3
Total
^3
14
1-12
Total
1
23
24
25
26
27
Total
Name
Plate
Capacity
(MW)
31 .0
31.0
14.0
25.0
75.0
383.0
559.0
163.0
163.0
326.0
69.0
114.0
239.0
400.0
822.0
82.0
180.0
400.0
662.0
150.0
465.0
158.0
Net
Dependable
Capacity Location
(MW) City County
34.0 Uncasville New London
14.0
34.0
19.0
81.0
410.0
592.0
162.0 So. Norwalk Fairfield
171.0
233.0
70.0 Middletown Middlesex
117.0
233.0
400.0
820.0
85.0 Bridgeport Fairfield
170.0
410.0
665.0
New Haven New Haven
108.0 1.
447.0 New Haven New Haven
Bridgeport Fairfield
157.0
ronn^y fli-t-ninmrnt Currently Enforced Emissions l.imifo
Status $3-2
SO MO 'PCD /lu / 1 n^ r\
av~ MUJL ri>P (lbs/10 Btu)
XX 0.5 % S
0.5 % S
0.5 % S
0.5 % S
0.5 % S
0.5 % S
X 0.5 % S
0.5 % S
X 0.5 % S
0.5 % S
0.5 % S
0.5 % S
X 0.5 % S
0.5 % S
O.S % S
X 0 . 5 % S
0.5 % S
0.5 % S
X 0.5 % S
X 0.5 % S
0.5 % S
0.5 % S
0.5 « S
0.5 % S
NO
X 6 '
(lbs/10 Btu)
0.3'
0.3
0.3
0.3
0.3
0.3
0.3 '
0.3
0.3
0.3
0.3
0.3
0.3
0.3
0.3
0.3
0.3
0.3
0.3
0.3
0.3
0.3
0.3
0.3
TSf '
fL
(lbs/10 fltu
0.2
0.2
0.2
0.2
0.2
0.2
0.2
0.2
0.2
0.2
0.2
0.2
0.2
0.2
0.2
0.2
0.2
0.2
0 2
0.2
0.2
0.2
0.2
0.2
Averaging
Bo i 1 c. r DA t- a
L Period Bottom Firina
limits = max
N/;i
t:/A
N/A
N/A
H/A
N/A
H/A
N/A
Wet
Wet
N/A
N/A
Wet
Wet
Dry
Dry
Dry
N/A
N/A
Dry
Dry
Dry
Dry
Dry
Front
Front
Front
Front
Tangential
Tangential
Tangential
Tangential
Pulv/Front
Pulv/Front
L'yclone
Tangential
Cyclone
Cyclone
Tangential
H/A
N/A
Front
Tangential
Pulv/Front
Pulv/Frcnt
Fulv/Front
Pulv/Front
Pulv/Front
Capacity data not available by unit
JL/ Units 1-3 of Montville have reserve status.
2/ Steel Point Boilers associated with turbines KlOKw)
1CI6HW), and 1K35MW).
J
2UOMW), 3UUMW), 4(13MW), 5U3MW), 6(13MW), 7U3H.}, 8(5Mw,, 9(301*).
o
o
o
30
o
O
m
O
-------
(Gf)c.l
1979 Fuel Consumption
1
1
1
1
i
1
i
j
*
j
i
;
*
;
,
Ut ility/Powerplant
CONNECTICUT (Cont'd)
Connecticut Light & Power
Montville
Norwalk Harbor
Hartford Electric Light Co.
Middletown
United Illuminating Co.
Bridgeport Harbor
English , ' ";
New Haven Harbor
Steel Point
a/ Sulfur content for 16 Fuel
O
Tl
«
z
o
0
00
TJ
O
^
m
O
Control Equipment Coal
Unit Particulates SO,, ,-3
Number Equip. Eff. (%) Equip. " Eff. (S) Tons /lb. Sulf. (%) Ash (%
4 - -
5 ESP 97.0
6 - -
1 ESP 99.0
2 ESP 99.0 - -
1 ESP 97.0+
2 ESP 98.5
3 ESP 98.5
4
Aux.
1 ' ESP 97.5
2 ' ESP 97.5
3 . ESP 99.5
13 ', ESP 95.0
. 14 ESP 95.0
1-12 -
''
1 ESP 95.0
23 ESP 95.0 - -
24 ESP 95.0
25 ESP 95.0
26 ESP 95.0
27 ESP' 95.0
oil only
.'' j
Oil (:.-,=
) "barrels BtU A(al. * m ' ' \rf °
55.2
430.4
1,288.1
1,773.9 146,447 0.43 a/
1,181.7
1,511.9
2,693.6 145,927 0.46
126.6
587.4
1,437.2
1,352.1
65.2
3,503.3 146,017 0.48
662.0
872.0
3,193.0
4,727.0 147,765 0.4
14.0
23.0
8.0
45.0 148,287 0.5
3,535.0 147,752 0-.5
13.0
20.0
30.0
63.0 145,478 0.29
r
t
3
Emissions (10 Tons)
u 3
/Ft . SO., NO TiJi'
2.54 1.41 0.22
4.04 2.14 0.15
5.6 3.3 0.2
5.98 4.75 0.32
.07 0.1 trac'.
5.66 7.78 .08
.06 .03 .01
-
-------
Ut i 1 i ty/Powerplant Number
DELAWARE
Delmarva Power & Light
Delaware City 1
2
3
Total
Edgemoor 1
2
3
4
5
Total
Indian River 1
2
3
Total
Dover Electric
McKee Run 1
2
3
Total
Name
Plate
28
28
75
131
70
70
75
177
4-16
838
82
82
177
341
19
19
134
172
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
Net '
Dependable County Attair
(MW
27
27
66
120
70
70
82
167
412
801
89
89
162
340
15
15
105
135
) City County SO, NO
*
.0 Delaware City New Castle
.0
.0
.0
.0 Wilmington New Castle - -
.0
.0
.0
.0
.0
.0 Millsboro Sussex
.0
.0
.0
.0 Dover Kent
.0
.0
.0
Currently Enforced Emissions Limits
iment ^
* (
TSP (lbs/10
1.0 %
1.0 %
1.0 %
_
1.0 %
1.0 %
1.0 %
1.0 %
1.0 *
0.3 %
0.3 %
0.3 %
None
None
None
NO
'utu) (lbs/10 Btu)
S I/
S
S
SI/
S
S
S
S
s y
S
s
None
None
None
None
None
None
None
None
None
None
None
None
None
None
TSP
(lbs/106Ht
0
0
0
0
0
0
0
0
0
0
0
0
0
0
.3
.3
.3
.3
.3
.3
.3
.3
.3
.3
.3
.3
.3
.3
Averaging Be
ii. Period Bottom Firino
2 hr. TSP Ket
Wet
2 hr.-TSP N/A
N/A
N/A
N/A
N/A
2 hr. TSP Er:y
Cry
Dry
2 hr.-TSP N/A
N/A
N/A
Pulverizer
Pulverizer
Tangential
Tangential
Tangential
Tangential
Opp. Wall
Pulverizer
Pulverizer
Pulverizer
N/A
N/A
N/A
I/ Sulfur-in-fuel standard applies to all fuels except distillate. Distillate limit is 0.3%S.
2/ Limit applies to distillate'^oil. No standard for residual oil.
O
TI
o
o
O
3
5
m
O
-------
(7b)c.l
1979 Fuel Consumption
f
!Unit
Utility/Powerplant Number
I DELAWARE (Cont'd)
}' Delmarva Power & Light
1 . Delaware City 1
2
3
Edgemoor 1
2
3
i 4
5
Indian River 1
2
" 3
| Cover Electric 1
4 McKee Run 2
. 3 '
Control Equipment
Particulates SO,
Equip.
MC
MC
MC
MC
MC
MC
ESP
MC
ESP
ESP
ESP
MC
MC
MC
Eff. (%) Equip. Eff. (%)
I/ WL 3/ 90.0
I/ WL 3/ 90.0
I/ WL 3/ 90.0
72.0
72.0
83.0
95.0
85.5
99.5
99.5
99.5
V - ' -
I/ - -
I/ - -
Coal
103 Btu
Jons /lb. Sulf. (%) Ash (%)
82.8 2/
72.2
75.1
230.1 14,328 5.4 0.'3
257.7
208.0
420.8
887.3 12,339_. 1.8 12.4
Oil Gas
103
Barrels
107
107
122
337
580
384
524
962
3,354
5,805
15
13
16
46
686
.9
.6
.1
.6
.1
.2
.2
.3
.8
.7
.7
,1
.8
.0
.5
Btu SUi£" 103
/gal. (%) JU MCF
1,400.
1,444.
1,251.
148,721 1.0 4,096.
427.
_
346.
1,508.
-
2,353.
148,317 0.98
137,036 0.27
149,878 2.07 1157
4
8
6
8
1
3
4
R
.8
BtU/Ft.3
1,075
1,031
1047
Estimated Actual 1979
Emissions (10 Tons)
SO,
18.7
N0
6.1 1.5
31.0 8.0 4.0
jj I/ Removal Efficiency data not available from Form 67
2_/ All Delaware City units are coke-fired.
3/ Retrofit in 1980 .. '
o
n
z
o
o
.30
o
O
3
.**
m
O
-------
{SJc.l
Ut i1ity/Powerpla nt
DISTRICT OF COLUMBIA
Potomac Electric Power Co.
Denning
Buzzard Point
Unit
Number
1
2
13
15
16
Total
2
3
4
5
6
Name
Plate
Capacity
(MW)
30
30
55
289
289
693
35
50
50
50
50
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
Net
Dependable
Capacity Location
.(MW) City County
28
28
52
275
275
658
30
48
48
48
43
.0 District of Columbia
.0
.0
.0
.0
.0
.0 District of Columbia
.0
.0
.0
.0
Currently Enforced Emissions Limits
Status 2~c "
NO
TSP .
SO, NO TSP (lbs/10 Btu) (lbs/10^Btu) (lbs/10 Btu)
- X-P 1.
1.
1.
1.
1.
- X-P 1.
1.
1.
1.
1.
0
0
0
0
0
0
0
0
0
0
% s
% s
% s
% s
% s
% s
% s
% s
% s
% s
None
None
None
None
None
None
None
None
None
None
.05
.05
.039
.026
.026
.043
.038
.038
.038
.038
Averaging Boiler Data
Period Bottom Firing
N/A
Specified Dry
N/A
rJot N/A
Specified N/A
N/A
M/A
Front
Front
Stoker
Stoker
Front
Tangential
Tangential
Tangential
Tangential
O
Tl
z
o
o
3
.TJ
O
30
m
O
-------
(3b)c.l
Unit
Utility/Powerplant Number
DISTRICT OF COLUMBIA (Cont'd)
Potomac Electric Power
Benning 1
2
13
15
16
Buzzard Point 2
3
4
' 5
f 6
1979 Fuel Consumption Estimated Actual }')';,
Control Equipment Coal Oil Gas 3
Part-inHatPs SO. ...1 _. ...1 ... . Rnlf ....1 . . "'"b^ons. UU Tons)
-
-
-
-
-
ESP
ESP
ESP
ESP
ESP
Eff. (%) Equip. Eff. (») Tons /lb. Sulf. (») Ash (*) Barrels /gal. (») MCF /Ft. so NO TS?
- - - . 186.1
_
- - - 35.1
- 801.0
709.6
1,731.4 144,059 0.85 I/ 3-b a -1
99.3
99.3
99.3
99.3
99.3
462.0 146,929 0.99
I/
1.02 0.1
I/ Not Available
o
Tl
o
o
3
o
O
m
o
-------
Name Net
Unit
Ut ili ty/Powerplant Number
FLORIDA
Florida Power i, Light
Cape Canaveral 1
2
Total
Fort Lauderdale 4
5
Total
Fort Myers 1
2
Total
Manatee 1
2
Total
Martin County 1
2
Total
Cutler 4
5
6
Capacity
(MW
402.
402.
804.
156.
156.
312.
156.
402.
558.
863.
863.
1,726.
863.
863.
1,726.
46.
69.
75.
)
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
Capacity Location
(MW)
381.
381.
762.
151.
144.
295.
154.
381.
535.
775.
775.
1,550.
775.
775.
1,550.
67.
67.
130.
City County
0 Cocoa Brevard
0
0
0 Dania Broward
0
0
0 Tice Lee
0
0
0 Parrish Manatee
0
0
0 N/A Martin
0
0
0 Cutler Dade
0
0
Status 2-
SO, HO TSP (lbs/10
- 2.
2.
- - - 1.
1.
- - - 2.
2.
- - - 2.
2.
- - - 0.
0.
- - - 1.
1.
1.
Btu)
75
75
1
1
75
75
75 I/
75 I/
8
8
1
1
1
N°x
(lbs/10 Btu)
None
None
None
None
None
Hone
None
None
0.3
0.3
None
None
None
TSP
(lbs/10
i
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
T Averaging
Btu) Period
3 I/ 2 hrs.
3 I/
1 2 hrs.
1
3 I/ 2 hrs.
3 I/
3 I/ 2 hrs.
3 I/
1 2 hrs.
1
1 2 hrs.
1
1
Boiler Data
Bottom
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
Firing
Front
Front
Front
Front
Front
H/A
H/A
N/A
N/A
N/A
Tangential
Tangential
Tangential
Total 190.0 264.0
I/ Temporary SIP Change.- in effect until 7/25/81.
2/ No emissions standards for gas
0
O
o
30
O
30
m
o
-------
1979 Fuel Consumption
Estimated Actual 157s
[
1
1
\
1
I
I
1
[
i
1
1
j
1
j
ii
.1
lj
,j
'!
.1
i
'i
>:
i
)j
i
i
J
|
1
I
1
;j
-------
(9d)c
Ut i li ty/Powerplant Number
FLORIDA (Cont'd)
Florida Power & Light
Port Everglades 1
2
3
4
Total
Riviera 1A/1B
2
3
4
Total
Sanford 3
4
5
Total
Turkey Point 1
2
Total
(MW
225.
225.
402.
402.
1,254.
43.
75.
310.
310.
739.
156.
436.
436.
1,028.
402.
402.
804.
icy
)
0
0
0
0
0
7
0
4
4
5
0
0
0
0
0
0
0
(MW)
219.
219.
381.
381.
1,200.
43.
69.
237.
287.
686.
154.
382.
382.
918.
381.
381.
762.
City County
0 Ft .Lauderdale Broweret
0
0
0
0
0 Riviera Beach Palm Beach
0
0
0
0
0 Lake Monroe Volusia
0
0
0
0 . Miami Cade
0
0
SO, NO TSP (lbs/10"Btu)
- - - 2
2
2
2
- - ' - 1
1
1
1
- - - 2
2
2
- - - 1
1
.75
.75
.75
.75
.1
.1
.1
.1
.75
.75
.75
.1
.1
NO
(lbs/10 Btu)
None
None
None
None
None
None
None
None
None
None
None
None
None
TSP
(lbs/10
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
btu) Period
1 2 hrs.
1
1
1
1 2 hrs.
1
4 I/
4 V
3 2 hrs.
3
3
1 2 hrs.
1
Boil
Bottom
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
ti/A
N/A
N/A
N/A
N/A
-er Data
Fi ring
Front
Front
Front
Front
Front
Tangential
Front
Front
Front
Front
Front
Front
N/A
I/ Riviera Plant: temporary SIP change in effect until 7/25/81.
2/ No emissions standards for, gas.
O
Tl
o
o
3
TJ
O
3
5
m
O
-------
(9f)c
1979 Fuel Consumption
Estimated Actual 197.-
Control Equipment Coal
Unit Particulates SO. ..3
Ut ility/Powerplant Number Equip.
FLORIDA (Cont'd)
Florida Power & Light
Port Everglades 1 MC
2 MC
3 MC
4 MC
Riviera 1 MC
2 MC
3 MC
4 MC
San ford 3
4 MC
5 MC
Turkey Point 1 MC
2 MC
Ef f.
85
85
88
88
78
88
88
88
_
84
84
84
84
(%) Equip. Eff. (%) Tons /*lb.
.0 - -
.0
.0
.0 - -
.5
.0
.0 - -
.0 - -
_ _
.0
.0
.0 - -
.0 -
Oil
Gas
103 Btu Sul£'. ' 103
Suit. (%) Ash (%) Barrels /qal. ft) MCF
1,
1,
2,
2,
6,
1,
2,
2,
5,
2,
1,
4,
204
281
2'15
150
850
41
80
955
843
919
111
643
451
205
259
946
205
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
^
.0
2
2
8
5
148,700 1.1 19
1
1
11
11.
147,183 0.94 25
4
148,485 1.4 4
9
6
149,065 1.23 15
,289
,818
,920
,500
,527
,044
,649
,139
,326
,158
,021
,021
,614
,258
,872
.0
.0
.0
.0
.0
.0
.0
.0
^0
.0
.0
-
-
.0
.0
.0
.0
j
Emissions (10 Tonr,}
Btu/Ft.3 so2 NO TS;<
1,000 25.7 18.9 2.7
1,000 6.5 9.1 0.6
1,000 25.2 12.2 2.6
1,000 17.5 12.4 0.9
o
T1
o
o
3
-0
O
3)
m
o
-------
(9h)c
Unit
Ut i 1 i ty/Powerplant Number
FLORIDA (Cont'd)
Florida Power Corp.
Anclote 1
2
Total
Bartow 1
2
3
Total
Crystal River 1
2
Total
G. E. Turner 3
4
; Total
Higgins 1
2
3
. Total
Suwannee River , 1
2
3
'' Total .
(MW)
556
556
1112
128
128
239
495
440
524
964
79
82
161
46
46
46
138
40
37
75
152
.0
.0
.0
.0
.0
.0
.0
.5
.0
.5
.0
.0
.0
.0
.0
.0
.0
.0
.5
.0
.0
Capacity Location status 2
(MW) City County SO. NO
515
515
1030
114
119
.0 Tarpon Springs Pinellas X-P
.0
.0
.0 St. Petersburg Pinellas X-P
.0
215.0
448
383
450
833
72
77
149
40
42
42
124
34
33
80
147
.0
.0 Inglis Levy -
.0
.0
.0 Enterprise Pinellas X-P
.0
.0
.0 Oldsraar Pinellas X-P
.0
.0
.0
.0 Live Oak Suwannee - -
.0
.0
.0
NO
X :
TSP (lbs/10 Btu) (lbs/10 Btu)
2
2
2
2
2
.75
.75
.75
.75
.75
6.17-C/2.75-0
6.17-C/2.75-0
2
2
2
2
2
2
2
2
.75
.75
.75
.75
.75
.75
.75
.75
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
TSP
(lbs/10 Btu)
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
Averaging Boiler Data
Period Bottom Firing
2 hrs. M/A
1J/A
2 hrs. N/A
1J/A
11/A
2 hrs. N/A
N/A
2 hrs. N/A
N/A
2 hrs. N/A
N/A
N/A
2 hrs. N/A
N/A
N/A
Tangential
N/A
Front
Tangential
Tancential
Tangential
Tangential
Front
Opp. Wall
Front
Front
Tancential
Tancential
Front
Front
O
Tl
o
o
3D
TJ
O
30
I/ Uo emission standards for gas.
m
O
-------
(9j)c
19?y Fuel Consumption
1
Unit
Ut ility/Poworplant Number
FLORIDA (Cont'd)
Florida Power
1978 data: Anclote 1
2
1978 data: Bartow 1
2
3
1
1978 data: Crystal River 1
2
1978 data: G. E. Turner 3
, ' 4
il
|i
1978 data: Higgins 1
2
3.
(
1 1978 data: Suwannee River 1
: 2
! 3
Control Equipment Coal
Particulates SO, 1Q3 ' 1Q3
Oil
Suit. 3
Gas
Equip. Eft. (%) Equip. * E££. Ci) Tons /lb. Suit'. (%) Ash (I) barrels /gal. (%) iu ^r-p ULU/Ff
-
- - - 3933
- - - 1033
4966
- 841
- - - - 378
- - - - 2145
3365
ESP I/ - - 1.0 ' 2841
ESP I/ 1004.4 13
1005.4 11,271 2.0 2855
- - - - 195
- - - - 253
449
----- 215
- - - - 350
- 434
1000
- - - - 323
- 310
- - - - 432
1066
.2
.7
.9
.2
.5
.4
.1
.8
.2
.0
.4
.7
.1
.6
.4
.9
.9
.7
.4
.7
.8
147,788 1.3
6,478
617
148,952 2.3 7,095
149,195 2.14
3379
3039
148,121 2.2 6,469
863
235
_
148,875 2.26 1,099
306
195
1,812
148,042 1.6 2 314
.2
.5
.7 1,023
.7
.3'
.0 1,024
.9
.5
.4 1,024
.8
.2
.1
.1 1.025
EstirtMtoO Actual IT/'
. . 3
Emissions (10 Ton-}
SO NO ' TSi'
0.6 17.8 5.1
0.5 27.5 5.1
1.9 66.0 17.7
0.1 2.7 1.4
0.2 7.3 1.4
0.2 7.7 1 . a
|,| I/ Not available ftpm FPC Form 67.
1,1 ~~ . ' ,. /
O
Tl
o
o
33
"0
O
30
m
o
-------
Name
Unit
Utility/Powerplant Number
FLORIDA (Cont'd)
Fort Pierce Utility Authority
4
King 5
6
7
8
Total
Gainesville Regional Utilities
Deerhaven 1
Kelly 6
7
8
Total
Gulf Power Company
Crist 1
2
; 3
4
5
C
7
Total
Scholz . 1
'2
; ', Total
Sm i th 1
2
Total
ridue
Capacity
(MW)
5
8
18
37
56
116
83
14
23
45
82
28
28
38
94
94
"t~]n
J / U
578
1,230
49
49
98
150
190
340
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
. 0
.0
.0
.0
.0
.0
.0
.0
.0
Net
Currently Enforced Emissions Limits I/
Dependable County Attainment
Capacity . Location Status 2-
(MW) City County SO, NO TSP (lbs/10
5
8
17
35
56
113
81
14
23
44
81
21
22
32
84
84
324
487
1,054
48
48
96
159
186
345
.0
.0 Fort Pierce St. Lucie -
.0
.0
.0
.0
.0 Gainesville Alachua -
.0 Gainesville Alachua - - -
.0 -
.0
.0
.0 Pensacola Escambia - -
0
.0
.0
.0
n
.0
.0
.0 Chattahoochee Jackson -
.0
.0
.0 Panama City Bay
.0
.0
b
Btu)
NOX .
TSP
Averaging Boiler nat.-i
(lbs/10 btu) (lbs/10 Btu) Period Bottom Firina
i
Latest Tech. None
Latest Tech. None
Latest Tech. None.
Latest Tech. None
0.
2.
2.
2.
2.
1.
1.
1.
5.
5.
5.
5.
6.
6.
6.
6.
8
75
75
75
75
88
88
88
9
9
g
9
17
17
17
.17
0.3
None
None
None
None
None
None
None
None
s None
None
None
None
None
None
None
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1 .
.1
.1
.1
.1
.1
.1
2 hrs. N/A
N/A
N/A
H/A
N/A
2 hrs. N/A
2 hrs. H/A
N/A
N/A
2 hrs. H/A
N/A
N/A
Dry
Dry
Dry
2 hrs. Dry
Dry
2 hrs. Dry
Dry
Front
Front
Front
Front
Front
Front
Front
Front
Front
Front
Front
Front
Pulver izer
Pulver izer
Pul ve r i zer
Pulver i zer
Pu Iver izer
Pulverizer
Pulver i zer
Pulver izer
I/ No emissions standards for gas
O
Tl
z
o
o
3
s
m
O
-------
(9n)c
1979 Fuel Consumption
Estimated Actual 197.'
Control Equipment Coal '
Unit
Ut ility/Pouerplant Number
FLORIDA (Cont'd)
Fort Pierce utility Authority 4
King I/ 5
6
' 7
8
Gainesville Regional utilities
Deerhaven 1
Kelly 6
7
8
Gulf Power Company
Crist 1
2
3
4
5
6
7
*
Scholz 1
2
Smith 1'
2
Part iculates
Equip.
-
-
MC
MC
-
-
_
-
-
-
-
-
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
Eff. (%)
-
-
86.0
91.0
-
-
-
-
-
-
-
-
99.1
99.1
98.0
98.2
99.5
99.5
99.1
99.1
SO, 3
Equip. * Eff. (%) Tons "/lb. Sulf. (%) Ash (%)
. -
-
- -
-
-
-
-
-
-
- -
_
_
118.3
122.2
- . - 662.8
664.0
1,567.4 11,777 2.5 10.9
104.4
99.9
204.3 12,442 2.4 11.2
457.3
541.9
999.2 11,709 .0.7 12.7
9. Gas Emission? (10 Tons)
3 Sulf. 3
Barrels BtU /gal. (») 10 MCF Dtu/Ft. SO, NQ^ T::P
.
1
.2
13.0
I5-0 517.8
8*2 7 _ 4 flQ _ f)
36.4 14/,UOU l.U 2,926.8 1,028 2.3 1.4
260.0 151,593 2.2 4,878.9 1,028 1.9 2.0 0.1
-
5.7 324.5
47.0 2,123.7
52.8 151,593 2.2 2,448.2 1,030 3.6 2.3 0.1
3.7 146,429 1.5 7,272.8 1,000 78.4 1.4 2.2
1.0 1.8 0.1
1.4 9.0 O.V
I/ Consumption data not available for unit 4.
o
Tl
o
o
3
TJ
O
m
O
-------
Utllity/Powerplant
FLOKI DA (Cont'd)
Jacksonville Electric Auth.
J. D. Kennedy
Northside
Southside
Key West Utilities Board
Key West
Stock Island
Unit
Number
8
9
10
Total
1
2
3
Total
1
2
3
4
5
Total
1
2
3
4
5
Total
Name
Plate
Capacity
(MH)
50.
50.
150.
200.
298.
298.
563.
1,159.
38.
38.
50.
75.
157.
288.
6.
6.
18.
18.
20.
70.
0
0
0
0
0
0
7
7
0
0
0
0
0
0
3
2
7
8
0
0
Net
Dependable
Capacity Location
(MW) City County
43
43
130
216
262
262
518
1,042
27
29
46
70
144
316
6
6
18
18
20
70
.0 Jacksonville Duval
.0
.0
.0
.0 Jacksonville Duval
.0
.4
.4
.0 Jacksonville Duval
.0
.0
.0
.0
.0
.3 Key West Keys
.2
.7
.8
.0
.0
._ . ._ Currently Enforced Emissions Limits 2/
Status S02-
SO, NO TSP
-------
?i)c
Control Equipment Coal
Unit Particulates SO, 1Q3 Qtu
Ut ility/Pownrplant Number Equip. E£f. (%) Equip. Eff. (%) Tons /lb. Sul£. (
: FLORIDA (cont'ci)
Jacksonville Electric Authity
i L978 data: J.D. Kennedy 8
1 9
10 - - - -
L97B data: Northside 1 - - - -
2 - - - -
j 3 _---.-
\
i (.978 data: Southside 1 - - -
1 .'::::
5 -
,1
-------
Utiii ty/Powerplant
FLORIDA (Cont'd)
City of Lakeland
Dept. of Electricity & Water
Larsen
Mclntosh
Lake Worth Utilities Authority
Tom Smith
Orlando Utilities
Indian River
Lake Highland
City of Tallahassee
Hopkins
Purdom
unit
Number
9
10
11
12
Total
1
2
Total
r
S-l
S-2
S-3
S-4
Total
1
2
3
Total
1
2
3
Total
1
2
Total
2
3
4
' 5
6
7
Name
Plate
Capacity
(MW)
20.0
25.0
25.0
53.0
123.0
103.5
126.0
229.5
8.0
8.0
26.5
32.6
75.1
86.7
207.6
334.5
628.8
29.0
38.0
38.0
105.0
75.0
237.0
312.0
7.5
7.5
7.5
25.0
25.0
50.0
Net
Dependable County Attainment
Capacity Location Status
Currently Enforced Emissions
SO.,
'* r.
(MW) City County SO^ NO TSP Jibs/10 Utu)
.
19.0 Lakeland Polk -
24.0
25.0
49.0
117.0
89.0 Lakeland "Polk -
116.0
205.0
7.0 Lake Worth Palm Beach -
7.0
25.6
33.0
72.6
90.0 Titusville Brevard - -
207.0
336.0
633.0
30.0 Orlando Orange -
30.0
30.0
90.0
82.0 Tallahassee Leon -
238.0 -.
320.0
8.0 St. Harks ' Wakulla -
8.0
8.0
23.0
23.0
47.0 '
2.75
2.75
2.75
2.75
2.75
0.8
2.75
2.75
2.75
2.75
2.75
2.75
2.75
2.75
2.75
2.75
1.87
1.87
1.87
1.87
1.87
1.87
1.87
1.87
NO
x 6
Limits I/
TSP
fc
(lbs/10 Btu) (lbs/lu"l)tu)
1
None
None
None
None
None
0.3
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
Averayincj lioiler Dota
Period Bottom Firing
2 hrs. 11/A
11/A
11/A
N/A
2 hrs. N/A
N/A
2 hrs. N/A
N/A
N/A
11/A
2 hrs. N/A
N/A
N/A
2 hrs. N/A
H/A
N/A
2 hrs. N/A
N/A
2 hrs. N/A
N/A
N/A
N/A
N/A
N/A
Front
Tron t
Front
Front
Opp. Wall
Front
Front
Front
Front
Front
Tangential
Tangential
Tangential
Front
Front
Front
Front
N/A
Front
Front
Front
Tangential
Front
Front
Total
130.0
125.0
I/ No emissions standards for gas.
o
z
o
o
3D
0
O
DO
m
O
-------
(Svjc
1979 Fuel Consumption
Estimated Actual 1979
Ut ility/Powerplant
F1ORIDA (Cont *d)
| City of Lakeland
Dopt. of Electric &
Larsen
Mclntosh
'i
\
' Lake Worth Utilities
Tom Smith
Orlando Utilities
Indian River
Lake Highland
City of Tallahassee
Hopkins
i
Purdom
I/ Form 67 data
Control Equipment Coal
Unit Particulates SO. 3
Number Equip. Eff. (%) Equip. * Eff. (%) Tons U/lb. Sulf. (%) Ash (»
Water
9 _
10 - - - -
11 -
12 - - - -
1 -
2 - - -
Authority
S-l MC 90.0
'S-2 MC 90.0
S-3 MC 90.0
S-4 - - - -
1
2
3
1 <
. ; 2 ;,
' . 3
1 - - - -
2 - - -
2 - - - -
3 -
4 _ ' _
5 -
6 - - - -
7 -
shows that 2 kinds of oil were consumed, but does not specify quantities of each.
Oil
103 Btu SU1£-
) Barrels /gal. (»)
1.1
12.3
14.2
57.3
85.2 146,900 1.2
272.8
719.3
992.1 148,363 1.20
0.2
-
16.0
33.2
57.4 I/ 150.0UO 2.2
408.1
1,087.7
1,483.9
2,979.7 149,843 1.79
17.1
8.6
22.5
48.2 149,261 1.07
129.8
839.9
965.7 149,665 2.3
0.8
2.4
3.6
67.8
33.9
71.8
180.3 148,750 2.15
Gas
193 Btu 3
MCF /Ft.
9.3
868.0
630.4
1 ,910.4
3,412.8 1,0-27
3,849.4
-
3,849.4 1,027
13.8
480.0
757.0
1,247.1 1,028
1,496.0
1,321.1
8,707.3
11,524.4 1,028
831.1
419.1
859.3
2,159.5 1,028
2,372.5
5,233.2
7,605.8 1,042
-
1.7
19.2
118.3
677.6
1,814.3
2,495.0 1,042
3
SO, NO TS?
0.2 6.8 0
3.8 9.6 0.2
0.3 0.7
17.99 2.50 .24
.18 .04 .001
5.8 3.1 .18
1.03 3.4 .036
2/ Characteristics of oil not shown above were 140,000 BTU'/gallon and 1.5% sulfur content.
t
;
0
! Tl
z
0
o
3
o
O
3
H
m
O
r
-------
Unit
Utility/Powerplant Number
FLORIDA (Cont'd)
Taippa Electric Company
Big Bend 1
2
3
Total
Gannon 1
2
3
4
5
6
Total
Hooker's Point 1
2
3
4
5
Vero Beach Kun. Power Plant
Vero Beach 1
2
' 3
4
Total
Name
Plate
Capacity
(KW)
445
445
445
1,336
125
125
179
187
239
414
1,269
33
34
34
49
81
232
13
20
33
56
122
.5
.5
.5
.5
.0
.0
.0
.5
.4
.0
.9
.0
.5
.5
.0
.6
.6
.0
.0
.0
.0
.0
Net
Dependable ' County Attainment
Capacity Location ' Status
(KW) City County SO, NO TSP
338
338
338
1,014
83
108
140
169
214
338
1,052
27
28
28
44
66
193
13
17
33
53
116
.0 Ruskin Hillsborough - XX-P -
.0
.0
.0
.0 Tampa Hillsborough - XX-P
.0
.0
.0
.0
.0
.0
.0 Tampa Hillsborough - XX-P
.0
.0
.0
.0
.0
.0 Vero Beach Indian River - - -
.0
.0
.0
.0
Currently Enforced Emissions Limits 2/
SO,
NO TSP
Averaginq
(lbs/10 Btu) (lbs/10 Btu) (lbs/10 Btu) Period
6
6
6
1
1
1
1
2
2
1
1
1
1
1
.5/5.8 I/
.5/5.8
.5/5.8
.1
.1
.1
.1
.4
.4
.1
.1
.1
.1
.1
Latest
Tech.
2
0
.75
.8
1
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
0.3-0/0.2-g
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
.1 S02 - I/
2 hrs- ISP
. I i hrs .
.1
.1
.1
.1
.1
.1 2 hrs.
.1
.1
.1
.1
.1 2 hrs.
.1
.1
.1
Boiler Data
Bottom
Ket
wet
Ket
We t
we t
wet
wet
we t
We t
N/A
H/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
Fir inq
Fu Iver izer
Pulverizer
Pu Iver i zer
Cyclone
Cyclone
Cyclone
Cyclone
Pulverizer
Fu Ive r i zer
Front
Front
Front
Front
Tangential
Front
F ront
Front
Front
I/ 6.5 lbs../mmutu's 2',-hour-average maximum; S.8 Ibs ./mraBtu1 s 3 hour average. Meet 25.0 tons/hr. on 24 hour average with load curve.
2/ No emissions standards for gas.
i
o
z
o
o
3D
0
O
a
5
m
o
-------
(9z)c '
1979 Fuel Consumption
Estimated Actual 197-*
Control Equipment Coal Oil Gas 3
Unit
Ut ility/Powerplant Number
FLORIDA (Cont'd)
Tampa Electric Company
Big Bend 1
2
3
Gannon 1
2
3
4
5
6
Hooker ' s Point 1
2
j 3
4
5
6
Vero Beach Mun. Power Plant
Vero E^ach 1
2
I ' .3
j
Part iculates
Equip.
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
-
-
-
-
«
-
_
_
E£f. (%)
99.0
99.8
99.8
90.0
90.0
93.0
95.5
98.5
99.8
-
-
-
-
_
-
_
_
_
-, > Suit 1 umiaoiuns. liu iuni|
~ 10 DtU 10 BtU 3UJ.L. J
Equip. Eff. (%) Tons /lb. Suit. (%) Ash (%) Barrels /gal. (%) iu MCF /Ft. SO NO TOP
,
-
- -
- -
2,381.7 11,475 2.2 10.4 . 112-1 35_7 1-Q
-
-
3,437.4
-
-
- 1,348.4
1,309.4 12,174 1.3- 10.1 3,437.4 150,083 0.95 38_5 2T .2 0.9
1,148.0
- -
-
-
_ _
1,148.0 149,574 0.96 3.3 2.5 .19
- - " 15.0 147.0
33.0 310.0
102.0 560.0
_ '" _"""' 67.0 2,042.0
217.0 147,000 1.35 3,059.0 1,060 1.3 0.2 0.
o
Tl
z
o
o
3)
TJ
O
m
O
-------
(10)c
Nome
Plate
Unit Capacity
Utilitv/Poverplant Number IMWI
GEOHGIA
Georgia Power
Arkw right 1 45
2 45
3 46
4 45
Total 181
Atkinson 1 60
2 60
3 60
4 60
Total 240
Bowen i 700
2 700
3 880
4 830
Total 3,160
Net
Dependable
Capacity Location
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
Harllee Branch 1 299.2
I 2 359.0
1 3 544.0
ft 4 544.0
H Total 1,746.2
1
Harrmond f ' \ 125.0
, ' , ./ 2 125.0
3 125.0
*tt « 578.0
g| Total 963.0
KB McDonough 1 245.0
Hi 2 245.0
1
1
1
fa
$
jW
|
1
1
MJJ i
.&
Total 490.
McManus 1 40.
2 75.
Total 115.
Mitchell 1 27.
2 27.
3 163.
Total 218.
a/ Atkinson S02 limit given as 800.8 Ibs./hr.
b/ Mi;ManL:s Su2 limit given as 1876 Ibs./hr.
c/ Emissions LimitD apply to all fuels.
O
if
n
0
0
0
0
5
5
2
2
-
42
42
45
45
174
60
62
64
64
250
718
716
897
897
3,228
.0 Bibb Macon
.0
.0
.0
.0
.0 Smyrna Cobb
.0
.0
.0
.0
.0 Taylorsville Bartow
.0
.0
.0
.0
221.0 Milledgeville Putnam
300.0
481.0
466.0
1,468.0
108.5 Coosa Floyd
108.5
105.0
400.0
722
255.
255.
510.
50.
81.
131.
24.
24.
161.
209.
o ;
3 Smyrna Cobb
3
6
0 Atlanta Brunswick
0
0
0 Albany Dougherty
0
0
0
'-cunt- Attainment Currently Enforced Emissions Limits^/
Status 2
- - - 3
3
3
- - - 3
3
3
3
- - - 3
3
3
3
- - - 3
3
3
3
3
3
3
3
- - - 3
3
- - - 3
3
- - - 3
3
3
% S
* S
% S
» Sa/
% S
i S
% S
% E
% S
% S
t S
% S
% S
i S
% S
% S
% s
% s
% s
% s
% s
% sV
% s
% s
% s
% s
NO
(lbs/10 btu)'
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
TSP
(lbs/106Btu)
0
0
0
0
0
0
0
0
0
0
.24
.24
.24
.24
.23
.29
.29
.24
.24
.24
0.24
0.24
0.24
0.27
0.27'
0 27
0.27
0.24
0.24
0.26
0.26
0.
0.
0.
24
24
24
Averaging boiler Dot.-j
Period Bottom Firing
1 hr. Dry
Dry
Dry-
Dry
1 hr. . tl/A
N/A
iJ/A
N/A
1 hr Dry
Dry
Dry
Dry
1 hr. Dry
Dry
Dry
Dry
1 hr. Dry
Dry
Dry
Dry
1 hr. Wet
Wet
1 hr. N/A
N/A
i hr. Dry
Dry
Dry
-
Pu Iver i zer
Pulveri zer
Pu Iver i zer
Pulverizer
Front
Tangential
Tangential
Tangential
Pulver izer
Pulver izer
Pu Iver i zer
Pulveri zer
Pu Iver izer
Pulverizer
Pulver i zer
Pulver izer
Pu Iver i zer
Pulverizer
Pulver izer
Pulverizer
Pu Iver izer
Pulverizer
Front
Front
Fu Ivor i zer
Pulver izer
Pulver i zer
-
m
O
-------
JL9.79 Fuel Consumption
Estimator Ac tual 1979
Control Equipment Coal
Unit
Ut ill ty/Powerplant Number
i KG 1 A (Cont'd)
Georgia Power
Arkwright 1
2
3
4
Atkinson 1
2
3
4
.
Bowen 1
2
. 3
4
Harllee Branch 1
2
3
4
Hammond , ' 1
'! 2
'3
4
Mctonough 1
2
McManus . 1
2
Mitchell 1
2
3
Pa
Equip
ESP
ESP
ESP
ESP
_
-
-
-
ESP
ESP
ESP
ESP
ESP
ESP
ESP
' ESP
' ESP
, ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
r t iculates
Eff. (I)
99.0
99.0
99.0
99.0
_
-
-
-
98.0
98.0
99.0
99.0
98.5
98.5
98.5
98.3
98.7
98.0
98.0
98.4
99.0
99.0
98.0
98.0
99.0
99.0
99.0
SO. 3
Equip. ' Eff. (») Tons /lb. Suit. (*) Ash (»)
81.2
64.6
82.8
94.2
322.8 12,050 1.9 12.5
_
_
-
-
615.6
1,159.4
1,996.3
2,223.4
5,994.7 11,728 1.8 11.6
538.0
427.0
500.0
593.0
2,058.0 12,126 1.1 11.1
222.3
216.3
208.1
1,000.9
1,647.6 11,974 1.6 11.3
"458.5
' - 588.9
1,047.4 11,898 1.8 10.6
_
-
46.3
37.8
407.9
492.9 12,675 1.2 10.8
Oil Gas .
3 "lilt- T EllUSSl
-,,J ,_ OU± L . - J » '
10 Barrels Btu /gal. , (%, 10 HCF Btu/Ft.3 SO.
17.9 5.9
a. 6 ' 3.5
9.2 2.1
12.7 4.5
48.4 137,500 16.0 1,037 11.0
11.9 426.6
2.9 401.6
9.8 314.9
55.6 385.2
80.2 137,693 0.15 1,528.3 1,031
17.7
21.3
23.7
23.7
86.4 140,000 110.3
2.6
4.7
4.0
3.7
15.0 136,000 0.3 43.0
1.7
3.0
3.2
5.7
13.6 136,000 52.7
2.7 . 88.1
7.7 107.5
10.4 137,693 195.6 1,031 33.2
70.0
105.0
175.0 149,253 1.8
1.4
0.7
2.3 7.6
4.4 137,500 0.21
onn (10 Tons)
HO TSP
6.0 0.3
0.5
54.0 7.0
18.0 2.6
14.8 5.1
15.8 0.4
0.03
6.0 1.8
o
Tl
o
o
3)
o
O
m
-------
(10d)c
Utility/Powerplant
GEORGIA (Cont'd)
Georg ia Power
Wansley
Yates
Savannah Electric & Power
Effingham
Port Wentworth'
Riverside
Unit
Number
1
2
Total
1
2
3
4
5
6
7
Total
1
1
2
3
4
Total
10/6
11/7
12/8
Total
Name
Plate
Capa ' '
city
(MW)
952
952
1,914
122
122
122
156
156
403
403
1,487
163
50
54
103
126
333
21
21
38
80
.0
.0
.0
.5
.5
.5
.3
.3
.8
.8
.7
.0
.0
.0
.5
.0
.5
.1
.3
^2
.4
Net
Dependable
Capaci' " '
(MW)
870.
870.
1,740.
113.
113.
113.
140.
140.
357.
357.
1,336.
163.
47.
51.
98.
110.
308.
19.
23.
35_;
78.
.ty Location
City County
0 Roopville Heard
0
0
6 . Newnan Coweta
6
6
6
6
0
0
0
0 Rincon Effingham
7 Port Chatham
6 Wentworth
4
8
5
1 Savannah Chatham
9
8
8
n ^ Currently Enforced Emis:
County Attainment
Status 2
SO, NO TSP (lbs/10
- - - 3 »
3 %
- - 3 %
3 %
3 %
3 %
3 i
3 %
' 3 %
- - - 3 %
- - X 3 %
3 %
3 %
3 %
- - X 3 %
3 %
3 %
Btu)
S
S
S
S
S
S
S
S
S
S
si/
S
S
S
S.2/
S
S
NO
(lbs/10 Btu;
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
Averaging
Boiler Data
0.2
0.2
0.24
0.24
0.24
0.24
0.24
0.24
0.24
0.25
0.32
0.32
0.28
0.27
.342
.346
.326
1 hr.
1 hr.
1 hr.
Bottom
Wet
Wet
Dry
Dry
Dry
Dry
Dry
Dry
Dry
N/A
Wet
Wet
Wet
Dry
N/A
N/A
N/A
Firing
Pulverizer
Pulverizer
PuIve r i zer
Pulverizer
PuIverizer
Pulverizer
Pu1ver i zer
Pulverizer
Fulveri zer
N/A
Pulverizer
PuIver izer
Pulverizer
Tangential
Front
Tangential
Tangential
_!/ Port Wentworth Plant SO2 limit given as 6162 Ibs./hr.
2/ Riverside Plant SO2 limit given as 588 Ibs./hr.
3/ Emissions limits apply to all fuels.
o
in
z
o
o
jj
T)
O
m
O
-------
(10f)c
1979 Fuel Consumption
Control Equipment
Unit
Ut ili ty/Powerplant Number
GEORGIA (Cont'd)
Georg ia
Wans ley 1
2
Yates 1
2
3
4
5
6
7
Part iculates
Equip.
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
Eft.
99
99
98
98
98
98
98
99
99
(%)
.1
.1
.3
.3
.3
.3
.3
.0
.0
SO 3
. Equip. Eff. (%) To
2,205
2,348
4,551
221
234
224
221
356
848
757
2,888
Coal
Oil Gas i
ns Btu/lb. Sulf. (%) Ash (4) 10 Barrels 1tu /qal. (%) 10 MCF
.0
.0
.0 11,111 1.9 9.5
.0
.0
.0
.0
.0
.0
.0
.0 11,715 1.8 12.7
23
20
46
2
1
2
2
1
3
3
19
*
0
.0
.0 137,500 0.1
.8
.8
.9
.3
.8
.5
.7
.0 137,500 0.3
uniasions 111) '!'..
DtU/Ft.3 SO^ HO
172.9 68.3 3
82.0 44.0 3
Savannah Electric S
Ef Eingham
Port Nentworth '
Riverside
1 1982:ESP
10/6
* 12/8
ESP
ESP
ESP
99.5
99.5
99.5
99.5
110.4
139.7
84.6
343.7
12,489
.93
9.05
1,085.3
708.7
708.7
0.4
53.6
46.4
100.5
147,732
147,153
146,791
2.8
1.95
172.9
228.9
93.1
255.9
724.7
112.2
607.2
188.7
' 1-5 908.0
1,139
1,131
3.19 5.16
5.1 2.4
2.56 .22
o
Tl
z
o
o
O
a
m
o
-------
utility/Powerplant
ILLINOIS
Central Illinois Light Corp.
Duck Creek
Wallace
Central Illinois Public Ser.
Coffeen
Grand Tower!/
Hutson.ville
Unit
Number
1
1
2
3
Total
3
4
5
6
7
Total
1
2
Total
7
8 >
9
Total
'l
>2
3
,4
'5
6
Total
Name
Plate
Capacity
(MW)
417.0
136.0
280.0
364.0
780.0
25.0
40.0
40.0
86.0
114.0
300.0
389.0
617.0
1006.0
199.7
. 25.0
25.0
75.0
75.0
200.0
Net
Dependable Countj
Capaci
(MW)
390.
131.
267.
358.
756.
32.
47.
49.
37.
106.
271.
360.
580.
940.
190.
29.
29.
74.
75.
207.
ty Liocacion
City County SO
2
0 Canton . Fulton
0 Bartonville Peoria X-P
0
0
0
0 East Peoria Tazewell X-P
0
0
0
0
0
0 Coffeen Montgomery -
0
0
Grand Tower Jackson - -
0
Hutsonville Crawford -
0
0
0
0
0
. t. . t Currently Enforced Emissions
t Attainment
so.
' c
NO TSP (lbs/10uBtu)
X
0
X-P 0
0
0
X-P 0
0
0
0
0
0
0
- 0
0
0
- 0
0
0
0
0
0
.8-0/1.
.3-0/1.
.3-0/1.
.3-0/1.
.3-0/1.
.3-0/1.
.3-0/1.
.3-0/1.
.3-0/1.
.3-0/5.
.3-0/5.
.3-0/6.
.3-0/6.
.3-0/6.
.3*
.3
.3
.3
.3-0/5.
.3-0/5.
2-C
8-C
8-C
8-C
8-C
8-C
8-C
8-C
8-C
81-C
81-C
0-C
0-C
0-C
1-C
,1-C
NO..
6
(lbs/10 Btu)
0. 3-0/0. 7-C
0.3-0/0. 9-C
0.3-0/0. 9-C
0.3-0/0. 9-C
0.3-0/0. 9-C
0.3-0/0. 9-C
0.3-0/0. 9-C
0.3-0/0. 9-C
0.3-g/0.9-C
None
None
None
None
None
None
None
None
None
None
None
Limits I/
TSP
1 (lbs/10"Btu) Period
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
1 0/C 1 hr.
1-0/0. 2-C l hr.
1-O/0.15-C
1-0/0. 1-C
1 0/C 1 hc.
1 0/C
1 O/C
1 0/C
1 0/C
1-0/0. 2-C l hr
1-0/0. 2-C
1-0/0. 2-C 1 hr.
1-0/0. 2-C
1-0/0. 2-C
1 1 hr.
1
1
1
1-0/0. 2-C
0.1-O/0.2-C
Bo i 1 "~ n~ *" ~
L e L u
-------
(12b)c
1979 Fuel Consumption
Control Equipment Coal Oil Gas
Unit particulates SO, 3 3 bull:. ...3
Utility/Powerplant Number Equip. Eff. (4) Equip. * E£f. (*) Tons /lb. Suit. (4) Ash (%) Barrels /gal. (4) MCF /Ft.
ILLINOIS (Cont.)
Central Illinois Light Comp.
Duck Creek 1 ESP 99.0 LS 91% 972.5 10,509 3.27 9.01 8.1 137,760 0.19
Edwards 1 ESP 97.0 - - 276.3 2.1
2 ESP 99.0 - - 461.6 9.1
,1 . 3 ESP 99.0 - - 530.1 5.9 Not
! 1,268.0 9,827 0.6 10.8 17.1 140 , 000 lest .). Avail.
Central Illinois Light Comp.
Wallace 3 - - -
4 .... -
5 -
' . ' 6 ESP 96.0 - - 44.8 222.4
7 ESP 97.0 - - 92.1 0.1 375.5 '
136.9 13,105 0.71 6.21 0.1 135,950 0.15 597.8 1,000
I
j Central Illinois Public Ser.
" Cofteen ! 1 ESP 99.0 - - 719.1 10.0
2 ESP 99.0 - - 1,542.8 11.1
2,261.8 9,263 3.7 19.4 21.1 136,663 0.2
,
' Grand Tower 7 ESP 97.1 - - 188.2 2.4
J 8 " ESP 97.1
] 9 ESP 97.1 - - 264.3 . 1.6
" . ' ' 452.5 10,882 2.9 11.8 4.0 137,899 0.2
jj Hutsonvillo , '' ^ 1 , - - - - - '
; 2 - -
3 . - - - - 6.6
4 ------ j
! 5 ESP 97.5 - - - 219.7 V 2.5
! 6 ESP 97.5 - - 175.2 . 4.7
394.9 10,896 1.9 10.4 13.8 136,946 0.2
j '
! o
n
i z
0
o
3J
o
O
3J
m
O
Emissions (10 Tons)
SO, NO TS?
8.45 7.15 .15
14.45 11.41 1.47
1.85 1.23 0.18
159.0 62.2 2.6
24.9 4.0 0.9
14.3 3.5 0.7
-------
U2d)c.l
Ut i1i ty/Powe rpla nt
ILLINOIS (Cont.)
Central Illinois Public Ser.
Meredosia
Unit
.Number
1-2
3-4
5
6
Total
Name Net
Plate Dependable
Capacity Capacity
(MM) (KM)
City
Currently Enforced Emissions Limits
BO, NO TSP
* 6 6 6 'Averaging
County SO NO TSP (lbs/10 Btu) (lbs/10 Btu) i (lbs/10 Btu) Period
County Attainment
Status
58.0
58.0
239.0
200.0
555.0
617.4
58.0
58.0
239.0
190.0
545.0
550.0
Meredosia
Newton
Morgan
Jasper
1.0-O/5.2-C
1.0-0/5.2-C
1.0-0/5.2-C
1.0
None
None
None
None
0.8-0/1.2-C 0.3-0/0.7-C
0.1-0/0.2-C
0.1-0/0.2-C
0.1-0/0.2-C
0.1
0.1 0/C
1 hr.
1 hr.
Boiler Data
Bottom
Dry
Dry
Dry
Dry
Dry
Fi ring
PuIveri zer
Pulver izer
Pulverizer
Pulverizer
Pulverizer
o
TI
o
o
3>
-0
O
3
m
o
-------
U2C)c
1979 Fuel Consumption
Ut illty/Powerplant
Est imat<;il Actual 197)
Control Equipment Coal ^U ^^ Gas Emissions (logons)
Unit Particulates SO 3 3 Sulf. ^3
Number Equip. Eff. (%) Equip. Eff. (%) Tons /lb. Sulf. (%) Ash (%) barrels " /yal. (%) MCF /Ft. SO _ NO TSP
1ILIHOIS (Cont.)
Central Illinois Public Ser.
Meredosia 1-2 ESP
3-4 ESP
98.0
98.0
ESP 97.0
99.5
208.1
442.4
10.6
5.0
355.5
650.5 10,914 2.8 6.9 371.1 148,239 0.57
95.0 1,415.3 11,039 2.6 13.2 21.2 137,997 0.2
34.6 5.8 0.9
7.0 12.7 0.6
V Boilers 1 s 2 and boilers 3 S 4 each have an ESP, with 98% removal efficiencies on all four ESP's.
o
Tl
z
o
o
3
TJ
O
m
-------
(12h)c
Un i t
Utility/Powerplant Number
ILLINOIS (Cont.)
Commonwealth Edison
Collins 1
2
3
4
5
Crawford 7
8
Fisk 19
Joilet 6
7
8
KincaidV 1
2
Powortoni/ . 51-52
61-62
.: - '
Ri'Jgeland 1
2
3
4
5
6
riate
Capac " """
:ity
(MW)
545.
545.
519.
520.
520.
2,649.
239.
358.
597.
374.
360.
660.
660.
1,680.
659.
659.
1,319.
893.
893.
1,786.
173.
173.
173.
173.
692.
0
0
0
0
0
0
0
0
0
0
0
0
0
0
7
7
4
0
0
0
0
0
0
0
0
uepenciQDjLe
Capac"""" r "" "
iL,y LAJ<; a L, 1 ui I
(MW) City County
510
510
500
505
505
2,530
219
319
538
336
330
533
533
1,396
606
606
1,212
850
850
1,700
157
152
137
136
852
.0 Morris Grundy
.0
.0
.0
.0
.0
.0 Chicago Cook
.0
.0
.0 Chicago Cook
.0 Joilet Will
.0
.0
.0
.0 Kincaid Christian
.0
.0
.0 Pekin Tazewell
.0
.0
.0 Stickney Cook
.0
.0 .
.0
0
Bouncy rtccaininenc
-1-111= B07
NO
X r
SO NO TSP (lbs/10 Btu) (lbs/10°Btu)
2 x
- - - 0.8
0.8
O.B
0.8
0.8
X-P - 1.8 Coal 0.
1.8 Coal 0.
X-P - 1.8 Coal 0.
1.8 Coal 0.
0.3-0/1. 8-C 0.
0.3-O/1.8-C 0.
- - X-P 105,162 #S02/hr.
(8.06)
X-P 1.0-0/1. 8-C
1.0-0/1. 8-C
X-P - 1.0 oil 0.3
1.0 oil 0.3
1.0 oil 0.3
1.0 oil 0.3
1.0 oil 0.3
1.0 oil 0.3
0.3
0.3
0.3
0.3
0.3
3-G/0.9-C
3-G/0.9-C
3-G/0.9-C
3-G/0.9-C
3-G/0.9-C
3-G/0.9-C
None
None
None
None
oil/gas
oil/gas
oil/gas
oil/gas
oil/gas
oil/gas
TSP
(lbs/10 litu) Period
0.1
0.1
0.1
0.1
0.1
0.1 Coal 1 hr.
0.1 Coal
0.1 Coal .1 hr.
.18 Coal i hr.
O.l-O/ .18-C
0.1-0/.18-C
0.1-O/0.3-C 1 hr.
0. 1-0/0. 3-C
0.1 1 hr.
0.1
0.1 oil ' 1 hr.
0.1 oil
0.1 oil
0.1 oil
0.1 oil
0.1 oil
.
BO ] ' ~ ~ r%~ .- .,
. .LCI UU I.CJ
Bottom Firing
N/A
N/A
N/'A
H/A
N/A
Dry
Dry
Dry
Dry
Dry
Dry
Wet
Ket
Wet
Ket
Wet
Wet
Wet
We t
Wet
Wet
N/A
I!/ A
H/A
ll/A
tl/A
Pulverizer
t'ul vo r i zer
Pulverizer
Pulverizer
Pulver i zer
Pulverizer
Cyclone
Cyclone
Cyclone
Cyclone
Cycl/Front
Cycl/Front
Cvcl/Front
Cycl/Front
Cycl/Front
Cycl/Front
I/ SC>2 limit is for whole plant, and applies to coal burned. Oil S02 limit is 0.1 Ibs./mmBtu.
2/ All four boilers listed are wet cyclones.
O
Tl
o
o
33
-o
O
3J
9
o
-------
1979 Fuel Consumption
Estimated Actual 1979
Utility/Power pi ant
,L!HOIS (Cont.)
Cuinrconwealth Edison
Collins
-
Crawford .
Fi skV
I
i Joiletl/
1
Kincaid '
j Power tool/
1
j
Ridgeland
j
I
' Fisk boiler »19 associated
' Consumption data for units
' All four boilers have ESP1
' Source: Cost G. Quality of
O
n
z
O
O
3
TJ
O
1 3
§
O
Control Equipment Coal Oil Gas
Unit Particulates SO, 3 3 Sulf. 3, _, ,
Number Equip. Eff. (%) Equip. Eff. (%) Tons /lb. Sulf. (%) Ash (») Barrels /gal, (%) MCF /Ft.
1 - 1,911.2
2 - - - - 1,537.1
3 - - 2,193.6
4 - - 1,621.0
5 - - 1,216.9
8,479.8 146,986 0.60
7 ESP 99.0 - - 393.0 2,603.5
8 ESP 98.0 - - 466.0 1,934.3
859.0 9,285 .54 5.46 4,537.8 1,025
19 ESP 98.5 - - 560.0 9,436 .48 4.53 3,791.9 1,026
6 ESP 98.0 - - 367.0 - 149.1
7 ESP 3,380.0 214.4
8 ESP - 2.1
3,747.0 9,432 0.5 4.9 214.4 138,220 0.22 152.0 1,027
1 ESP 98.0 - - 1,461.0 10.1 4.2
2 ESP . 98.0 - - 787.0 8.0 5.9
2,248.0 10,147 3.53 10.33 18.1 137,825 0.5 10.1 986.0
51-52 ESP 99.5 LS 84.0 1,383.0 13.7 24.8
61-62' ESP 99.5 1,859.0 26.4 101.4
' 3,242.0 9,763 1.31 7.19 40.1 136,837 0.26i/ 126.2 1,000
1 . ESP 98.0 - '- 895.0 3,515.3
2 ' ESP 98.0 i
3 ESP 98.0 - 980.0 3,530.4
4 ESP 98.0
5 ESP 98.0 - . - 485.6 " 2,368.7
6 ESP 98.0 - ' - 366.5 2.886.6
2,655.1 149,187 .92 12,300.4 1,003
with turbines t!9 & 20.
7 i 8 from Cost £ Quality of Fuels for Electric Utility Plants - 1979.
5 with removal efficiencies of 99.5. Only boiler 5J. has a Lime Scrubber.
Fuels for Electric Utility Plants - 1979.
'
liSnissions (10 Tons)
SO »O TSP
17.03 7.79 -87
10.41 7.27 7.93
5.56 4.43 .30
4.5 4.9 0.1
158.77 32.0 1.27
82.81 44.62 .22
7.91 10.14 .15
-------
U21)c
Utility/Powerplant
ILI.T11OIS (Cont.)
Commonwealth Edison (cont.)
Waukegan
Will Cnunty
Electric Energy,
Joppa
Unit
Number
6
7
8
Total
1
2
3
4
Total
1
2
3
4
5
6
Name
Plate
Capacity
(MW)
121
326
355
802
188
184
299
598
1,269
183
183
183
183
183
183
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
Net
Dependable
Capacity Location
(MW) . City County
88
328
358
774
139
161
251
510
1,061
167
167
167
167
167
167
.0 Waukegan Lake
.0
.0
.0
.0 Joliet Will
.0
.0
.0
.0
.0 Joppa Massac
.0
.0
.0
.0
.0
_ . Currently Enforced Emissions
Status
SO,
SO, NO TSP (lbs/10u
XX-P 0.
0.
0.
X-P 0.
0.
0.
0.
XX-P 0.
0.
0.
0.
0.
0.
3-0/1
3-0/1
3-0/1
3-0/1
3-0/1
3-0/1
3-0/1
3-0/3
3-0/3
3-0/3
3-0/3
3-0/3
3-0/3
Btu)
.8-C
.8-C
.8-C
.8-C
.8-C
.8-C
.8-C
.61-C
.61-C
.61-C
.61-C
.61-C
.61-C
NO
(lbs/10 Btu),
0. 3-0/0. 9-C
0.3-O/0.9-C '
0.3-0/0. 9-C
0.3-0/0. 9-C
0.3-0/0. 9-C
0.3-0/0. 9-C
0.3-O/0.9-C
None
None
None
None
None
None
Limits
TSP
(lbs/10DBtU) ^JLJ
0
0
0
0
0
0
0
0
0
0
0
0
0
.1 oiVcoal 1 hr.
.1 oil/ coal
. 1-0/0. 12-C
.1 oil/coal 1 hr.
.1 oil/ coal
.1 oil/ coal
.l-O/O. 16-C
.1-0/0.2-C 1 hr.
. 1-0/0. 2-C
.l-O/O. 2-C
.l-O/O. 2-C
.1-0/0.2-C
.l-O/O. 2-C
We t CycLone
Wet
Wet
Wet
Wet
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Pulverizer
Pulverizer
Cyclone
Cyclone
Pulverizer
Pulverizer
Pulverizer
Pu Iver i zer
Pulvec izer
Pulver izer
Pulverizer
Pulver izer
Total 1,098.0
1,002.0
o
Tl
o
o
3
T)
O
3
9
o
-------
(12n)c
1979 Fuel Consumption
Estimated Actual 1'J7'J
Control Equipment Coal
Unit Particulates
Utility/Powerplant Number Equip.
ILLINOIS (Cont.)
Commonwealth Edison (cont.)
Waukegan 6 ESP
7 ESP
8 ESP
Will County 1 ESP/Vent.
2 ESP
3 ESP
4 ESP
Electric Energy, 'Inc.
Joppa 1 ESP
2 ESP
3 ESP
4 ESP
; s ESP
6 - ESP
Eff. (%)
98.0
98.0
98.0
76.0/98.0
99.0
98.5
98.0
98.6
98.6
98.6
98.6
98.6
98.6
Equip. ' Eff. (%J *" Tons """/Ib. Suit. (%) Ash_l»J *'
190.0
787.0
809.0
1,786.0 9,449.0 0.52 8.37
LSS/Vent. 81.0/76.0 145.0
437.0
656.0
1,339.0
2,577.0 9,208.0 0.5 4.88
495.7
456.5
439.0
508.3
477.4
534.0
2,911.0 11,577.0 2.1 10.1
Oil Gas
^Barrels "tu /«,.!. * m ' ^MCF
4.4
37.1
16.0
57.5 138,156 0.5
2.9
5.5
16.3
43.8
68.5 138,071 0.5
3.1
3.0
3.2
3.4
3.5
2.6
18.7 137,368 0.251/
3.
UtU/Ft.3 SO NO TSP
18.78 13.46 2.20
25.98 21.81 1.44
121.7 26.2 2.7
I/ Source:- Cost & Quality of Fuels for Electric Utility Plants - 1979.
0
0
3D
m
0
-------
(12p)c
Utility/Powerplant Number (MW) (MW) City County SO, NO TSP (lbs/106Btu) (lbs/106Btu) (lbs/106Btuj Period
ILLINOIS (Cont.)
Illinois Power
Baldwin 1 623.0 605.0 Baldwin Randolph - 0.3-O/6.0-C None 0.1-O/0.2-C 1 hr.
2 634.5 605.0 0. 3-0/6. 0-C None' 0.1-O/0.2-C
3 634.5 605.0 0.3-O/6.0-C None O.l-O/0 .1-C.
Total 1,892.0 1,815.0
HavanaV 1-8 230.0 260.0 Havana Mason - - 1.0 oiVcoal None 0.1-oiVcoal 1 hr.
Total 680.0 710.0
Hennepin 1 75.0 76.0 Hennepin Putnam - - XX-P 5.77 coal None 0.1 coal 1 hr.
2 231.0 235.0 5.77 coal Hnno n.l <-r,a 1
Total 306.3 311.0
Vermilion 1 73.5 77.0 Oakwood Vermilion - 0.3-O/6.0-C None 0.1-O/0.2-C 1 hr.
181.7 186.0
V Units 1-8 associated with turbines 1-5, unit 9 associated with turbine 6.
4
c5
n
o
o
3 ... - .
TJ
§ -'
9 '
o
Boiler Data
Bottom Firing
Wet Cyclone
Wet Cyclone
Dry Tangential
Dry Pulver izer
Dry Pulver i zer
-------
(12c)c
1979 Fuel Consumption
Control Equipment Coal
Unit
Ut ill ty/Powerplant Number
ILLINOIS (Cont.)
Illinois Power
Baldwin 1
2
3
Havana 1-8
9
Hennepin 1
2
Vermilion 1
2
Part iculates
Equip.
ESP
ESP
ESP
MC
ESP
ESP
ESP
ESP
ESP
Ef £.
99
99
99
15
99
99
99
99
99
(%)
.0
.0
.5
.0
.5
.5
.0
.5
.5
qO T
Equip. ' Eff. 1%) " Tons '"'"/Ib. Sulf. (*) Ash (%) J
1,665.0
1,883.0
1,612.3
5,160.3 10,547 3.0 11.0
_
426.6
426.6 12,658 0.5 6.2
180.0
582.5
762.5 10,965 2.6 10.4
213.6
272.9
486.5 10,573 2.94 13.4 .
LO3
Barrels
2.
1.
29.
33.
568.
40.
609.
0.
0.
1.
4
2
7
2
9
1
0
8
7
5
Oil Gas
" If 3 DlUi!.
BWA,ai. m' ' IO«CP Btum.3 so.
Not
140,000 Avail. 294.1
148,430 0.9 5.7
241.4
614.9
856.3 1,028 37.4
139,394 0.25 27.2
Estimated Actual 197.
Emissions (10 Ton-.',
NO
5.2 0.3
6.9 1.3
o
Tl
I
3
TJ
O
3J
9
o
-------
(12t)c
Utility/Powerplant
Name Net
Plate Dependable
Unit Capacity Capacity
Number (MM) (HW)
Location
City
County
County Attainment
Status
SO
NO
TSP
Currently Enforced Emissions Limits
SO_ NO TSP
(lbs/106Btu) (lbs/106Btu) (lbs/106Btu)
Averag ing
Period
Boiler Data
ILLINOIS (Cont.)
Illinois Power {cont.}
Wood River
1-3 350.0 150.0
Total
112.5
387.6
650.1
150.0
103.0
398.0
651.0
East Alton
Madison
X-P 0.30 oil 0.3 oil/gas 0.1 oil
0.3-0/1.80-C 0.3-0,G/0.9-C 0.1 oil/coal
0.3-0/1.80-C 0.3-0/0.9-C 0.l-O/O.184-C
hr.
DrV
Dry
Pulverizer
Pulverizer
Iowa-Illinois Gas & Electric
Mo1 in?
15.0
25.0
25.0
65.0
20.1
25.9
26.4
72.4
Moline
Rock Island
0.3 oil
0.3 oil
0.3 oil
None
None
None
0.1 oil
0.1 oil
0.1 oil
1 hr.
Dry
Dry
Dry
M/A
H/A
N/A
o
-n
o
o
3
0
O
DO
m
o
-------
(12v)c
Control Equipment
Coal
1979 Fuel Consumption
Oil
Unit
Particulates
Ut illty/Powerplant
ILLINOIS (Cont.)
Illinois Power (cont.)
Wood River
10 ' Btu
*"
Bt"
' 10 Bt"3
Estimated Actual I'-1'!
Emissions (10 Tor..-.)
Number Equip. Eff. (%) Equip. Eff. (%) Tons ' /lb. Suit. (%) Ash U) Barrels Xgal. (%) HCF /Ft. _§22-
1-3 MC 15.0
4 ESP/MC 99.7/90.0
5 ESP 99.0
151.5
742.8
Iowa-Illinois Gas & Electric
Molinej/ 5
6
7
Not Available
Not Available
Not Available
158.4
2.9
12.9
446.5
3.4
894.3 10,923.0 0.6 9.8 174.1 139,390 0.25 449.9
1,033 10.5 8.4 O.b
137,385 0.01 2,316.0 1,028 Not Available
V Fuel consumption data from Cost and Duality of Fuels for Electric Utility Plants - 1979.
o
Tl
2
O
O
33
0
O
30
m
O
-------
(12x)c
Unit
Util i ty/Powerplant Number
ILLINOIS (Cont.)
Southern Illinois Power Coop.
Marion 1
2
3
4
Name
Plate
Capacity
(MW)
33.0
33.0
33.0
173.0
Net
Dependable
Capacity Lo
(MW) City
37
37
37
173
.0 Marion
.0
.0
.0
County SO NO TSP (:
2 x
Williamson - - XX-P 0
0
0
0
Currently Enforced Emissions Limits
SO
6
Lbs/10 BtuJ
.3-0/6
.3-0/6
.3-0/6
.3-0/1
,0-C
.0-C
.0-C
.2-C
NO
(lbs/106Btu)
None .
None
None
0. 3-0/0. 7-C
TSP
(lbS/106
0 . 1-0/0
0 . l-O/O
0.1-0/0
0.1 0/C
, Averaging
Btu) Period
.2-C 1 hr
.2-C
.2-C
Boiler Data
Bottom Firing
Wet
Ket
Wet
Wet
Cyclone
Cyclone
Cyclone
Cyclone
City of Springfield
Dallman
Lakeside?./
Total
272.0
1 90.0
2 90.0
3 192.0
Total 372.0
2-4
5
6
7
8
Total 156.0
284.0
87.0 Springfield Sangamon
87.0
180.0
354.0
Springfield Sangamon
151.0
0
0
0
.3-0/6. 0-C
.3-O/6. 0-C
.3-0/6. 0-C
None
0.3 Oil
6.0 coal
6.0 coal
6.0 coal
None
None
None
None
None
None
None
None
0.1-0/C 1 hr.
0.1 -0/C
0 . 1-0/C
None 1 hr.
0.1 oil
0.1 coal
0.1 coal
0.1 coal
Ket
Wet
Wet
N/A
Dry
Dry
Wet
Ket
Cyclone
Cyclone
Pulverizer
Front
Pulver i zer
Pulverizer
Cyclone
Cyclone
I/ Unit 4 capacity data from FERC form 67.
2/ Lakeside boilers 2-8. associated with turbines 1(10 MW), 2 (15MW) , 3(15 MW) , 4(20 MW) , 5(20 MW), 6(38 MW) , 7(38 MW) .
o
Tl
z
o
o
3
-o
O
3D
m
o
-------
(12z)c
1979 Fuel Consumption
Control Equipment
Unit
Ut ility/Powerplant Number
ILLINOIS (Cont.)
Southern Illinois Power Corp.
Marion 1
2
3
4
City of Springfield
Dallgian 1
2
3
Lakeside 2-4
5
6
7
: s
Particulates SO, , «3
Equip.
MC/ESP
MC/ESP
MC/ESP
ESP
MC/ESP
ESP
ESP
_
MC/ESP
MC/ESP
ESP
ESP
Eff.
69
69
69
99
82
97
99
«
70
70
97
97
(%) Equip.
.0/96.0
.0/96.0
.0/96.0
.6 LSS
.8/95.0
.5
.5 LS
_
.0/97.5
.0/97.5
.5
.5
* Eff. (%) *" To
83
79
88
89.4 459
711
237
206
95.0 282
725
_
1
1
66
66
Coal
Oil Gas
ns Btu/lb. Sulf. (%) Ash (%) Barrels Bt" /gal. (*) ' 10 MCF Btu/Ft.3
.8
.2
.6
.8
;3 10,224 3.13 15.63
.1
.7
.0
.8 10,659 3.3 10.1
.9
.5
.2
.1
0.
0.
0.
1.
2.
26.
3.
-
-
-
4
5
6
1
6 138,615 0.36
.8 136,000 0.2
,1
Kr.timated Actual 1'iTi
Emissions (10 Tor,:;)
SO.
NO
135.7 10,559 3.2
10.0
9.2 136,000 0.2
21.22 7.27 0.17
3.73 0.2
45.5 16.4 0.73
o
o
o
3
-0
O
3
m
o
-------
(12z.2)c
Ut i I ity/Powecplant
ILLINOIS (Cont.)
Union Electric
Venice 12
University of Illinois
AbbottV
Unit
Number
Western Illinois Power Coop.
Pearl
Total
Total
Name
Plate
Capa ' '
cicy
(MN)
40
40
98
98
98
100
474
3
3
3
3
3
8
8
31
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
Net
Dependable
Capac ' ^ "
icy Location
(MW) City County
42
42
94
94
94
94
460
3
3
2
3
3
7
7
29
.0 Venice Madison
.0
.0
.0
.0
.0
.0
.0 Champaign Champaign
.0
.6
.0
.0
.5
.5
.6
. . Currently Emforced Emissions Limits
County Attainment
so.
'
(lbs/10uBtu)
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
oil
oil
oil
oil
oil
oil
oil
oil
oil
oil
oil
oil
oil
Averaging Boil " '
Period Bottom
1 hr. Dry
Dry
Dry
Dry
Dry
Dry
1 hr. N/A
N/A
N/A
IJ/A
Dry
Dry
Dry
er Lfca ta
Firing
N/A
N/A
N/A
N/A
N/A
N/A
N/A
Front
Front
Front
N/A
II/A
N/A
27.0
22.0
Pleasant Hill
Pike
0.3-0/6.0-C
0.1 oil/coal 1 hr.
N/A
N/A
V Only capacity data available for unit 1.
2/ SO2 limit changes to 6.8 ibs./mmBtu in 1983.
o
Tl
o
o
3
s
a
m
o
-------
(12z.4)c
1979 Fuel Consumption
Estimated Actual 197V
Utility/ Powerplant
ILLINOIS (Cont.)
^ Union Electr ic
Venice 12
University ot Illinois
Abbott!/
Unit
Number
1
2
3
4
5
6
2
3
4
5
6
7
Control Equipment Coal
Particulates SO 3
Equip. E£f. (%) Equip. Eff. (%) Tons /lb. Sulf. (%) Ash (%
_ _
- -
- -
_ _
_
-
- -
_
BH/MC 99.5/97.0
BH/MC 99.5/92.0
BH/MC 99.5/93.1
Oil
3 Sulf. 3
10 Btu -10
J Barrels /pal. (%) MCF
20
25
39
41
38
35
201
90
4
61
20
78
134
.2
.0
.9
.8
.9
.7
.6
.5
.9
.7
.0
.1
.5
75.
87.
320.
220.
192.
139.
137,636 0.27 1,030.
48,
3,
67.
-
-
-
Gas Emissions (10 Tons)
BtU/Ft.3 SO, NO TS?
6
2
6
1
4
7
6 1,035 0.16 0.4 0.01
.3
.7
.0
Western Illinois Power Coop.
Pearl!/ ' 1
57.2 11,262
2.97 Not Avail.
138,760 0.19
137,289 0.7
1,000 0.36 0.93 0.03
Hot Available
I/ Units 5, 6, 7 switching to coal/adding baghouses by 1983.
o
Tl
z
o
o
a
-o
o
3
m
O
-------
(13) C.I
CurrentlyEnforced Emissions Limits'
Unit
Ut il i ty/Powerplant Number
INDIANA
Commonwealth Edison of Ind.
State Line 3
4
Total
Crawfordsville Municipal
Crawfordsville 4
5
Total
Hoosier Energy Division
Ratts 1
2
Total
Capacity
(MH)
225
389
614
12
13
25
116
116
232
.0
.0
.0
.0
.0
.0
.0
.0
.0
Capacity Location Status
SO
(KW) City County SO. NO TSP
-------
(13b)c.l
1979 Fuel Consumption
Control Equipment
Coal
Oil
Particulates
Ut ility/Poworplant
10 _ Btu ,
10 J
Btu
Estimated Actual 197'j
Emissions (10 Tons)
Number Equip. EfE. (» Equip. ' Eff. (%) " Tons ""Vlb. Sulf. 1%) Ash (%) " Barrels "" /gal. (8) '10 MCF Btu/Ft.3 SO,, HO TSf
INDIANA
Commonwealth Edison of Ind.
Stateline 3
4
Crawfordsvilie Municipal
Crawfocdsville i/ 4
5
ESP 98.0
ESP 98.0
MC
MC
2/
Hoosier Energy Division
Ratts
ESP 99.5
ESP 99.5
542.0
742.0
1284.0 9,504 0.43 4.53
3.0 11,168 3.92 2/
370.0
377.0
\ I/ Consumption data from Cost & Quality of Fuels for Electric Utility Plants - 1979,
| 27 Not Available.
o
Tl
z
o
o
18.8
29.1
148.0
30.3
178.3 1,023 10.78 8.61 0.53
747.0 10,487 3.7 13.9 47.9 140,619 .35
53.3 6.7 0.41
O
3D
55
m
O
-------
(13d)c.l
Utility/Powerplant
Incl iana-Kentucky Electric
Clifty-Creek
Indiana £. Michigan Electric
Breed
Tanners Creek
Twin Branch
Indianapolis Power & Light
Perry 2/ ' ,
Petersburg
Unit
Number
1
2
3
4
5
6
Total
1
2
Total
1
2
3
4
Total
4
5
Total
11
12
13
14
15
16
17
18
Total
1
2
3
Total
Name
Plate
Capai
~ity
(MW)
217
217
217
217
217
217
1303
248
248
496
153
153
215
580
1101
85
153
238
60
293
471
574
1338
.3
.3
.3
.3
.3
.3
.8
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
To
.4
.0
.0
.4
Net
Dependable County Attainment
Capac
ity location scacus
Currently Enforced Emissions Limits^
SO
a
NO
A c.
TSP
Averaging
(MW) City County SO, NO TSP
-------
(13f)c.l
1979 Fuel Consumption
Estimated Actual 1973
1
,
j
i!
y
\
i
ij
jj
[
'H
3
|
1
j
t
J
;
i
i
i
:
Utility/Powerplant
INDIANA
Indiana-Kentucky Electric
Clifty-Creek
Indiana's Michigan Electric
Breed
Tanners Creek
Twin Branch
Indianapol is Power & Light
Per ry
'
' i ,
Petersburg
Unit
Number
1
2
3
4
5
6
1
2
1
2
3
4
4
5
11
12
13
14
15
16
. 17
18
1
2
3
I/ Petersburg S2 ESP will be upgraded
2/ Limestone scrubber has particulate
O
Tl
z
o
o
x
o
o
3
J>
Control Equipment Coal
Particulates SO. ..3 _. , .3
Equip
ESP
ESP
ESP
ESP
ESP
ESP
MC/ESP
MC/ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
in 1982
design
Eff. (%) Equip. * Eff. (%) Tons "/lb. Sulf. (%) Ash (%) Barrels
.
98.0 614.0
98.0 646.0
98.0 632.0
98.0 617.0
98.0 767.0
99.4 652.0
3928.9 10,968 4.0 13.2
90.0/98.7
90.0/98.7 652.0 11,087 3.79 9.53 3.8
99.7 276.0 8.8
99.7 315.2 7.5
99.7 471.0 9.0
98.3 1037.0 32.3
2099.2 11,323 2.13 11.72 57.6
113.5
- 227.8
341.3
97.0
97.0
98.9 - '
98.9
99.8
99.8
416.8 10,932 2.3 10.0 25.4
99.2 - -
99.0 -
99.3 LSSi/ 85.0 C.F. C.F.
2948.1 10,953 3.16 10.2 48.6
to increase efficiency.
removal efficiency of 99.3%.
~
. '
Oil Gas 3
_ , - ^ Emissions (10 Tons)
Btu J.O Btu 3
/gal. (%) MCF /Ft. SO NO TSP
1 ' x
284.0 58.9 0.4
137,469
126.7 11.5 49.8
139,597 - 89.5 38.2 0.8
137,999 0.39 0.4 0.8 0
134,717 0.3 35.8 1000 (est) 19.2 6.4 0.4
136,988 - 143.4 44.3 1.9
.
-------
<13h)c.l
Ut i1i ty/Powe rpla nt
INDIANA
Indianapolis Power & Light
Pritchard
Stout
Logansport Municipal
Logansport
Northern Indiana Public Service
Bailly , '
Michigan City
Mitchell
Unit
Number
1
2
3
4
5
6
Total
1
2
3
4
5
6
7
Total
4
5
Total
ee
7
, 8i/
Total
1
2
3
12
4
5
6
11
Name
Plate
Capacity
(HW)
46.0
46.0
50.0
69.0
69.0
114.0
394.0
35.0
35.0
38.0
40.0
114.0
114.0
471.0
847.0
18.0
25.0
43.0
194.0
422.0
616.0
71.0
70.0
70.0
521.0
732.0
138.0
138.0
138.0
115.0
Net
Dependable
Capacity Location
(MW) City County
45.0 Martinsville Morgan
45.0
45.0
66.0
66.0
106.0
373.0
35.0 Indianapolis Marion
35.0
40.0
42.0
106.0
106.0
439.0
803.0
16.0 Logansport, Cass
21.0
37.0
186.0 Chesterton Porter
404.0
590.0
71.0 Michigan City LaPorte
66.0
66.0
468.0
671.0
131.0 Gary Lake
131.0
131.0
80.0
C-unt" Attainment Currently
"" t - 1 1
SO, NO TSP (lbs/10 Btu)
- 6.0
6.0
6.0
6.0
6.0
6.0
X - X-P .35
.35
.35
.35
5.30
5.30
5.30
- 6.0
6.0
- - X 6.0
6.0
X-P - XX-P 5.3
5.3
5.3
5.3
X-P - X-P 1.2
1.2
1.2
1.2
Enforced Emi.'
NO
(lbs/10 Btu)
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
f.
(lbs/10 Btu)'
.19
.19
.19
.19
.19
.19
.015
.015
.015
.015
.135
.135
.046
.8
.8
.22
.22
.15
.15
.15
.15
.223
.223
.223
.223
Averag ing
Period
3 hr. TSPiNOx/
30 day S02
3 hr. TSPSNOX/
30 day SO2
3 hr. TSP&NOX/
30 day SO2
3 hr. TSPiNOx/
30 day SOj
3 hr. TSPSNOX/
30 day SO2
3 hr. TSPSNOX/
30 day S02
Boiler Data
Bottom
Wet
Wet
Wot
Dry
Dry
Dry
N/A
N/A
Wet
Ket
Dry
Dry
Dry
Dry
Dry
wet
Wet
Wet
Wet
Wet
Vie t
Dry
Dry
Dry
Dry
Fir inq
Pulve ize
Pulve ize
Pulve ize
Pulve ize
Pulve ize
Pulve ize
N/A
N/A
Pulverizer
Pulver izer
Pulverizer
Pulver izer
Pulverizer
Stoker
Stoker
Cyclone
Cyclone
Cyclone
Cyclone
Cyclone
Cyclone
Pulverizer
Pu Iver izer
Pulverizer
Pulverizer
Total 529.0
472.0
I/ Bailly 02 will upgrade ESP in 1980 to meet TSP standard.
2/ Emissions limits apply to all fuels.
o
Tl
z
o
o
a
-o
O
m
O
-------
1979 Fuel Consumption
Estimate'! Actual 197'J
Control Equipment Coal Oil Gas
Ut il i ty/Po^er plant
INDIANA
unit
Number
Participates SO, ,3 _ ,,,3 Btu Suit. -3
Equip. Eff. (%) Equip. Eft. (%) Tons /lb. Sulf. (%) Ash (*) Barrels /gal. (%) MCF /Ft.
m's 'on- 03T'on-
SO 110 TSP
' x
Indianapolis Power & Light
2
1
i
1
1
1
|
i
j
!
Pritchard
Stout '
.
Logansport Municipal
Ixxjansport I/,
Northern Indiana Public
Bailly
Michigan City
Mitchell
-/ Fuel Consumption
O
Tl
z
o
o
a
O
33
J^
m
o
1
2
3
4
. 5
6
1
2
3
4
5
6
7
-
4
5
Service
7
8 .
' i . 1 '
' 2
3
.12
4
5
6
11
data from:
KC
MC
ESP
ESP
ESP
ESP
MC
MC
ESP
ESP
ESP
BH
BH
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
Cost S Quality
75.0
75.0
99.3
99.0
99.0
99.0
493.3 10,895 2.2 10.3 27.4 134,947 0.3
0.5
90.2 1.3 20.0
90.2
98.9 410.2 5.6
99.0
99.5 1072.8 14.8
1483.0 10,719 1.7 9.3 78.2 135,295 0.3
"67.5 ~~T£7347 l~.Bd~~~Z~oi'av~aii. 9.3 138,005 1.00
99.0 426.6 622.5
99.0 662.8 361.0
1089.4 10,721 2.88 10.29 9834.4 1,000
99.5 147.8 175.4
99.5 . 143.5
99.5 109.0
99.7 1053.1 J ' 741.2
1453.3 ' 10,493 2.53 11.79 916.6 1,000'
98.0 ' 302.0
98.0 ' , 298.5
98.0 236.6
98.0 WL 90.0 274.7
1111.9 10,864 1.07 7.86
129.5 1,000
Of Fuels for Electric Utility Plants - 1979.
.
--
'
21.4 7.4 0.4
50.4 22.4 0.9
not available
62.75 29.96 .39
73.5 40.0 .36
11.11 16.68 1.4
_
-------
Utllity/Powerplant
INDIANA
Northern Indiana Public Service
R.M. Schah£er
Peru Light & Power
Peru
Public Service of Indiana
Cayuga
Edwardcpor tZ/
Gallagher
Gibson
Noblesville
Unit
Number
:e
14
15
Total
1
2
3
Total
1
2
Total
6-1
7-1
7-2
8
1t>tal
' 1
2
' 3
' 4
', Total
1
' 2
3
4
Total
1
2
Total
Name
Plate
Capacity
521.0
556.0
1077.0
10.0
5.0
25.0
40.0
531.0
531.0
1062.0
146.8
150.0
150.0
150.0
150.0
600.0
668.1
668.1
668.0
668.0
2672.2
50.0
50.0
100.0
Net
Dependable County Attainment
Capacity Location Stat.is
Currently Enforced Emissions Limits-'
S°2.
NO
TSP
Averaa i na
(MW) City County SO, NO TSP (lbs/10bBtu) (lbs/10BBtu) (lbs/10bBtu) period
477
527
1004
10
5
22
37
503
502
1005
167
160
159
159
159
633
650
650
650
650
2600
50
51
101
.0 Wheatfield Jasper -
.0
.0
.0 Peru Miami - - -
.0
.0
.0
.0 Cayuga Vermillion -
.0
.0
Edwardsport Knox - - -
.5
.0 New Albany Floyd -
.0
0
.0
.0
.0 Mt. Carmel Gibson - - -
.0
.0
.0
.0
.0 Noblesville "Hamilton -
.0
.0
4
1
6
6
6
6
6
6
6
6
6
6
6
6
6
5
5
5
5
6
6
.5i/
.2
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.83/
.8
.8
.8
.0
.0
1
0.7
0.7 '
None
None
None
None
None
None
None
None
None
None
None
None
None
0.7
0.7
0.7
0.7
None
None
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
.1
.1
.8
.8
.8
.23
.23
.8
.8
.8
.8
.8
.8
.8
.8
.12
.12
.12
.12
.2
.2
3 he. TSPSNOX/
30 day S02
3 hr. TSP&NOX'/
30 day S02
3 hr. TSPiNOx/
30 day S02
3 hr. TSP6NOX/
30 day SO2
3 hr. TSP6NOX/
30 day S02
3 hr. TSPSNOx/
30 day S02
3 hr. TSPSNOX/
30 day S02
Boiler Data
Bottom
Wet
Dry
Dry
Dry
Dry
Dry
Dry
H/A
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Firing
Cyclone
Pulver izer
Pu Iver izer
Pulver i zer
Pulverizer
Pulverizer
Pulverizer
Front
Pulverizer
Pulverizer
Pulverizer
Pulver izer
Pulverizer
Pulverizer
Pulverizer
Pulver i zer
Pu Iver i zer
Pulverizer
Pulver izer
Pu Iver izer
Pul veri zer
V R.M. Schahfer II operating at a variance until 1981, when S02 limit will be 1.2.
y Edwardsport boilers associated with turbines 6(35 MW), 7(40.3 MW) , 8(69 MW), and 66(2.5 MW) .
3/ All Gibson units will have to meet 5.1 Ibs. SO2 standard by 1981.
4/ Emissions limits apply to all fuels.
o
Tl
z
o
o
3
TJ
O
30
m
O
-------
<13n)c.l
1979 Fuel Consumption
Unit Parti
Ut ili ty/Powerplant Number Equip.
INDIANA
Northern Indiana Public Service
R.M. Schahfer 14 ESP
15 ESP
Peru Light & Power
Peru 1 MC
2 ESP
3 MC
Public Service of Indiana
Cayuga 1 ESP
2 ESP
Edwardsport - 6-1
7-1 ESP
7-2 ESP
8-1 ESP
] Gallagher 1 ESP
; 2 ESP
i . 3; ESP
> ' . 4 ESP
1 /
t :
Gibson 1 ESP
2 ESP
3 ESP
4 ESP
Noblesville 1 ESP
2 ESP
3 ESP
:
j
0
m
z
o
o
3
! "0
O
2
i H
m
O
Control Equipment Coal
Eff. {%) EC
99.5
99.5
80.0
98.0
80.0
99.0
99.0
98.0
98.0
98.0
99.0
99.0
99.0
99.0
99.0
99.0
99.0
99.0
98.0
98.0
98.0
SO 3 ,
juip. ' Eff. (%) Tons /lb. Sulf. (%) Ash (%)
643.6
211.0
854.6 10,403 1.29 11.08
6.5
43.5
0
50.0 11,300 3.5 10.7
1438.0
1408.0
2846.0 10,289 2.5 11.4
_
223.0
223.0 10,622 2.4 12.8
141.0
318.0
304.0
219.0
982.0 11,077 3.4 10.1
1531.0
1276.0 '
1365.0
1124.0
5296.0 10,700 2.8 12.4
*
115.0
115.0 11,076 3.7 9.9
rf
t
Oil Gas
Barrels Bt" /gal. (%) l° MCF Bt"/Ft.3 SO,
21.1
70.8
91.9 139,000 .27
12.9
12.8
25.7 137,000 0.3
20.0
14.0
34.0 137,000 0.3
7.7
10.0
16.5
13.2
47.4 137,000 0.3
85.5
45.7
8.4
5.4
145.0 137,000 0.3
3.0
3.0 137,000 0.3
,
- -
21.95
135.19
10.17
63.44
281.75
8.08
Estimated Actual 197'J
Emissions (10 Tons)
NO
0.22
10.17 2.01 0.30
63.44 8.84 1.26
281.75 47.66 5.02
8.08 1.04 0.15
-------
(13p)c.l
Utility/Powerplant
Public Service of Indiana
Wabash River
RichmonJ Power & Light
Whitewater Valley
Southern Indiana Gas & Electric
A.B. Brown
F.B. Culley
Ohio River
Uni t
Number
1
2
3
4
5
6
Total
1
2
Total
c
1
1
2
3
Total
1
2
3
4
5
6
7
1
2
3
4
Total
imit Wabash
Name Net
Plate Dependable County Attainment
Capacity Ca ^" ' ' *""'
(KM)
112.5
112.5
112.5
112.5
125.0
387.0
962.0
30.0
60.0
90.0
265.0
50.0
104.0
265.0
419.0
8.0
13.0
13.0
20.0
23.0
23.0
23.0
123.0
144.0
144.0
144.0
323.0
755.0
River boilers
pacity ijocacion status
(MW) City County SO., NO TSP
97.0 Terre Haute Vigo X - X-P
98.0
98.0
98.0
120.0
361.0
872.0
33.0 Richmond Wayne X-P - X-P
60.0
93.0
250.0 West Franklin Posey -
46.0 Newburgh Warrick -
96.0
255.0
397.0
6.0 Evansville Vanderburgh - - XX-P
13.0
13,0
20.0
23.0
23.0
23.0
121.0
- Newburgh Warrick - -
324.0
to the following Ibs./hr.i
Currentl'
SO,
1 c
(lbs/10 Btu;
4.04
4.04
4.04
4.04
4.04
4.04
6.02/
6.0
6.0
6.0
6.0
6.0
6.0
6.0
6.0
6.0
6.0
6.0
6.0
6.0
6.0
6.0
6.0
Currently Enforced Emissions Limits^
WarrickV
H - 43.90; »2 - 67.94; t3 - 63.79; »4 - 67.02; »S - 65.17; J6 - 154.37.
Lbs./106 gtu figures in table have been converted using Net Dependable Capacity.
2/ Attainment Status for Whitewater Valley Plant in dispute; SO2 limit,will probably be lowered soon.
2/ Units 1-3 of Warrick owned by Alcoa, and used foe aluminum,production. Net Dependable Capacity not available to those units.
4/ Emissions limits apply to all fuels.
None
None
None
None
None
None
None
None
0.7
None
None
0.7
None
None
None
None
None
None
None
None
None
None
None
.045V
.069
.065
.068
.054
.04J
.04
.07
.25
.25
.25
.25
.25
.25
.25
.25
.25
.25
.25
Averag ing
Period
3 hr. TSPSHOX
30 day SO2
.233
.233
.233
.233
3 hr. TSPSNOX
30 day SO2
3 hr. TSPSNOX
30 day SO2
3 hr. TSPSNOX
30 day S02
3 hr. TSPSNOX
30 day S02
3 hr. TSPiNOx
30 day SO2
Uoiler Data
ttom Firing
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
PuIveri zer
Pulverizer
Pulver izer
Pulveri zer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Dry Pulverizer
Dry Pulverizer
Dry Pulverizer
Dry Pulverizer
Not Available
Not Available
Not Available
Hot Available
Not Available
Not Available
Hot Available
Dry Pulverizer
Dry Pulverizer
Dry Pulverizer
Dry Pulverizer
o
Tl
o
o
3
s
3
m
O
-------
(13r)c.l
1979 Fuel Consumption
Estimated Actual 19">3
Control EquJDment Coal Oil Gas
Unit Particulates SO 3 3 Suit. ,Q3 Qtu
Utility/Powerplant Number Equip. Eff. (%) Equip. Eff. (%) Tons /lb. Sulf. (%) Ash (%) Barrels /gal. (%) HCF /Ft.
INDIANA
Public Service of Indiana
Wabash River
Richmond Power & Light
Whitewater Valley
t
I Southern Indiana Gas & Electric
A.B. Brown!/
F.B. Culley
Ohio R.I/
' , .
f ' '
J
War rick
.
t
j
3 ESP 98.5 1117.0 54.8
4 ESP 98.5 1 I
5 ESP 98.5 1 1
6 ESP 98.5 666.0 9.4
1783.0 10,892 2.2 10.7 64.2 137,000 0.3
1 ESP 99.0 14.0 .2
2 ESP 99.0 190.0 .5
204.0 10,775 2.3 12.4 .7 138,000 0.3
1 ESP 99.5 DA/VENT 85.0 410.4 11,176 3.49 9.96 21.5 138,147
1 NC/ESP 85.0/97.6 146.8 0.8
2 ESP 99.3 252.3 1.0
3 ESP 99.0 . 666.4 - 8.7
1065.5 10,655 2.89 12.16 1.8 137,900 - 8.7 1,008
1
2
2
4 ..
5
6'
7
1 ESP 96.9 ' t
2 ESP 96.6 " '
3 ESP 96.5
4 ESP 92.4
2291.6 11,045 3.31 10.65 5.5 140,000 56.7 1,005
' ' s 1 3Tor
SO, NO TSP
74.53 16.05 1.95
4.5 3.6 0.3
7.2 0.4 1.9
51.4 8.0 2.01
75.0 21.0 4.5
I/ The Dual Alkali Scrubber has a Particulate design removal efficienct of 99.5%. Both the DA and Venturi Absorber have S02 removal efficiencies of
85.0%.
2/ F.B. Culley Plant 1979 Emissions from State records.
; J/ Ohio River did not operate in
j
0
i ^
i z
o
1 o
'a
""
0
3
Si
m
o
1979: Cold Reserve Status.
-
~
f
-------
Uti 1 ity/Powerplant
City of Alaes
Ames
Cedar Falls
Streeter
Central lova Power Coop
Prairie Creek
Prairie Creek
Corn Belt Power
Hurr.boldt 2/
Unit
Number
5
6
7
Total
4
5
6
7
Total
1
2
3
Total
4
1
2
3
4
Total
1
>P-
1
2
Total
2
3
4
Total
1
2
Total
Name
Plate
Capacity
8.0
13.0
38.0
59.0
5.0
5.0
18.8
37.8
66.6
23.0
23.0
50.0
"9678
149.0
8.0
8.0
12.0
17.0
45.0
38.0
25.0
38.0
63.0
15.0
28.7
37.5
81.2
18.7
218.4
237.1
Net
Currently Enforced Emissions Limits
Dependable ' County Attainment 3/
Capacity Location Status 2 x
(MW) City County SO,
7.0 Ames Story
12.0
37.0
56.0
S.O Cedar Falls Black Hawk
5.0
17.0
36.0
63.0
24.0 Cedar Rapids Linn
24.0
50.0
98.0
139.0 Cedar Rapids Linn
8.0 Humboldt Humboldt
8.0
12.0
17.0
45.0
38.0 Spencer Clay
24.0 Wilton Muscatine
39.0
63.0 .
15.0 Dubuque Dubuque X-P
30.0
35.0
80.0
18.5 Clinton Clinton
220.0
238.5
TSP^
NO TSP (lbs/10 Utu) (lbs/10 Btu) (lbs/10 lltu)
8.0/5.0
8.0/5.0 I/
8.0/5.0 I/
XX-P 6.0
6.0
6.0
6.0
X-P 8.0/5.0
8.0/5.0
2.5-0//B.O/5.0-C
X-P 2.5-O//8.0/5.0-C
8.0/5.0
8.0/5.0
8.0/5.0
8.0/5.0
8.0/5.0
6.0
6.0
2.5-O/6.0-C
; 2.5-O/6.0-C
2.5-0/6.0-C
XX-P 2.5-0/6.0-C
2.5-0/6.0-C
l
None
None
None
None
None
None
None
None
None
None .
None
None
None
None
None
None
None
None
None
None
None
None
None
0.8
0.8
0.8
0.6
0.6
0.6
0.6
.17
.17
.17
.1704
0.8
0.8
0.8
0.8
0.8
.431
.431
0.6
0.6
0.6
0.8
0.44
Averaging Uoiler Djta
Period Bottom Firing
2 hrg. Dry
Dry
Dry
2 hrs. Dry
Dry
Dry
Dry
2 hrs. Dry
Dry
We t
2 hrs. Ket
2 hr. Dry
Dry
Dry
We t
2 hr. Dry
2 hr. Dry
Dry
2 hr. Dry
Dry
Dry
2 hr. Dry
Dr v
UL y
Stoker
Stoker
Pulverizer
Stoker
stoker
Stoker
Pulverizer
Stoker
Stoker
Pulver i zer
Pulverizer
Stoker
Stoker
Stoker
Pulverizer
Pulverizer
Pulver i zer
Pulverizer
Pulver izer
Pulverizer
Pul ver izer
Pulverizer
Pu Iver i zer
Eastern Iowa Light & Power Coop
Fa ir
Interstate Power Co.
Dubuque
M.L. Kapp
I/ Form 67 lists 50Z limit for units 6 and 7 as 1.2 Ibs/mmBTU, although these are not New Sources.
2/ Not dependable capacity data Not available; Nameplate capacity used instead.
3/ Dual entries for coal SO2 standards show state standard first, federal standard second. Standards do not apply to gas.
£/ TSP standards apply to all fuels.
O
Tl
z
o
o
3)
TJ
O
-------
J14n)c.l
Ut ility/Powerplant
iff-'i. (Cont'd)
,'ity of Ames
] Ames
Cedar Falls
Streeter
Central Iowa Power Coop
Prairie Creek
ft Prairie Creek
| Corn Belt Power
I Humboldt
1
|
y
1
Wisdom
Eastern Iowa Light & Power
Fair
Interstate Power Co.
Dubuque
M.L. Kapp
t 0
Tl
I _
; Z
! o
o
3
: -0
o
1 >
H
; m
o
Unit
Number
5
6
7
4
. 5
6
7
1
2
3
4
'
1
2
3
4
1
Coop .
' 1
2
2
3
4
1
2
Control Equipment
Particulates SO,
Equip. Eff. {%) Equip. Eff. (%)
w: 95.0 - -
MC 95.0
ESP Not Avail.
_ _ _
- - -
MC 95.5
ESP 99.5
"
MC/ESP 85.0/98.0
MC/ESP 85.0/98.0
MC/ESP 85.0/98.0
\
ESP 99.5
MC 82.0
MC 82.0
MC 84 .0
ESP/MC 96.0/80.0
'. MC 86.0
/
MC/ESP 85.0/92.0
..MC/ESP 85.0/92.0
ESP 99.0
ESP 99.0
ESP 99.0
ESP 99.0
ESP 99.5
r,l
f
f
197y Fuel Consumption .. Estimated Actual 197J
Coal Oil Gas _ . . .,,3
: '""Tf T Emissions (10 Tonr, )
10 Tons BtU/lb. Suit. (*) Ash (») "barrels BtU/qal. (%)' 10MCF Btu/Ft.3 SO, NO Ti;>
A"
*
21.0 '
79.1 Not Available
100.1 10,105 1.52 9.95
-
43.3
20.3 188.5
49-3 233.9 985 3.0 446.0 0.4
69.6 11,171 2.3 ' 8.9
17.5 - - - 233.5
17.0 - - - 218.1
79.7 ' .72 317.7
114.2 9,839 ' 1.9 9.0 .72 138,500 0.2 769.3 1,026 3.6 1.7 0.1
238.9 9,972. "1.6 8.35 1.0 138,500 0.2 210.15 1,026 6.5 3.6 0.1
7.0
7.3
11.3
16.4
42.0 11,538 2.9 11.17 2.44 .55 .7-5
52.4 10,971 3.06 12.88 1.43 .47 .17
129.4 10,600 2.7 8.3 9.2 1,028 7.0 1.2 0.2
14.1 0.5 109.0
36.5 1.1 512.0
80.4 2.0 880.3
131.0 10,828 2.7 10.3 3.6 140,000 Not Avail. 1501.3 985 7.1 1.2 0.2
41.8 2.0
357.9 ~ 397.7
399.7 10,895 2.94 10.1 2.0 140,000 0.3 397.7 986 23.5 3,6 0.2
1
-------
Ut i1i ty/Powe rpla nt
IOWA (cont'd)
Interstate Power Co.
Lansing
Iowa Electric Light & Power
-Boone
Sixth Street
Su therland
Iowa-Illinois Gas & Electric
Riverside I/
Name
Unit
Number
1
2
3
4
Total
2
1-2
4
5-6
7
8
Total
1
2
3
Total
5
6
7
8
9
Plate
Capacity
15
11
37
274
338
27
16
15
17
15
28
91
37
37
81
156
.0
.5
.5
.5
.5
.0
.0
.0
.5
.0
.0
.5
.5
.5
.6
.6
Net
Currently Enforced Emissions Limits
Dependable County Attainment 2/
Capacity Location Status 2:
(MW) City County SO.,
-
17
10
33
260
322
27
14
20
17
20
31
102
34
34
81
149
.5 Lansing Allamakee
.7
.8
.0
.0
.0 Boone Boone -
.0 Cedar Rapids Linn
.0
.0
.0
.0
.0
.0 Marshalltown Marshall
.0
.6
.6
Bettendorf Scott
NO
TSP3/
NO TSP (lbs/10 Btu) (lbs/10 Btu) (lbs/10 Btu)
- 2.5-0//8.0/5.0-C
8.0/5.0
2.5-O//8.0/5.0-C
0. 8-0/1. 2-C
8.0/5.0
- X-P Hone
2.5 0//8. 0/5.0 C
2.5 O//8. 0/5.0 C
2.5 0//8. 0/5.0 C
2.5 0//8. 0/5.0 C
- XX-P 8.0/5.0
8.0/5.0
8.0/5.0 '
- X-P 6.0/6.0
6.0/6.0
6.0/6.0
6.0/6.0
6.0/6.0
l
None
None
None
0. 3-0/0. 7-C
None
None
None
None
None
None
None
None
None
None
None
None
None
None
0.6
0.6
0.6
0.1
.734
.187
.107
.187
.187
.187
.1704
.1704
.1704
.282
.282
.282
.282
.282
Averaging Boiler Data
Period Bottom Firing
2 hr. Dry
Dry
Dry
Dry
2 hr. Dry
2 hrs. Dry
Dry
Dry
Dry
Dry
2 hr. Dry
Dry
Ket
2 hr. Wet
Dry
Dry
Dry
Dry
Pulver i zer
Pulverizer
Pu Iver i zer
Pulverizer
Pulver i zer
Pul "/Front
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pu Iveri zer
Pulverizer
Cyclone
Pulver i zer
Pulver izer
Pulver i zer
Pulverizer
Pulverizer
Total 222.0
241.4
I/ Capacity data not available by units. Boilers 5-9 associated with turbines 1,2,3 and 5.
2/ Dudl entries for coal SO^ standards show state standard first, federal standard second. Standards do not apply to gas.
3_/ TSP standards apply to all fuels.
o
-n
z
o
o
3J
o
O
3
m
O
-------
14b)cl
1979 Fuel Consumption
Estimated Actual IZTj
Unit Part
Ut ili ty/Powerplant Number Equip.
Q'.;A (Cont'd)
Interstate Power Co.
Lansing 1 ESP
2 ESP
3 ESP
4 ESP
Iowa Electric Light & Power
Boone 2 MC/ESP
Sixth Street 1-2
4 ESP
5-6 ESP
7 ESP
8 ESP
Sutherland 1 ESP
2 . ESP
3 MVESP
Iowa-Illinois Gas & Electric
Riverside 5 - 'ESP
6 ESP
7 : ESP
I . . 8 ESP
1 /:, . 9 / ESP
ICF INCORPORATED
Control Equipment Coal Oil
.iculates SO. Q3 Q3 u Suit.
Eff. (%) Equip. Eff. (1) " Tons ""Vlb. Sulf. (») Ash (%) Barrels /gal. (%)
i
99.0 - - 15.3 0.7
99.0 - - . 0.5 - .
99.0 - - 91.0 1.3
99.5 - - 460.0 5.4
566.6 8,696 0.67 6.2 7.4 140,000 0.3
80.0/98.0 22.7 9,841 2.5 10.6 0.7 138,500 0.25
98.0 - - 28.9 0.2
98.0 - - 31.3 0.5
98.0 - - 34.7 73.3
99.3 - - 59.8 0.1
154.7 10,194 1.9 9.0 1.1 139,100 0.3
99.8 - - 76.5
99.8 - - 90.8
80.0/99.8 - - 197.0
364.3 10,003 3.8 13.8
99.1 - - 34.6
99-1 - - 25.2
99.2 - - 39.7
99.2 - - 36.9
99.2 - - 348.5
485.3 10,137 2.6 9.8
Gas . 3
MCF /Ft. S02 NO TS?
6.7 5.1 0.2
106.0 990.0 1.0 0.2 0.1
428.6
959.4
201.1
176.3
242.2 '
2,007.6 1,028 5.0 2.7 0.2
62.3
77.5
25.3
165.1 991 23.5 7.0 0.3
153.9
112.9
274.7
260.6
634.3
1,436.5 1,028 23.9 4.9 0.2
-------
(14d)c.l
Currently Enforced Emissions Limits
Uni t
Ut ility/Powerplant Number
IOWA (Cont'd)
Iowa Power & Light
Council Bluffs 1
2
3
Total
Des Moines 4
5
6
7
total
Iowa Public Service
Maynard 6
7
Total
Neal 1
2
3
4
' Total
Iowa Southern utilities
Bridgeport '1
',2
'.' . 3
Total
Bu r 1 i ng ton 1
Iowa State University of
Science and Technology
Heating Plant 1
2
4
5 '
Total
Plate
Capac ity
(KW)
49.0
81.6
650.0
780.6
35.0
46.0
75.0
113.6
269.6
23.0
54.0
77.0
147.0
330.0
550.0
640.0
1,667.0
23.0
23.0
25.0
71.0
212.0
3.0
3.0
6.0
12.0
24.0
Dependable
Capacity Loca
(KW) City
48.0 Council
90.6 Bluffs
650.0
788.6
39.7 Des Moines
50.2
71.0
116.0
276.9
23.0 Waterloo
57.0
80.0
147.0 Salix
320.0
520.0
576.0
1,563.0
20.0 Eddyville
20.0
21.0
61.0 '
207.0 . Burlington
3.0 Ames
3.0
7.0
11.0
24.0
County Attainment so i/
NO
£
TSP y
f
County SO, NO^ TSP (lbs/10 Btu) (lbs/lo"Btu) (lbs/10°Btu)
Pottawattamie - - X-P 2. 5-0//8 .0/5.0-C
2. 5-0//8. 0/5.0-C
0.8-0/1. 2-C
Polk - - X-P 2.5
8.0/5.0
8.0/5.0
8.0/5.0
Black Hawk - - XX-P 2.5
8.0/5.0
Woodbury - - XX-P 8.0/5.0
8.0/5.0
2. 5-0//8. 0/5.0-C
0.8-0/1. 2-C
Monroe 7- - 2.5 O/8. 0/5.0 C
2.5 O/8. 0/5.0 C
2.5 0/8.0/5.0 C
Des Moines - 2.5 O/8. 0/5.0 C
Story - - - 8.0/5.0
8.0/5.0
8.0/5.0
8.0/5.0
'
None
None
0.3-0/0. 7-C
None
None
None
None
None
None
None
None
None
0.3-0/0. 7-C
None
None
None
None
None
None
None
None
.488
.488
0.1
.156
.156
.156
.156
0.6
0.6
0.17
0.17
0.17
0.10
0.8
0.8
0.8
0.8
.38
.38
.38
.38
Averaging uoi
.ler uaca
Period Bottom Firing
2 hr. Dry
Dry
Dry
2 hr. N/A
Dry
Dry
Dry
2 hr
2 hr. Wet
Dry
Dry
Dry
2 hr Cry
Dry
Dry
2 hr. Dry
2 hr. Dry-
Dry
Dry
Dry
Pulver i zer
Pulverizer
Pulverizer
N/A
Pulverizer
Pulverizer
Pulverizer
Not Available
Hot Available
Cyclone
Pulverizer
Pulverizer
Pulverizer
Stoker
Stoker
Stoker
Pulverizer
Stoker
Stoker
Stoker
Stoker
I/ Dual entries for coal SO2 standards show state standard
2_/ TSP standards apply to all fuels.
first, federal standard second. Standards do not apply to gas.
o
Tl
o
o
3
0
O
33
m
D
-------
(UL-)C.l
1979 Fuel Consumption
Estimated Actual 19'.
Control Equipment
Ut il i ty/ Power pi ant
IOWA (Cont'd)
Iowa Electric Light & Power
Council Bluffs
Des Moines
Iowa Public Service
Maynard
Neal
Iowa Southern utilities
Bridgeport
' ;..
Burlington
Iowa State University
of Science and Technology
Heating Plant
Unit
Number
1
2
3
4
5
6
7
6
7
1
2
3
4
1 .
2 ;
3
/
1 .
1
2
4
5
Part iculates
Equip.
ESP
ESP
ESP
_
MC
ESP
ESP
MC
ESP
ESP
ESP
ESP
ESP
MC
MC
MC
ESP
MC
MC
MC/ESP
MC/ESP
Eff.
99
99
99
-
65
99
99
85
99
99
99
99
99
93
93
93
98
93
93
93
93
(%) J
.3
.3
.4
.0
.3
.3
.0
.0
.0
.0
.6
.7
.0
.0
.0
.0
.0
.0
.0/98.0
.0/98.0
SO. ..3
Squip. Eff. (%) Ton
157.
249.
1,386.
1,793.
_
_
144.
166.
311.
_ _. ... ^
1 41.
41.
303.
642.
1,455.
996.
3,398.
5.
16~T
472.
60.
45.
53.
51.
210.
Coal
Oil
is Btu/lb. Sulf. (%) Ash (%) Barrels BtU /gal. (%) ' MC
6
8
0
4 8,299.0 0.4 5.1
2
7
5 10,017 1.74 9.91
0
0 10,646 0.4 6.1
4
6
8
5
3 9,542 0.7 10.0
2
I I/ 10,021 3.1 13.3
3 10,272 2.4 9.4
0
6
8
5
9 10,600 2.4 10.5
0
0
73
75
6
'
.8
.7
.7
.2 136,000 0.4
.96
18
50
Gas rm i - - I
P "Vt.3 SO,
.0
.8
68.7 989.0 11.0
.ons (10 Ton;
NO T:;;
16.1 O.b
100.7
60.5
87.0
6
39
39
-
-
19
114
133
10
32~
1
.96 136,000 0.5
.7
.7 136,560
.0
.7
.7 140,000(est.) Not Av.
.6
7s I/ 137,881 Trace
.4 137,881 0.4
243.5 987.0 12.4
13.
232.
235.
103.
467.
_
_
571.
0.
_
0.
0.
oT
7
5
9 2/ 1,000 0.3
9
4
3 l,000(est.) 59.0
0.9
22.7
1
2
2
5 9 80 5.9
5.6 0.3
1.2 0
41.7 25.2
0.1 0.2
4.3 0.4
1.1 0.8
I/ Fuel consumption data for units 2 & 3 missing from Form 67.
2/ Gas consumption for Maynard plant recorded as given on Form 67.
O
TI
o
o
x
o
O
3)
m
O
-------
(14h)c.l
Name
Unit
Utili ty/Powerplant Number
IOWA (Cont'd)
City of Muscatine
Muscatine 5
6
7
8
Total
Pella Municipal Power s Light
.Pella 6/6
7/6
8/6
Total
Plate
Capa - '
cir-s
(MW)
8
13
25
75
121
27
-
.0
.0
.0
.0
.0
.0
Net
Currently Enforced Emissions Limits
Dependable
' Capac ' ' " ' ' ~~~
ity bocacion
(MW) City County
8
13
24
80
125
26
-
.0 Muscatine Muscatine
.0
.0
.0
.0
.0 Pella Marion
County Attainment
"t i n "
NO.. , , TSf^
C,
" j u a
Pe r iod Bo t torn Firing
2 hr Wet
Wet
Wet
Wet
2 hr. Dry
Dry
Dry
Stoker
Stoker
Stoker
Cyclone
Stoker
Stoker
Stoker
I/ Dual entries for coal S02 standards show state standard first, federal standard second.
2/ TSP standards apply to all fuels.
Standards do not apply to gas.
o
Tl
z
o
o
O
3
m
o
-------
Ut ility/Powerplant
IOWA (Cont'd)
City of Muscatine
Muscatine
Pella Municipal Power i Light
Pella
Consumption data not available by unit.
Unit
Number
5
6
7
8
it
6
7
Control Equipment Coal Oil
Particulates SO. ,n3 _ _3 ... Sul£
HC
MC
ESP
ESP
MC/ESP
MVESP
Eff. (*) Equip. * Eff. (%) " Tons ""Vlb. Sulf. (*) Ash (%) ''" Barrels "'" /qal. (%)
95.0
95.0 - .
95.4 - -
98.0
293.8 I/ 10,350 2.98 10.0
85.0/95.0 - - 39.8
85.0/95.0 - - 47.6
Gas
"'MCF ""/Ft.3 SO,
Estimated Actual 197J
ssions (10 Ton.", I
NO
Tb,<
o
Tl
o
o
a
u
o
21
87.4 10,020 3.81 12.2
0.2
0.2 140,000 0.5
Not Available
6.65
m
O
-------
(15JC.1
Unit
Utility/Powerplant Number
KANSAS
Coffeyville Municipal Light
6 Water
Coffeyville 1
2
3
4
Total
Empire District Electric
Riverton 3
4
6
7
8
Total
Kansas City Bd. of Public Utils.
Kaw ' 1
2
3
Name
Plate
Capacity
10
10
19
40
74
10
12
.0
.0
.0
.0
.0
.0
.0
25.0
38
50
135
46
50
65
.0
.0
.0
.0
.0
.0
Net
Dependable County Attainment
Capacity Location Status -
Currently Enforced Emissions
S°2
NO
Limits ^/
TSP
(MW) City County SO, NO TSP (lbs/10 Btu) (lbs/10 Btuji (lbs/10 btu)
9
10
18
35
72
11
9
25
40
51
136
40
44
60
.5 Coffeyville Montgomery -
.0
.0
.0
.5
.0 Riverton Cherokee -
.0
.0
.0
.0
.0
.0 Kansas City Wyandotte - - X-P
.0
.0
3.0
3.0
3.0
3.0
3.0
3.0
3.0
3.0
3.0
3.0
3.0
3.0
.30
.30
.30
.30
.30
.30
.30
.90-coal/
.90-coal/
.90-coal/
.90-coal/
.90-coal/
oil/gas
oil/gas
oil/gas
oil/gas
oil/gas
oil/gas
oil/gas
.30 oil/gas
.30 oil/gas
.30 oil/gas
.30 oil/gas
.30 oil/gas
.355V
.351V
.3061/
.2621/
.343!/
.36Q2/
.2832/
.255
.287
.24
.24
.28
Period Uottom
1 hr. n/A
N/A
N/A
N/A
1 hr. N/A
N/A
N/A
Dry
Dry
1 hr. Ket
Wet
Wet
Firing
Front
Front
Front
Front
Front
Front
Tangential
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Cyclone
Total
161.0
144.0
I/ Coffeyville stated limits for TSP are: 81-45.42 Ibs/hr; 12-45.42 Ibs/hr; 13-63,11 Ibs/hr; 14-104.32 Ibs/hr. Entire plant limited to 191.07 Ibs/hr.
Stated TSP figures are derived using State SIP formula.
2/ Riverton Nos. 1-3 TSP figures derived using State SIP formula.-
3/ S02 i TSP emissions limits apply to all fossil fuels.
o
Tl
z
o
o
33
-0
O
30
m
O
-------
(15b)c.l
Ut il ity/Powerplant
y.NSAS (Confd)
1979 Fuel Consumption Estimatpd Actual 1
-------
<15d)c.l
Unit
Utili ty/Powerplant Number
KANSAS (Cont'd)
Kansas City Bci . of Public Utils.
Quindaro, NO. 2 1
2
Quindaro, No. 3 7
8
9i/
Total
Kansas City Power t Light
La Cygne 1
2
Total
Kansas Gas & Electric
Gordon Evans 1
2
Total
Hurray Gill 1
2
3
4
Total
NeoshoV . 3
Riplcy ;.. '' 1/1
2/1
3/2
4/2
5/3
Total
Name Net
Plate Dependable
Capacity Caoacitv Location
(MW
82.
158.
30.
30.
35.
335.
873.
686.
1,559.
150.
390.
540.
46.
75.
114.
114.
349.
74.
: 23.
_
31.
31.
87.
1
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
(MW) City County
83
135
32
32
32
314
824
630
1,454
162
380
542
51
78
121
122
372
75
26
_
29
.0 Kansas City Wyandotte
.0
.0
.0
.0
.0
.0 LaCygne Linn
.0
.0
.0 Colwich Sedgwick
.0
.0
.0 Wichita Sedgwick
.0
.0
.0
.0
.0 Parsons La Bet to
. 0 Wichita Sedgwick
° i-
2. 34.0 . "
0
89
.0 .
r . Currently Enforced iimissions
Status
S°2 .
NO
Limits '
** - - Averaging
SO, NO TSP (lbs/10 Btu) (lbs/10 Btu) (lbs/10 Btu) Period
X-P 3
3
3
3
3
- - 3
1
- - 3
3
- - 3
3
3
3
- 3
- - - 3
3
3
3
3
.0
.0
.0
.0
.0
.0
.2
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.90 Coal/. 30
.90 Coal/. 30
.90 Coal/. 30
.90 Coal/. 30
.90 Coal/. 30
.90 Coal/. 30
0.7
.30-oil &
.30-oil &
.30-oil &
.30-oil &
.30-oil &
.30-oil &
.30-oil &
.30-oijL &
.30-oil &
.30-oil &
.30-oil &
.30-oil &
oil/Gas
oil/Gas
oil/Gas
oil/Gas
oil/Gas
oil/Gas
gas
gas
gas
gas
gas
gas
gas
gas
gas
gas
gas
gas
.21 1 hr.
.19
.26S2/
.26al/
.25
.128 ! hr-
.10
.19 l hr-
.152
.227 l nr-
.208
.197
.197
.212 X hr-
.294 1 hr.
.294
.29-1 ^
.294
.294 2/
Boiler Data
Bottom Firing
wet
Dry
wet
W
-------
Control Equipment
Unit Particulates SO,
Utility/Poworplant Number Equip. Eff. (%) Equip. A Eff. (%)
KANSAS (Cont'd)
Kansas City HH . of Public Utils.
Quindaro No. 2 l Esp 9 7.0
2 ESP 99.35 - - '
Quindaro No. 3 7
8 - -
9 MC 85.0
Kansas City Power £ Light
La Cygne 1 Vent. 98.2 LSS 80.0
2 ESP 99.4
Kansas Gas & Electric
Gordon Evans 1 -
: : : :
Murray Gill 1 - - -
2 - _ .. _
3 - -
4 - - - -
Neosho 3 - - -
Ripley .':!,
" . 2 - ; -
4 ' -
5 - - -
| I/ Source: Cost and Quality of Fuels for Electric .Utility Plants - 1979.
(
|
'
o
n
DO
! 5!
i 3
1979 Fuel Consumption E..t lm,.ltp(l A,.. ,..,, , ,,
Coal Oil Gas 3
3 3 Miilf. 3 t-uisblons (1U 'lo,i;;,
" Tons ""Vlb. Sulf. (%) Ash (») iu Barrels "^ /qa.1. (%) ' 10 MCF Dtu/Ft 3 so NO !
349'4 . °-76 .' 1,654.3 954.0
35.3 1.55 2,569.4
384.7 12,233 3.J4 11.53 2.J1 138,000 0.5 4,223.7 ' 949 25.7 22.84 .7.
1,026.0 44.0 ..
2,138.0 85.0 0 3-
3,164.0 8,715 2.03 11.6 129.0 138,049 37-0 48 0 Q a
107.0
250.7
357.8 150,101 1.43 25,458.4 948 1.73 5.75 0.
1 2
78.8 2,600.2
87.0 4,803.8
157.7 5,783.5
323.7 150,848 1.66 15,453.4 978 1.84 3.72 0.17
88.6 151,915 2.31 2,624.6 1,018 .71 .71 .0)
19.4 292.3
19-6 300.0
19-9 -285.8
20-4 . 290.1
38.4 ' fiss_7
117.8 150,053 1.7 1>836.9 9g6 gg ^ UJ
j
-------
kH (ish)c.i
:iJE'. Name Net
(ijS' : Plate Dependable
!$K: Unit Capacity Capacity
J'fcj? Utilitv/Powerplant Number (KW) (MW)
'''TO
!$ ; ' ' KANSAS (Cont'd)
^^f* Kansas Power & Light
;*? ; Abilene 1 15.0 21.0
$Jffl 2 19.0 21.0
S'j'wi Total 34.0 42.0
$& \\
j'S i» Hutchinson 1 23.0 21.0
j$i S. 2 22.0 21.0
jfiSK, . 3 34.5 34.0
iffeST ' 4 171.7 201.0
MS \f. . Total 251.2 277.0
*JA ' Jeffrey, 1 720.0 680.0
fej ? Lawrence . 2 38.0 36.0
PJ>$, 3 49.0' 62.0
iji'j B 4 114.0 134.0
M £ 5 403.0 419.0
5$* . Total 604.0 651.0
r.nunt.. r-ttninmcnt Currently Enforced Emissions Limits */
County Attainment SQ HQ ,fsp
Location Status 2~ x -: Averaqinq
City County SO0 NO TSP (lbs/10 Btu) (Ibs/lQ Btu) (lbs/10 Btu) Period
Abilene Dickinson - 3.0 .30 oil/gas .295l/ 1 hr.
3.0 .30 oil/gas .2951/
Hutchinson Reno - - - 3.0 .30 oil/gas .295V 1 hr.
3.0 .30 oil/gas .29S2/
3.0 .30 oil/gas -2642/
3.0 .30 oil/gas .174V
Bellvue Pohawotomie - 1.2-C/0.8-O 0.7-C/0.3-O .1 1 hr.
Lawrence Douglas - 3.0 .90 coal/. 30 oil/gas .2603/ 1 hr.
3.0 .90 coal/. 30 oil/gas .229V
3.0 .90 coal/. 30 oil/gas .192V
3.0 .90 coal/. 30 oil/gas .1473/
Bottom Firing
N/A Front
N/A Fron t
N/A Front
N/A Front
t'/A Front
N/A Tangential
Dry Pulverizer
Dry Pulv./Tan.
Dry Pulverizer
Dry Pulverizer
Dry Pulverizer
H! £ i/ TSP Limit for Abilene plant given as 121.31 Ibs/hr; figure derived using formula from State SIP.
W » '
B! (f U TSP limit for Hutchinson. plant given as 485.38 Ibs/hr; figure derived using formula from State SIP.
£« 3/ TSP limit f or/ .Lawrence plant given as 768.67 Ibs/hr; figure derived using state SIP formula.
$« ' '' 4_/ S02 & TSP emissions limits apply to all fossil fuels.
i '
O
-------
(L5J1C.1
1979 Fuel Consumption
Unit
Utility/Powerplant Number
KANSAS (Cont'fl)
Kansas Power & Light
Abilene 1
2
Hutchinson 1
2
3
4
Jeffrey 1
Lawrence 2
3
4
5
Control Equ
Particulates
Equip. Eff. (4)
-
-
_
- -
-
ESP 98.6
_
ESP 99.1
ESP 99.0
ESP 99.0
ipment
so.
Equip. " Eff. (%)
-
-
_
- -
-
LSS 80.0
GC 10.0
-
LSS 73.0
LSS 52.0
Coal Oil
103 Btu 103 Btu SuU'"
Tons /lb. Sulf. (%) Ash (%) Barrels /qa,l. (4)
19.3
-
19.3 152,145 1.27
83.7
-
-
220.2
303.7 150,802 1.46
2,084.8 8,386 .34 4.93 67.5 140,910 1.81
65.0
139.9 13.1
258.1 11.9
802.2 19.0
1,200.2 10,421 .61 10.38 109.0 149,752 1.33
Gas Emiss
' 103MCF BtU/Ft.3 SO,
980.6
-
980.6 982 .0£
2,447.0
-
_
11,220.2
13,667.2 999 1.4
6.2
643,0
25.0
27.0
228.0
923.9 1,029 7.6
Estimated Actual 197_<
Emissions (10 Tons)
HO VSF
1.95
0.70 .0:
19.0 1.3
12.84 1.2,
-------
Ut il i ty/Powerplant
KANSAS (Cont'd)
Kansas Power & Light
Tecumseh
McPherson Bd. of Publ.
McPnerson 12
Sunflower Electric Coop
Garden City
Unit
Number
3
4
5
6
7
8
Total
Utilities
1
1
2
3
Total
(MW)
15.0
25.0
33.0
38.0
82.0
150.0
348.0
32.0
4.0
8.0
11.5
23.5
Capacity Location
(MW) City County
15
25
32
32
86
143
333
28
4
8
11
23
.0 Tecumseh Shawnee
.0
.0
.0
.0
.0
.0
.0 McPherson McPherson
.0 Garden City Finney
.0
.5
.5
Status 2
NO
TSP
; ; Averaqinq
SO, NO TSP (lbs/10 Btu) (lbs/10 Btu) (lbs/10 Btu) Period
X-P ' 3
3
3
3
3
3
- - - 0
3
3
3
.0
.0
.0
.0
.0
.0
.8
.0
.0
.0
.30
.30
.90 coal/
.90 coal/
.90 coal/
.90 coal/
.30
.30
.30
oil/gas
oil/gas
.30 oil/gas
.30 oil/gas
.30 oil/gas
.30 oil/gas
0.3
oil/gas
oil/gas
oil/gas
.319V 1 hr.
.283V
.268i/
.268i/ 1
.213V
.189V
.1 1 hr.
.3U1 1 hr.
.309
Boiler Data
Bottom
N/A
N/A
Dry
Dry
Dry
Dry
N/A
N/A
N/A
N/A
Firing
Front
Front
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Front
Front
Front
Front
Sunflower
98.0
94.0
Garden City Finney
3.0
.30 oil/gas
.2082/
N/A
I/ TSP limit for Tecumseh plant given as 451.89 Ibs/hr; figure derived using State SIP formula.
2/ Sunflower II TSP limit given as 185.05 Ibs/hr; above TSP figure derived using State SIP formula.
3/ SO^ & TSP emissions limits apply to all fossil fuels.
o
n
o
o
3D
s
30
m
o
-------
(ISn)c.l
Utility/Ponerplant
KANSAS (Cont'd)
Kansas Power s Light
Tecumseh
McPherson Bd of Publ. Utilities
McPherson H2
Sunflower Electric Coop
Garden City
Sunflower
Unit
Number
3
4
5
6
7
8
les
1
1
2
3
' . . 1979 Fuel Consumption ^
Control Equipment rvTTi ' ^-r5- Estimated Actual IS',
Particulates qn "i ' Gas >
^HHi^ ^^1_ J*^ < Eff. ,t> ». Tons "yb. ^^ ^^ lo3Barreis _3!;^a^ ,u«. . ^3^^ ^^^ -^-^Ip^
: : GC 1S:S :
GC 10.0
GC 10.0
ESP/MC 99.1/85.0 - - 176.5
ESP/MC 99.1/85.0 - - 234.9 "'7 J^'4
"14-4 10'321 "59 10'75 223-5 146,569 1.46 2,799.7' 1,025 5.94 9.66 n,;
_
14.6 150,660 1.0 1,599.6 967 49.0 336-3 15_9
_
77. '4
1,737.0
6.8
1,000 (est.)
1,964.4 854 .4 1-2
6.8 1,000 (est)
2.4 .03
o
Tl
o
o
3
TJ
O
m
O
-------
<15p)c.l
Utility/Power plant
KANSAS (Cont'd)
City of Wellington
Wellington
Western Power-Central Tele.
f. Utilities
Cimarron River
Judson Large 2/
Arthur Mullergren
Unit
Number
4
1
3
4
Total
1
2
3
Total
Capacity
(MW)
20.0
50.0
19.0
149.0
168.0
19.0
19.0
82.0
120.0
Capacity Location
(MW) City County
20
59
19
148
167
19
19
95
133
.0 Wellington Suraner
.0 Liberal Seward
.0 Dodge City Ford
.0
.0
.0 Great Bend Barton
.0
.0
.0
Status 2
SO, NO TSP (lbs/10 Btu)
- 3
- - - 3
- - - 3
3
- - - 3
3
3
.0
.0
.0
.0
.0
.0
.0
NO
TSP
(lbs/106Btu) (lbs/106btu) Period
.30
.30
.30
.30
.30
.30
.30
oil/gas
oil/gas
oil/gas
oil/gas
oil/gas
oil/gas
oil/gas
.
i
.2991/ ' 1 hr
.2322/ 1 hr.
.24 1 hr
.17
.24 1 hr.
21
.21
BOt tO!TI
N/A
N/A
H/A
N/A
N/A
N/A
N/A
Firing
Front
Front
Front
Front
Front
Front
Tangential
I/ Wellington TSP limit plant total, based on State SIP formula.
2/ Cirnarron River TSP limit based on State SIP formula.
3/ Juclson Large Units 1A, IB and 2 not in operation.
4/ SO2 & TSP emissions limits apply to all fossil fuels.
O
Tl
z
o
O
3
TJ
O
3
m
O
-------
USqJc.l
1979 Fuel Consumption
Utility/Powerplant
KANSAS (Cont'd)
City of Wellington
Welling ton
Western Power-Central
Tele. & Utilities
Cimarron River
Judson Large
Arthur Mullergren
Unit
Number
4
1
3
4
1
2
3
Control Eouipment Coal
Particulates SO ,.3 3
Equip. EfC. (%) Equip. * Eff. (%) " Tons ""Vlb. Sulf. (%) Ash (%) i" Barrels
- 10
162
173
- - - - 14
- - - - 11
59
85
.7
.5
.1
.0
.7
.7
.5
Oil
Gas
«»,«!. S<" '"'HC, '»/«.'
886
4,739
379
3,944
145,000 .75 4,323
' 348
112
4,028
145,290 .75 4,488
.1 1,005
.0 967
.6
_._!
.6 937
.0
.4
.4
5 950
Emiss
SO,
.39
.19
Estimated Actual 197j
Emissions (10 Tons)
NO
TSP
.009 -
1.56
.39 1.2 0.0
19 1.1 .03
o
z
o
o
33
-o
O
DO
m
O
-------
Name
Dl at-Q
Unit
Utility/Powerplant Number
Capacity
(MM)
Net
Dependable County Attainment
Capacity Location status -
(MK)
KENTUCKY
I/
0
m
z
o
o
3
TJ
O
30
Big Rivers Elec. Corp.
Coleman 1
2
3
Total
Green (Reid 3) 1
'Henderson II Hl/1
H2/1
Re id . 1
East Kentucky Power Corp.
Cooper 1
2
Total
Dale 1
2
3
4
Total
Spur lock , 1
Henderson Mun. Power. & Light
Henderson I ' 5
6
Total
Kentucky Power
Ui-3 Sandy 1
2
Total
Kentucky utilities
Brown 1
2
3
Total
TSP standards apply to all fuels.
174.
174.
173.
521.
240.
355.
80.
114.
230.
344.
22.
22.
66.
66.
176.
300.
11.
29.
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
5
0
40.5 ..
281.
816.
1,097.
114.
180.
446.
740.
0
0
0
0
0
0
0
155.
150.
150.
455.
210.
300.
70.
121.
233.
354.
23.
23.
74.
. 74.
194.
330.
City County SO_
0 Hawesville Hancock
0
0
0
0" Sebree Henderson X-P
0 Sebree Henderson X-P
0 Sebree Henderson X-P
0 Burnside Pulaski
0
0
0 Ford Clark
0
0
0
0
0 Maysville Mason
10.0 Henderson Henderson X-P
29.0
Currently Enforcc-d Emissions Limits lx
S00 NO
NO TSP (lbs/lUbBtu) (lbs/10bBtu)
- 5
5
5
X-P 1
X-P 6
X-P 5
- 3
3
2
2
2
2
6
X-P 6
6
.2-C/3.5-0/G None.
.2-C/3.5-O/G None
. 2-C/3 . 5-0/G None
.2 0.7
.0-C/4.0-O None
. 2-C/3 . 5-O None
.3-C/2.2-0 None
. 3-C/2.2-O None
.3-C/1.5-O None
.3-C/1.5-O . None
.3-C/1.5-0 . None
.3-C/1.5-O None
.0-C/4.0-O None
. 0 None
.0 None
TSP
^ t Averaging
(lbs/10 fctu) Period
0.3 24 hrs.
0.3
p 3 Sulfur- 30 days
0.1
0.21
0.28
0.3
0.3
0.21
0.21
0.32
0.32
0.32
0.4
0.4
Boiler Data
Bottom
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Firing
Pulver i zer
Pu Iver izer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pu Iver izer
Stoker
Stoker
. 39.0 _ :
260.
800.
1,060.
114.
170.
420.
704.
'
0 Louisa Lawrence -
0
0
0 Burg in Mercer
0
0
0
X-P 6
6
- 6
6
6
.0-C/4.0-O None
.0-C/4.0-O None
.0-C/4.0-O None
.O-C/4.0-0 None
.0-C/4.0-O None
0.245
0.190
0.15
0.15
0.15
.
Dry
Dry
Dry
Dry
Dry
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Fulver izer
-------
(16b)c.l
Control Equipment
Unit
Utility/Powerplant Number
KENTUCKY (Cont.)
Big Rivers Electric Coop.
Coleman
Green (Reid 3)i/
Henderson II
Reid
East Kentucky Power Coop.
Cooper
Dale
Spurlock t
Henderson Kun. Power & Light
Henderson I
Kentucky Power
Big Sandy
Kentucky utilities
Brown
1
2
3
1
Hl/1
H2/1
1
1
2
1
2
3
4
!
'
5
6'
1
2
1
2
3
Part iculates
Equip.
ESP
ESP
ESP
ESP
ESP
ESP
MC/ESP
MC/ESP
MC/ESP
MC/ESP
MC/ESP
MC/ESP
MC/ESP
ESP
MC
MC/ESP
ESP
ESP
ESP
ESP
ESP
Eff.
99.
99.
99.
99.
99.
99.
85.
86.
86.
85.
85.
85.
85.
99.
92.
92.
98.
98.
98.
99.
99.
SO
(%J Equip.
0
0
0
5 IS
0
0
0/99.9
0/98.0
0/98.0
0/99.1
0/99.1
0/97.1
0/97.3
5
5
0/98.5
-
5
5
5
0
0
103
" Eff. (%) TO
505
518
562
1,586
90.0
531
501
1,032
241
247
543
805
4
2
142
117
267
604
20
- 18
39
765
1,317
2,083
185
344
955
Coal
Oil Gas
ns Btu/lb. Sulf. (t) Ash (%> "barrels BtU /,al. "m" ' ^MCF BtU/Ft.3
.1
.4
.8
.3 10,839 2.7 9.8
.1
.7
.8 " . 10,509 3.4 12.9
.0 10,221 3.4 13.0
.6
.4
.7 12,046 1.5 10.4
.8
.5
.3
.5
.1 11,620 0.8 11.5
.2 11,352 1.2 12.1
.5
.5 ' .
.0 10,655 2.1 11.9
.7
.8
.5 11,286 1.19 13.65
.5
.9
.4
1
1
1
4
1
2
4
1
0
1
1
0
0
0
0
3
2
24
69
93
.2 25.7
.5 ' 25.3
.5 26.1
.2 91,500 - 77.1 1,000
.7
.3
.0 136,000 0.4
.6 136,000 0.4
.6
^
.7 138,600 0.1
.1
.1
.9
.8
.4 138,600 0.2
.9 138,600 0.1
.5
._4
.9 138,391
1,485.8 11,763
2.41
12.50
0.7
138,400 0.3
I/ No fuel or emissions data for Green - started up 11/79.
Estimated Actual 1V7
Emissions (10 Tor..".!
SO
2-
85.7
NO
TJP
14.3 I.1)
70.23 10.33 1.3
16.4 2.4 0.3
29.7
7.4 1.8
5.6 2.6 1.3
25.2 8.0 1.0
1-5 1.0 0. L'
49.48 18.75 11.:
71.6 13.37 0.-<
o
Tl
o
o
X
TJ
O
3
m
O
-------
(16d)c.l
Uni t
Utility/Powerplant Number
KENTUCKY (Cont.)
Kentucky utilities
Ghent 1
2
Total
Greon River 1
2
3
4
Total
Pinsville 3
11
0
,j Tyrone 1
] 2
1 ,, 3
1 ' Total
jj Louisville Gas & Electric
* Cane Run 1
II . 2
'jj 3
ij 4
j . 5
,j '/ .' Total
j Mill Creek ' 1
. .2
' ' 3
Total
; I/ TSP standards apply to all fuels.
Name
Plate
Capacity
(MW)
511.0
556.0
1,067.0 "
38.0
38.0
75.0
100.0
251.0
30.0
25.0
25.0
60.0
110.0
112.5
112.5
147.1
163.2
209.4
744.7
355.5
355.5
462.6
1,173.6
Net
Currently Enforced Emissions Linut.s
Dependable County Attainment
Capaci
(MW)
525.
..500.
1,025
29.
30.
72.
113.
244.
37.
31.
32.
47.
140.
106.
109.
141.
175.
183.
714.
334
325.
425
1,084.
cy location Dtdiu±>
City County S00 NO
0 Ghent Carrol
0
0
0 Central City Muhlenberg X
0
0
0
0
0 Four Mile Bell
0 Versailles Woodford
0
0
0
0 Louisville Jefferson X
0
0
0
0
0
0 Louisville, Jefferson X
0
0 !.:
0 "
so
' L
TSP Jlbs/lfl"
5
1
X 3
3
3
3
X 2
1
1
1
X 1
1
1
1
1
X 1
1
1
.67-C/4
.17-C/O
.5
.5
.5
.5
.3-C/l.
.2-C/O.
.2-C/O.
.2-C/O.
.2-C/O.
.2-C/O.
.2-C/O.
.2-C/O.
.2-C/O.
. 2-C/O .
.2-C/O.
.2-C/O.
NO..
* c.
Btu) (lbs/10"l)tu)
.O-O
.B-O
5-0
8-O
8-O
8-0
8-O/G
8-O/G
8-O/G
8-O/G
8-O/G
8-O/G
8-O/G
8-O/G
None
0.7-C/0.3-O
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
0.7-C/0.3-0
TSP-
£ »
Averaging Bo
iler. Data
(lbs/10 Btu) Period bottom Firing
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
.18
.10
.14
.14
.14
.14
.31
.22
.22
.22
.116
.116
.116
.116
.116
.
.15
.15
.10
24 hrs. tiry
Sult.ur-30 days Drv
Dry
Dry
Dry
Dry
Dry
N/'A
N/A
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Pulverizer
Pulverizer
Pu 1 ver i zer
Pulverizer
Pu Iver izer
Pulverizer
Pu Iver i zer
Front
Front
Pulverizer
Pu Iver i zer
Pulverizer
Pulver i zer
Pulverizer
Pulver izer
Pulver i zer
Pulverizer
Pu Iver izer
Tl
O
o
0
O
m
o
-------
(16£)c.l
1979 Fuel Consumption
Estimated Actual 1979
Unit
Ut ility/Powerplant Number
KENTUCKY (COnt . )
Kentucky Utilities
Ghent 1
2
Green River 1
2
3
4
(Pineville " 3
Tyrone 1
2
3
i Louisville Gas & Electric 1
1 1978 data Cane Run 2
t 3
4
5
6
1978 data Mill Creek''- . 1
2
3
Control Equipment
Particulates SO, ..3
ESP
ESP
ESP
ESP
ESP
ESP
MC/ESP
-
-
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
E£f.
98
99
98
98
98
99
81
-
-
99
97
97
97
98
98
98
99
99
99
(%} Equip,
.5
.0
.0 LS
.0 LS
.5 LS
.0
.7/98.5
-
-
.5
.5
.5
.5
.5 LSS
.5 LSS
.5 DA
.5
.5
.6 CA
' Eff. (*) To
1,326
529
1,855
80. Oi/ 1
80. 0V 1
80. Oi/ 123
216
342
29
-
-
30
30
- - 152
166
191
85.0 258
85.0 362
95.0 460
1,590
723
783
85.0 332
1,839
Coal
ns Btu/lb. Suit. (%) Ash (%) Barrels
.6
.2
.6 11,646 2.1 10.0
.2
.0
.1
.6
.0 11,391 2.2 11.5
.1 12,769 1.09 7.99
.7
.7 11,507 1.14 13.36
.6
.7
.4
.3
.3
.0
.9 10,776 3.5 14.7
.9
.0
.2
.1 10,097 3.5 15.3
6
10
17
1
0
0
_
0
0
0
-
10
4
5
21
_
_
24
24
.3
.6
.6
.0
.2
.1
.3
.4
.9
.2
.0
.6
.5
.9
.9
Oil Gas . 3
Btu MO Btu 3
/gal. (%) MCF /Ft. SO, NO TSP
138,400 0.21 77.9 16.7 1.6
Not Available
132,000 0.02 0.64 0.26 0.01
139,753 0.42 0.61 0.28 0.02
511.4
6.2
455.5
187.4
218.4
432.5
140,000 - 1,811.4 1,025 38.4 144.0 1.9
17 5. .2
69.3
140,000 - 244.6 1,025 93.15 15.65 1.12
\J Capacity of Scrubber is 64.0 raw.
Tl
o
o
33
0
O
30
m
o
-------
(16h)c
Utility/Powerplant
KENTUCKY (Cont.)
Louisville Gas & Electric
Paddy's Run
Owensboro Muni. Utilities
Elmer Smith
Tennessee Valley Authority
Paradise
Shawnee
Unit
Number
2
3
4
5
6
Total
1
2
Total
1
2
3
Total
1
2
3
4
5
6
7
8
9
10
Total
Name
Plate
Capacity
(MM)
7c o
£D U
25.0
69.0
69.0
74.8
74.8
337.6
151.0
265.0
416.0
704.0
704.0
1,150.0
2,558.0
175.0
175.0
175.0
175.0
175.0
175.0
175.0
175.0
175.0
175.0
1,750.0
Net
Dependable Count;
Capaci'
(KW)
9Q
£.7
28.
63.
45.
70.
67.
312.
151.
265.
416.
663.
663.
1,096.
2,422.
155.
155.
155.
155.
155.
155.
155.
155.
155.
155.
1,550.
cy Location
City County SO,
0
0
0
0
0
0
0 Owensboro Daviess X-P
0
0
0 Drakesboro Muhlenberg X-P
0
£
0
0 Paducha McCracken X
0
0
0
0
0
0
0 .
0
o !
0
Status
Currently Enforced Emissions Lim
SO
' c
HO
NO TSP (lbs/10°Dtu) (lbs/10%tu)
XI
1
1
1
1
1
X-P 6
6
X-P 3
3
3
XI
1
1
1
1
1
1
1
1
1
1
. 2-C/O .
.2-C/O.
. 2-C/O .
.2-C/O.
.2-C/O.
.2-C/O.
.O-C/4.
.O-C/4.
.l-C/2.
.l-C/2.
.l-C/2.
.2-C/O.
.2-C/O.
.2-C/O.
.2-C/O.
. 2-C/O .
.2-C/O.
. 2-C/O .
.2-C/O.
.2-C/O.
.2-C/O.
.2-C/O.
d O/G
8-O/G
8 -O/G
8-O/G
8-O/G
8-O/G
O-O
0-0
1-0
1-0
1-0
8-O
8-0
8-0
8-O
8-0
8-0
8-0
8-0
8-0
8-0
8-O
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
its
TSP
-y
Averaging Bo:
Her Data
(lbs/10°Btu) Period bottom Firinq
o
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
. 0
0
0
. 19
.19
.19
.19
.19
.10
.34
.28
.11
.11
.11
.11
.11
.11
.11
.11
.11
.11
.11
.11
.11
.11
24 hirs . Dry
Sulfur-30 days Dr>'
Dry
Dry
Dry
Dry
Wet
Dry
Wet
Wet
Wet
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Pulverizer
Pulver i zer
Pulverizer
Pulverizer
Pulverizer
Cyclone
Pulverizer
Cyclone
Cyclone
Cyclone
Pulver i zer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
V TSP standards apply to all fuels.
o
T!
z
o
o
3
TJ
O
30
m
O
-------
Ut i li ty/ Power pi ant
Unit
Number
KKNTUCKK (Cont.)
louisville Gas & Electric
Paduy's Bun 1
1978 data 2
3
4
5
6
Owensboro Municipal Utilities
Elmer Smith 1
2
Tennessee Valley Authority
Paradise 1
2
3
Shawnee 1
2
3
4
5
6
- ^ .;
" . 8
9
10 :
]/ Paradise Units 1 i 2 will
O
-n
o
o
a
T3
o
a
m
0
retrofit
Control Equipment
Particulates SO..
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
scrubbers
Eff. (%) Equip. ' Eff. («)
98.0
98.0
98.0
98.0
98.0
99.1 LS 90.0
97.0
98.0
98.0 I/
98.0 I/
98.0
90.0
90.0
90.0
90.0
90.0
90.0
90.0
90.0
90.0
90.0
in 6/82 and 3/82 respectively.
1979 Fuel Consumption
Coal Oil
10 Tons Btu/lb. Sulf. (%) Ash (%) 10 Barrels Bt" /qal . (%)
92.1 0.1
57.5 0.1
27.1 0.2
32.5 0.2
209.5 10,812 3.6 16.4 0.6 140,000
379.3 0.5
621.1 3.1
1,002.0 , 11,112 2.89 9.62 3.5 136,000 0.12
975.8
1,372.4
2,619.2
4,967.4 10,600 4.2 16.5 63.4 137,300 0.2
293.0
248.9
338.4
337.1
243.5
345.1
353.2
351.8
355.7
302.1
3,168.8 11,680.0 2.1 10.8 36.9 137,900 0.2
Estimated Af?t-ti;*l 1M7-*
Gas 3
3 " ' Eitiiusions (It) Tons)
iU MCf DtU/Ft.3 S02 HO TSP
10.0
7.1
9.7
25-6 1,025 5.76 0.51 0.1
57.8 16.0 1.16
404.4 144.2 13.8
123.0 28.5 2.1
-------
(17)c.2
Util i._ty/Power_p_lant
LOUISIANA
City of Alexandria
D.G. Hunter
Cajun Electric Power Corp.
Big Cajun II
Central Louisiana Elec. Co.
Coughlin
Rodemacher
Teche
Gulf states Utilities
Louisiana SI
Louisiana $2
Nelson
Willow Glen
I/ Emissions limits apply to all fuels.
Unit
Number
1
2
3
4
Total
1
2
Total
1
2
3
4
5
6
7
Total
1
1
2
3
Total
(1-9JA11
1A
2A
3A
Total
1
2
.3
4
Total
1
2
3
4
5
Total
Name
Plate
Capacity
17
17
55
83
172
115
115
230
7
7
10
25
65
125
243
483
445
25
54
348
427
280
23
63
63
149
114
114
163
592
983
163
239
592
592
592
2178
.0
.0
.0
.0
.0
.0
.0
.0
.5
.5
.0
.0
.3
.0
.1
.4
.5
.0
.4
.5
.9
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
Net
Dependable County Attainment
Capacity Location Status
Currently Enforced Emissions Limits =/
so.
HO
(HW) City County SO, NO TSP (lbs/10bBtu) (lbs/10butu)
18
18
55
85
176
109
109
218
8
8
10
24
54
112
224
442
449
23
48
359
431
235
15
42
42
99
100
111
162
515
888
146
220
580
522
550
2018
.0 Alexandria Rapides -
.0
.0
.0
.0
.0 New Roads Pointe Coupee -
.0
.0
.3 St. Landry Evangeline - -
.2
.8
.0
.7
.0
.0
.0
.7 Lena Rapides -
.4 Baldwin St. Mary -
.7
.3
.4
.0 Baton Rouge E. Baton Rouge - -
.0 Baton Rouge E. baton Rouge -
.0
.0
.0
.0 Lake Charles Calcasieu -
.0
.0
.0
.0
.0 St. Gabriel Iberville -
0
.0
.0
.0
.0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
o
0
0
0
0
0
0
0
0
0
.7%S
.7 IS
.7%S
.78S
.7%S
.7%S
.7%S
.7%S
.7 IS
.7%S
.7%S
.7%S
.7%S
.713
.7%S
.74S
.743
.745
."7%S
.7*3
.7%S
.743 .
.7%S
.74S
.743
.743
.743
.745
.743
.7«S
1
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
TSP
(lbs/10biitu)
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
.6
.6
.6
.0
.6
.6
.6
.6
.6
.6
.6
.6
.6
.6
.6
.6
.6
.6
.6
.6
.6
.6
.6
.6
.6
.6
.6
.6
.6
.6
Averaging Boi]
Period Bottom
Not N/A
Specified II/A
N/A
N/A
N/A
N/A
N/A
N/A
1J/A
IV A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
If
Firing
-
Tangential
Tangential
Front
Front
Front
Front
Front
Front
Front
Front
Front
Front
Opp. Wall
Opp. wall
Front
Front
N/A
Front
Tangential
Tangential
Tangential
Tangential
Tangential
Tangential
Opp. Wall
Tangential
Tangent i al
Opp. Wall
Opp. Wall
Tangential
O
Tl
o
o
3
TJ
O
33
*
m
O
-------
i)c.2
Ut il i ty /Power pi ant
! [SIAN'A
:ity of Alexandria
D.G. Hunter
:ajun Electric Power Corp.
Big Cajun #1
*
;
i
| 'rntral Louisiana Electric
P Coughlin
a
i
i
;
.
2
i
i
i Rodemacher
! Teche
iulf States utilities
Louisiana If 1
Louisiana 12
Nelson
Willow Glen
Source: Cost and Quality
O
n
z
0
o
-o
0
3J
m
0
3
Control Equipment Coal
Unit Particulates SO, 3
Number Equip. Eft". (%) Equip. * E££. (%) Tons u b. Sul£. (%) Ash (%
1
2
3
4
1
2
Co.
1
2
3
4
5
6
' 7
1
1
2
3
' " All
1A ;
2A
3A
1
2
3
4 ESP ' 95.0
1
2
3
4 ESP 95.0
5
of Fuels For Electric Utility Plants - 1979
1979 Fuel Consumption Estimated Ar:tual 197J
O^-l (jas ... . . , . 3...
T ^ T7 ^ Kmssion.-. (10 Tons)
1 " Barrels Bt" /gal. (%) 10 MCF Btu/Ft.3 SO, NO TSP
" '"
t
35.3
92.6
621.9
4614.9
5364.6 1,0 24l/ Not Available
53.8 4,970.0
69.3 6,312.9
123.1 140,633 1.0 or 11,282.9 1,036 .07 2.47 .11
less
2.0
1.2
115.5
264.7
1,716.6
5,562.1
8,310.8 Not !.">".. t
15,972.6 1,061 Available 3.12 Avails:
18.0 146,643 0.46 25,422.6 1,023 .02 4.97 .01
420.7
1,489.3
19,580.4 Not No-.
21,490.5 l,047i/ Available 4.22 Avail
7512.0 1,072 Not 55.3 0.1
Available
4,002.0
4,344.0
5,766.0 Not
14,112.0 1,072 Available 27.5 0.1
2074.7 146,740 0.7 22,493.0 1,043 4.5 48.4 0.3
4632.0 149,139 0.5
45,000.0 1,053 10.6 97.9 l.i
_
-------
(17d)c.l
Utility/Powerplant
City of Houma
Municipal Power Plant
City o£ Lafayette Utilities
Don in
Curtis Rodemacher
Louisiana Power 4 Light
Little Gypsy
nine Mile.Point
Unit
Number
14
15
16
Total
1
2
3
Total
1
2
3
4
Total
1
2
3
Total
1
2 :
3
4
5
Total
Name
Plate
Capacity
(MW)
13
26
48
87
53
90
187
330
4
4
13
22
43
248
421
582
1251
69
113
170
783
783
1918
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
Net
Dependable County Attainment
Capacity .Location Status
. (MW
13
26
44
83
57
95
195
347
5
5
13
27
50
244
400
573
1217
74
107
Currently Enforced Emissions Limits-'
S°2-
K0«
TSP
Averanin
-------
(17f)c.2
Estimate-.! Actual 197.'
Control Equipment Coal
unit Particulates SO 3
Utility/Powerplant Number Equip. Eft. (%) Equip. " Eff. (%) Tons /lb. Sulf. (%) Ash (%
LOUISIANA
City of Houma
Municipal Power plant 14 - - - -
15 - - -
16 - - -
City of Lafayette
Bon in 1 - -
2 - - -
3 _
Curtis Rodemacher 3 - -
4 _
Louisiana Power & Light
Little Gypsy 1 -
2 -
3 - -
-
Nine Mile Point 1 -
2 - -
3 '
4
. ". 5 ',
I/ Source: Cost and Quality of Fuels For Electric Utility Plants - 1979
Oil Gas - . (1Q3_
in3 Rfn Sulf. .3 ,
) 10 Barrels BtU /gal. (») 10 MCF BtU/Ft.3 SO., NO TSP
114 .7
313.6
1336.7
1801.0 1,000 (est) 2/
1,798.1
4,239.0
9,457.6
15,525.1 1,062 U 30.3 */
168.8
550.6-
719.8 1,095 ?./ 1.4 If
.1 7,342.7
72.2 20,862.1
28,030.3
72.3 141,516 0.2V 56,235.1 1,041 0.7 20.0 0.4
127.2 1,385.8
246.2 2,228.9
2B4.3 2,188.4
265.0 29,974.4
516.5 ' 26.974.9
1439.2 144,007 1.2 62,752.5 1,039 3.57 445.92 .68
2/ Not Available.
o
T1
o
o
3
-0
O
a
5
m
D
-------
(17h)c.l
Unit
Ut il i ty/Powerplant Number
LOUISIANA
Louisiana Power & Light
Sterlington 5
6
Total
watecford 1
2
Total
City o£ Minden Light S, Water
Municipal. Sta. 1
2
Total
Monroe Utilities
Monroe . 10
11
12
Total
City ol Natchitoches
Natchitoches 8
9
10
Total
Hew Orleans Public Service
Market St. . 11
12
13
Total
Michaud 1
2
3
I/ Emissions limits apply to all fuels
O
-n
z
o
o
3J
-o
O
3)
m
a
Name
Plate
Capacity
(KU)
44.0
248.0
292.0
455.0
446.0
901.0
13.0
13.0
26.0
25.0
37.5
75.0
137.5
5.0
26.0
26.0
57.0
30.0
38.0
29.0
97.0
115.0
262.0
582.0
959.0
Net
Dependable County Attainment
Capacity Location Status
(MW) City County SO NO TSP
2 x
44.0 Sterlington Ouachita -
210.0
254.0
410.0 Kilona St. Charles -
411.0
821.0
13.0 Minden Webster -
13.0
26.0
25.0 Monroe Ouachita -
38.0
75.0
138.0
6.0 Natchitoches Natchitoches -
13.0
27.0
46.0
36.0 New Orleans Orleans - -
36.0
31.0
103.0
113.0 New Orleans Orleans -
244.0
548.0
905.0
Currently Enforced Emissions Limits
SO, NO TSP
27 x , Averaging Boiler Data
(lbs/10 Btu) (lbs/10 Btu) (lbs/10 Btu) Period Bottom Firing
Not
0.7%S None' 0.6 Specified Front
0.7%S None 0.6 opp. Wall
0.7%S None 0.6 . Front
0.7%S None 0.6 Front
0.7%S None 0.6 . Front
0.7%S None 0.6 . Front
0.7%S None 0.6 Front
0.7%S None 0.6 Front
0.7%S None 0.6 Front
0.7%S None 0.6 Front
0.7%S None 0.6 Front
0.74S None 0.6 Front
0.7»S None 0.6 Front/Opp. Wall
0.7%S None 0.6 Front/Opp. Wall
0.7%S None 0.6 Front/Opp. Wall
0.7%s None 0.6 Front
0.7%S None 0.6 Opp. Wall
0.7%S None 0.6 opp. Hall
r
-------
, (17J1C.2 '
Control Equipment Coal
Unit Particulates SO. ...3
Utility/Powerplant Number Equip. Eff. (%) Equip. * ECf. (%) Tons /lb. Sulf. (%) Ash (%
LOUISIANA
Louisiana Power & Light
Sterlington 5
6
Waterford 1
2
City of Minden Light i Water
Municipal Sta. 1
! . 2
Monroe Utilities
Monroe 10
11
12
City of Natchitoches
Natchitoches 8
9
10
New Orleans Public Service
Market St. , ". . 11 ',
'' 12
13
i
Michaud 1
2
3
1 I/ Source: Cost and Quality of Fuels For Electric Utility Plants - 1979.
r
|
i
0
-n
z
o
o
3)
i T)
0
i a
: 1>
i 5
| 3
i
1
1979 Fuel Consumption Estimated Actual 197'.t
Oil Gas . . .3
3 Sulf. &3 Emissions (10 Tons)
) Barrels " /gal. (%) MCF "/Ft. SO NO TSP
x
34.0 13,936.1
2,069.3
34.0 137,644 1.0 16,005.5 1,043 .18 9.36 .2'i
2230.7 2196.6
1966.2 2974.8
4196.9 147,934 1.0 5171.4 957.4 13.33 11.05 1.19
204.3 1,000 Hot Available
4.0 134,061 3297.6 l,020i/ .01 1.16 .02
Not operating this year
397.2
418.8
816.0 1,000 Not .33 Not
(est.) Avail'. Avail.
5.9 501.5
6.7 566.8.
6.5 68.9
19.1 144,973 0.3 1137.2 1,036 .02 .38 .01
148.1 , 3,995.1
108.8 5,351.6
1198.2 18,994.5
1455.1 148,654 1.37 28,341.2 1,051 6.63 11.71 .46
-------
New Orleans Sewerage &
Water Board
Power House 12i/
Opelousas Elec. Lt. & wtr.
Opelousas
Ruston Utilities
Steam Gen. Plant
Southwestern Electric Power
Arsenal Hill
Lieberman
Jnit
jmber
1
2
3
4
Total
1
2
3
4
5
6
Total
1
2
Total
1
2
3
Total
5
1
2
3
4
Capacity
(MW)
46
45
52
81
224
41
13
26
39
12
26
41
81
100
25
25
100
100
150
.0
.0
.0
.0
.0
.0
.0
.0
.0
.7
.8
.5
.0
.0
.0
.0
.0
.0
.0
uepena
Capac
(MW
46
44
56
auie Bouncy Attainment
ity Location Status °~~
SO,
i:
NO
^ c
) City County SO NO TSP (lbs/10°Btu) (lbs/10uBtu)
2 x
.0 New Orleans Orleans -
.0
.0
87.0
233
41
13
27
40
13
28
40
81
113
27
29
111
109
276
.0
New Orleans Orleans - -
.0
.0 Opelousas St. Landry - -
.0
.0
.0 Ruston Lincoln -
.0
i?_
.0
.0 " shreveport Caddo -
.0 Mooringsport Caddo -
.0
.0
.0
.0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
.7%S
.7%S
.7%S
.7%S
.7%S
.7%S
.7»S
.7%S
.7%S
.7%S
.7%S
.7%S
.7%S
.7%S
.7%S
.7*3
.7%S
.7%S
.7%S
.7%S
None-
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
TSP
(lbs/10°Btu)
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
.6
.6
.6
.6
.6
.6
.6
.6
.6
.6
.6
.6
.6
.6 ,
.6
.6
.6
.6
.6
.6
Averaging Boiler Data
Period Bottom Firing
Not
Specified Front
Front
Front
Front
11/A
N/A
N/A
N/A
N/A
N/A
Front
Front
Front
Front
Tangential
Tangential
Front
Front
Tangential
Tangential
I/ Boilers 1-6 associated with turbines: 1 = 6.0 MW Naraeplate/6.0 Net Dependable,
3 = 15.0 MW Nameplate/15.0 Net Dependable,
and 4 = 20.0 MW Nameplate/20.0 Net Dependable.
2/ Emissions limits apply to all fuels.
o
Tl
o
o
3
-o
O
3>
m
O
-------
! (17n)c.2
1979 Fuel Consumption
Estimated Actual 197'j
Ut ility/Powerplant
LOUISIANA
New Orleans Public Service
i Pater son
i
i
New Orleans Sewerage &
Water Board
Power House 1 2
1
,
i
Control Equipment . Coal
Unit Particulates SO, ,,,3
Number Equip. Eff. (%) Equip. * Eff. (%) Tons "/lb- Sulf . (%) Ash (»
1
2
3
4
1
2
3
4
5
6
Oil
Gas
) "Lrel. ""/gai. Tif' "'MCF' "Vt.3
46.8 1319
49.7 ' 1164
74.2 1474
111.4 1480
282.1 146,119 1.32 5438
3
22
418
564
469
1478
.4
.9
.1
.3
.7 1,044
.3
.4
.9
.9
.4
.1
.9 1,050
3
SO, NO TSP
1.11 2.24 0.1
Not Available
Opelousas Elec. Light & Water
Opelousas
i
Ruston Utilities
Steam Generating Plant
f '
', Southwestern Electric Power
j Arsenal Hill
j
Lieberroan
O
n
'i Z
i °
I o
J TJ
> 0
2)
1
2
1
2
3 '
'
5A
1
2
3
4
-
540
1258
1798
1713
9
9
16.7 4657
53.0 5054
69.7 147,400 .7 9730
.0
.9
.9 1,071
.8 1,070
.6
.6
.3
.3
.7 1,059
Not Available
Not 3.0 Not
Available AvailabJ
.16 19.13 .08
-------
(18).1
Unit
Ut ility/Powerplant Number
MAINE
Bangor Hydro Electric
Graham 3
4
5
Total
Central Maine Power
Mason 1A/B
2A/B
3
4
5
Total
Wyman 1
2
3
4
Total
Plate
Capa ' '
city
(MM)
12
19
27
58
20
20
33
33
33
139
44
44
121
305
514
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
oependaoie uounty Attainment
Capaci
(KM)
12.
18.
28.
58.
22.
22.
36.
36.
33.
117.
51.
51.
120.
305.
577.
cy ixjc<
City
0 Veazie
0
0
0
0 Wiscasset
0
0
0
0 I/
0
0 Yarmouth
0
0
0
0
County SO, NO TSP (lbs/10
Penobscot X-P - XX-P 2.
- 2.
2.
Lincoln - - - 2.
2.
2.
2.
2.
Cumberland - - - 2.
2.
2.
0.
Btu)
5%S
5%S
5tS
5%S
5%S
5%S
5%S
S%S
5«S
5»S
5%S
8
NO
A f
(lbs/10 Btu|
1
None
None
None
None
None
None
None
None
None
None
None
0.3
TUP
f
(lbs/10'"ntu)
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
3
3
3
3
3
3
3
3
3
3
3
1
rtvecaginy txjin
Period Bottom
2 hr. TSP N/A
sulfur-max H/A
N/A
2 hr. TSP Dry
sultur-max Dry
Wet
Wet
H/A
2 hr. TSP N/A
sulfur-max N/A
N/A
H/A
il ltd Ld
Firing
Front
Front
Front
Front
Front
Front
Front
Front
Front
Front
Front
tl/A
I/ Net dependable capacity not available; Nameplate capacity used instead.
O
Tl
z
o
O
3
TJ
O
DO
m
o
-------
(IBb)c.l
1979 Fuel Consumption
Utility/Power-plant
MAINE (Cont'd)
Banrjor Hydro Electric
Graham
Central Main*? Power
Mason-
Wynuin
Control Equipment Coal
Unit
Number 1
3
4
5
1A/B
2A/B
3
4
5
1
2
3
4 '
Participates SO 1Q3 D(_u
Equip. Eff. (%) Equip. Eff. (*) " Tons ~"~/lb.
-
MC
MC
MC/ESP
MC/ESP
MC
MC
MC
MC
_
-
86.0
86.0
86.0/95.0
86.0/95.0 - - '
86.0
85.0
85.0
85.0
_
Oil r.a«
Sulf. (%) Ash (%) 10 Barrels Bt" /gal. (%) 10 MCF Btu/ft.3
1
28
94
128
19
16
100
80
101
323
253
236
721
534
.1
.6
.3
.3 148,643 2.22
.2
.4
.2
.8
.7
.5 149,338 2.35
.0
.3
.9
.1
Estimated Actual I'j'i
Em issions (10 Ton.-)
SO.
2-
1.0
NO
0.3
0.3
1.85
1,785.0
149,872 1.22
0.22
1.72
-------
U9)c.l
Utility/Powerplant
Unit
Number
Location
County Attainment
Status
Currently Enforced Emissions Limits
SO,, NO TSP
City
County
NO
TSP (lbs/10 Btu) (lbs/10 Htu) (lbs/10 Htu)
Averaging
Period
toiler Data
MARYLAND
Baltimore Gas & Electric
Crane
Gould St.
Riverside
Total
190.4
209.4
399.8
103.5
60.0
60.0
60.0
72.3
81.3
333.6
192.0
192.0
384.0
103.0
58.0
59.0
61.0
78.0
65.0
321.0
Baltimore
Baltimore
Baltimore
Baltimore
Baltimore
Baltimore
1.0 % S
1.0 % S
None
None
.02/SCFU
.02/SCFD
sulfur- max
emissions-
3 hrs.
X-P
X-P
1.0 1
1.0 '
1.0 1
1.0 '
1.0 i
1.0
i S
i S
i S
« S
i S
I S
None
None
None
None
None
None
.02/SCFD
.02/SCFD
.02/SCFD
.02/SCFD
.02/SCFD
.02/SCFD
wet
wet
Dry
Dry
Dry
Dry
Dry
Dry
Cyclone
Cyclone
Front
Front
Front
Front
Front
o
Tl
z
o
o
a
TJ
o
3D
m
O
-------
(19b)c.l
Unit
Utility/Powerplant Number
MARYLAND (Cont'd)
Baltimore Gas & Electric
Crane 1
2
Gould 3
Riverside 1
2
3
4
5
Control Equipment
Particulates so 3
Equip. Eff. (%) Equip. * Eff. (%) 10 Tons
ESP
ESP
ESP
ESP
ESP
ESP
MC
MC
Not Given
Not Given
56.1
43.0
70.7
Not Given
Not Given
Not Given
Coal
ni i ,-,~ 1
^22 Emissions (lU'Tons)
BtU/lb. Sulf. (%) Ash (%) 10 Barrels Btu /o*i . "»i" ' M* *,., Btu/rf3 sn HO TSP
1,639
1,379
3,018
592
154
149
222
348
227
.1
.6
.7 147,310 0.9 9.3 6.6 0.3
.4 147,580 1.0 1.9 1.3 .06
.4
.5
.1
.6
.7
1,102.3
147,555 1.0
3.5
0.2
-------
<19d)c.l
Unit
Utility/Powerplant Number
MARYLAND (Cont'd)
Baltimore Gas & Electric
Wagner 1
2
3
4
Total
Westport 1
3
4
Total
Delmarva Power & Light
Vienna 5
6
7
8
Total
Potomac Edison
Smith 3
. 4
Total
Potomac Electric power Co.
Chalk Point '' . . - 1
:. '' 2
3
Total
Dickerson 1
2
3
Total
Morgantown 1
2
Fiate
Capacity
(MW)
132.8
136.0
359.0
414.7
1,042.5
25.0
60.0
69.0
129.0
17.0
17.0
37.5
162.0
233.5
34.5
75.0
109.5
363.0
363.0
660.0
1,386.0
195.0
195.0
195.0
585.0
626.0
626.0
uepenaaoie
Capacity
(MW)
137.0
134.0
319.0
398.0
988.0
19.0
58.0
68.0
126.0
17.0
17.0
40.0
150.0
224.0
39.0
90.0
129.0
330.0
330.0
632.0
1,292.0
182.0
183.0
183.0
548.0
556.0 '
556.0
Bouncy attainment -
Location Status 2
o
TSP
c
City County S0n NO TSP (lbs/10 Btu) (lbs/10"Btu) . (lbs/10"btu)
Baltimore Anne Arundel - - X-P 1.0 % S
1.0 % S
1.0 % S-C/O
Baltimore . Baltimore - - X-P 1.0 % S
Baltimore Baltimore - - X-P 1.0 4 S
1.0 % S
1.0 % S
Vienna Dorchester - - - 2.0 % S
2.0 % S
2.0 % S
2.0 % S
Williamsport Washington - 1.8-Coal/l.O %S/O
1.8-Coal/l.O %S/0
.... ... _ .
Aquasco Prince George - - - . 3.5-C/2.0%S-O
3.5-C/2.0 %-O
Dickerson Montgomery - - - 2.8
2.8
,.
Newburg Charles - 3.5-Coal/2.0% S-oil
3.5-Coal/2.0% s-oil
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
.02 SCFD
.02 SCFD
. 03/SCFD-C/ . 0 2/SCF-O
.02 SCFD
.02/SCFD
.02/SCFD
.02/SCFD
.31 *
.31 *
.25 *
.19 *
.24
.20
.24/.03/SCF-'82
.24/.03/SCF-'82
.01SCFU
.03/SCF
.03/SCF
*.14
*.14
Averaqinq Boiler
Period Bottom
Sulfur - max Dry
emissions- Dry
3 hrs. Dry
Dry
Dry
Dry
N/A
U/A
N/A
N/A
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Data
Firing
Front
Front
Pulverizer
Opp. Wall
Front
Front
Front
Front
Front
Front
Tangential
Pulverizer
Pulverizer
Pulver i zer
Pulverizer
Pulver i zer
Pulver i zer
Pulverizer
Pu Iver i zer
Pulverizer
Total 1,252.0
1,112.0
* Max. Allowable TSP Discharge in Ibs/mmBtu = 1.026H-0.23299
H = heat input in 10^ stu/hr. Estimates assume 10,000 Btu/Kwh.
o
Tl
o
o
DO
O
O
m
O
-------
(19f)c.l
1979 Fuel Consumption
Control Equipment
Unit
Ut ility/Powerplant Number
MARYLAND (Cont'd)
Baltimore Cos & Electric
Wagner
Westpor t
Delmarva Power &' Light
Vienna
;
Potomac Edison
Smith
Potomac Electric Power Co.
Chalk Point
Dickerson
Morgantown
1
2
3
4
*1
3
4
5
6
7
8
9
11
1 '
2 '
3 ;
1
2
3
1
2
Particulates SO.
. ^2^- .
ESP
ESP
ESP
MC
ESP
ESP
ESP
MC
MC
MC
MC
ESP
ESP
ESP
ESP
Vent.
ESP/Vent.**
ESP/ Vent.
ESP/Vent.
ESP
ESP
Eff.
95
75
98
29
82
87
86
85
85
85
87
94
99
97
97
90
97
97
97
99
99
(%) Equip. ' Eff.
.8
.4
.5
.7
.0
.0
.0
.0
.0
.0
.5
.0
.5
.5
.5
.4
.5/99.5
.5/99.5
.5/99.5
.5
.5
ID3
(%) /TOI
-
-
597
_
597
61
178
239
464
401
- -
866
369
411
399
1,180
' 1,335
1,066
2,401
Coal
ns BtU/lb. Sulf. («) Ash (%) 10/Barn
.0
.0 12,870
.3
.3
.6 10,698
.6
.4
.0 12,345
.6
.1
.3
.0 12,249
.4
.1
.5 12,379
1,201
716
13
900
0.9 9.8 2,831
44
127
244
416
116
87
285
912
1,400
4
2
1.1 17.6 6
71
213
3,378
1.81 12.4 3,663
1.0 12.14
182
397
1.66 13.07 580
011 Gas ->
buir. } Emissions (10 Tonsj
el. ""/Hal. (%, "/MCF Btu/pc 3 qn
.4
.5
.2
.4
.4 146,961 0.96 1(J_8 11-g Q_7
.3
.7
.1
-1 146'75° 1"° 1.2 0.9 .07
.0
.0
.2
.2
.3 149,173 1.85 - ,
8.6 3.1 .01
.0
.3
.3 141,000 1.01 5.24 2<16 ^^
.9
.1
4
TT 148,082 1.99 N0t Avail- 15-86 I6-77
^ ^ -
Not Avail. 10.96 24.37
.9
.3
.2 149,039 1.78 . 214-6 .,.,_ ..^
Unit 1 retiring in 1983.
(Participates only)
O
Tl
o
o
3)
O
O
3
m
O
-------
O
Tl
o
o
3)
o
O
m
O
(20)c.l
Ut ili tv/Powerolant
MASSACHUSETTS
Boston Edison
Myst ic
New Boston
Cambridge Electric Light
Kendall Square
Canal Electric Company
Canal
Holyoke Water Power Co.
y.t. Ton
Montaup Electric Company .
Somers.et4/
Uni t
Number
4
5
6
7
Total
1
2
Total
1
2
3
Total
1
2
Total
1
1
2
5/5
6/6
3
4
9
Total
Name
Plate
Capacity
Net
Dependable County Attainment
Capac
Ity IjOL-ciClUn OCelCUS
Currently Enforced Emissions Limits '
SO,
(I*)J (MW) City County S0n NO TSP (lbs/10°Btu)
15S.3
156.3
156.3
617.0
1,085.9
358.0
380.0
738.0
17.2
23.0
27.2
67.4
543.0
530.0
1,073.0
136.0
36.0
35.0
69.0
125.0
20.0
40.0
*
325.0
145.0 Everett, Middlesex - - XX-P
142.0
155.0
591.0
358
380
738
.16
21
26
63
572
584
1,156
144
38
35
74
122
22
43
334
.0 South Boston Suffolk - - X-P
.0
.0
.0 Cambridge Middlesex - - XX-P
.0
.0
.0
.0 Sandwich Barnstable -
.0
.0
.0 Holyoke Hampton - - X-P
.0 Somerset Bristol - - XX-P
.0
.0
.0
.0 . '
.0
*
.0
1
1
1
1
1
1
0
0
0
2
2
1
2
2
2
2
2
2
2
.10
.10
.10
.10
.10
.10
.56
.56
.56
.42
.42
.103/
.42
.42
.42
.42
.42
.42
.42
NO
,(lbs/10°Btu)
None
None
None
None ,05/
None
None
None
None
None
None
None
None
None
None
None
None
None
None .
None
TSP ,
(lbs/10°Dtu) Perioa
0
0
0
.15 in
0
0
0
0
0
0
0
0
0
0
0
0
0
.12 .5 ppm SO2-
.12 3 hrs.
.12 .14 ppm -
19832/ 24 hrs.
12 .5 ppm S02-
3 hrs.
.14 ppm -
24 hrs.
.12 1 he. -TSP
.12
.12 max. -SO,
2
-12 1 hr. - TSP
12 rax. -SO,
z.
.12 1 hr~ TSP
na*.-S02
.12 1 hr. - TSP
-12 max. - SO,
.12 2
.12
.12
.12
.12
.
Bo l "" - "
bottom
Dry
Dry
Dry
Dry
Dry
Dry
K/A
ll/A
N/A
N/A
N/A
Dry
N/A
N/A
N/A
ll/A
N/A
N/A
N/A
lei IAJ L.i
t'ic::v:
Tancjonci ..
Tangent: -
Tangon ti.a
Tangcntiu '
Opp. Wall
Opp. Kal.L
Front
Front
Front
N/A
N/A
Pulv./Fro:-.-.
Front
Front
Front
Front
Front
Front
Front
* Unit |9 is auxiliary boiler used for building heating and auxiliary equipment operation only.
.L/ Massachusetts emissions limits apply to all fossil fuels.
2/ Mystic Unit 7: TSP limit change as per FERC Form 67.
3/ Mt. Tom: SO2 limit changes to 2.42 in 1982 per FERC Form 67.
4/ Units 1 and 2 on standby capacity - did not consume fuel in 1979.
-------
(20b)C.l
Ut il i ty/ Power pi ant
MASSACHUSETTS (Cont'd)
Boston Edison
Mystic
ji New Boston
j
1
| Cambridge Electric Light
j Kendall Square
|
I
i
J Canal Electric Company
S Canal
i
i
| llolyoke Water power Co.
Mt. Tom
Hontaup Electric Corap
Somerset
g
!'
Control Equipment
Unit Particulates SO
Number Ecuip. Eff. (%) Equip. * Eff. (»)
4 ESP Untested
5 ESP Untested
6 ESP Untested
7 ESP Untested
1
2
1
2
3
1 ESP 90.0
2 ESP 95.0
1 ESP 95.0
5/5
' 6/6
7/3 MC 87.5
8/4 MC 88.5
9
1979 Fuel Consumption Estimated Actual lOTi
Coal Oil Gas 3
^ -> c..t f T ~ Emissions (10 Tons)
in nt- In Rt- > ouit.« in n i ' ^^^ ^^-^
/Tons u/lb. Sulf. (%) Ash (%) /Barrels /gal. (%) /MCF "/Ft. so tio TSP
717.5
317.8
915.5
4,915.7
6,886.5 146,991 .95 21.07 5.66 .33
3,724.7
3,122.3
6,847.0 145,842 .85 18.74 8-91 _22
295.7 145,592 0.5 2,873.0 1,000 .25 1.21* .04-
4,097.0
5,675.0
9,775.0 148,366 2. 73_Q 21_4 0_g
995.3 148,649 1. 4-0 0_8 _Q7
3.6
149.1
39.9
1,174.8
44.3 8 8 3 1 5
1,411.7 148,066 1.85
1 ' Oased on 4.4 Ibs/barrel for oil and 390 lbs/1000 MCF for gas.
Based on 1972 stack testing data and 1979 fuel consumption.
o
o
o
3
O
O
3)
5
m
-------
(20a)c.l
Utility/Powerplant
MASSACHUSETTS (Cont'd)
New Bedford Gas 5 Edison Light
Cannon St.
New England Power
Salem Harbor
Taunton Municipal
Cleary
*Westwater
Western' Mass. Electric Co.
West Springfield
New England Power
Brayton Point
Unit
Number
1/1
2/1
3/2
7/7
8/7
10/7
Total
1
2
3
4
Total
8
4
5
6
7
Total
1
2
3
Total
1
2
3
4
Name
Plate
Capac '
(MW
25.
38.
20.
157
82.
82.
170'.
476.
810.
27.
5.
10.
10.
10.
35.
46.
50.
114.
210.
241.
241.
643.
436.
Ity
1
0
0
0
°
0
0
0
0
0
0
0
0
0
0_
0
0
0
0
0
0
0
0
8
Net
Dependable
Capac i "
(MW)
25.
35.
17.
W.
83.
80.
147.
453.
763.
25.
5.
7.
11.
10.
33.
51.
51.
107.
209.
245.
250.
657.
455.
ty Location
City County
4 New Bedford Bristol
2
9 .
7
0 Salem Essex
0
0
0
0
0 Taunton Bristol
0 Taunton Bristol
0
0
0.
0
0 W. Springfield Hampden '
0
0
0
0 ,. Somerset Bristol
0
0
0
Currently Enforced Emissions Limits ->
Status 2
SO, NO TSP (lbs/10
XX-P 1.
1.
,.
Btu),
10
10
NO
A 6 *
(lbs/10 Btu)
None
None
None
TSP
Averaging
(lbs/10 Btu) Period
.12 1 hr.
.12
.12
Boi'
Hot torn
N/A
N'/A
N/A
1.10 ]!/A
X-P 2.42
2.42
2.42
2
XX-P 2.
XX-P 1.
1.
1.
1.
X-P 2.
2.
2.
XX-P 2.
2.
2.
1.
.42
42
10
10
10
10
42
42
42
42
42
42
10
None
None
None
None
None
None ,
None
None
None
None
None
None
None
None
None
None
.12 1 hr.
.12
.12
'.12
.12 1 hr.
15 1 hr.
.15
.15
.15
.12 1 hr.
.12
.12
.12 SC^:
.12 30-day
.12 TSP-1 hr.
.12
N/A
N/A
Wet
Wet
Wet
l.'/A
N/A
N/A
N/A
N/A
Dry
Dry
Dry
Dry
Dry
Dry
Dry
ler D.-it.,
fid.
Fro:.-.
Froi.L
Froi.c
Fro:.-_
Front
Front
Pulvori^t
Pulv/Fro:
Pulv/Frc:.
N/A
Tar.ger.ti.:
Fror.c
Frcn'-
Fron -c
' Fron-c
Pulv/Tan
Pulv/Tar.
Pulv/Tcin
Pulv/Tan
Pulv/Tan
Pulv/Opp
v/a
i\/ f\
.Total 1,561.8
1,607.0
o
T1
o
o
3J
TJ
O
* Retiring in 1980.
I/ Emissions limits apply to all fuels.
m
O
-------
(20f)c.l
1979 Fuel Consumption
Ut i I i ty/ Power pi ant
MASS/tfJHUSETTS (Cont'd)
i New Bedford Gas & Edison
Cannon St,
i
New England Power
i Salem Harbor
t
I
(
!
Taunton Municipal
Cleary
i
Westwater I/
'
i
1 Western Mass. Electric po
, WescSpringfield
i
i
i
New England Power
< " Brayton Point
j
I/ Westwater Plant retiring
M
O
n
^_
z
o
o
TJ
o
3
H
m
O
Unit
Number
Light
1/1
2/1
3/2
7/7
8/7
10/7
1
2
3
4
8
4
5
6
7
1
2
3
1
2
3
4
in 1980.
Control Equipment Coal Oil Gas -,
Particulates SO, 3 3 Sulf. 3 Emissions (10 Ton:.,
Equip. Eff. (%) Equip. ' Eff. (») iu/Tons """/In. Sulf. (%) Ash (%) "/Barrels "" /gal. (%) ' "/MCF "LU/Ft.J so tin
"
_
ESP 94.0 101.1 ' 276.0
ESP 94.0 . -
ESP 9-1.0 106.3 158.1
ESP 94.0 42.4
ESP 94.0 "
ESP 94.0
250.0 147,190 0.9 434.0 1,000 Not Given
ESP 97.0 .5 70D.3
ESP 97.0 - 715.3
ESP 97.0 - 1,442.3
ESP 90.0 . 3,130.2
.5 13,559 2.63 9.46 6,000.1 149,214 1.95 39_g 13
61.6 146,087 1.65 ,.
.24 .07 trac
_
19.1
14.0
-
33.2 148,137 1.02 Not Available
ESP 95.0 . 283.7
ESP 95.0 229.9
ESP 97.5 ' 714.0
i . 1,247.6 149,368 2.02 3,274.6 1,000 9.9 1.1 .07
ESP 99.3 . 2,693.3
ESP 98.5 * 2,740.4
ESP 85.1 5,568.3
ESP Untested 3,049.9
14,051.9 140, 000 (est) Unavail. 0.5 42.7 30.9
''
~
'
S
-------
i2i)c
lit i 1 1 ty/ Powe rpla nt
MICHIGAN
Consumer's Power Co.
Campbell
Cobb
Karn
Mor row
Wead.ock
Whiting
Name
Plate D
Unit Capacity
Number (>^)
1
2
1
2
3
4
5
1
2
3
4
1
2
3
4
1
2
3
4
5
6
7
8
1
2
3
267.0
385.0
652.0
66.0
66.0
66.0
156.0
156.0
510.0
265.0
265.0
605.0
632.0
Total 1,767.0
35.0
35.0
50.0
66.0
186.0
35.0
35.0
50.0
50.0
66.0
66.0
165.0
156.0
623.0
100.0
100.0
125.0
325.0
Net
spendable County Attainment
Capacity Location Status
(.v.vJ> City County SO.. NO TSP
267.0 West Olive Ottawa
372.0
639.0
67.0 Muskegon Muskegon
67.0
67.0
158.0
166.0
525.0
275.0 Essexville Bay
275.0
500.0
633.0
1,713.0
35.0 Comsloch Kalamazoo
35.0
50.0 :
60.0
180.0
42.0 Essexville Bay
42.0
62.0
62.0
72.0
72.0
163. fl-
ies. o
678.0
106.Q Eric ' Monroe
106.0
131.0
343.0
XX -P
XX-P
XX-P
1
XX-P
Currently Enforcc-d Emissions Limits
I/ Campoell: variance 1980- 198S- 2 .8%s
2/ Cobb: variance 1980- 1»85- requires blend of l.o%s and 2.Sis
o
Tl
o
o
3
-O
O
30
SO, NO
6 6
(lbs/10 Btu) (lbs/10 Btu)
1.11 0/1.67 C-/
1.11 0/1.67 C'
1.11 0/1.67 c2/
1.11 O/1.67 C
1.11 0/1.67 C
1.11 0/1.67 C
1.11 0/1.67 C
1.11 0/1.67 C
1.11 0/1.67 C
1.11
1.11
1.11
1.11
1.11
1.11
1.11
1.11
1.11
1.11
1.11
1.11
1.11-0/1.67 C
1. 11-0/1. 67-C
1.11-O/1.67-C
1. 11-0/1. 67-C
1.11 -0/1. 67-C
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
TSP
(Ibs/lO^lbs)
(Stack Gas)
.16
.16
.21
.21
.21
.18
.IB
.16
.16-
.16
.16
.30
.30
.30
. -30
.18
.18
.18
.18
.18
.18
.18
.18
.2
.2
.2
Averaa ing Boiler Data
Period Bottom
TSP 1.S02 Dty
1 fir. Dry
1 hr. Dry
Dry
Dry
Wet
Wet
1 hr. Dry
Dry
Dry
N/A
1 hr. N/A
N/A
N/A
N/A
1 hr. N/A
N/A
N/A
N/A
N/A
N/A
Dry
Dry
1 hr,. Dry
Dry
Dry
Firing
Pulver izer
Pulverizer
Pu Iver i zor
Pulverizer
Pulver izor
Pulverize-:
Pulver izc=r
Pulverizer
Pulverizer
N/A
N/A
Front
Front
Front
Front
Front
Front
Front
Front
Front
Front
Pulverizer
Pulverizer
Pu Iver i ::-:
Pulverizer
Pu Iver izer
m
o
-------
1979 Fuo]^ Consumption
1
/ Unit
| Utility/Powerplant Number
4
] .11 CAN
» Jonr.umer a Power Company
Campbell 1
2
Cobb 1
' 2
3
4
5
i Karn 1
2
3
4
i Morrow 1
2
3
4
Wcadock 1
i ' 2
3
:. 4
: 5 '
6
7
1 8
I
' Whiting 1
! 2
3
Control Equipment
Particulates
EC*uiP-
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
-
-
_
_
_
_
MC
MC
MC
MC
MC
MC
ESP
ESP '
ESP
ESP
ESP
EEE. (»)
97.0
- 98.0
99.0
99.0
99.0
99.0
99.0
99.0
99.0
-
-
_
_
_
_
80.0
80.0
81.0
81.0
81.0
81.0
99.0
99.0
99.0
99.0
99.0
S°2 103
Equip. * Eft". (%) Tons
\
577.2
940.2
1,517.6
190.6
184.8
199.7
460.5
522.3
1,555.9
669.5
713.9
_
_
1,383.4
_
_ _
_
_
_
-
-
-
-
_ _
420.9
382.0
802.9
225.7
309.4
347.5
882.6
Coal Oil Gas
Btu 103 Btu Sul£' 103 Btu 3
/lb. Sulf. (%) Ash (%) liarrels /gal. (4) hCF /Ft.
i
2.9
6.2
'10,962 2.17 11.36 9.2 139,000
0.7
0.5
0.7
2.5
1.1
11,199 3.87 10.69 7.3 139,000 0.3
23.6
1.9
4,193.5
3,361.7
11,231 2.35 14.46 7,580.5 144,489
59.0
54 7
89.7 112'°
. 106.9 29 '
309.8 146,000 1.0 141-9 i'013
20.2
23.4
37.7
97.2
146.1
44.8
1.3
' ' 7.7
11,510 2.77 14.86 378.5 138,236 1.0 test)
.5
.7
1.0
11,895 .77 11.67 2.3 140,000 0.4
Emiss
so.
65.9
120 . 4
83.0
1.1
34.5
13 .6
Estimated Actual
Emissions (10 Tons)
NO
TSP
120.4 19.9 2.12
83.0 12.5 2.0
34.5 8.4 1.7
13.6 8.0 0.9
O
Tl
z
o
o
3]
TJ
O
m
o
-------
Name Ne t
Plate Dependable
County
Currently Enforced Emissions Limits
Unit
Ut il ity/Powerplant Number
MICHIGAN (Cont'd)
Detroit Edison
Connors Creek 1,3,4,9
10,11,13
15
16
n
18
Total
Delray 1-12 I/
Enrico Fermi 1
Harbor Beach 1
Capacity
(MW)
270.
270.
540.
375.
158.
121.
0
0
0
0
0
0
Capacity Location
(KW) City County
299
300
599
375
161
110
.0 Detroit Wayne
.0
.0
.0 2/ Detroit Wayne
.0 Frenchtown Monroe
.0 Harbor Beach Huron
Status 2-
SO, NO TSP (lbs/10 Btu)
0
X-P 0
1
1
1
1
X-P 0
XX-P 1
- - - 3
IX U
13f
- Averauinq Boiler Data
(lbs/106 Btu) (l'bs/i03lbs) Period Bottom Firimj
(Stack Gas) '
.343
.3%S
.67
.67
.67
.67
.743
.11
.0*3 to
1% in 1980
Marysville 9 3/
10
11
12
Total
Monroe 1
2
3
4
' . Total
Pennsalt 21 5/
22
23
24
Total
200.
817.
823.
823.
817.
328.
39.
0
0
0
0
0
0
0
228
750
750
750
750
3,000
.
22
Marysville St. Clair
.0
.0 Monroe Monroe
.0
.0
.0
.0
Riverview Wayne
.0
(1.11 0/1
XX-P 1
1
1
1
XX-P 3
3
3
3
X-P 0
' 0
1.11 0/1
1.11 0/1
.67 C)
.67
.67
.67
.67
.68 4/
.68
.68
.68
.3»S
.3%S
.67 C
.67 C
,None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
.30
.30
.30
.30
.30
.30
.30
.30
.19
.22
.22
.22
.22
.12
.12
.12
.12
.30
.30
.24
.24
TSP S SO2 N/A
N/A
Dry
1 hr. Dry
Dry
Dry
1 hr. ' N/A
1 hr. N/A
1 hr. Wet
1 hr. Dry
Dry
Dry
Dry
1 hr. Dry
Dry
Dry
Dry
1 hr. N/A
N/A
Dry
Dry
Opp . Wa 1 i
Opp. Wall
Pulveriz<
Pulveri^.,-
.Pulveriu^
Pulverize
ODD . Wa 1 1
N/A
Pulver iz~
Pu Ivor ize:
Pulverise;
Pulverize
Pu Iveri ze
Pulverize
Pulver i zv.
Pulver ize
Pul veri ze
Front
Front
i
r
r
r
r
Pulverizer
Pulverizer
I/ Delray boilers 1-12 feed into turbines 11(50 MW), 12 (50 MW) , 12(50MW), 13 (50MW) ,
2/ Met dependable capacity data not available; Nameplate capacity listed instead.
3_/ Marysville boilers 9-12 feed into turbines 6(50 MM), 7(75 MW) , and 8(75 MW) .
4_/ Variance
5/ Pc-nnsault boilers 21-24 feed into turbines 11(3 MW), 12(5 MW) , 14 (6MW) , 15(6 MW) ,
14(75 MW) , 15 (75 MW) , and 16(75 MW) .
16(8 MW) , 17(8 MW) , 18(3 MW) .
o
Tl
z
o
o
3
0
O
3
m
O
-------
(21f)c.l
1979 Fuel Consumption
Ut ility/Pouerplant
MICHIGAN (Cont'd)
1978 data: Connors Creek
1978 data: Delray
1978 data: Enrico Fermi
1978 data: Harbor Beach
1978 data: Marysville
1978 data: Monroe
1978 data: Pennsalt
Control Equipment
Unit
Number
Particulates
Eauip.
Eff.
<»)
SO, 1Q3
Equip. Eff. (%) TO:
Coal
ns BtU/lb. Sulf. (%)
1,3/4,9,
10,11,13 - -
15
16
17
18
1-12
1
1
9
10
11 .
12
1
2
3 -
4
21
22
23
24
ESP
ESP
ESP
ESP
-
-
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
98.
98.
98.
98.
-
-
99.
99.
99.
99.
99.
99.
99.
99.
99.
98.
98.
0
0
0
0
4
0
0
0
0
6
2
2
7
7
7
_ _
.515
-
515
-
-
256
- - C
_ _
-
_ _
492
- 1,088
1,295
1,737
1,648
5,768
C
-
-
.0
.0 11,964 0.9
.0 11,553 2.5
.F.
.0 11,829 1.2 .
.0
.0
.0
.0
.0 12,183 2.6
.F.
Oil
103 Btu Sulf-
Ash (%) Barrels /gal. (4)
t
164.0
_
_
-
_
11.2 164.0 137,287 0.3
1,161.0 148,111 1.0
142.0 137,244 0.3
14.1 46.0 136,866 .4
12.3
135.0
204.0
196.0
149.0
11.7 683.0 137,144 0.3
C.F.
Gas
103^F BtVt.3
924.0
59.0
983.0 1,018.
5,430.0 907.0
C.F.
235.0 1,004.
Estimated Actual I'j7j
Emissions (10 To.:.";,
SO
2-
9.98 5.54 0.8!
3.8 2.6 0.1
Not Available
12.3 2.4 O.ld
142.0
11,599.0
1.0
12.0
69.0
137,242
0.3
261.4
2.8
55.2
3.2
.02
o
Tl
z
o
o
3
0
O
3J
m
o
-------
(21h)c.l
Ut il i ty/Powc-rplnnt Number
MICHIGAN (Cont'd)
Detroit Edison
River Rouge 1
2
3
Total
St. Clair 1
2
3
4
5
6
7
Name
Plate
(MW)
283.
293
358
934.
169
156.
156.
169
358.
353,
545
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
Net
Dependable
(MW) City County
199.
257,
301,
757,
163.
162.
162.
147.
300.
315.
433
. 0 River Rouge Wayne
.0
.0
.0
.0 Belle River St. Clair
.0
.0
.0
.0
.0
.0
County Attainment Currently Enforce
SO., NO TSP (lbs/10"
X-P
1.11
1.11
- -XX-P 1.11
1.11
1.11
1.11
1.11
1.11
1.11
:d Emissions
NO
Dtu) (lbs/10°Btu)
0.74S
0/1
0/1
0/1
0/1
0/1
0/1
0/1
0/1
.67
.67
.67
.67
.67
.67
.67
.67
C
C
C
C
C
C
C
C
None
None
None
None
None
None
None
None
None
None
Limits
TSP
(IJjn/lp IDS
.30
.17
.17
.17
.17
.17
.17
.30
.15
.13
Trenton Channel
Total 1,906.0
9A*
16*
17*
18*
19*
Total
Greenwood
776.0
815.0
1,682.0
748.0
780.0
Trenton
Channel
Wayne -
1.11 0/1.67 C
1.11/0/1.67 C
1.11 0/1.67 C
1.11 O/1.67 C
1.11 0/1.67 C
1.11 0/1.67 C
None
None
None
None
None
None
.15
.20
.20
.20
.20
.20
Averag ing
Period
TSP &SO2
1 hr.
1 hr.
1 hr.
Boiler 0,1 1 a
Uo t torn
N/A
Dry
N/A
Dry
Dry
Dry
Dry
N/A
Dry
Dry
Dry
Dry
Dry
Dry
Dry
₯ i r i n-
Front
Pulvcri.i'.ci:
front
IPulvori zor
Pulveriser
Puiver i::<. i
Pulvcri:;ai
Opp. Wall
Pulverize:!
Pulverizer
Pu Iver i zei
Pul ver i 20 r
Pu Iver i 7..' r
Pulverizer
Puiver izor
St. Clair
0.8
- 0.3
.l(lbs/10&BTU)
N/A
N/A
Wayne
City of Detroit Public
Lighting Dept.
Mister sky
Holland Board of Public Works
DeYoung
Total
3
4
5-
Total
12.0
22.0
29.0
63.0
42.0
47.0
_58.0
147.0
11.0
22.0
28.0
61.0
Holland
0.7%S
0.7%S
0.7%S
2.50
2.50
2.50
None
None
None
None
None
None
.30
.30
.30
.27 lbs/105BTU
.25 lbs/106BTU
.30
1 hr.
1 hr.
Wet
Wet
N/A
Dry
Dry
Dry
Pulv/Tan
Pulv/Tan
N/A
Puiver i zer
Pulverizer
Puiver iz-.-r
Trenton channel boilers feed into turbines 71120MW), 8(120 MW), and 9(536 MW).
o
z
o
o
a
-o
O
m
o
-------
Uljjc.i
-IJJ79 Fuel Consumption
Ut il i ty/Powcrplant
Mrriuc/vN (Cont'd)
Unit
Number
Uetiroit Edison
1978 data: River Rouge 1
2
3
1978 data: St. Clair 1
2
3
4
5
6
7
1978 data: Trenton Channel 9A
16
17
18
19
Greenwood 1
i City of Detroit Public
tj Lighting Dcpt .
Mistersky 5
6
' 7
Holland Board of Public Works
DeYoung 3
4
5
* Fuel consumption data not available
Ft I/ Removal efficiency not available.
|"
1 0
[ 7
3 Z
0
o
! 3
' 9
i >
A m
H O
Control tfnuipmont Coal Oil Gas
Particulates SO, ,«3 _ ,«3 .... Suit. , n3
Equip.
ESP
ESP
ESP
ESP
ESP
ESP
ESP
MC/ESP
ESP
ESP
ESP
ESP
ESP
ESP
Other Not
MC
MC
MC
I-C/ESP
MC/ESP
Eff. (11 Equip. E£f. (1) " Tons """"/Ib. Su.U. (») Ash (») " Barrels "" /qal . (%) f" MCF """/Ft.'
Not Avail. - - - 2,177.0 4,950.0
Not Avail. - - 420.0 45.0 . 2,465.0
Not Avail. - - 278.0 664.0 2,579.0
Not Avail. 694.0 11,720 0.9 10.6 2,886.0 148,199 0.9 9,995.0 1,129.0
99.95 - - 426.0 173.0
99.9 - - 370.0 178.6
99.9 - - 430.0 235.0
99.0 - - 479.0 133.0
- - - 1,757.0 41.0
I/ 772.0 58.8 31.0
I/ - - 849.0 9.6 156.0
~ 3,326.0 9,906.0 0.8 6.1 2,545.0 148,875 1.1 228.0 1,005.0
98.5 - - 1,142.0 231.0
98.0
98.0 - - 563.0 90.0
98.0 - '
98.0
1,705.0 .11,785 1.2 11.9 321.0 137,244 0.3
Avail. - - * *
96.5 - - 279.4
97.7 - - 137.0
95.0 - - ' 408.4
855.9 147,698 0.9
- 3.0
86.0/98.0 - ' - 62.6
86.0/98.0 - - 87.2
' 152.8 12,528 1.5 9.7
for Greenwood.
Estimated Actual 197.*
r^nissions (10 Ton:jl
5.79 12.G3
.71
59.13 35.13
1.63
36.17 16.06 2.81
Not Available
Not Available
Not Available
-------
Ut iIity/Powerplant
MICHIGAN (Cont'd)
Lancing Board of Water & Light
Eckert
Unit
Number
Total
Er ickson
Ottawa
Total
Marquette Board of Light & Power
Shiras 1
Total
Michigan State University
Plant 65 .
Total
Northern Michigan Electric Coop
Advance 1
2
3
Name Ne t
Plate
50.0
46.0
50.0
80.0
80.0
80.0
386.0
160.0
25.0
4.0
4.0
25.0
25.0
83.0
13.0
21.0
34.0
Total
uepenaciDie
Capacity
(MW)
49
46
47
81
78
84
385
165
32
4
3
2G
32
97
12
22
34
12
12
13
38
. 8
8
22
38
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.5
.5
.5
.5
.0
.0
.0
.0
county Attainment
Location Status 2
NO
x
City County SO., NO TSP (lbs/10 Btu) (lbs/10 Btu^
Lansing Ingham X-P - X-P 1.11 O/1.67 C
1.11 0/1.67 C
1.11 0/1.67 C
1.11 0/1.67 C
1.11 O/1.67 C
1.11 0/1.67 C
Lansing Eaton - - 1.11 O/1.67 C
Lansing Ingham X-P - X-P 1.11 O/1.67 C
1.11 0/1.67 C
1.11 0/1.67 C
1.11 0/1.67 C
1.11 O/1.67 C
Marquette Marquette - 1.67
1.67
1
East Lansing Ingham X-P - X-P 2.50
2.50
1.2
Eveline Charlevoix >- - -1.67 oil/2.50 coal
1.67 oil/2.50 coal
1.67 oil/2.50 coal
.
1
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
0.7
None
None
None
TSP
(Ib3/103lbs)
(Stack Gas)
.22
.22
.22
.2
f 2
.2
.17
.25
.25
.25
.28
.28
.65
.45
.25
.25
.1
0.3/
0.3/
0.3/
Averaging Boiler Data
Period Bottom Firing
TSP S. S02 Dry
1 hr. Dry
Dry
Dry
Dry
Dry
1 hr. Dry
1 hr. Wet
We t
Wet
Wet
Wet
1 hr. Dry
Dry
1 hr. Dry
Dry
Dry
1 hr. Dry
Dry
Dry
Pulver i zer
Pulverize:'
Pulver i zer
Pulver izor
Pulver izer
Pulver izor
Pulver izi.-r
Pu Ivor i zor
Pulverizer
Pu Iver i zer
Pulverizer
Stoker
Scoker
Pu Iver i zer
Pulver izer
Pulverizer
Pulver i zer
Pulverizer
Pulverizer
O
Tl
o
o
3
TJ
O
3)
m
O
-------
<21n)c.l
1979 Fuel Consumption
Estimated Actual 19'.
Unit
Util ity/Powcrplant Number
MICHIGAN (Cont'd)
Lansing Board of Water & Light
Eckert 1
2
3
4
5
6
Erickson 1
Ottawa 3
4
5
1
2
Marquette Board of Light & Power
Shiras 1
2
Michigan State University
Plant 65 1
2
3
northern Michigan Electric Coop
Advance 1
2
3
Control Equipment
Participates S0_
Equip.
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP/BH
ESP/BH
BH
ESP
ESP
MC/ESP
MVESP
MC/ESP
Eff. U) Eauio. Eft". (%)
99.2
98.9
98.9
99.6
99.6
99.6
99.0
97.5
97.5
97.5
97.5
97.5 -
99.8 - . -
99.8 . -
99.7
97.0
99.8
85.0/94.0
85.0/94.0
85.0/94.0 - . -
Coal
103 Btu
Tons /lb. Suit. (%)
11.5
28.2
78.8
135.8
149.1
116.3
519.6 12,705 0.75
464.9 12,325 2.4
9.3
22.6
18.4
-_ 1
48.4 13,021 0.7
44.7
48.8
93.5 ' 12,914 1.5
38.2
57.7
65.9
161.8 12,182 0.8
18.6
17.8
54.7
91.0 12,399 1.89
Oil
103 Btu Sul£"
Ash (%) Barrels /gal. (%)
'
1.3
1.3
3.4
1.4
1.9
2.5
8.1 11.8 136,506 0.4
9.7 1.1 134,661 0.3
0.7
0.8
1.1
3.7 77? 135,093 0.3
8.7
10.7
-
1.8
1.2
0.3'
7.84 3.3 137,100 0.3
Gas . . 3 ,
iO Btu 3
MCF /Ft . SO, NO T«-
7.7 4.7 0
22.7 4.2 0.2
-
0.6 0.7
2.8 .08 .6u
23.5
23.1
30.2
103.6 1,000 2.3 1.45 1.5
5.6 11.6 0.2
o
Tl
o
o
DO
T3
O
3)
m
O
-------
(21p)c.l
Utility/Powcrplant
MICHIGAN (Cont'd)
Upper Pcnninsula Generating
Presque Island
Unit
Number
Total
Wyandotte Dcpt. of Municipal
Service
Wyondot te
Name
Plate
Capacity
(MW)
Net
Dependable
Capacity
(MW)
1
2
3
4
5
6
7
8
9
25.0
37.5
54.4
57.8
90.0
90.0
90.0
90.0
90.0
25.0
37.4
56.9
59.6
80.0
80.0
80.0
80.0
80.0
624.7
Total
578.9
12.0
20.0
32.0
Location
County Attainment
Status
Currently Enforced Emissions Limits
so.,
NO
City
Macquette
County
Marquette
NO
TSP (lbs/10"Btu) (lbs/10"Btu)
1.11 0/1.67 C
1.11 0/1.67 C
1.11 O/1.67 C
1.11 0/1.67 C
l-.ll 0/1.67 C
1.11 0/1.67 C
0.8 O/1.2C 0.
0.8 O/1.2C 0
O/O
0/0
Npne
None
None
None
None
None
7 C
.7 C
0.8 0/1.2C 0.3 0/0.7 C
Wyandotte
Wayne
Hone
Nonee
None
None
r Averag ing
(lbs/10-*ibs) ' Period
(Stack Gas)
.27 TSP&SO2
.24 1 hr.
.23
.23
.20
.20
.lOlb/nunBtu
.lOlb/miuBtu
.lOlD/mmBtu
None 1 hr.
None
BOL
Bottom
Dry
Wet
Wet
Wet
Wet
wet
we t
wet
Wet
i e r ua \. t
Firi
Pulvet
Pulvei
Pu Ivei
Pulvei
Pulvei
Pulvei
Pu Ivei
Pulvei
Pulvei
Scokc-i
Stokei
i
.nf,
i ::OL-
rizor
: i 2'ji"
: i 2 e r
: i zor
: i z _ r
: iz-.-t
c i z o r
: izer
t
c
o
Tl
o
o
3
TJ
O
3J
m
O
-------
1979 Fuel Consumption
Control Equipment
Unit
Ut i 1 i ty/Poworplant Number
CIIIGAN (Cont'd)
Upper Pcnninsula Generating
Presque Island 1
2
3
4
. 5
6
7
8
9
Particulates
Equip.
MC/ESP
rc/ESP
MC/ESP
IC/ESP
ESP
ESP
ESP
ESP
ESP
Erf.
85.
85.
85.
85.
99.
99.
99.
99.
99.
0/95
0/95
0/95
0/95
6
6
2
2
2
SO, 3
(%) Equip. Eff. (%) iv/To
.0
.0
.0
.0
.
-
.
-
-
19
89
161
114
. 242
252
305
i 311
117
1,614
Coal
Oil .- Gas
Btu 103 Btu Sulf. 3
ns /lb. Sulf. (%) Ash'(%) /Barrels /gal. (%) /MCP /Ft.
.0
.5
.8
.9
.6
.2
.0
.4
.9
.3 12,240
1
5
7
3
2
2
6
7
9
.75 9.57 40
I
.4
.5
.3
.2
.1
.3
.9
.2
.4
.8 138,000 0.5
Estimated Actual IS"'
Emissions (10 Tour.)
so..
HO
9.78 24.19
.55
Kyandotte Dept. of Municipal
Service
1978 data: Wyandotte 4
5
MC
MC
80.0
70.0
828.6
1,657.6
2,612.1
1,015
Not Available
o
n
o
o
DO
-o
o
DO
m
O
-------
<22)c.l
ICF INCORPORATED
Name
Plate
Unit Capacity
Ut i li ty/Powerolant - Number (MW)
MINNESOTA
Austin Utilities
Austin 1 5.0
2 4.0
3 8.0
4 12.0
Total 29.0
Northeast 1 32.0
Interstate Power Co.
Fox Lake 1 11.5
2 11.5
3 81.6
Total 104.6
Minnesota Power & Light
Aurora (Laskin) 1 58.0
2 58.0
Total 116.0
Boswell 1 75.0
. 2 75.0
3 365.0
Total 515.0
Hibbard 1 25.0
:.. 2 25.0
3 35.0
4 38.0
Total 123.0
i/ SO2/ limits apply only to solid or liquid fuels.
2_/ NOX and TS? limits apply to all fuels.
' . . ', . . Currently Enforced Bioissions Limits
Capacity Location Status 2 r x Averaging
(MW) city County SO, NO TSP (lbs/10 Btu) (lbs/}0 Btu) (lbs/10GBtu) Period
5.0 Austin Mower - 2.0 None 0.6 S02 Weekly
4.0 2.0 Hone 0.6
8.0 2.0 None 0.6
12.0 - - 2.0 None ' 0.6
29.0
32.0 Austin Mower - 4.0 None 0.6 S02 Daily
12.0 Fox Lake Martin - 2.0 None 0.6
12.0 2.0 None 0.6 S02 Weekly
84.0 4.0-Coal/2.0-Oil None 0.6
108.0
55.0 Aurora St. Louis - - XX-P 4 .0-Coal/2.0-Oil None 0.6 S02 Daily
55.0 ' . 4.0-Coal/2.0-Oil None 0.6
110.0
69.0 Cohasset Itasca - - XX-P 4 .0-Coal/2.0-Oil None 0.6 S02 Daily
69.0 4.0-Coal/2.0-Oil None 0.6
350.0 4.0-Coal/2.0-Oil None 0.6
488.0
25.0 Duluth St. Louis - - XX-P 4 .0-Coal/2, 0-Oil None 0.4 SO2 Weekly
25.0 2.0 None 0.4
35.0 ' 2.0 None 0.4
39.0 . 2.0 None 0.4
124.0
Boiler Data
Bottom Firi.':.~
Dry Pu Iver i z^:
Dry Pulverizer
Wet Pulverize:'
Dry Pulverize-::
Dry Pulv/Frcnt
Dry Pulv/Fro:v.
Dry Pulv/Fronu
Dry Pulverizer
Dry Pulverizer
Dry Pulverizer
Dry Pulverizer
Dry Pulverizer
N/A Front
N/A Front
N/A Front
N/A Front
-------
1979 Fuel Consumption
Estimated Actual 197'j
Control Equipment Coal
Unit
Ut il i ty/Powerplant Number
'NKSOTA
Austin Utilities
Austin 1
2
3
4
northeast 1
Interstate Power Co.
Fox Lake 1
2
3
Minnesota Power & Light
Aurora (Laskin) 1
2
floswell 1
2
3
nibbard ' 1
:. 2
3'
4
Part
Equip.
KC
-
MC
MC
ESP
-
-
ESP
PS
PS
ESP
ESP
PS
MC
MC
MC
KC
icula tes
Eff.
85.
-
85.
85.
99.
-
-
(%)
0
0
0
3
I/
98.
98.
99.
99.
98.
30.
85.
85.
85.
8
8
7
7
7
2
3
0
0
SO, 3 n3
Equio. . Eff. (%) Tons /lb. Sulf. (%) Ash (%) Barr
-
9
45
55
28.9 12,345 1.96 8.37
33
49
60.1 86
60.1 8,632 0.68 10.3 168
PS 37.0 165.7 3
PS 37.0 164.4 3
330.1 8,531 1.1 10.6 7
241.2 ' ' 3
220.3 3
PS 20.0 1292.9 7
1754.5 8,620 0.9 9.6 29
59
150
58
129
399
Oil
Btu Sulf.
els /qal. ' (4)
.3
.1
.8
.3 148,000 1.67
.0
.4
.2
.7 150,507 1.79
.8
.8
.6 143,787 1.15
.1
.1
.1
.1 139,047 .35
.7
.6
.9
.9
.2 150,523 1.8
i'o3MCF
334.
109.
210.
373.
1033.
599.
37.
57.
1054.
1148.
Gas __ __ Eni<-'- ionn (10 Ton '}
BtVt.3 so2 NO TSP
i
d
4
6
3 986 .172 .122 .DCS
9 986 .56 .26 .017
5
3
0
8 987 8.7 3.7 0.3
Not Available
Not Available
1.3
1.1
3
.8
16.5
22
.8 990 2.3 .9 .OUa
Removal efficiency not given.
o
Tl
o
o
3)
g
O
3
m
O
-------
(22d) .1
O
Tl
z
o
O
3)
-O
O
3
m
o
Ut i11ty/Powe rplant
MINNESOTA
Moorhoad Public Service Dept.
Moorhead
ftew Ulm Municipal Utilities
New ulm
Northern States Power
Black Dog
High Bridge
A.S. King
Minnesota Valley
Unit
Number
3
4
5
7
Total
1
2
3
4
Total
1
2
3
4
Total
3
4
5
6
Total
1
3
Name
Plate
Capacity
(MM)
3.
3.
6.
22.
34.
3.
6.
6.
15.
30.
81.
113.
114.
180.
488.
58.
63.
114.
163.
398.
598.
46.
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
Net
Currently Enforced Emissions Limits
Dependable County Attainment I/ 2/
Capacity Location Status 2 ~, \ x
(MW)
3.
3.
6.
22.
34.
3.
1.
1.
13.
18.
75.
100.
115.
173.
463.
44.
44.
107.
168.
363.
560.
47.
City County SO,,
0 Moorhead Clay -
0
0
0
0
0 New ulm Brown -
0
0
0
0
0 Burnsville Dakota X
0
0
0
0
0 St. Paul Ramsey X
0
0
0
0
0 Stillwater Washington X
0 Granite Falls Chippewa -
' TSP^
NO TSP (lbs/10 Btu) (lbs/10 Btu) (lbs/10
4.0-Coal/2.
4.0-Coal/2.
4.0-Coal/2.
4.0-Coal/2.
- None
None
None
None
X 3.0-Coal/l.
3.0-Coal/l.
3.0-Coal/l.
3.0-Coal/l.
X 3.0-Coal/l.
3.0-Coal/l.
3.0-Coal/l.
3.0-Coal/l.
- X 3.0
4.0-Coal/2.
0-0 il
0-Oil
0-Oil
0-Oil
6-Oil
6-Oil
6-Oil
6-Oil
6-Oil
6-Oil
6-Oil
6-Oil
0-Oil
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
0.
0.
0.
0.
0.
0.
. 0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
Btu) p,,ri^
6 SCh Daily
6
6
6
6 S02 Daily
6
6
6 .
4 S02 Daily
4
4
4
4 S02 Daily
4
4
4
4
6
Dry
Dry
Dry
Dry
N/A
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Wet
Dry
Stoke!
Stoker
Seek or
N/A
Stoker
Stoker
Stoker
Pulver i r.
Pulver iz.
Pulver i^t
Pulvori;:
Pulveriz-L
Pulver ir,.
Pulveri.^
Cyclone
Pulver i z^-
_!/ SO2 limits apply only to solid or liquid fuels.
^/ NOX and TSP limits apply to all fuels.
-------
(22C)-1
Unit
Ut i 1 i ty/Powerplant Number
MINNESOTA
Moorhead Public Service Dept.
Moorhead 3
4
5
7
New Ulm Municipal Services
Now Ulm 1
3
4
'
Northern States Power
Black Dog 1
2
3
4
I High Bridge 3
4
5
6
1
A. S. King 1
1 Minnesota Valley 3
i
Control Equipment
Particulates so.
Eauip. Eff. (4) Equip. * Ef
ESP 99.5
2/ 2/
MC 93.0
ESP 99.0
ESP 99.0
ESP 97.8
ESP 99.0
ESP 99.0
ESP 99.0
ESP 99.0
ESP 99.0
ESP 99.0
ESP 99.0
1979 Fuel Consumption Estimated Actual
Coal Oil Gas 3
, , f , - Euibbioiii. (10 Tui.
f. (») Tons /lb. Sulf. (%) Ash (%) Barrels /qal. (%) MCF u/Ft . SO., NO -.:.:.'
0.4
128 "7 Mot
129.1'. 7,000 1.3 7.6 1.6 140,000 ~ Hot Available
63.1
13.5 - 239.7
1.2
33.7 - 457.5
47.7 12,500 1.9S 7.85 1.3 137,000 .35 844.7 985 Not Available
46.6 1.6 0.2
83.3 5.7 23.5
176.3 2.1 18.6
286.3 2.0 20.3
592.5 9,216 1.46 10.18 11.4 139,730 .54-' 62.5 987 15.36 5.33 .]..
182.2 7.7 106.3
301.1 10.3 105.4
557.2 9,266 1.4 9.8 27.6 139,583 0.5 or 274.0 985 14.0 3.7 .0-;
less
30.4 10.9V .y
1,269.8 9,004 1.3 10.0
47.8 9,641 1.5 9.6 0.4 139,664 0.5 or ' 1-0 994 1.14 .34 .a'
less
'; I/ A. S. King NOX emissions based on Stack Test.
| ?./ No equipment specified. Assume renoval efficiency of 93.0%.
V Source: Cost S Quality of Fuels for Electric Utility Plants - 1979.
O
z
o
1
o
3D
m
O '
-------
120h)c.l
ut i 1 i ty/1'owerplant
MINHI'-SOTA
Northern states Power
Riversidej/
Sherburne
Wi.lmar th
Unit
Number
Total 384.0
1 720.0
2 720.0
Total 1440.0
1 13.0
2 13.0
Total 26.0
Location
City
County
Minneapolis Hennepin
698.0 Becker Sherburne
700.0
1398.0
12.0 Manakato Blue Earth
13.0
25.0
County Attainment
Status
Currently En£orcod emissions Limits
SCL. - NO - TbP
(lbs/10 Btu) (IQs/lU Utu) (lbs/10 btu)
3.0-Coal/1.6-Oil None
3.0-Coal/1.6-Oil Hone
3.0-Coal/1.6-Oil None
.96-Coal/0.8-Oil 0.2
.96-Coal/0.8-Oil 0.2
4.0 None
4.0 None
0.4
0.4
0.4
.087
.087
0.6
0.6
Averag ing
Period
S02 Daily
S02 Daily
Boiler Dacn
Dry
Dry
Wet
Dry
Dry
Dry
Dry
Pulver i ?.-:.'.
Pulvor i zei
Cyclone
Pulver i zur
Pulverizer
Stoker
Stoker
V Riverside boilers associated with turbines 1(35 MW), 2(35 MW), 6(75 MW), and 8(239 MW).
2_/ SO2 limits apply only to solid and liquid fuels.
V NOX and TSP limits apply to all fuels.
o
Tl
z
o
o
30
TJ
O
a
m
O
-------
(22j)c.l
1979 Fuel Consumption Estimated Actual ifj'i j
Control Equipment Coal Oil Gas 3
i Un i t
Ut ility /Power pi ant Number
! 1TNNBSOTA
Northern States Power
"
Riverside
6V
7
' 8
Sherburne 1
2
wilmarth I
2
Part iculates
Equip.
ESP
ESP
ESP
MC/VE:JT.
MC/VENT.
MC/ESPi/
MC/ESP
Eft.
94.
94.
99.
99.
99.
85.
85.
i0 3 3 Sulf .' , tiuibbiui.s uu Juno'
(*) Eauip. Eff. (%) Tons /lb. Sulf. (%) Ash (*) Barrels /gal. (%) MCF /Ft. SO NO «:
0 173.0 ' 5.2 16.6
0 ,
9 557.7 . 1.0 - -
730.7 9,290 1.2 8.1 6.2 139,539 .5 or 16.6 969 19.1 7.5 0.3
less
0 LSS 50.0 2028.2 10.7
0 LSS 50.0 2375.6 9.7 22.3 39.6 3.3
4403.9 8,615 .74 9.22 20.4 139,697 .5 or
less
0/99.2
°/99-2 .53 .21 .!>
j / Riverside t's 6 and 7 will install scrubbers and baghouse in 1980.
i
/ Kilmarth Plant ESP's will be installed by 1981.
23.2 8,673
1.4
9.0
o
Tl
z
o
o
33
0
O
m
O
-------
O
TI
o
o
33
0
O
3]
m
O
(221)c.l
Currently Enforced Emissions Limits
Ut i 1 i ty/Powerplant Number
MINNESOTA
Otter Tail Power
Hoot Lake 1
2
3
Total
Owatonna Public Utility
Central!/ 4
5
6
Total
Plate
(MW)
8.
54.
75,
137.
4
6.
20.
30,
.0
.0
.0
.0
.0
.0
.0
.0
Dependable County Attainment 2/ 3/
(MW) City County SO, NO
a
61
79
148
4
6
20
30
.0 Fergus Falls Otter Tail
.0
.0
.0
.0 Owatonna Steele
.0
.0
.0
TSP (lbs/10 Btu) (lb£/
4.0-Coal/2.0-Oil'
4.0-Coal/2.0-Oil
4.0-Coal/2.0-Oil
2.0
2.0
2.0
None
None
None
None
None
None
.TSP -'
(Ibs/lU Btu) Period
0.6 S02 Daily
0.6
0.6-
0.4 S02 weekly
0.4
0.4
Bottom Firir.j
Dry
Dry
Dry
N/A
1I/A
ii/A
Stoker
Pulver iz
Pulver i^
N/A
N'/A
H/A
I/ Only Net Dependable Capacity data available on Central; these were used as nameplate capacity on chart.
2_/ S02 limits apply to solid and liquid fuels.
3/ NOX TSP limits apply to all fuels.
-------
Utility/Powerplant
Otter Tail Power
Hoot Lake
Owatonna Public Utility
Centra 1
Unit
Number
1
2
' 3
4
5
6
Control Equipment
Particulates "SO
Equip. Eff. (%) Equip.
MC/BH 90,5/99.9
ESP 99.0
ESP 99.0
1979 Fuel Consumption Estimated Actual i-J'rJ
Coal Oil . Gas 3
3 3 ( Sul£ '-- - E.aibiions (10 Toil:,)
2 Eff. (%) 1C Tons ULU/lb. Sulf. (%) Ash (%) 10 Barrels UtU /qai. (*) 10 MCF BLu/Ft.3 SO liO Tsr
13.5
139.0
- 337.6 ,
490.1 7,043 .69 7.02 1.6 140,OUOl/ 0 . 5V 5.1 4.4 0.4
18.0 374.1
24.9 23.2
47.1 544.3
99.6 150,500 1.4 1027.6 987 .24 1.9 .0:,
Hoot Lake Oil Data - estimate.
o
Tl
o
o
3
13
O
3D
m
O
-------
o
Tl
o
o
3D
0
O
m
a
(22p)c.l
Currently Enforced Emissions Limits
Plate Dependable
Unit Caoacitv Caoacitv Location
Utilitv/Poworplant Number
MINNESOTA
City of Rochester
Silver Lake 1
2
3
4
Total
United Power Assn.
Elk River 1
2
3
Total
Virginia, Minn. Dept. of Public Utilities
Virginia fl 2/ 5
6
7
8
9
Total
Willmar Municipal utilities
Willmar
:- 3
4
5
Total
(MK)
8
12
25
54
99
12
12
22
46
Is
18
8
4
30
.0
.0
.0
.0
.0
.0
.0
.0
.0
To
.0
.0
.0
.0
I/ Silver Lake Plant will switch to low sulfur coal
(MW)
8.
13.
25.
60.
106.
12.
11.
26.
49.
W.
15.
7.
4.
26.
in 1983 t
City County
0 Rochester Olmsted
0
0
0
0
1 Elk River Sherburne
8
0_
9
Virginia St. Louis
]
"o"
Willmar Kandiyoni
0
0
0
0
County Attainment SQ 3/
Status 2; x
V
TSP
- Averaq inq
SO-, NO TSP (lbs/10 Btu) (Ibs'/lO Utu) (lbs/10 Btu) Period
X-P 4
4
4
4
4
4
4
XX-P 4
4
4
4
4
_
4
4
4
'
. Oi/
.0
.0
.0
.O-Coal/2. 0-Oil
.O-Coal/2. 0-Oil
.O-Coal/2. 0-Oil
.0
.0
.0
.0
.0
.0
.0
.0
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
.6 SO, Daily
.6 2
.6
.6
.6
6 SOj Daily
.6
.36 SO2 Daily
.36
.36
.36
.36
.6 s°2 Daily
.6
.6
Boiler Dat.-i
Bottom firm.;
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
N/A
N/A
N/A
Pulver izt :
Pulver ir.oi
Pulver i/.^i
Pulver iz^-i
Stoker
Stoker
Pulviver
Stoker
Stoker
Stoker
Pulver i;'.'-.
Pulver izv:
Stoker
Stoker
Stoker
2/ Virginia boilers 5-9 associated with turbines 1(5 MW) , 2(1 MW) , 3(2*MW), 4 (3 MW) , 5(8 MW) and 6 (19 MW) .
3_/ SO2 limits apply only to solid and liquid fuels.
4_/ NOX and TS? limits apply to all fuels.
-------
<22c)c.l
1979 Fuel Consumption
Estimated Actual !-->"
Control Equipment Coal Oil .. . Gas .,__,. _ ,,n3
Unit
Ut ility/Pouerplant Number
HrriNESOTA
City of Rochester
Silver Lake 1
2
3
4
United Power Assn.
Elk River 1
2
3
Virginia, Minn. Dept. of Public Utilit
Virginia «1 5
6
7
8
9
Willmar Municipal utilities
Willmar
3
4
5
Particulates
Equip.
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ies
KC
MC
MC
ESP
ESP
MC
MC
MC
Eff.
98.
97.
98.
99.
99.
99.
99.
80.
80.
85.
99.
JS)
0
5
6
0
8
8
8
0
0
0
0
99.0
99.
99.
99.
0
0
0
_ - -. "I, If 1 Ulllaamno VJ-- .
2 10 Dtu 10 Dtu auj.L. ,Q^ Q -.
Equip. Eff. (%) Tons /lb. Sulf. (%) Ash (%) Barrels /qkl. (*) MCF /Ft. SO, HO T---
12.0. 2.5
19.9 21.8
46.0 . 76.7
91.2 194.7
169.1 12,363 2.09 8.24 295.7 1,010 6.7 1.5 0.3
15.1
11.2
30.4 1.17
56.7 8,574 .64 9.8 1.17 138,800 0.5 Not Available
2.3 -
2.1
27.5
37.5 . ' 173.6
57.4
126.8 . 8,780 .82 8.2 173.6 1,000 2.4 .04 0.44
55.3
4.2
1.0
60.5 8,756 . .8 8.4 1.0 0.4 1.3
o
TI
z
o
o
3
O
O
m
D
-------
1979 Fuel Consumption
Estimated Actual 1979
Control Equipment
Unit
ur. i li ty/ Powerplant Number
) (Cont.)
ordinal Operating Co.
Cardinal 1
2
3
'incinnati Gas s. Electric
Ueokjord 1
2
3
4
5
6
Miami Fort 3
4
5
6
7
8
'levoland Electric Ilium.
Ashtabula '. 1
2
'-.3
4 '
5
6
7
8
9
10
11
Particulates
Equip.
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
Eff.
(%) Equip
95.0/99.4
95
98
99
99
99
99
99
99
99
99
99
99
95
85
85
99
99
.0/99.4
8/
.5
.5
.5
.5
.5
.6
.5
.5
.5
.5
.0
.0
.0
.5
.6
so- io3
. .' Eff. (%) Ton
1,272.
1,425.
1,910.
4,608.
305.
254.
310.
371.
644.
571.
2,457.
129.
394.
1,253.
970.
2,747.
-
_
_
_
_
690.
103.
136.
95.
83.
Coal
Oil Gas 3
is Dtu/lb. Sulf. (%) Ash (%) 1 Barrels tu /qal. i (I) 10 MCF Btu/Ft.3 SO_ NO TdP"
0
7
8
5 . 11,543 2.0 14.7
5
5
3
6
0
5
4 10,753 2.49 17.92
1
6
3
2
2 11,371 2.08 13.70
7 l
6
1
2
2 .
62
U2
38
183
12
11
14
11
22
3
75
242
140
28
11
69
33
538
60
47
48
58
49
46
6
0
0
0
0
.5
.6
.1
.2 139,322 0.28 184.3 41.5 51.5
.7
.7
.2
.7
.5
.1
.9 138,015 0.24 122.4 22.1 3.5
.1
.9
.4
.1
.1
.7
.8 138,061 0.24 114.2 24.7 3.0
.7
.1
.6
.5
.9
.0
.0
.8
.7
.4
.3
1,108.8
11,789
4.1
14.0
319.0
150,666
1.5
88.0
11.0
1.5
o
-n
z
o
o
3
0
O
3D
m
O
-------
<34)c
Utility/Powerplnnt
Cardinal
Cincinnati Gas &'Electric
Beckjord
Miami Fort
Cieveland Electric Ilium
Ashtabula
Unit
Number
1
2
3
Total
1
2
3
4
5
6
Total
3
4
5
6
7
8
Total
1
2
3
4
5
6
7/5
8/6
9/7
10/3
11/9
Total
Name
Plate
Capacity
(KW)
625.0
625.0
620.0
1,U70.0
115.0
112.5
125.0
163.2
244.8
460.8
1,221.3
65.0
65.0
100.0
163.2
557.1
557.0
1,507.3
100.0
100.0
256.0
46.0
46.0
46.0
46.0
640.0
Net
Dependable
Capacity Location
(MW) City County
625.0 Billiant Jefferson
590.0
625.0
1,840.0
98.0 New Richmond Clermont
101.0
128.0
155.0
246.0
434.0
1,162.0
61.5 North Bend Hamilton
61.5
85.0
16 9 . 0
500.0
500.0 '
1,377.0
Ashtabula Ashtabula
111.0
116.0
256.0+
47.0
47.0
47-.0
47.0
671.0
Currently KnEorced Em is a ions __L_inutr;
, so.
StriLun 2
f
HO
t
TUI'
c.
SO, NO TS1> (Ibs/lo"l3tu) (lbs/10ubtu) (lbs/10uutu)
1
X-P - X-P 7
7
2
4
X-P - XX-P 1
1
1
1
7
7
2
X-P - X-P 0
0
3
3
5
.08
.08 .
.00
,7o plant
.84
.84
.84
.84
.4
.4
.02 plant
.5
.5
.3
.3
.5
1.2-C/0.8-0
- - X-P 2
2
2
2
2
2
9
8
8
8
8
.4
.4
.4
.4
.4
.4
.1
.2
.2
.2
.2
1
None
None
None
Hone
None
None
None
None
None
None
None
None
None
None
0.7-C/0.3-O
None
None
None
None
None
None
None
None
None
None
None
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1-
0.1
0.1
0.1
Avcrci'j iny ito i
Pec iod Bot com Pi r i ng
30 days Dry
Dry
Dry
30 days Dry
Dry
Dry
Dry
Dry
Dry
30 days NA
NA
Dry
Dry
Dry
Dry
30 days NA
NA
NA
NA
NA
NA
Dry
Dry
Dry
Dry
Dry
Pulver i zer
Pulver i zor
Pulverizer
Pulver izer
Pulver izer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Front
Front
Pulverizer
Pulverizer
Pulverizer
Pulver izer
Opp. wall
'Opp. Wall
Opp. Wall
Opp. Wall
Opp. wall
Opp. wall
Pulverizer
Pulverizer
Pulverizer
Pulver izer
Pulverizer
Units 1, 2, 3 = DOE units 1 and 2
Units 4, 5, 6 = DOE units 3 and 4
Unit 7 = DUli unit 5 (Net depend, rating not available from GURF)
Unit 8-11 = DOE units 6-9
I/ Emissions limits apply to all fuels.
O
o
o
30
TJ
O
3
m
-------
[ Control Equipment
.It ill ty/Powcrplant
I DAKOTA (Cont'd)
f I-T in Electric Power Coop
Lei and Olds
Meal
* iop Power Association
j dial Creek
I
Milton Young
.tntana-Dakota Utilities
llcskett
nited Power Association
Stanton
Source: DOE/EIA Cost e, Qu
Unit
Number
1
2
1
2 '
1
1
2
1
2
1
ality of
Particulates SO.
Equip.
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP/MC
ESP/MC
ESP
Fuels for
Eft.
99
99
98
98
99
99
99
99
97
98
(%) Equip. * Eff. (%)
.5
.1
.0
.0
.5' LSS 90.0
.8
.9
.0/90.0
.0/88.0
.0
1979 Fuel Consumption Estimated Actual 1978
C0al Oil Gas Emissions <103Tons)
10 Tons BtU/lb. Sulf. (%) Ash (%) 10 Barrels Bt" /gal. {%) 10 MCF Btu/Ft.3 SO, NO TSP
1,127.8 4.8 0.3 16.8 7.5
2,301.5 25.8 Not 1.2 26.8 12.4
3,429.3 .6,653 0.6 13.9 30.6 140 ,000 (est . ) Avail. 1.5 43.6 19.9
Not
218.5 6,557 0.4 36.8 0.7 140 ,000 (est. ) Avail. 1.2 1.5 l.C
l,147.7l/ 6,500 0.65 9.0 Not Available
Not Available
4,016.6 6,736 0.65 8.3 2,083.3 140,000 0.3
150.8
330.8
481.5 6,977 0.7 7.5, 6.5 1.4 0.1
729.1 6,870 0.63 10.5 9.7 137,550 0.5 9.2 66.0 1.0
Electric Utilities - 1979.
o
Tl
z
o
o
DO
m
O
-------
(331C.1
I/
Plate Dependable
Unit Capacity Capacity Location
Ut ill tv/Powerplant Number (MW) (MW) City County
NORTH DAKOTA
Bnr.in Electric Power coop
Leland Olds 1 216.7 217.0 Stanton Mercer
2 440.0 433.0
Total 656.7 650.0
Noal 1 15.0 18.0 Velva Mcllenry
2 15.0 18.0
Total 30.0 36.0
Cooperative Power Assn.
Coal Creek 1 550.0 490.0 Underwood McLean
Milton Young 1 265.5 240.0 Center Oliver
2 454.0 408.0
Total 719.5 648.0
Montana-Dakota utilities
Heskett 1 25.0 28.0 Mandan Morton
2 75.0 72.0
Total 100.0 100.0
United Power Association
Stanton . 1 172.0 167.0 Stanton Mercer
I/ Emissions Standards apply to all fuels, unless otherwise noted.
O
-n
z
o
o
a
o
O
a
m
o
county Attainment ^ TTT: ij^-p
SO, NO TSP (lbs/10 Btu) (lbs/10 Btu) (Ibs/LO Btu) Period Bottom Firir.o
t
- 3.0 None 0.8 SO2-20 min. Dry Pulverizer
3.0 None 0.3 TSP - 1 hr. Wet Cyclone
- - - 3.0 None 0.8 SO2-20 min. Dry Pulverizer
3.0 None 0.8 TSP - 1 hr. Dry Pulverizer
- - - 1.2 0.6 0.1 SO2-20 min. Dry Pulverizer
TSP/NOX -
- 3.0 None 0.8 . 1 hr. Not Available
1.2-r. lignite 0.6-lignite 0.1 . Not Available
0. 3- oil 0.3-oil
- - 3.0 None 0.8 SO2-20 min. Dry Stoker
3.0 None u.fc TSP - 1 hr. Dry stoker
- - - 3.0 None 0.8 SCb-20 min.
TSP - 1 hr. Dry Pulverizer
-------
J2f.l)c.l
1979 Fuel Consumption
Control Equipment
Unit
Ut i 1 i ty/Powcrplant Number
Oicril CAROLINA (Cont'd)
Duke Power Co.
Allen 1
2
3
4
5
Belews Creek 1
2
Buck ' 5
6
7
8
9
Cliffsicie 1
2
3
4
5
Dan River ' - . . 1
2
3
Marshall . 1
2
3
4
Riverbend 4
5
6
7
Particulates S0_
Eg u i p .
MC/ESP
MC/ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
' ESP
ESP
ESP
ESP
ESP
ESP
ESP/MC
ESP/MC
ESP
ESP
ESP
ESP
ESP
ESP
Eff.
85
85
99
99
99
99
99
99
99
99
99
99
99
99
99
99
99
99
(%) Equip. '
.0/99.0
.0/99.0
.5
.5
.5
.7
.7
.0
.0
.0
.0
.0
.0
.0
.0
.0
.5
.0
99.0
99
99
99
99
99
99
99
99
99
.2
.0/85.0
.0/85.0
.7
.7
.0
.0
.1
.1
io3
Eff. (4) Ton:
195
234
522
568
548
2,069
1,995
2,634
4,630
29
30
23
292
247
622
28
28
104
90
1,092
1,345
82
77
269
429
721
765
1,309
1,377
4,173
165
153
218
171
709
Coal
s Btu/lb. Sulf. (%) Ash (%) 10Barrels
.9
.6
.3
.5
.5
.8 12,200
.7
.3
.0 12,028
.0
.2
.6
.1
.2
.1 12,041
.5
.9
.8
.9
.6
.7 11,990
.4
.7
.1
.1 11,908
.2
.6
.0
.9
.7 12,082
.8
.6
.8
.8
.9 11,794
5
5
5
6
5
.91 12.19 28
19
12
0.89 11.38 32
2
2
2
6
7
1.12 12.18 20
2
2
4
3
17
1.34 14.86 31
5
5
7
0.94 13.18 18
0
0
11
8
1.02 12.34 19
4
5
6
6
1.2 12.26 22
.9
.4
.6
.0
.5
.4
.9
_._4_
.2
.1
.2
.3
.5
.6
.7
.7
.9
.5
.9
^2
.6
.3
.7
.5
.6
.1
.5
.0
.2
.9
.3
.1
.8
.4
.5
Oil Gas
BtU/,ai. 'a,' 10^P Btu/pt3
138,190 I/ 0.2
138,193 I/ 0.2
137,057 I/ 0.2
138,196 I/ 0.2
136, 398 I/ 0.2
138,172 0.2
137,869 0.2
Estimated Actual ll.>7<
Emissions (10 Tons)
SO,
37.7 18.6 5.5
82.4 41.7 8. US
13.9 5.6 1.63
36.1 12.1 3.86
8.1 3.9 0.89
85.1 37.6 11.5
17.0 6.4 i.-l
Source: DOE/EIA Cost and Quality of Fuels for Electric Utility Plants - 1979, June, 1980.
O
in
o
o
3
TJ
O
m
o
-------
(32d)c
Uti11ty/Powerplant
NORTH CAROLINA (Cont'd)
Duke Power Co.
Allen
Belews Creek
Cliffside
Dan River
Marshall
Riverbend
Unit
Number
1
2
3
4
5
Total
1
2
Total
5/3
6/3
7/ 4
8/ 5
9/ 6
1
2
3'
4
5
Total
1
2
3
Total
1
2
3
4
Total
4
5
6 .
7
Total
Name
Plate
Capacity
(MW)
165.0
165.0
275.0
275-.0
275.0
1,155.0
1,080.0
1,080.0
2,160.0
80.0
40.0
125.0
125.0
370.0
41.0
40.0
65.0
65.0
571.0
782.0
70.0
70.0
150.0
290.0
4
350.0
350.0
650.0
650.0
2,000.0
100.0
100.0
133.0
133.0
466.0
Net
Dependa
Capaci
(MW)
Emissions Limits
ble County Attainment
ty Location Status
so|/
NO
TbP
Citv County SO_ NO TSP (lbs/10 Btu) (lbs/10 Btu) 1 (lbs/10
162.0 Belmont Gaston -
162.
272.
272.
272.
1,140.
0
0
0
0
0
1,140.0 Walnut Cove Stokes -
1,140.
2,280.
66.
34.
103.
103.
306.
38.
38.
63.
63.
569.
771.
69.
69.
146.
285.
356.
356.
656.
656.
2,024.
73.
73.
95.
95.
336.
0_
0
0 Spencer Rowan - -
0
0
0
0
0 Cliffside Rutherford -
0
0
0
0
0
0 Eden Rockingham -
0
0
0
1
0 Terrell Catawba -
0
0
0
0
0 Mt. Holly Gaston - - -
0
0
0
0
2
2
2
2
2
2
2
2
2
2
2
2
2
2
2
2
2
2
2
2
2
2
2
2
2
2
2
2
.3
.3
.3
.3
.3
.3
.3
.3
.3
.3
.3
.3
.3
.3
.3
.3
.3
.3
.3
.3
.3
.3
.3
.3
.3
.3
.3
.3
0.6-Oil/l
0.6-Oil/l
0.6-Oil/l
0.6-Oil/l
0.6-Oil/l
0.6-Oil/l
0.6-Oil/l
0.6-Oil/l
0.6-Oil/l
0.6-Oil/l
0.6-Oil/l
0.6-Oil/l
0.6-Oil/l
0.6-Oil/l
0.6-Oil/l
0.6-Oil/l
0.6-Oil/l
0.6-Oil/l
0.6-Oil/l
0.6-Oil/l
0.6-Oil/l
0.6-Oil/l
0.6-Oil/l
0.6-Oil/l
0.6-Oil/l
0.6-Oil/l
0.6-Oil/l
0.6-Oil/l
.3 -Coal
.3 -Coal
.3-Coal
.3 -Coal
.3 -Coal
.3-Coal
.3 -Coal
.3-Coal
.3-Coal
.3-Coal
.3-Coal
.3-Coal
.3-Coal
.3-Coal
.3-Coal
.3-Coal
.3-Coal
.3-Coal
.3-Coal
.3-Coal
. 3-Coal
.3-Coal
.3-Coal
.3-Coal
.3-Coal
.3-Coal
.3-Coal
.3-Coal
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
,0
0
0
0
0
0
0
0
y
Av^rng i nfj
ttt-"} Period
.25* i hr.
.25*
.25*
.25*
.25*
-25*" l hr.
.25*
.23* i hr.
.23*
.23*
.20*
.20*
.23* 1 hr.
.23*
.20*
.20*
.25*
-20* 1 hr.
.20*
.25*
25* i hr.
.25*
.25*
.25*
20* i hr.
.20*
.20*
.20*
Boiler Data
Bottom Fi ring
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Pu Iver ize
Pu Ivor 120
Pu Iver i ze
?u Iver ize
Pulver i ze
Pulver i zer
Pulverizer
Pulverizer
Pulverizer
Pulver i zer
Pulver izer
Pulverizer
Pulver i zer
Pulverizer
Pu Iver izer
Pulverizer
Pulver i zer
Pulver izer
Pulverizer
Pulver i zer
Pu Iver izer
Pulverizer
Pulverizer
Pulverizer
Pu Iver izer
Pulverizer
Pulverizer
Pulverizer
* Operating at variance from 1979-1982. New TSP limit will be set in 1982.9
I/ SO^ and TSP emissions limits apply to all fuels
o
Tl
o
o
3
o
O
3
m
O
-------
Unit
Control Equipment
Particulates SO_
lit i I i ty/ Power pi ant Number Equip.
11 CAROLINA (Conc'd)
J'lrul inn Power & Light
Asiiovi lie 1
2
I
Cape Fear 5
6
Lee 1
! 2
I 3
\ Roxboro 1
2
3
-Sutton 1
2
3
Woatherspoon . 1
2
3 .
ESP
ESP
ESP
ESP
ESP
MC/ESP
ESP
ESP
ESP
ESP
ESP
MC/ESP
I-C/ESP
ESP
ESP
ESP
Eff. (%) Equip.
99.2
99.0
99.4
99.5
99.3
85.0/99.2
99.4
99.6
99.5
99.3
99.0
85.0/99.3
85.0/99.0
99.3
99.3
99.3
1979 Fuel Consumption
Coal Oil .Gas
103 BLu 103 BLU iSulf. 3
Eff. (%) iuTons *"""/lb. Sulf. (%) 'Ash (!) ''"Barrels *""" /gal. (4) "MCF
485.0
423.0
908.0 12,342 1.0 12.2 22.0 138,000 0.2
248.0
313.0
561.0 12,295 0.98 12.1 29.0 138,000 0.2
89.0
99.0
558.0
776.0 12,131 0.94 11.7 38.0 138,000 0.2
774.0
1,481.0
1,465.0
3,720.0 12,282 0.71 11.5.
213.0
238.0
398.0
849.0 12,257 0.91 10.6 55.0 138,000 0.2
79.0
122.0
91.0
Estimated Actual 1979
3
DtU/Ft.3 SO, NO TSP
20.0 8.2 1.0
11.2 5.0 0.1
14.7 10.4 4.3
29.8 33.5 46.3
17.2 11.2 . 2.2
2S2.0 12,407
0.92 11.1
35.0 138,000 0.2
5.6 2.6 0.1
o
Tl
o
o
3
O
O
3D
-------
(32c).1
Ut i 1 i ty/ Power oljnt
NORTH CAROLINA
Carolina Power & Light
Asheville
Cspe Fear
Lee
Roxboro
Sutton
Moatherspoo'n-..
Unit
Number
1
2
Total
3 .
4
5
6
Total
1
2
3
Total
1
2
3
Total
1
2
3
Total
1 .
2
3
N.im
e
Plato
Caoacity
(KK)
206
207
113
31
31
140
187
391
75
75
252
402
410
657
745
1,813
112
446
112
671
46
46
73
.6
.0
.6
.3
.3
.6
.9
.1
.0
.0
.4
.4
.9
.0
.2
.1
.5
.6
.5
.6
.0
.0
.5
Not
Currently
Dependable County Attainment
Caoacity Location Status -
SO,-
y
Enforced Emissions 1.
NO
inn t
(MW) City County SO, NO TSP (lbs/10 Btu) (Ibs/ilO Btu) (IbE/lu
198
194
392
32
32
143
173
381
79
76
252
407
385
670
650
1,705
97
385
106
588
49
49
78
.0 Skyland Buncombe -
.0
.0
.5 Monaure Chatham -
.5
.0
.0
.0
.0 Goldsboro Wayne -
.0
.0
.0
.0 Roxboro Person - - -
.0
.0
'0
.0 Wilmington New Hanover -
.0
.0
.0
.0 Lumber ton Robeson - - -
.0
.0
2
2
2
' 2
2
2
2
2
2
2
2
2
2
2
2
2
2
2
.3
.3
.3
.3
.3
.3
.3
.3
.3
.3
.3
.3
.3
.3
.3
.3
.3
.3
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
.6-Oil/l
. 6-Oil/l
.6-Oil/l
.6-Oil/l
.6-Oil/l
.6-Oil/l
.6-Oil/l
.6-Oil/l
.6-Oil/l
.6-Oil/l
.6-Oil/l
.6-011/1
.6-011/1
.6-Oil/l
.6-Oil/l
.6-Oil/l
.6-Oil/l
.6-Oil/l
.3-Coal
.3-Coal
.3-Coi.l
.3-Coal
.3-Coal
.3-Coal
.3-Coal
.3-Coal
.3-Coal
.3-Coal
.3-Coal
.3-Coal
.3-Coal
.3-Coal
.3-Coal
.3-Coal
.3-Coal
.3-Coal
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
;J
- Averaging Boiler Data
litu)
25
25
25
25
25
25
25
25
25 '
25
25
25
25
25
25
20
20
25
Period Bottom Firing
1 hr. Dry
1 hr. Dry
Dry
Dry
Dry
1 hr. Dry
Dry
Wet
1 hr. Dry
Dry
Dry
1 hr. Dry
Dry
Dry
1 hr. Dry
Dry
Dry
Pu Iver i zer
Pu Iver i zer
Pulverizer
Pu Iver i zer
Pulver izer
Pu Iver izer
Pulverizer
Pu Iver izer
Pulver i zer
Pulverizer
Pulver i zer
Pulverizer
Pulverizer
Pulver izer
Pulver i zer
Pulverizer
Pulver i zer
Total
165.5
176.0
i/ SO_ and TSP emissions limits apply to all fuels
O
Tl
o
o
DO
o
O
30
m
O
-------
1979 Fuel Consumption
Control Equiomont
Ut il i ty/Powerpj^ant
^;w_YOR£ (Cont.)
Rochester Gas & Electric
Rochester f3
Unit
Nunh er
Participates
Rochester J7
1
2
3
4
7
8
12
1
2
3
4
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
94
94
9-1
94
95
95
97
97
97
97
97
.0-95
.0-95
.0-95
.0-95
.0
.0
.5
.5
.5
.5
.5
.0
.0
.0
.0
E£f. (»)
197.3
197.3
131.2
75.2
147.2
211.7
565.3
Coal
Suie._[%) Ash (%)
12,610
12,460
2.8
2.37
11.0
10J
52.8
71.0
131.5
124.4
203.9
155.2
1.8
738.9
4.1
4.9
1.9
4.6
15.5
Oil
Gas
io3
BtU/ft.3
Estimated Actual 1979
Emissions (10 Ton:;)
SO, l.'O TSP
149,300
137,300
1.94
0.21
16.0
26.3
1.8
0.6
o
Tl
o
o
3
0
O
31
-------
(31t)c.l
Name
Unit
Ut i I i tv/Powerplant Number
NKW YORK (Cont.)
Rochester Gas & Electric
Rochester i 32/ 1
2
3
4
7
8
12
Rochester ft7 1
2
3
4
Capacity
(MW)
114.
81.
196.
46.
62.
62.
81.
252.
6 '
6
2
0
5
5
6
6
Net
Capacity Location
(MW)
126.
80.
206.
50.
65.
65.
80.
260.
City County
.Rochester Monroe
0
0
0
0 Rochester Monroe
0
0
0
0
. Currently Enforced Emissions Limits -*
Status 2
N0u
SO., NO TSP (lbs/10 Btu) (lbs/10 Btu)
- - - 2
2
2
2
2
2
5
3
- 3
3
3
3
.0% S
.04 S
.0% S
.04 S
.04 S
.0%S
6-
-------
Urjc.l
Control Equipment - Coal
Unit Particulates . SO,, 3
Utilitj^/Powerplant Number Eouip. Eff. (%) Equip_. * Eff. (%) Tons U/lb. Sulf. (%') Ash
KW YORK (Cont . )
Niagara Mohawk Power
Dunkirk 1 ESP 99.5 218.7
2 ESP 99.5 213.9
. 3 ESP 99.5 . 559.1
4 ESP 99.5 467.2 .
1979 Fuel Consumption Estimated Actual 1979
Oil . r,,ti 3
103 Btu ' Sulf- 103 Btu 3
(%) Barrels /gal. (») MCF /Ft. SO, NO TSP
1,467.0 12,641 2.15 11.11 63.1 13.2 0.86
C.R. Huntley 63 ESP 99.5 200.5
64 ESP 99.5 217.1
65 ESP 99.5 168.6
66 ESP 99.5 AC!/ 90.0 186.4
67 ESP 99.5 380.0
68 ESP 99.5 420.0
1,605.0 12,788 1.61 . 9.27 51.68 19.26 0.94
Oswego 1 MC 25.0
2 MC 25.0
3 MC 25.0
4 MC 25.0 '
5 ESP 98.5
i
j Orange & Rockland Util.
{ Bowline Point ' 1
'; ' 2
j '- .
j Lovett 3 HC 85.0
4 ESP 95.0
5 ESP 95.0 ' >
Power Authority State of NY
Astoria 1
I/ Source: Cost & Quality for Fuels for Electric Utility Plants-1979.
' V Huntley Unit 66 will retrofit aqueous carbonate (dry) scrubbers in 1982.
|
O
* z
0
O
3
TJ
O
3
rn
°
547.6
511.7
599.7
653.1
5,788.4
8,455.0 148,127 2.51 73.98 18.2 2.63
2,103.5 . 134.8
3,364.8 l,fi55.9
b,46U.J 145,748 0.2b) 1,960.7 1,028 4.76 5.04 0.7y
22-5 18.1
477-2 4,647.7
568-9 5,159.7
1,068.6 144,844 0.28 9,835.2 1,031 0.90 2.14 0.23
4,143.2 145,503l/ 0.24 170.9 1,029 4.25 9.11 0.22
.
t
-------
(Jlp)c.l
Utility/Powerplant
NEW YORK (Cont.)
Niagara Mohawk Power
Dunkirk
C.R. Huntley
Oswego
Orange & Rockland Util.
Bowline Point
Name Net
Plate Dependable
Unit Capacity Capacity
Number (KM) (KW)
100.0
100.0
220.0
220.0
640.0
91.0
100.0
100.0
100.0
220.0
220.0
831.0
90.0
90.0
95.0 :
100.0
850.0
1,225.0
County Attainment Currently linforcea Emissions Limits*/
1
2
3
4
Total
63
64
65
66
67
68
Total
1
2
3
4
5
Total
1
2
Total
*1
*2
3
4
5
Total
96
96
218
218
628
92
.0
.0
.0
.0
.0
.0
100.0
100
100
218
218
828
92
92
92
100
902
1,278
621
621
1,242
23
23
69
197
202
514
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0 '
.0
.0
Location
Status
City
County
SO0
Dunkirk
Tanawanda
Chautauqua
Erie
Oswego
Oswego
559.0 West Rockland
559.0 Haverstraw
1,118.0
19.0 Stony Point Rockland
20.0
68.0
18 7.. 0
202.0
496.0
so_
(lbs/10
3.
3.
3.
3.
2.
2.
2.
2.
2.
2.
1.
1.
1.
1.
1.
0.
0.
0.
0.
0.
0.
0.
6
Btu)
8
8
8
8
8
8
8
8
8
8
7» S
7* S
7% S
7% S
7% S
6%
6»-(v)
37 %
37 %
37 %
37 %
37 %
NO
(lbs/10 Btu)
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
TSP
(lbs/10
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
Averaaina Boiler Data
6Btu)
23
23
17
17
17
17
17
17
17
17
1
1
1
1
1
1
1
1
1
1
1
1
Period Bottom
TSP - 1 hr. Dry
SO2 - 3 months Dry
Dry
Dry
TSP - 1 hr .
SO2 - 3 months
Dry
Dry
TSP - 1 hr. N/A
Sulfur - 3 month N/A
N/A
N/A
N/A
TSP - 1 hr. tJ/A
Sulfur - 1 month N/A
TSP - 1 hr. Dry
Sulfur - 1 month Dry
Dry
Dry
Dry
Fi ring
Pulver izer
Pulver izer
Pulver izer
Pulverizer
Pulve izer
Pulve izer
Pulve izer
Pulve izer
Pulve izer
Pulve izer
Front
Fror.t
Front
Front
Front
Tangential
Opp . Wall
Pulv/Front
Pulv/Front
Pulv/Tan
Pulv/Front
Fulv/Front
Power Authority State of NY
Astoria 1
1,551.0 737.0 Long Island Queens
I/ Sulfur, SO2 and TSP standards apply only to coal and oil.
(v) - variance
Capacity data only available for units 1 and 2.
o
0.3 % S
0.1
TSP - 1 hr.
Sulfur - 1 month
N/A .N/A
o
o
a
o
O
3D
5
m
O
-------
(jln)c.1
Control Equipment
Unit Participates SO,,
Ut i 1 i ty/Powerplant
NKW YORK (Cont.)
N.Y. State Elec. & Gas
Greenr idge
Hickling Station
Jennison
Milliken
Niagara Mohawk Power
Albany
* Units 4, 5 & 6 have SO3
0
n
z
o
o
g
0
3J
-\
m
O
Number Equip.
1/1 MC/ESP
2/1 -
3/2 MC/ESP
*4/2 MC/ESP
*5 MC/ESP
*6 ESP
1/1 MC/ESP
2/1 MC/ESP
3/2 MC/ESP
4/2 MC/ESP
1/1 MC/ESP
2/1 MC/ESP
3/2 MC/ESP
4/2 MC/ESP
1 ESP
2 ESP
'--'..
1 MC
2 MC
3 MC
4 MC
flue gas conditioner.
*
Eff. (») Equip. ' Eff. (»)
80.0/99.8
- -
76.4/99.8
80.0/98.0
80.0/98.0
98.0
90.0/99.5
90..0/99.5
93.5/99.5
93.5/99.5
92.0/99.5
92.0/99.5
92.0/99.5
92.0/99.5
99.0
99.0
33.0
33.0
33.0 - - .
33.0 - '
"
, '
*
1979 Fuel Consumption , Estimated Actual r,-7
Coal Oil , Gas . . no3T
103 Btu 103 Btu Suit". .3 ,
Tons /lb. Sulf. ('*) Ash (%) Barrels /qal. (%) MCF /Ft. so, NO .".'; :'
49.8 10.5
1. 1
49.2. 4.1
159.1 9.7
I 1
296.8 5.5
554.8 11,561 2.0 16.4 29.8 137,500 0.2 or 22.19 4.99 1...
less
74.9
80.0
91.9
95.8
342.6 10,611 1.07 24.1 7-54 3.08 0.=
74.2
73.7
73.9 ' .
69.1
290.9 10,294 0.9 24.5 5.24 2.62 0.4
316.0 3.6
448.1 .' 1.8 Not
764.1 11,431 1.8 17.0 5.5 136,934 Avail. 27.51 6.88 l.U-
796.3
i 910.7
943.8
612.9
3,255.0 148,307 1.98 21.82 7.16 l.U
1
4
-------
(311JC.I
Ut 11 ity/Powerplant
NEW YORK (Cont.)
H.Y. State Eiec. & Gas (Cone.)
Greeneidge
Hickling Station
Jennison
Milliken
Niagara Mohawk Power
Albany
Total 400.0 ' 400.0.
I/ Sulfur, SO2 and TSP limits apply only to coal and oil.
Unit
Number
1/1
2/1
3/2
4/2
5/3
6/4
Total
1/1
2/1
3/2
4/2
Total
1
2
3
4
Total
1
2
Total
1
2
3
4
Name
Plate
Capacity
(MW)
20
20
50
80
170
30
40
TO"
30
30
30
30
60
135
135
270
100
100
100
100
.0
.0
.0
.0
.0
.0
.0
To"
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
Net
Dependable
Capacity Location
(MW) City County
24
23
55
103
205
33
50
83
35
35
38
. 38
73
143
147
290
100
100
100
100
.0 Dresden Yates
.0
.0
.0
.0
.0 East Corning steuben
.0
To
.0 Bainbridge Chenango
.0
.0 ..
.0
.0
.0 Ludlowville Tompkins
.0 '
.0
.0 Albany Albany
0
.0
.0
Status
Currently Ent'orced Emissions Limits -/
S°2
-x-^-
. SO2 NO' TSP _(l.bs/10e>Btu) (lbs/106Btu)
- - - 3
3
3
3
3
3
- - - 3
3
3
3
- - - 3
3
3
3
- - - 3
3
XX-P 2
2
2
2
.8-C/2SS-O
.8-C/24S-O
.8-C/24S-0
.8-C/2%S-O
.8-C/2SS-0
.8-C/2%S-0
.8
.8
.8
.8
.8
.8
.8
.8
.8-C/2%-0
.8-C/2%-0
.0%s
.0%s
.0%s
.0%s
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
TSP
Avoraq inq Boiler D.it.i
(lbs/10btltu) Period Uottom firing
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
.1
.1
.1
.1
.1
.1
.25
.25
.25
.25
.1
.1
.1
.1
.1
.1
.1
.1
.1 .
.1
TSP - 1 hr. Dry
SC>2 - 3 months Dry
Dry
Dry
Dry
Dry
TSP - 1 hr. Dry
SC>2 - 3 months Dry
Dry
Dry
TSP - 1 hr. Dry
SO2 - 3 months Dry
Dry
Dry
TSP - 1 hr. Dry
SO2 - 3 months Dry
TSP - 1 hr. N/A
Sulfur - 1 month N/A
N/A
N/A
Pulverizer
Pu Iver izer
Pulver izer
Pulverizer
pulverizer
Pulverizer,
Stoker
Stoker
Stoker
Stoker
Stoker
Stoker
Stoker
Stoker
Pulverizer
Pulverizer
Tangential
Tangential
Tangential
Tangential
O
Tl
z
o
O
30
o
O
DO
s
o
-------
.!
Ut i li ty/Powerplant
1
j YOKK (Cont.)
f i ty of Jamestown
Carlson
I
i
,l
r.oo9 Island Light i ng
B.F. Barrett
!
Kar Rock aw ay
|{
(Hen wood
i
iiorthport
i
j For t Jefferson
ij
1
') I.Y. State Electric & Gas
I Goudey
1
]'
1
j '(os Cond. System.
i< Source: Cost & Quality of
ij
1
1
s
j 1
i 1
1 o
! 5
1979 Fuel Consumption
Control Equipment Coal Oil ,Gas
Unlt Particulates SO, 3 .3 I Sulf. 1
Number Equip. Eff. (%) Equip. " Eff. (*) Tons U/lb. Sulf. (S) 'Ash (%) Barrels " /gal. (%) 10 MCF Btu/Ft.
3 ESP 99.0+
4 ESP 99.0+
5 ESP 99.0+
6 ESP 99.0+
84.0 12,000{est.) 2.16I/ Not Avail.
1 ESP 97.9 352.0 4,587.0
2 ESP 95.0 465.0 4,829.0
816.0 146,099 0.3 9,416.0 1,030
4 IC/ESP Not Avail. 188.0 145,955.0 0.3 140.0 1,025
4 MC/ESP Not Avail. 298.0 443.0
5 MC/ESP Not Avail. 157.0 497.0
455.0 145,792 0.3 940.0 1,031
1 ESP 98.0 ' . 2,701.0
2 ESP 98.0 3,323.0
3 ESP 98.0 2,375.0
4 ESP 98.0 2,657.0
11,055.0 149,147 1.9
:_1 MC/ESP Not Avail. 132.0
"'2' MC/ESP Not Avail. . i
3 MC/ESP Not Avail. . 1,912.0
4 MC/ESP Not Avail. 1,738.0
3,778.0 149,615 2.4
11/7 ESP* 99.8 148.2 7.1
12/7 ESP* 99.8 I I
13/8 ESP 99.8 253.9 1.8
402.1 11,378 1.9 18.2 8.6 137,567 0.2
Fuels for Electric utility Plants - 1979.
rf
^
Estimated Actual 197S
Emissions (10 Tons)
SO, NO TSP
1.0 2.2 0.1
0.2 0.2 Not
0.6 0.6 0.1
80.0 9.5 1.5
32.5 3.6 0.6
15.28 3.62 0.29
'
-------
(31h)c.l
Uni t
Ut il i ty/Powerolant Number
NEW YORK (Cont.)
City of Jamestown
Carlson!/ 2
3
4
5
6
Total
Long Island Lighting
E.F. Barrett 1
2
Total
Far Rockaway 4
Glenwood 4
5
Total
Nor-thport 1
'2
3
4
Port Jefferson '"- . 1
2
3
4
Total
New York State Electric £ Gas
Goudey 11/7
12/7
13/8
Total
Name
Plate
Capac
ity
(MW)
5.
15.
13.
23.
27.
83.
187.
187.
375.
113.
113.
113.
227.
387.
387.
387.
367.
1,543.
45.
46.
187.
187.
466.
43.
60.
103.
0
0
0
0
0
0
5
5
0
6
6
6
2
1
1
1
0
3
0
0
5
5
0
8
0
8
Net
Depend
Capac
able County Attainment
ity Location Status
Currently Enforced l^missions Limits-
sc.,
2 c
NO TSP
A c '
(NW) City County SO. NO ' TSP (lbs/lo"Btu) (lbs/10uBtu)
5
15
10
20
25
75
190
190
380
114
114
113
227
383
383
.0 Jamestown Chatauqua - - XX-P
.0
.0
.0
.0
.0
. 0 Mineola Nassau - -
.0
.0
.0 Far Rockaway Queens - - XX-P
.0 Glenwood Landing Nassau - -
.0
.0
.0 Northport Suffolk -
.0
383.0
386
1,535
49
48
190
190
477
44
82
126
.0
.0
.0 Port Jefferson Suffolk - - -
.0
.0
0
.0
Johnson City Broome - -
.0
.0
.0
3.8
3.8
3.8
3.8
3.8
1.54%-(v)
1.54%-(v)
0.34S
1 .0% (v)
1. 0%- (v)
2.8%-(v)
2.8%- (v)
2.8%- (v)
2.8%- (v)-
1.0%S
1.0%S
2.8%-(v)
2.8%-(v)
3.8-C/23-0
3.8-C/2%-O
3.8-C/2%-0
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
c
Averaging
Boiler ~
(lbs/10uBtu) Period Bottom
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
TSP - 1 hr.
SO2 - 3 months
TSP - 1 hr.
Sulfur - 1 month
TSP - 1 hr.
Sulfur - 1 month
TSP - 1 hr.
Sulfur - 1 month
TSP - 1 hr.
Sulfur - 1 month
TSP - 1 hr.
Sulfur - 1 month
TSP - 1 hr.
SO2 - 3 months
Dry
Dry
Dry
Dry
Dry
N/A
N/A
N/A
Dry
Dry
N/A
N/A
N/A
N/A
Dry
Dry
Dry
Dry
Dry
Dry
r uaca
Firing
Pulver i z«r
Pulver izer
Pulvor izer
Pulver i zer
Pulverizer
Tangential
Tangential
Tangential
Pulv/Tan
Pulv/Tan
Tangential
Tangential
Tangential
N'/A
Pulv/Tan
Pulv/Tan
Pulv/Tan
Pulverizer
Pulver izer
Pu Iverizer
2/ Sulfur, SO2 and TS? standards apply only to coal
(v) - variance
and oil.
O
Tl
o
o
33
0
O
3)
5
m
-------
ana .
Ut i11ty/Powerplant
Unit
Nuim er
1979 Fuel Consumption
Control Equipment
Oil
Gas
Part iculates
uip. Eft. (%)
3uipt 2 Eft. (1} 10 Tons BtU/]b . Suit. (%) Ash (%)
10 Barrels Btu /gal'. "»)'
10 MCF BCVt.3
Estimated Actual I
^IL i s is i o n s (10 To n jj ?
O,, NO TS?
V YORK (Cont.)
jj Con-. Ed. of N.Y (Cont.)
Hudson Ave.
O
Tl
o
o
3
0
O
m
O
10
445.4 145,879 0.26
0.41 0.37 0.03
Ravenswood
ESP 99.0
1,226.7
1,392.2
1,902.7
.4,521.6
145,959
' 7,974.0
8,530.4
1,454.1
0.26 17,958.5
1,030 4.16 5.64 0.6S
74th Street
120
121
122
558.5 145,583 0.26
0.51 0.39 0.06
Waterside
9
14
15
1,617.0 145,668 0.26 6,757.0 1,030 1.33 2.01 0.33
-------
(JlU)c.l
Utility/Powerplant Number
MEW YOHK (Cont.)
Con. Ed. of N.Y. (Cont.)
Hudson Ave. 5
7
8
10
Total
Ravenswood 1
2
3
Total
74th Street!/ 120
121
122
Total
Waterside^/ 4
5
6
7
8
9
14
15
Plate
(NW)
110
160
160
75
505
400
400
1,027
1,827
209
50
66
74
81
62
62
. 60
75
.0
.0
.0
.0
.0
.0
.0
.7
.7
.0
.0
.3 .
.8
.3
.5
.5
.0
.0
Dependable
(MW) City County
59
141
141
44
385
405
401
972
1,778
219
29
33
41
44
43
37
53
65
.0 Kings Kings
.0
.0
.0
.0
.0 Queens Queens
.0
.0
.0
Lenox Hill N.Y.
.0
.0 Murray Hill N.Y.
.0
.0
.0
.0
.0
.0
.0
rn t- Art- ' Curr
ently En
SO, ' NO TSP (Ibs/I0"litu)
XX-P 0
0
0
0
0
XX-P 0
0
1
XX-P 0
0
0
XX-P 0
0
0
0
0
0
0
.343
.3*3
.313
.315
.3%S
.3»S
.3%S
.5«S
.3%
.3%
.3%
.3%
.3%
.3*
.3%
.3%
.3%
.3%
torcea BIUSSH
NO
(lbs/10 Utu)
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
rap
(lbs/i
0
0
0
0
0
. 0
0
0
0
0
0
0
0
0
0
0
0
0
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
u) Period Lnttom
TS? - 1 hr. N/A
Sulfur - 1 month N/A
t.'/A
N/A
TSP - 1 hr. N/A
Sulfur - 1 montli N/A
Dry
TSP - 1 hr. N/A
Sulfur - 1 month N/A
N/A
TSP - 1 hr. N/A
Sulfur - 1 month N/A
N/A
N/A
N/A
N/A
N/A
N/A
Fi r i nfj
Front
Front
Front
Frcnt
Tangential
Tangential
Pulv/Tan
Tangential
Tangential
Tangential
Tangential
Tangential
Tancentiai
N/A
Tangential
Tangential
Tangential
Tanqential
Total
532.4
345.0
I/ 74th Street boilers associated with turbines 3 (30 MW), .9 (75 MW) , 10 (69 MW) , 11 (35 MH) .
2_/ Each boiler associated with separate turbine, plus all .boilers associated with
turbines 14 and 15.
V Sulfur, S02 and TSP limits apply only to oil and coal.
o
Tl
o
o
m
O
-------
Ih ) C
1979 Fuoi Consumption
Est imated Actual
Control Equipment
Unit
Ut il i ty/Powerplant Nunh er
i YORK (Cont.)
Central Hudson Gas i Electric
Dana ammer Pt . 1
2
3
4
Rose ton 1
2
Consolidated Edison of N.Y.
Arthur Kill 2
3
Astoria 1
2
3
4
5
Kast River 5
6
7
59th Street 110
111
112
113
114
115
Particulates SO, , ,,3
Equip.
ESP
ESP
ESP
ESP
HC
MC
ESP
ESP
ESP
ESP
ESP
ESP
ESP
_
-
-
-
-
-
-
-
-
E££.
98
98
98
98
85
85
99
99,
97.
97.
99.
99.
99.
_
-
-
-
-
-
-
-
-
(%) Equip. - ' Eft. (») Ton
.0 - -
.0 - -
.0 - -
.0 . -
.0 - -
.0 - -
.0 - -
.5 - -
.0 - -
.0
.0 - -
.0
.0 - -
_
-
-
_
-
-
' _
-
-
Coal
Btu 10
s /In. Sulf. (%) Ash (%) Barrels
152
173
550
1,632
2,507
4,939
4,556
9,495
1,549
2,641
4,190
536
394
1,055
1,478
624
4,OU9
613
449
535
1,598
1
.0
.0
.0
.0
.0
.0
.0
.0
.1
.6
.7
.9
.9
.1
.4
.4
.7
.5
.6
.4
.5
Uil
btU /qal.' U) 10 MC
16
2,444
14
33
147,340 1.0 2,508
148,425 1.93
146,001 0.27
5,304
4,125
3,701
253
206
145,797 0.25 13,590
1,742
1,355
4,683
145,718 0.26 7,781
Gas
F
.7
.4
.0
.7
.8
.3
.4
.0
-0 .
.4
.5
.7
.4
.7
.8
3
BCU/Pt.3 SO, NO TSP
1,010 8.31 3.76 .63
60.80 12.85 1.96
3.86 3.09 0.53
1,030 3.51 4.84 0.42
1,030 1.47 2.44 0.16
145,037 0.26
1,029
0.58 0.47 0.06
o
Tl
o
o
3)
0
O
m
O
-------
jJtil ity/Powerplant
Central Hudson Gas & Electric
Uanskarcmer Pt.
Consolidated Edison of N.Y.
Arthur Kill
Astoria
East River
59th Street
Name
Plate
Unit
Number
1
2
3
4
Total
1
2
Total
20
30
Total
10
20
30
40
50
Total
50
60
70
Total
110/13
111/14
112/14
113/14
114/15
115/15
Capa
JK
72
73
147
239
531
621
621
1,242
376
535
911
200
200
376
387
387
1,549
156
156
200
512
57
22
-
-
35
-
city
")
.0
.0
.0
.0
.0
.0
.0
.0
.2
.5
.7
.0
.0
.2
.2
.2
.6
.3
.3
.0
.6
.5
.0
.0
Net
Currently Enforced Emissions Limi
Dependable
Capaci
(MW)
39.
73.
122.
234.
468.
600.
600.
1,200.
335.
491.
826.
161.
161.
378.
379.
359.
1,438.
130.
130.
166.
426.
47,
16".
r
-
19.
-
ty Location
City County
0 Newburgh Orange
0
0
0
0
0 Newburgh Orange
0
0
0 Staten Island Richmond
0
0
0 Woolsey Queens
Or
0
0
0
0
0 Peter Stuyversant N.Y.
0
0
0
0 Radio City, N.Y.
0
0
County Attainment
Status 2-
S02 'NO TSP (lbs/10
- - - 1.
1.
1.
1.
- - - 2.
2.
XX-P 1.
1.
XX-P 0.
0.
0.
0.
0.
XX-P 0.
0.
0.
- ( - XX-P 0.
0.
0.
0.
0.
0.
y
6
BtUj
0%S
0%S
0%S
0%S
04S
0%S
5%S
5%S
3%S
3%S
3»S
3SS
3%S
3%S
3%S
3%S
3%S
3%S
3%S
3%S
3%S
3%S
NO
(lbs/106Btu)
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
TSP
(lbs/10
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.'
0.
0.
0.
0.
ts
y
6Btu)
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
Averaging Boil
Period Bottom
TSP - 1 hr. Dry
Sulfur - 1 month Dry
Dry
Drv
TSP - 1 hr. N/A
Sulfur - 1 month N/A
TSP - 1 hr. Dry
Sulfur - 1 month Dry
TSP - 1 hr. Dry
SulCur - 1 month Dry
Dry
Dry
Dry
TSP - 1 hr. N/A
Sulfur - 1 month N/A
N/A
TSP - 1 hr. N/A
Sulfur - 1 month N/A
N/A
N/A
N/A
N/A
er Data
Firing
Tangential
Tangential
Tangential
Tangen ti ;-.l
Tangential
Tangential
Pulv/Fror.L
Pulv/Fronu
Pulv/Fronu
Pulv/Fron;_
Pulv/rro.-.L
Pulv/Tan
Pulv/Tan .
N/A
N/A
Front
Front
Front
Front
Front
T.inger.tia j
Tangential
114.5
82.0
I/ Sulfur, S02, and TSP limits apply only to oil and coal.
o
TI
o
o
3
TJ
O
3)
m
O
-------
soJTc
!j Control Equipment
J Unit Particulars SO^ 3
j Ut ility/Powerplant Number Equip. Eff. (%) Equip. * Eft', (t) " Tons
:!.-.< MEXICO (Cont'd)
: Public Service of New Mexico
! San Juani/ 1 ESP/Vent. 99.8 - NL 85.0 1,065.9
2 ESP/Vent. 99.5 WL 85.0 1,123.0
3 ESP/Vent. 99.9 WL 90.0 0
2,189.1
Southwestern Public Service Co.
Carlsbad 2
3
4
5
6
Cunningham 1
2
Roswell .10
11
/ Wellman Lord Scrubbers have particulate design removal efficiencies of 99.5% each.
i
'"
i
|
ii
i
;
,f
it
a '
j
\
\ $
; Z
O
§
s
§ '
a m
1
1979 Fuel Consumption
Coal Oil Gas
Btu 10 Btu Sulf. 3 3
/lb. Sulf. (%) Ash (%) Barrels /gal. (%) MCF /Ft.
<
47.1
12.5
22.4
9,200 0.82 20.5 82.0 135,000 0.07
517.0
572.0
trace . 415.0
trace 417.0
trace 1,921.0 1,054
4,453.0
11,925.0
16,378.0 1,000
918.0
918.0 1,000
«
Estimated Actual 1979
Emissions (10 Tons)
_§°
2_
2.6 6.36 .62
.25 0
1.81 0
0.14 0
-------
(30h)c.l
Plate uopenaaoie
Unit Capacity Capacity Location
Utilitv/Powerplant Number (MW) (KW) City County
NKW MEXFCO (Cont'd)
Public Service o£ New Mexico
San Ju.m 1 330.0 326.0 Water Flow San Juan
2 329.0 330.0
3 534.0 468.0
Total 1,193.0 1,124.0
Southwestern Public Service Co.
Carlsbad 2/2 {, 3 24.7 26.4 Carlsbad Eddy
3/2 & 3
4/2 S. 3
5/4 19.6 20.0
6/4
Total 44.3 46.4
Cunningham 1 75.0 75.0 Hobbs Lea
2 190.4 200.0
Total 265.4 275.0
Roswell 10 5.0 5.6 Roswell Chares
11 19.2 20.0
Total 24.2 25 .'6
I/ San Juan Units 1, 3 Emissions limits for SO2 apply through 1982.
o
m
2
O
O
3D
-o ,-
O
>
m
O
t-ounty Attainment ~ ~
.St,-,tus 2 ^x Avoraqinq Boiler Ii.it.',
SO, NO TSP (lbs/10 btu) (lbs/10 btu) (lbs/10 Btu) Period Bottom tiring.
i
X-P - - 0. 34-0/1. 2-cV 0.3-O/0.7-C 0.05 SO2-30 days Dry Pulverizer
0.34-O/0.53-Ci/ 0.3-O/0.7-C 0.05 TSP,NOX Dry Pulverizer
0. 34-0/1. 2-ci/ 0. 3-0/0. 45-C 0.05 1 hr. Dry Pulverizer
0.55-plant
X-P None 0.3 None 1 hr. N/A Front
None 0.3 None N/A Front
None 0.3 Hone N/A Fror.t
None 0.3 ' 0.05-oii N'/A Front
None 0.3 0.05-oil H/A Front
X-P None 0.3 :ione 1 hr. N/A Tangential
None 0.3 done N/A Tangential
-. - - None 0.3 None 1 hr. N/A Front
None 0.3 None N/A Front
'
i
-------
Unit
Ut il i ty/Powerolant N'ur.iber
.: MEXICO (Cont'd)
How Mexico Electric Service
Kaddox 1
Plains Electric Co. & Trans. Corp.
Algodanes 1
2
. 3
Public Service Co. o£ New Mexico
Person 1
2
3
4
Prager 7
g
9
10
11
Reeves 1
2
3
Control Equipment . Coal
Participates SO, 3 3
Equip. Eff. (1) Equip. * Eft. (*) Tons /lb. Sulf. (%) Ash (%) Barr
3
7
.
11
5
7
22
2
38
29
35
!9_
94
Oil
Btu SuU'
els /qal. (%)
I
.9
.1
71 140,000 0.5
.7
.0
.8
.8
.3 142,253 0.3
.3
.6
.8
.7 144,347 0.4
Gas
103MCF '
7,009.2
0.6
0.6
0.5
1.7
1,233.6
983.6
1,61-1.0
1,587.2
5,418.9
70.0
3,166.3
3,159.6
4,697.3
11,023.7
3tu . 3
/Ft.
1,030
880
1,028
1,030
1,028
Estimated Actual 1975
Emissions (10 Tons)
so
2-
i;o
TS?
12.88 0
Not Available
.04 1.98
.03
.14 4.07
.07
O
Tl
o
O
3>
n
O
DO
m
O
-------
(30d>c.l
ti^l ity/Powerplant
NEW MEXICO (Cont'd)
New Mexico Elelctric Service
Maddox
Plains Electric Co. & Trans. Corp.
Algodanes
Public Service Co. of New Mexico
Person
Prager
Unit
Number
1
:orp.
1
2
3
Total
.CO
1
2
3
4
Total
7/7 & 8
8/7 & 8
9/7 S 8
10/7 S 8
11/9
Total
1
2
3
Total
Name
Plate
Capac ' '
(MW
114
17
17
17
51
25
25
38
38
126
12
12
24
50
50
75
175
ity
1
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0 '
.0
.0
.0
.0
Net
Dependable
Capaci^ '
-------
Ut ility/Powerplant
MKM MEXICO (Cont'd)
Arizona Public Service
Four Corners
Community Public Service
Lordsburg
El Paso Electric Co.
Rio Grande
Karmington Electric Utility
Animas
Lea County Electric Corp.
No. Loving ton
Unit
Number
Control Equipment
Coal
1979 Fuel Consumption
Oil
Part iculates
SO,
Vent
Vent
Vent
Vent
Vent
Eff. (%)
99.5
99.5
99.5
97.0
97.0
L/AF
L/AF
L/AF
L/AF
Eft. (%)
67.5
67.5
67.5
y
v
10
Btu
103 Btu Sul£'
'lb. Sulf. (%) Ash (i) Barrels /gal. (%)
Estimated Actual 1972
Emissions (10 Ton.qj
2,131.7
4,156.2
6,287.9 8,769 .70 21.97
MCF
508.47
BtU/Ft.3
59.0
31.6.
90.8 145,000
0.4
9.4
16.4
77.2
62.4
258.7
425.3
1.0
141,648 0.48
7.9 .
1.2
57.1
362.6
153.7
1,242.1
1,410.5
5,012.5
8,454.0
0.1 140,000(est)
23.7
52.3
424.4
Not 1,061.1
avail. 1,464.7
1,010.0
1,383.0
2,393.0
^2-
1,077.3 1,080 69.0 38.0 33.9
.20 .21
0.8 0.3 0
1,039
1,107
1,110 Not Available
]/
Four Corners Units 4,5 planning to retrofit scrubbers with 67.5% removal efficiency by 1982.
o
Tl
z
o
o
3
0
O
3
m
-------
(30)c.l
Name Net
Plate
Ut i 1 i ty/_P_pwo rpla nt
NEW MEXICO
Arizona Public Service
Four Corners
Community Public Service
Lordsburg
El Paso Electric Co.
Rio Grancie
Farroington Electric Utility
Animas
Lea County Electric Corp.
No. Loving ton
Unit
Number
1
2
3
4
5
Total
3
4
Total
1
2
3
4
5
6
7
8
Total
1
2
3
4
Total
Si
82
Total
Capac
(MH
190.
190.
252.
818.
818.
2,268.
12.
25.
37.
15.
25.
23.
34.
37.
50.
50.
166.
401.
3.
3.
9.
16.
33.
16.
33.
49.
it
JL
0
0
0
0
0
0
0
0
0
0
0
0
5
5
0
0
5
5
8
8
0
5
1
0
0
0
Dependable
(KW)
175.0
177.0
220.0
800.0
790.0
2,162.0
11.5
18.0
29.5
12.9
13.4
18.5
33.6
31.6
47.0
47.0 -'
147.0
351.0
3.8
3.8
9.0
16.5
33.1
.
16.0
33. -0
County Attainnrnt Currently En
IxDcation Status 2
City County SO, NO TKP (lbs/10 btu)
Fruitland San Juan X-P - - None-G/0 . 53-C
None-G/0. 53-C
None-G/0. 53-C
None-G/0. 53-C
None-G/0 . 53-C
Lordsburg Hidalgo - - - 0.34
0.34
El Paso Dona Ana - - - None
None
None
None-G/0. 34 -O
None-G/0. 3 4 -O
0.34
0.34
0.34
Farmington San Juan X-P ~- None
None
None-G/0. 3 4-0
None
i
Lovington Lea ' - - X-P None
None
forced Einissn
HO
(lbs/10 Utu)
0.3-G/0.7-C
0.3-G/0.7-C
0.3-G/0.7-C
0.3-G/0.7-C
0.3-G/0.7-C
0.3
0.3
0.3
0.3
0.3
0.3-O/G
0.3-0/G
0.3
0.3
0.3
0.3
0.3
0.3 G/0
0.3
0.3
0.3
Dns Limits
TSP
(lbs/10 btu) Period
0.05 1 hr.
0.05
0.05
0.5-interim
0.5-interim
0.05 1 hr.
0.05
None '1 hr.
None
0.05
0.05
0.05
0.05
0.05
0.05
0.05 1 hr.
0.05
0.05
0.05
None 1 hr.
None
Bo i I
IJOttom
Dry
Dry
Dry
Dry
Dry
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
e r Da t
-------
1979 Fuel Consumption
Estimated Actual 157'j
Control Equipment
Unit
Utility/Powerplant Number
:i;w JERSEY (Cont.)
vine-land Electric Utilities
Howard Down 4
7
8
. 9
10
Jersey Central Power & Light
Gilbert 1,2/1
1,2/2
3/3
Sayreville 5/1
5/2
5/3
7/4
8/5
Werner 4 -
Particulates SO,
Equip.
MC
MC
MC
MC
ESP/MC
MC
MC
MC
KC
ESP
ESP
ESP
EEf.
92
92
90
98
90
86
36
86
90
90
85
Coal
(%} Equip.. * Eff. (%) "" Tons /lb. Sulf. (S) Ash (%) Barn
.7
.8
.0
.0/78.0
.0
.2
.2
.2
.0
.0
.0
6
9
73
181
71.8 11
71.8 12,593 1.32 10.7 283
112
-
188
300
50
-
. . 610
743
1,403
291
Oil r^
Btu Sulf- l'o3 Etu 3
els /gal. (%) MCF /Ft.
.8
.8
.6
.3
.7
.2 150,133 1.88
.0
0 1,652.0
.0 145, 53i O.S 1,652.0 1,031
.0
.0 863.0
0 1,136.0
.0 144,805 0.3 1,999.0 1,043
.0 144,777 0.3
3
SO, NO TSP
0.01 0.9 1.0
0.04 1.33 3.09
0.01 0.28 0.6-1
o
Tl
o
o
O
2J
5
m
O
-------
(29d)c.l
Name
Utility/Powerplant Number
NliW JERSEY (Cont. )
Vineland Electric Utilities
Howard Down 4
5
6
7
8
9
10
Total
Jersey Central Power & Light
Gilbert 1,2/1
1,2/2
3/3
Total
Sayreville 5/1
5/2
5/3
. 7/4
8/5
Total
Plate
(MW)
7
4
5
8
10
19
27
80
11
45
69
126
35
35
23
122
125
346
.0
.0
.0
.0
.0
.0
.0
.0
.8
.3
.0
.1
.3
.3
.7
.5
.0
.8
Net
Currently Enforces Emissions Limits
Dependable County Attainment
(MW) City County SO., NO TSP
4
4
5
7
10
18
26
75
10
35
72
117
37
37
26
138
138
376
.0 Vineland Cumberland - - XX-P
.0
.0
.5
.0
.7
.0
.2
.0 Milford Hunterdon - -
.0
.0
.0
.0 Sayreville Middlesex - - XX-P
.0
.0
.0
.0
.0
so.
I/
(lbs/10°Btu)
2
2
2
2
2
2
2%-0/l
1
1
1
0
0
0
0
0
.0%
.0%
.0%
.0%
.01
.0*
.5%
.0%
.0%
.0%
.3%
.3%
.3%
.3%
.3%
S
S
S
S
S
S
s-c
S
S
S
S
S
S
S
S
NO
K c
(lbs/10 Btu)
' None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
2/
TSP -
(lbs/10 atu) Period Uottom Firlr.t;
.23
.25
.22
.21
.17
.11
.10
.11
.10.
.10
.1
.1
.1
.1
. .1
Sulfur- max N/A
emissions - N/A
1 hr. N/A
N/A
N/A
N/A
N/A
N/A
N/A
Wet
Wet
Front
N/rt
!!/A
Stoker
Stoker
Stoker
Pulverizer
Front
Front
Tangential
N/A
N/A
Front
Cyc I/Fro:.;
Cycl/Frcnt
60.0
63.0
Morristown
Middlesex
0.3% S
.1
N/A
Cycl/Fronu
I/ S02 standards do not apply to gas.
2/ TSP Standards apply to all fuels.
o
Tl
z
o
o
3
0
O
a
-------
b. IJc.l
1979 Fuel Consumption
Estimated Actudl 1979
Control Equipment Coal
Unit
Ut ility/Powerplant Number
;l JRRSEY
I'uulic Service Electric & Gas
Bergen 1
2
iiu r 1 i ng ton .7
14
Hudson 1
i 2
Kearney 7
8
Linden 11
12
13
2
4
Mercer 1
2
Sewaren 1
2
3
4
: - . 5
Par
Eg u i p .
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
t iculates
Ef £.
98.
98.
97.
95.
99.
99.
97.
97.
99.
99.
95.
95.
95.
95.
95.
SO, ,,3 _. ,n3
Oil
,,M, Sult'- ,,,3
(%) Equip.. * Eff. (%) " Tons """/lb. SulE. (%) Ash (%) " Barrels " /gal, (») iu MCF
0
0
0
0
0
5
0
0
0
0
0
0
0
0
0
626
1,198
1,1)24
820
20
840
2,286
683.1 529
683.1 12,848 1.19 9.9 2,816
824
800
1,624
891
994
885
961
866
4,618
435.6
401.5
837.1 12,625 1.27 8.1
366
429
417
627
2,114
3,954
.5
.0
.5
.2
.4
.6
.9
.6
.5
.1
.1
.2
.1
.3
.0
.9
.0
.3
.5
.4
.2
.3
.3
.7
Gas . 3 .
BCU/Ft.3 SO, NO TS~
44.2 19.8 1.39
144,876 0.27
0.5
4,618.9
146,775 0.4 4,619.4 1,030 1.6 4.9
1.1 2.0
144,997 0.27 (all est.)
8,047.9
2,292.2 (all est.)
145,343 0.28 10,340.2 1,059 18.7 14.4 1.0
1.4 3.6 N/A
146,782 0.28
434.8
1,007.9
1,442.
533.
811.
903.
1,567.
I' 1.037 4.1 10.2 N/A
7
9
3
1
0 1,034 21.3 12.8 1.0
Removal efficiencies not available.
O
Tl
o
o
3
TJ
O
a
m
O
-------
Name
Unit
ut i 1 ity/Powerplant Number
Nl-M JERSEY
Public Service Electric & Gas
Bergen 1
2
Total
Burlington 7
14
Total
Hudson 1
2
Total
Kearney 7
8
Total
Linden 11/1
12/1
13/1
2
- ' 4
Total
Mercer - 1
2
' "' . Total
Sewaren 1
2
3
4
5
Total
Plate
Capacity
(MM)
325.
325.
650.
195.
120.
315.
455.
660.
1,115.
142.
146.
288.
259.
259.
93.
612.
326.
326.
652.
103.
100.
109.
119.
389.
820.
0
0
0
5
0
5
0
0
0
0
0
0
7
7
5
9
0
0
0
0
0
0
0
0
0
Net
Currently Enforced Emissions Limits
Dependable
Capacity Location
. (I'M) City County
287
283
570
180
120
300
383
600
983
142
146
288
244
225
25
494
306
300
606
104
111
107
124
326
772
.0 Ridgefield, Bergen
.0
.0
.0 Burlington, Burlington
.0
.0
.0 Jersey City, Hudson
.0
.0
.0 Kearney, Hudson
.0
.0
Linden, Union
.0.
.0
.0
.0
.0 Trenton, Mercer
.0
.0
.0 Sewaren, Middlesex
.0
.0
.0
.0
.0
County Attainment I/
Status 27
H0,; ,
SO, HO TSP (lbs/10 Btu) (lbs/10°Btu)
- - - 0
0
- - - 0
0
XX-P 0
.3%
.3%
.3%
.3%
.3%
0.3%-O/1.5%-C
XX-P 0
0
XX-P 0
0
0
0
0
- - - 1
1
- - xx-p o
p 0
0
0
0
.34
.3%
.3%
.3%
.3%
.3%
.3%
.5%
.5%
.3%
.3%
.3%
.3%
.3%
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
TSP *
/
Averaging Boiler D-ita
(lbs/10 Btu) Period Bottom Firing
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
sulfur - max i.;et
emissions- 1 hr. Ket
N/A
N/A
We t
Dry
N/A
N/A
N/A
N/A
N/A
N/A
N/A
Wet
Wet
N/A
N/A
N/A
N/A
N/A
Fror.t
Front
Fror.t
Fror.t
Cyclone
Pulverizer
Tangential
Tancential
Fror. t
Front
Fror.t
Front
Front
Pulverizer
Pulveriser
Tangential
Tancential
Tancential
Tancential
Opp. Wall
I/ SO2 Standards do not apply to gas.
2/ TSP standards apply to all fuels.
O
Tl
o
o
3
-a
O
3
m
O
-------
(29b)c.l
1979 Fuel Consumption
Control Equipment Coal
Unit
Ut ility/Powerplant Number
MKW .1KRSEY (Cont . )
Atlantic City Electric
B.L. England 1
2
3
Deepwater 1/1
3/3
5/3
4/4
6/4
7/5
8/6
9/7
Part iculates
Equip.
ESP
ESP
MC
ESP
MC
MC
MC
HC
MC
HC
MC
Eff. (4)
97.1
98.1
90.0
I/
V
V
I/
V
V
I/
I/
SO, 3 - ,03
Equip. ' Eff. (%) " Tons "'"/Ib. Sulf. (%) Ash (%) " Barr.
255.5
338.1
1,599
593.6 12,719 3.0 11.1 1,599
5.2 604
- -268
-
-
-
739
344
746
5.2 12,999 3.0 10.5 2,702
Oil Gas
Btu Sulf- lO3 Btu 3
els /gill. (4) /MCF /Ft.
.0
.0 148,400 1.8
.1
.3
.5
.2 2,723.9
.5
.6 148,474 1.2 2,723.9 1,031
Estimated Actual ll)7b
Emissions (10 Tons)
SO,
2-
1JO
0.1 10.5 6.0
o
Tl
o
o
3
-0
O
33
m
O
-------
(29)c.l
Cue c o n_t. ly En for cecj gin i s s i_ons L i ni its
Place
Unit
Ut i 1 i tv/Powerolant Number
NEK JEKSKY
Atlantic City Electric
B.L. England 1
2
3
Total
Dc-opwater . 1/1
3/3
5/3
4/4
6/4
7/5
8/6
9/7
Total
Capacity
(MK
136.
163.
163.
462.
82.
53.
-
54.
-
23.
75.
23.
310.
) .
0
0
0
0
0
0
0
0
0
8
0
Dependable
Capacity Location
(MK)
127.
160.
160.
447.
78.
53.
-
54.
-
24.
80.
25.
314.
City County
0 Marmora, Cape May
0
0
0
0 Pennsgrove Salem
0
0
0
0
0
0
County Attainment I/
Status 2-
SO., NO TSP (lbs/10
- 3.
3.
2.
- - - 1.
1.
1.
1.
1.
1.
1.
1.
Btu)
5% S
5% S
0% S
0%
0%
0*
0%
0%
0%
0%
0%
(lbs/106 btu)
None
None
None
None
None
None
None
None
None
None
None
(lbs/10
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
2/
Averaging
Btu) Period
1 sulfur-
1 ,
i
1 sulfur - max
1 emissions- 1 hr.
1
1
1
1
1
1
Boiler Data
Bottom
Wet
Wet
N/A
N/A
N/A
N/A
N/A
Ket
N/A
Wet
Fir ir.t^
Cyclone
Cyclone
N/A
N/A
N/A
S/A
N/A
Cyclone
N/A
Cyclone
!_/ S(>2 Standards do not apply to gas.
2J TSP standards'apply to all fuels.
O
n
o
o
3
0
O
33
5
m
O
-------
(28b)c
1979 Fuel Consumption
Ut i li ty/Powerplant
iL'.K HAMPSHIRE (Cont'd)
Public Serv. Co. of
Mer r imack
Newing ton
Schiller
Unit
Number
New Hamp.
1
2
' 1
3
4
5
6
Control Equipment
Particulates SO
Equip.
ESP
ESP
ESP
ESP
ESP
Eft". (%} Eauip. ' Eff. (%)
90.0
97.5
98.0
95.8
95.8
Coal Oil Gas
lo3Tons Btu/lb. sulf . (%) Ash (%, ^Barrels Bt" /qaA. "<"' 1>0/MCF Btu,Ft 3
305.6
762.9
1,068.6 1J,379 2.56 7.14
2,163.3 148,165 1.73
22.2
343.4
336.4
378.1
Estimated Actual 1979
Emissions (10 Ton.s)
SO
NO
54.7 29.4
TS?
1.11
1,080.0
149,148 1.79
3.47 1.32
.02
o
Tl
z
o
o
a
o
O
3D
m
O
-------
(2tl)c
Ut i 1 i ty/ Powe r pl.-i nt
Name Nee
Plate Dependable
Unit Capacity Capacity
Number (MM) (MW)
Location
City
County
County Attainment
Status_
TS-
Currcntly Enforced Emissions Limits
SO,
NO
TSP
Averag ing
(lbs/106Btu) (lbs/106Btu) (lbs/106Htu) Period
Boiler Data
NEW HAMPSHIRE
Public Ser. Co. of New Hamp.
Merrimack
114.0
346.0
460.0
119.0
337.0
456.0
Mecrimack
4.0
4.0
None
None
.28
.23
3 mo. SO2
max - TSP
Wet
Wet
Cyclone
Cyclone
Newington
Schiller
Total
414.0
29.0
50.0
50.0
50.0
179.0
420.0
28.7
48.0
51.0
52.0
179.7
Portsmouth
Portsmouth
Rockingham
Rockingham
2.0 % S
2.0 % S
2.0 % S
2.0 % S
2.0 % S
None
None
None
None
.22 S s TSP max. N/A Tangential
.32 S & TSP max. N/A Front
.32 Dry Pulv/Front
.31 Dry Pulv/Front
.31 VA Front
o
o
o
3
0
O
9
51
m
O
-------
(27b)c
' - '
1979 Fuel Consumption
Ut ility/Powerplant
1KVADA (Cont'd)
Nevada Power Company
Clark
Keid Gardner
Sunrise
Sierra Pacific Power
(1978 Data) Fort
Tracy
Southern California
Mohave
Unit
Number
1
2
3
1
2
3
1
Co.
Churchill 1
2
1
2
3
Edison
1
2
Control Equipment Coal
Particulates SO, 3 . ,3
Equio. E£f. (%) Equip". " Ef£. (%) " Tons ""/lb. Sulf. (%) Ash (%) " Barrels
12
21
_
33
MC/Vent. 88.1/99.5 Vent. 84.4 332.3 3
MC/Vent. 88.1/99.5 Vent. 84.4 291.1 3
MC 75.0 375.8 3
999.3 11,598 .65 10.5 9
38
694
947
1,642
13
181
934
1,128
ESP 98.6 C.F.
ESP 98.6
.0
.0
.0
.3
.0
.6
.9
.1
.7
.3
.0
.0
.2
.2
.4
oil :
Sulf. ,'3~
BtU L 10
/gal. (t) KC
3,156
4,379
2,995
146,848 0.7 10,530
139,325 0.21
144,095 .49 444
867
597
146,197 .68 1,430
.58
113
1,230
146,420 .75 1,402
C
Gas
" ""/Ft.3
0
0
0
0 1 , 0 80
1 1,080
3
3
1 1,041
1
8
7
5 1,046
F.
Estimated Actual 197J
' s on" (103Tons)
SO, NO TSP
0.1 20.6 .01
0.64 6.9 .95
0.06 8.75 0.006
1.74 3.9 .03
1.32 2.76 .02
3,371.1
12,196
.56
10.58
3,367.8
1,080
35.66 30.34 5.0
o
Tl
o
o
DO
0
O
DO
m
O
-------
(27)c.l
ICF INCORPORATED
Plate Dopcncjaoie
Ut i 1 itv/Powerplant Number (MW) - (MW) City County
NhVADA
Nevada Power Company
Clark 1 50.0 48.0 E. Las Vegas Clark
2 65.0 72.0
3 75.0 73.0
Total 190.0 193.0
Reid Gardner 1 114.0 110.0 Moapa Clark
2 114.0 110.0
3 110.0 110.0
Total 338.0 330.0
Sunrise 1 82.0 85.0 Las Vegas Clark
Fort Churchill 1 110.0 110.0 Wabuska Lyon
2 110.0 110.0
Total 220.0 220.0
Tracy 1 53.0 53.0 Sparks Storey
2 80.0 83.0
3 110.0 110.0
Total 143.0 146.0
Southern California Edison
Mohave - 1 755.0 818.0 Laughlin Clark
2 755.0 790.0
"- . Total 1,510.0 1,608.1
I/ S02 emissions limits do not apply to gas.
2/ TSP limits apply to all fuels.
rf
/
-.
/
-, H ^ N0 'T6P */ - - n ,
S02 NO TSP (lbs/10 Btu) (lbs/10 Btu) (lbs/10 Btu) Period Bottom Firing
- - X-P 0.8 Hone .42 limits = max N/A Front
0.8 None .38 . N/A Front
0.8 None .38 N/A Tangential
X-P 0.8-O/1.2-C None . .34 Ket Pulverizer
X-P 0.8-O/1.2-C None .34 Ket Pulverizer
X-P 0.8-O/1.2-C 0.3-O/0.7-C ' .1 Wet Pulverizer
X-P 0.8 None .37 _ N/A Front
X-P 0.8 None .34 ' N/A Front
0.8 None .34 N/A Front
X-P 0.8 None ' .41 N/A Front
0.8 None .37 N/A Front
0.8 None .34 . N/A Front
- X-P 1.2 None 0.1 Dry Pulverizer
1.2 None .0.1 Dry Pulverizer
1
-------
[26f)c
1979 Fuel Consumption
lit il i ty/Po«erpl ant
HIIUKASKA (Cont'd)
Nebraska Public Power Dist.
Kramer
Omaha Public Power Dist.
Jones St.
Nebraska City
North Omaha
Control Equipment
Unit Particulates
Number ,Equio.
1 BH
2 BH
3 BH
4 BH
1 ESP
2 ESP
26 KC
27 MC
1 ESP
1 MC/ESP
2 NC/ESP
3 MC/ESP
4 ESP
5 ESP
EfC.
99.
99.
99.
99.
97.
97.
85.
85.
99.
85.
85.
85.
96.
98.
SO .
,n3
(%) Eauip. ' Eff. (%) " To
9+
9 +
9 +
9 +
9
9
0
0
9 +
0/96.0
0/96.0
0/96.0
0
0
64
56
54
82
257
197
187
384
773
123
196
203
265
238
Coal
Oil
Gas
Btu 103 Btu Suit. 3
ns /lb. Sulf. (%) Ash (%) Barrels /gal. i'i) MCP /Ft.
.4
.6
.5
.1
.6 10,132 0.5 3.7
.1
.2
.3 11,394 .76 8.7
.2 8,252 .31 6.48
.0
.4
.7
.3
.7
5
5
5
4
20
2
: 2
4
3.6 7
2.6 17
6.1 135,494 .24 . 2-1
39.5 137,278 .24
12
. 24
25
27
30
.4
.6
.0
.3
.3 '
.8
.0
.9
.0
.7'
.7
.3
.5
.3
.5
.1
989
991
983
Estimated Actual 197-J
Emissions (10 Tonr.j
TS?
2.6
3.9
10.6
1,027.7
10,352
.85
10.87
trace
5.05
7.39
9.25
o
71
z
o
o
3
TJ
O
3
5
m
-------
(26d)c.l
Ut i 1 i tv/Powe rpla nt
NEBRASKA (Confd)
Nebraska Publ. Power Dist.
Kramer
Sheldon
Omaha Public Power Dist.
Jones St.
Nebraska City
North Omaha
Unit
Number
(Cont'd)
1/1
?/l
3/2
4/3
Total
1
2
Total
11
12
Total
1
1
2
3
4
5
Name
Plate
Caoacity
44
45
45
136
100
119
219
35
49
84
565
74
109
109
136
218
.5
.5
.5
-5
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
Net
Dependable County Attainment -~
Capacity Location Status -
(MW)
35.
35.
35.
105
105.
111.
216.
37.
46.
83.
575.
76.
102.
102.
131.
219.
Currently
*>,.
City County SO, NO TSP (lbs/10 Btu)
0 Bellvue Sarpy - - X
0
0
.0
0 Hallam Lancaster
5
5
0 Omaha Douglas - - X
0
0
0 Nebraska City Otoe -
0 Omaha Douglas - - X
0
0
0
0
2.
2.
2.
2,
2,
2,
2.
2
1.
2,
2.
2
2.
2.
.5
.5
.5
.5
.5
.5
.5
.5
,2
.5
.5
.5
.5
.5
Enforced Emissions Limits
NO
(lbs/10 Btu)
None
None
None
None
None
None
None
None
0.7
None
None
None
None
None
TSP
Averaqim Boiler Data
(lbs/10 Btu) Period Bottom
0.2
0.2
0.2
0.2
.15
;' -15
.15 .
.15
.1
.15
.15
.15
.15
.15
. Entire State: Dry
TSP -60rci"utes Dry
SO2 - 2 hrs. Dry
Dry
Wet
Wet
N/A
N/A
Dry
Dry
Dry
Dry
Dry
Dry
Firing
Pulver i zor
Pulverizer
Pu Iver i z.-r
Pulverizer
Cvclone
Cyclone
Front
Front
Pulver i zer
Pulverizer
Pulver i zer
Pulverizer
Pulver i zer
Pulverizer
Total
646.0
630.0
o
Tl
z
o
o
9
TJ
O
3
m
O
-------
(26b)c.l
197!j Fuel Consumption^
Control Equipment Coal
MI:
Ut ili
:DIIASKA
ty/Po'
(Cont
werplant
'd)
Unit
Number
Part iculates
Eg u i p .
Sff. (4)
SO, 3
Equip. E££. (%) " Tons """"/! b. Sulf. (%) Ash (%
Oil
103 Btu Sulf.
) Barrels /qal. (%)
Gas
103MCF BtU/Ft.3
Central Nebraska Public
. Power & Irrig. Dist.
Canaday
Fremont Dc-pt. of Utilities
Wright (Fremont 12)
Grand Island Water & Light
C. W. Burdick
Hastings Utility
North Denver
BH
BH
ESP
99.9
99.9
99.6
23.3
46.0
130.6
199.9
10,375
0.4
8.0
168.9 150,000 1.1 5,052.0
18.4
70.1
27.4
104.6 153,000 1.9
150,000
115.9
160.5
39G.7
2,199.7"
2,756.9
1,542.9
1,542.9
932
1,000
942
940
Estimated Actual 1^7-j
Emissions (10 Tone)
0.1
1.6
MO
0.1
TS1'
Not Available
Nebraska Public Power Dist.
Bluffs
Gerald Gentleman
99.8
857.4
8,812
.38
5.2
150,609
141,572
1.05
.34
1,770.9 1,033
.70
.44
.85
7.7
.01
.07
o
Z
O
o
3>
0
O
30
m
O
-------
(20JC.1
o
Tl
o
o
3D
T>
O
3)
Plato
Unit
Ut il i tv/Powerplant Number
NEBRASKA
Central Nebraska Public
Power & Irrig. Dist.
Canaaay 1
Fremont Dept . of- utilities
Wright (Fremont 82) 6
7
8
Total
Grand Island water & Light
C. W. Burdick 1
2
3
Total
Hastings Utility
North Denver 2
3
4
5
' Total
Nebraska Public Power Dist.
Bluffs . 1
2
:-- . 3
. 4
Total
Capac
:ity
(MH)
108
16
22
91
129
16
22
54
92
6
6
17
22
51
2
5
7
28
43
.8
.0
.0
.0
.0
.5
.0
.0
.5
.0
.0
.0 -
.0
.0
.5
.0
.5
.0
.0
Dependable county Attainment
Capac
. (MW
108
16
24
85
ity Location status
SO
2
) City County SO., NO TSP (lbs/10
.0 Lexington Gosper -
.0 Fremont .Dodge - - -
.0
.0
2.
2.
2.
1.
g
Btu)
5
5
5
2
NO
^ 6
(lbs/10 Btu)
None
None
None
0.7
I;SP
6
.
Averaging Boi}"~ ~-^-
(lbs/10 Btu) Period Botto:n
0.2
.15
.15
.1
Entire State:
TSP SOminutes
SO2 - 2 hrs. N/A
Dry
Dry
Dry
.til. U*jLcl
Firing
Tanger.tia
1
Pulver i zer
Pulverizer
Pulverizer
125.0
15
21
52
88
6
6
7
22.
41
0
6
8
27
41
.5 Grand Island Hall -
.0
.4
.9
.0 Hastings Adams - ' - -
.0
.0
.0
.0
.0 Scottsbluff Scottsbluff -
.0
.3
.5
.8
2.
2.
2.
2.
2.
2.
2.
2.
2.
2.
2.
5
5
5
5
5
5
5
5
5
5
5
None
None
None
None
None
None
None
None
None
None
None
.15
.15
.15
.25
-.25
.25
.25
.23
.23
.23
.23
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
Front
Front
Front
Front
Front
Front
Front
Front
Front
Front
Front
Gerald Gentlemen
650.0
600.0 Southerland Lincoln1
0.8-0/1.2-C 0.3-0/0.7-C
0.1 0/C
Pulverizer
m
O
-------
Util i tv/Powerplant
MONTANA (Cont'd)
Montana Dakota Utilities
Lewis t Clark
Montana Power Co.
IJird
Colstrip
Corette
Unit
Number
1
1
1
2
1
1979 Fuel Consumption
Control Equipment Coal Oil : Gas
Particulars SO. ,_3 _. ,n3 .. . Sulf. , _3
Equip.
MC/Vent.
Vent.
Vent.
ESP
E££. (%) Equip. Eff. (%) /Tons /lb. Sulf. (%) Ash (%) /Barrels /gal. (*) /MCF /Ft.
85.7/98.1 303.9 6,508 0.5 8.0 ' 5.7 . 1,045
(Lignite)'
38.9 146,577 .65 1,613.9 1,133
99.5 LSS 60.0
99.5 LSS 60.0 ;:
2,530.4 8,730 0.71 8.7 90.3 91,800 .OJ.(est.)
96.0 599.4 8,693 0.8 9.0
Estimated Actual 1S7^
SO. NO TSP
3.0 1.2 0.2
.08 .36
5.85 22.8 0.63
o
Tl
o
o
3)
s
490.3- 1,140
m
o
-------
(25)c
Ut i lity/Poworplant
MONTANA
Montana Dakota Utilities
Lewis & Clark
Montana Power Co.
Bird
Colstrip
Unit
Number
1
1
1.
2
Total
Capacity
50.0
69.0
358.0
358.0
716.0
Capacity
(UK)
44.0
70.0
330.0
330.0
660.0
Location Status
City County SO, NO TS"
Sidney Richland - -
Billings Yellowstone X-P - XX-P
Colstrip Rosebud - - X-P
SO.,
(lbs/10 Btu)
2.0-Coali/
2.0-Oill/ .
1.2-C/0.8-G
1.2-C 0.8-G
NO
(lbs/,10 Utu)
None
None
0.7-C/0.3-0
0.7-C/0.3-0
TSP
(lbs/106Btu)
.23 C/G
.29 0/G
.1 C/G
.1. C/G
Averaging
Period
1 hr.
1 hr.
1 hr.
Boiler Daca
Bottom Firing
Dry
N/A
Dry
Pulver i zer
Front
Pulveri zer
o
Tl
o
o
3)
-0
O
30
m
o
Corette 1 173.0 180.0 Billings Yellowstone X-P - XX-P 2.0-Coall/ None .19 C/G ' 1 hr.- Dry Pulverizer
J_' Sulfur in gas limited to 50 grains per 100 cubic feet.
-------
1979 Fuel Consumption
Control Equipment Coal Oil
Unit Particulates SO_2 3 D|_u 1Q3 Etu Suit.
Ut ility/Powerplant Number Eauip. Eff. (%) Equip.- ' Eff. (%) Tons ' /lb. Sulf. (*) Ash (4) Barrels /qal.1 (I)
:KOUHI
Union Electric
Labadie 1 ESP 99.5 - - 1329.5 34.0
2 ESP 99.5 - - 1364.5 43.6
3 ESP 99.5 - - 1379.8 40.6
4 ESP 99.5 - - 1473.6 38.8
5547.4 10,781 2.42 10.82 156.9 137,000 0.3
Merameci./ 1 ESP 97.5 - - 230.3
2 ESP 97.5 - - 215.4
3 ESP 97.5 - - 253.2
4 ESP 97.5 - - 489.9
1188.7 12,304 1.30 7.84
Rush Island 1 ESP ' 99.7 - - 1453.5 22.8
2 ESP 99.7 - - 1518.6 24.0
2972.1 10,589 1.12 13.49 46.8 137,000 0.3
Sioux 1 ESP 99.6 - - 1327.2 6.7
2 ESP 99.6 - .- 1016.2 ' 2.7
4729.5 10,206 2.22 13.04 9.5 137,000 0.3
Meramec will install 99.5% efficient ESP's in 1981.
0
-n
z
o
o
DO
o
O
33
Gas . . 3
10 Btu 3
MCF /Ft. SO HO TS?
134.2 49.9 9.0
37.7
: 43.6
25.0
21.9
128.2 1,035 29.3 10.7 1.6
63.2 26.7 1.1
98.8 21.1 1.5
-------
(24p)c
Ut i 1 i tv/ Powe rpla nt
MISSOURI
Union Electric
Labadie
Meramec
Rush Island
Sioux
Number
1
2
3
4
Total
. 1
2
3
4
Total
1
2
Total
1
2
Name
Plate
Capa
city
(MW)
621
621
621
621
2484
138
138
289
359
924
555
555
1110
550
550
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
Net
Dependable County Attainment
Caoac
Currently Enforced Emissions Limits
SO,
2
-------
Inlc.l
1979 Fuel Consumption
Control Equipment
Ut il i ty/ Power pi ant
;SOURI
St. Joseph Light i Power
Lake Road
Springfield Utilities
James River
Unit
Number
1
2
3
4
1
2
3
4
5
Part
Equip.
-
ESP
-
ESP
MC
KC
MC/ESP
ESP
iculates
Eff.
-
99.
-
99.
88.
88.
SO,
(%) Eauio. Eff. (%)
-
0 - -
_
0 - -
0 - -
0 - -
87.0/98.0
98.
-
0 - -
io3
Tons
-
71
-
293
365
20
21
68
-
144
236
.9
.7
.6
.8
.1
.9
.'2
.8
Coal
Btu IO3
/lb. Sul£. (%) Ash J%) Barrels
51.2
0.2
18.4
-
10,673 4.28 14.3 69.9
.
-
-
-
6.2
11,684 3.93 14.80 5.7
Oil
Gas
Btu Sulf- '103 Btu 3
/qall (%) MCF /Ft.
808
452
211
246
154,802 2.49 1719
80
; 120
449
1073
138,200 0.16i/ 1736
.3
.5
.9
.4
.1 969
.6
.1
.5
-
.4
.5 ' 1,013
99.5
LSSl/ . 80.3 317.0 11,640
Union Electric
Ashley
Source: Cost f. Quality of.Fuels for Electric Utility Plants - 1979.
Limestone Scrubber also has particulate design removal efficiency of 99.7%.
o
Tl
o
o
3.6
14.0
8.0
96.1
97.8
63.2
97.8
79.2
434.1
138,200 0.4
153,277 1.62
Estimated Actual Ib7'.
Emissions (10 Tons)
SO,
NO
Not Available
9.3 42.61 28.0
15.6 2.5 0.5
2.4 1.0 0.1
m
O
-------
(241JC.1
Ut ility/Powerplant
MISSOURI
St. Joseph Light & Power
Lake Road
Springfield utilities
James River
Southwest
Union Electric
Ashley. -/
Unit
Number
Total
Total
Nome
Plate
Capa ' '
city
(MK)
23
25
13
90
151
22
22
44
60
109
257
194
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
Net
Dependable Count]
Capac"'" " ' -----
icy Location
(MH) City County SO
22
29
15
95
161
24
24
48
66
112
274
200
2'
.0 St. Joseph Buchanan
.0
.0
,0
.0
.0 Springfield Greene -
.0
.0
.0
.0
.0
.0 Springfield Greene -
St. Louis St. Louis X-P
Currently Enforced Emissions
"1 -I r 11 r T
£
NO
" c
Limits
.TSP
NO TSP (lbs/10uBtu) (lbs/10uBtu) (lbs/10
X
X-P 8
8
8
8
- - 9
9
9
9
9
.0
.6 !/
.0
.6
.2
.2
.2
.2
.2
0. 8-0/1. 2-C
X-P 2
2
2
2
2
.0%
.0%
.0%
.0%
.0%
lione
None
None
None
None
None
None
None
None
0. 3-0/0. 7-C
None
None
None
None
None
0.
0.
0.
0.
; 0.
0.
0.
0.
0.
0.
.
7 Averaging
Btu) Period
14 3 hr S02
14 TSP-1 hr. ,
14
14
16 3 hr SO,
16 TSP-1 hr.
16
16
16
1 0/C 3 hr SO,
TSP-i hr.
NOx-max
54 3 hr SO2
54
54
54
54
BO ' ' " " '^~ " "
J-J-tft U.I Lrt
Bottom Firinq
Dry
Dry
Dry
Wet
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Front
Pulverizer
Front
Cyclone
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Front
Front
Front
Front
Front
"70.0
70.0
I/ Lake Road 12.will meet 8.0 SO2 standard in 1980.
2/ Ashley holers 2-6 associated with turbines 1(10 MW),
7 (20 MW) , 8 (20 MH) , 9 (20 MW) .
o
Tl
z
o
o
3
0
O
3
m
o
-------
1979 Fuel Consumption
Control Equipment
Oil
Ut ility/Poworplant
Particulates _ SO _ 3 Btu 1Q3 Suif.
Number Equip
_ _ Btu 1Q Btu .
Eff. 1%) Equip. Elf. (%) Tons /lb. Sulf. (%) Ash (%) Barrels _ /gal. (t)
Estimated Actual !'./
10 MCF BtVt.3 SO
Emissions (10 Tory:]
NO TSi'
'ISSOURI
Missouri Public Service Co.
Green
MC
MC
94.6
94.6
691.0 .
710.0
1401.0 1,007
0.33 0
Sihley
ESP
ESP
ESP
99.0
99.0
99.3
119.0
127.0
555.0
801.0 11,282
3.34 11.7
53.5 22.0 2.3
St. Joseph Li'jht & Power
Erimond St. i/
Fuel Consumption data from Cost & ) uality of Fuels for Electric Utility Plants - 1979.
o
-n
z
o
o
I*
T3
O
31.5 150,541 2.7 295.3 968 Not Available
m
o
-------
O
TI
o
O
y
o
§
21
m
O
(24h)c.l
Ut il i ty/Powerplant Number
MISSOURI
Missouri Public Service Co.
Green 1
2
Total
Sibley 1
2
3
Total
St. Joseph Light & Power
Esmond St. 4
5
7
Total
Plate
(MW) "
25.0
25.0
50.0
50.0
50.0
419.0
519.0
20.0
10.0
13.0
43.0
Dependable County Attainment -
Curr
so.
ently I
(HW) City County SO NO TSP (lbs/10°Btu)
20
21
41
50
48
360
458
20
12
14
46
2 x
.0 Pleasant Hill Cass XX
.0
.0
.0 Sibley Jackson - - X-P
.0
.0
.0
.0 St. Joseph Buchanan - - X-P
.0
.0
.0
8
8
9
9
9
8
8
8
.0
.0
.0
.0
.0
.0
.0
.0
Sntorced Emissi
NO
(lbs/10 Btu)
None
None
None
None
None
None
None
None
ons Lim
its 1.
' TSP
/
Averaging
(lbs/10°Htu) Period
0
0
0
0
0
0
0
0
.27
.27
.14
.14
.14
.19-
.19
.19
3 hr SO,
TSP-1 hr.
3 hr S02
TSP-i hr.
3 hr SO2
TSP-1 hr.
Bottom Firina
Dry
Dry
Wet
Wet
Wet
N/A
N/A
N/A
Pulv/Froni.
Pulv/Front
Cyclone
Cyclone
Cyclone
Front
Front
Front
I/ All limits for "existing" plants apply to all fuels.
-------
(24f)c.l
Unit
I Ut ility/Powerplant Number
MISSOURI
City of Independence
1978 data: Blue Valley 1
2
3
Kansas City Power i, Light
Grand Avenue 1
5
7
8
9
Hawthorn 1
2
3
4
5
latan 1
Montrose 1
: -. 2
'' 3
/ Source: Cost 6 Quality of Fuels for
1979 Fuel Consumption
Control Equipment - Coal Oil Gas
Particulates SO, ,n3 _.. ,n3 _.. Sulf. ,',3
MC 3/
MC 3/
MC y
-
MC
MC/ESP
MC
-
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
Electric
Eff. (%) Equip. * Eff. (%) Tons /lb. Sulf. (11 Ash (%) Barrels _Zgdl. J%) MCF /Ft.
- - 31.2 18.2 . 534.6
- - 30.1 - 20.6 644.1
- - 24.9 24.6 96.8
86.2 11,685 3.5 14.9 63.4 136,508 0.381/ 1275.5 984
- '. 57.0 .'.
80.0 - - - '
80.0/97.0 - - 170.0
80.0 - - . .
_ _ _ _ _
170.0 12,030 3.9 11.9 57.0 138,100 0.3V 873.0 950
99.4 - - - -
99.4 - - - -
99.0 LS 70.0 ..299.0 .
99.0 LS ' 70.0 582.0 - ' -
99.4 - - - 39.0 542.0
881.0 10,745 1.9 11.9 93. Q2/ 138,100 0.3V 5447. fl2/ 950
99.4 - - 412. 2^1/9, assi/-/ .32 5.8
99.5 - - '
99.5
99.5 - - :
1591.0 9,477 5.4 21.7 18.0 137,888 0.35 .
Utility Plants - 1979. " '
Estimated Actual 1979
Emissions (10 Tonr.)
SO
/ Unit totals do not equal grand totals on Form 67.
!( '
g './ Homoval efficiency not available.
P
i; !/ Represents deliveries, not consumption. Unit will commence operation in 1980.
o
Tl
z
o
o
a
TJ
O
m
O
2-
2.7
NO
3.8 1.3
25.0
1.8 0.2
9.0 0.6
163.0 14.4 1.4
-------
(24d)c.l
Unit
Ut i 1 i ty/Powerolant Number
MISSOURI
City of Independence
Blue Valley 1
2
3
Total
Kansas City Power & Light
Grand Avenue 1
5
7
8
9
Total
Hawthorn 1
2
3
4
5
Total
latan 1
Montcose. 1
2
3
' Total
Nnmc Not
Plate Dependable
Capacity Caoacitv Location
25.0
25.0
65.0
115.0
12.0
10.0
35.0 .
30.0
40.0
127.0
69.0
69.0
113.0
143.0
515.0
909.0
726.0
188.0
183.0
188.0
564.0
(MW) City County
24
24
60
108
5
5
35
.0 Independence Jackson
.0
.0
.0
.0 Kansas City Jackson
.0
.0
14.0
40
99
70
70
125
140
520
925
630
182
182
182
546
.0
.0
.0 Kansas City Jackson
.0
.0
.0
.0
.0
.0 Weston Platte
.0 Clinton Henry
.0
.0
.0
.... . Currently Enforced admissions Liiui
Status 2-
SO NO TSP (lbs/10
2 x
- X-P 6.
6.
6.
X-P 9.
9.
9.
9.
9.
- X-P 6.
6.
6.
6.
6.
- - XX 1.
- 12.
12.
12.
faBtu)
3
3
3
0
0
0
0
0
1
1
1
1
1
2
9
9
9
NOX
(Ib's/lU Qtu)
None
None
None
None
None
None
None
None
None
None
None
None
None
0.7
None
None
None
, TSP
(lbs/10
0.
0.
0.
': 0.
0.
0.
0.
0.
0.
0.
0.
0.
o.
0.
0.
0.
0.
ts
6
btu)
28
2B
28
18
18
18
18
18
18
18
18
18
12
1
2
2
2
Averag ing
Per iod
3 hr SO2
Ti'p-l hr..
3 hr SO2
TSP-i hr .
3 hr SO2
TSP-1 hr.
TSP-1 hr.
3 hr SO?
N(Jx-max
3 hr SO;
TSP-1 nr.
Boiler Data
Bottom
Wet
Wot
Wet
N/A
Dry
Dry
Dry
N/A
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Firing
Pulveriz-.. i:
Pulverize!
Pulverizer
front
Pulverizer
Pulverizer
Pulverizer
N'/A
Pulver izi^r
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulver i zer
Pulverize:'
Pulverizer
Pulverizer
i/ All limits for "existing" plants apply to all fuels.
2/ New Source. On-Line in 1980.
o
T1
z
o
o
3
0
O
DO
5
m
-------
!4b)c
Ut ility/Powerplant
'.SSOUUI
Arkansas-Missouri Power Co.
Jim Hill
Ar.soc. Electric
New Madrid!/
Thomas Hill
Central Electric Power Coop
Chamois
City of Columbia
Columbia
-
Empire District Electric :
As bury
Unit
Number
1
1
2
1
2
1
2
2
4
5
6
7
8
1
Control Equipment
1979 Fuel Consumption
Coal Oil . Gas
Particulates .SO, ,_3 ,_.. ,n3 ,.,. , Sulf. 1n3 __
EauiD. Eft. (%) Equip.
- -
ESP 90.0
ESP 90.0
ESP 89.0
ESP 99.0
ESP 99.5
ESP 99.5
- -
_
MC 88.5
-
MC 92.0
_ _
ESP 98.4
' Eff. (%) Tons /lb. Sulf. (%> Ash (%) Barrels /gal. <*) MCF /Ft.
53.5 149,673 1.06 1,087.9 . 1,028
_
_
2,900.0 10,200 3.5 . 16.0
/
1,400.0 10,000 4.0 16.0
18.0 0.6
56.0 0.5 Not
74.0 10,785 3.4 10.8 1.1 135,000 Avail.
_
: - - . -
28.2
- - . -
45.8
- - 3.1 320.1
74.0 10,876 3.96 11.99 5.3 138,000 0.3 347.3 1,000
Not
653.9 10,172 4.9 24.6 2.2 145,600 Avail.
Estimated Actual 19V-
Emissions (10 Tons;
SO,
2-
NO
Not Availaole
Not Available
Not Available
5.0 1.7
2.93 2.03 .04
64.0 18.0 1.0
r Madrid will retrofit 99.6% efficient ESP's in 1980.
o
Tl
z
o
o
DO
0
O
30
m
O
-------
<24)c.l
Util i ty/Powerolant
MISSOURI
Arkansas-Missouri Power Co.
Jim Hill
Assoc. Electric
New Madrid
Thomas Hill
Central Electric Power Coop.
Chamois
City o£ Columbia
Columbia
Empire District Electric
As bury '" -
Unit
Number
1
1
2
Total
1
2
Total
1
2
Total
2
4
5
6
7
8
Total
1
Plate Depenaaoie Bouncy Attainment
Capacity Caoacitv Location Status 2
(MW)
33.
600.
600.
1200.
180.
303.
483.
15.
44.
59.
9.
5.
19.
13.
29.
41.
107.
213.
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
(MW)
35.
600.
600.
1200.
180.
290
470.
17.
49.
66.
8.
4'.
16.
10.
22.
36.
96.
200.
City
0 Campbell
0 Marston
0
0
0 Moberly
0
0
0 Chamois
0
0
0 Columbia
0
0
0
0
0
0
0 Asbury
County SO NO TSP (lbs/10
2 x
Dunklin - - - 2.
New Madrid - - X-P 10.
10.
Randolph ' - 9.
9.
Osage - - 6.
6.
Boone - - ' XX-P 4.
4.
4.
4.
4.
Jasper - - - 12.
6
Qtu)
857 -/
0
0
Si/
5
7
7
o V
0
0
0
0
0
NO
(lbs/10 Dtu)
None
None
None
None
None
None
None
None
None
None
None
None
None
TSP
(lbs/106Eto)
0.3
.18
.IS
:' .22
.22
0.3
0.3
.0.3
0.3
0.3
0.3
0.3
0.23
Averag ing
Period
3 hr SO,
TSP-1 hr.
3 nr SO2
TbP-i hr.
3 hr S02
TSP-i hr.
3 hr S02
TbP-i hr.
3 hr SO2
TSP-i hr.
3 hr S02
TSP-1 nr.
Boiler Data
Bottom
li/A
Wet
Wet
Wet
Wet
Dry
Ket
Dry
Dry
Dry
Dry
N/A
Wet
Fi r i r-5
Front
Cyclone
Cyclone-
Cyclone
Cyclone
Pulverizer
Cyclone
Stoker
Stoker
Stoker
Stoker
Front
Cyclone
I/ All limits for e x i s t i ng plants apply to all1 fuels burned.
2/ Jim Hill S02 limit given as 1000 lbs/hr.; stated figure derived.
3/ Thomas Hill will meet 8.0 SO2 standard by 1/1/82.
4/ Columbia SO2 'limit is 4.0 until 1/1/81, and 8.0 thereafter.
O
-n
o
o
3>
-0
O
DO
m
-------
(23£)c.l
Utility/Powerplant
Unit
Number
1979 Fuel Consumption
Control Equipment
Oil
Particulates
quip. Eff. (%)
SO,
10
Btu
10
Eff. (%) Tons /lb. Sulf. (%) Ash (%) Barrels /gal.
s""-. : io3
Bt"/Ft.3
Estimated Actual 1'j
Emissions (10 Ton.
so,, Ji£x
MISSISSIPPI
Mississippi Power Co.
Watson
ESP
ESP
98.0
99.0
22.7
18.9
27.9
22.7
506.9
850.6 .
1357.5 12,070 2.44 11.5 92.2 142,044 .24 4431.4 1,057 66.4 18.5
1234.4
1097.7
1523.6
35.1
540.6
Southern Miss. Elec. Pwr.
R.D. Morrow
Moselle
ESP 99.6 LSS 85.0 156.2
ESP 99.6 LSS 85.0 284.2
440.4 11,147 1.43 17.2
6.1
10.7
16.8
70.2
110.4
83.2
136,187 1.37
1180.6
1300.0
630.2
12.4 7.9 0.
263.8 146,158 3.22 3110.8 1,021 Not Available
L No Consumption data was given on Form 67 for unit 2. Stated figures are difference between .total consumption and unit 1 consumption.
o
Tl
o
o
3J
s
JO
3
o
-------
(23d)c.l
Ut11i ty/Powe rpla nt
MISSISSIPPI
Mississippi Power Co.
Watson
Southern Miss. Elec. Pwr.
R,D. Morrow
Moselle
Number
1
2
3
4
5
Total
1
2
Total
1
2
3
Total
Name
Plate
(UK)
94
94
109
299
578
1174
180
201
381
59
59
59
177
.0
.0
.0
.0
.0
.0
.8
.0
.8
.0
.0
.0
.0
Net
Dependable
(MW)
79.
79.
116.
250.
552.
1078.
180.
80.
360.
59.
59.
59.
177.
City County
8 Gulfport Harrison
8
2
6
0
4
0 Purvis Lamar
0
0
0 Moselle Jones
0
0
0
^ ,^ . ^ Currently Enforced Emissions Limits
SO NO TSP (lbs/10
2 x
- - - 4.
4.
4.
4.
4.
- 0.8-0/1.
0.8-0/1.
X-P 4.
4.
4.
Btu)
8
3
8
8
8
2-C
2-C
8
8
8
NO
(Ibs/lQ Btu)
None
None
None
None
None
0.3-O/7-C
0.3-0/7-C
None
None
None
TSP
(lbs/10 Btu) Period
For State:
.29 4-1/2 hrs.
.29 for TSP
.27 and SO2
.27
.22
'o.i-oii/c.
0.1-Oil/C. '.
0.30
0.30
0.30
Boiler Data
Bottom Firing
Tangential
Tangential
Tangential
Dry Pulverizer
Dry Pulverizer
Dry Pulverizer
Dry Pulverizer
Front
Front
Front
o
Tl
z
o
o
3)
o
O
3
m
D
-------
3b)c.l
1979 FUG! Consumption
Ut ility/Powerplant
SSISSIPPI
Greenwood Utilities
Henderson
Mississippi Power s Light
Andrus
Delta
Natchez
Baxter Wilson
MC
.MC
90.8
92.0
26.1
43.1
69.3 13,202
1.5 54.5
0.6 . 70.4
1.1 5.9 2.1 147,031 2.2 106.7
4572.7 147,409 1.94
2,267.6
4,387.7
4,182.3
17,616.7
145,557 0.88 26,813.3
43.0
295.5
410.1
726.8
100.5
2397.0
1849.2
4248.2
148,675
148,541
1852.7
1797.2
2-4 3649.9
0.58 1969.7
8,846.3
7,688.3
149,053 2.25 16,493.0
Estimated Actual 1979
Dnissions (10 Tons)
2-
1,000 1.5 Not 0.3
Available
29.7 10.1 0.8
l.OOOl/ .13 5.3 0.2
l,003i/ 5.8 2.3 .15
955 .24 .64 .0-!
l,044i/ 31.9 12.6 .84
Mississippi Power Co.
Daniel
ESP
99.0
601.1 11,565
.55
9.3
114.9 145,303 .53
7.2 5.4
.33
33.7
37.1
70.8 145,489 2.4
1.9
2.4
4.3
150,1
1.9
434.8
485.0
919.8 1,119
0.4
.12 .002
.04 .02 Not Ava:
Source: Cost and Quality of Fuels for Electric Utility Plants - 1979.
o
z
o
o
DO
TJ
O
3J
m
O
-------
(23) C.I
Unit
Ut il i ty/Powerplant Number
MISSISSIPPI
Greenwood utilities
Henderson 2/ 1
2
Total
Mississippi Power & Light
Andrus 1
Rex Brown 1
2
3
4
Total
Delta 1
2
Total
Natchez 1
Name
Plate
Net
Dependable
Capacitv Capacity
(MW)
12.7
20.0
32.7
781.0
35.0
44.0
66.0
239.0
384.0
110.0
110.0
220.0
66.0
(MW)
12.7
20.0
32.7
761.0
36.0
47.0
69.0
210.0
362.0
95.0
95.0
190.0
73-.0
Location
City County
Greenwood LeFlore
Greenville Washington
Jackson Hinds
Cleveland Bolivar
Natchez Adams
.... Currently Enforced Emissions Limits .
Status ~2~G ~X~G ^"(i Averaging Boiler Data
SO NO TSP (lbs/10 Btu) (lbs/10 Btu) (lbs/10 Btu) Period Bottom Firing
2 x
1 1/2 hrs.
- 4.8 ' None .37 ' for a whole Dry Stoker
4.8 None .35 State - for Dry Stoker
TSP 4 502'
- - - 4.8 None .20 Opp. Kail
4.8 None ; .33 Front
4.8 None .32 . Front
4.8 None .30 ' Front
4.8 None .24 Front
4.8 None .27 . Front
4.8 None .27 Front
4.8 None ' .30 Front
Tangential
Baxter Wilson 1
2
Total
Mississippi Power Co.
Da n i e 1 1
Ea tonV 1
2
3
Total
Sweatt 1
2
Total
545.0
783.0
1328.0
548.0
26.0
26.0
26.0
78.0
46.0
49.0
95.0
V SO2 and TSP limits for existing plants apply to
2/ Net Dependable Capacity ratings not available.
O
Tl
z
0
o
3
TJ
O
3
m
O
3/ No Fuel Consumption data available for
Unit 3.
525.0
650.0
1175.0
503.0
25.0
25.0
25.0
75.0
45.0
48.0
93.0
Vicksburg Warren
Jackson Escataupa
Petal Forrest
Meridian Lauderdale
4.8 None .21 opp. Wall
4.8 None ' .19
- 0.8-Oil/1.2-Coal 0.3/0.7-Coal 0.1-O/C. Dry Pulverize:
4.8 None . .35 Front
4.8 None .35 Front
' 4.8 . None ' ' .35 Front
4.8 None .3 Front
4.8 None .3 Front
all fuels burned.
Nameplate Capacity used instead.
'~
, '
f
._
-------
(3-1.De-
t Hi ty/Powerplant
OHIO (Cent.)
Cleveland Electric Ilium.
Avon Lake"
Unit
Number
1
2
3
4
5
6
7
8
9
10
11
12
Name
Plate
Capa~
u i i-y
(MH)
190
86
86
233
680
1,275
123
123
123
208
680
1,254
60
'60
69
69
256
. 514
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
Net
Dependable . ' County Attainment
Capctc
ii.y UI-II.U I. lull ^>k-ui-ua
Currently
SO.,
C.
Enforced Emissions Limits 3/
NO
rt z
(MW) City County SO, NO TSP (lbs/lo"utu) (lbs/10°Btu)
213
96
96
232
650
1,287
136
136
136
243
650
1,301
62
62
75
75
253
527
Avon Lake Lorain X-P - X-P
.0
.0
.0
.0
.0
.0
.0 Willoughby Lake X-P - X-P
.0
.0
.0
.0
.0
.0 Cleveland Cuyahoga X-P - X-P
.0
.0
.0
.0
.0
1
1
1
1
1
1
1
1
4
4
4
4
5
5
5
5
5
1
1
1
1
1
.04/0
.04/0
.01/0
.04/0
.04/0
.04/0
.04/0
.04/0
.10/4
.10/4
.10/4
.10/4
.34 I/
.3%
.34
.3%
.3%
.3%
.3%
.3%
.65
.65
.65
.65
.64 2/
.65
.64
.64
.64
.9
.9
.9
.9
.3
1
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None -
None
None
None
None
None
None
rep
(lbs/10uatu)
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.
Averaging Boi "' f~ * -
t lui Ljtj i-a
Period Bottom Firing
30 days N/A
N/A
N/A
N/A
N/A
K/A
N/A
N/A
Dry
Dry
Dry
Dry
30 days Dry
Dry
Dry
Dry
Dry
30 days Wet
Wet
Wet
Wet
Dry
Opp. Wall
Opp. Wall
Opp. Wall
Opp. Wall
Opp. Wall
Opp. Wall
Opp. Wall
Opp. Wall
Pulverizer
Pulveriser
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Eastlake 1
2
3
4
5
Lakeshore ,91
92
93
94
18
I/ Avon Lake 503 emissions limits allow 4.1 Ibs SO2/10^BTU from the coal-fired units when 1.0% sulfur oil is burned in the other units, or 4.65
Ibs S07/106BTU when 0.3% sulfur oil is burned, assuming a stack height credit. Without a stack height credit the limits are 3.43 Ibs
S02/10"BTU with 1.0% sulfur oil and 3.93 Ibs SO2/106BTU with 0.3% sulfur oil. '
2/ Eastlake SO2 emission limit assumes stack height credit.' Without credit, limit is 3.04 Ibs SO2/106BTU.
3_/ Emissions limits apply to all fuels.
o
Tl
o
o
33
o
O
3
m
O
-------
(Mf)c
1979 Fuel Consumption
Estimated /actual 1979
Control Equipment
Unit
(Jt ili ty/Powerplant Number
OHIO (Cont.)
Cleveland Electric Ilium.
Avon Lake 1
2
3
4
5
6
7
8
9
10
11
12
East Lake 1
2
3
4
5
Lake shore 91
92
93
94
:.-. 18
Particulates S0_ ..3'
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
set.
99.
99.
97.
99.
98.
98.
98.
98.
99.
99.
(%) Equip.
0
5
0
5
2
2
2
2
8
4
2 EM. (%) 10 TO
254
193
383
1,388
2,219
232
292
297
515
1,108
2,445
512
512
Coal
Oil Gas
ns Dtu/lb. Sulf. (%) Ash (%) Barrels tU /qal. (%) ° MCF
.9
.1
.3
.3
.6 11,953 2.8 12.0
.1
.2
.6
.1
.5
.5 '12,169 3.47 12.10
.8
.8 12,217 0.73 10.4
32
18
23
6
11
17
4
6
1
3
2
11
139
6
8
4
13
12
45
141
178
242
. 303
6
872
.1
.6
.3
.8
.2
.1
.7
.1
.8
.1
.8
.6
.2 146,368 0.88 \J
.2
.7
.4
.9
.7
.9 137,771 -0.30 I/
.2
.4
.6
.5
.4
.1 151,104 1.37
3
Emissions (10 Tons)
BtU/Ft.3 SO, NO TSP
121.1 21.0 2.3
165.0 22.6 3.1
10.6 7.3 1.0
I/ Source: DOE/EIA, Cost and 3uality of Fuels for Electric Utilities - 1979
o
Tl
o
o
a
T)
o
3
m
o
-------
(34h)c
Ut i1ity/Powe rpla nt
OHIO (Cont'd)
Columbus & Southern Ohio
Conesville
Picway
Dayton Power & Electric
Hutchings
Stuart
Unit
Number
1
2
3
4
5
6
Total
7*
8*
9
Total
1
2
3
4
Total
1
2
3
4
5
6
Total
1
2
3
4
AUX .
Name
Plate
Capa
city
(MW)
136
136
162
842
444
403
2,123
30
34
106
170
44
44
69
75
232
69
69
69
69
69
69
414
610
610
^610
610
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
Net
Dependable
Capaci'
(KK)
122.
122.
178.
800.
375.
375.
1,972.
29.
29.
95.
153.
45.
45.
71.
71.
232.
61.
60.
67.
67.
67.
67.
389.
585.
585.
585.
570.
.ty Loca
City
-
0 Conesville
0
0
0
0
0
0
0 Lockbourne
0
0
0
0 Athens
0
0
0
0
0 Miamisburg
0
0
0
0
0
0
0 Aberdeen
0
0
0
rt . Currently Enforced Emissions Limits V
County Attainment -
tiorr Status 2~
County SO2 NO TSP (lbs/10
Coshocton X-P - - 5.
.5.
5.
5.
1.
1.
Picway X-P - - 6.
6.
6.
Athens - - 3.
3.
3.
3.
Montgomery ' X-P - X-P 1.
1.
1.
1.
1.
1.
Adams - - 3.
3.
i 3.
3.
C
6Btu)
66
66
66
66
2
2
04
04
04
72
72
72
72
2
2
2
2
2
2
16
16
16
16
NO
6
(lbs/10 Btu)
1
None
None
None
None
0.7
0.7
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
TSP
(lbs/10
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
- /wecaging
Btu) Period
1 30 days
1
1
1
1
1
1 ' 30 days
1
1
1 30 days
1
1
1
1 30 days
1
1
1
1
1
1 30 days
1
1
1
Boil
Bottom
Wet
Wet
Dry
Dry
Dry
Dry
Wet
Wet
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
er Data
Firing
Cyclone
Cyclone
Pulverizer
Pulverizer
Pulver i zer
Pulver izer
Pulverizer
Pulverizer
Pulverizer
Pulver i zer
Pulverizer
Pulverizer
Pulverizer
Pulver izer
Pulverizer
Pulver izer
Pulverizer
Pulverizer
Pulverizer
Pulver izer
Pulverizer
Pulverizer
Pulverizer
2,440.0
2,325.0
*Picway Units 7 ana 8 retire in 1980.
I/ Emissions limits apply to all fuels.
o
Tl
o
o
30
-0
O
31
m
O
-------
1979 Fuel Consumption
Estimated Actual 1979
1 Control Equipment
Unit
Ut i li ty/Powerolant Number
0 (Cont'd)
Columbus & Southern Ohio
Conesville 1
2
3
4
I 5
: ' 6
Picway 7
8
9
{
Poston 1
| 2
3
4
I
Dayton Power & Electric
Hutchings 1
2
3
4
5
6
:..-
I Stuart 1
2
j 3
' 4
Aux.
I
Part iculates
Equip.
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
Eff. (%)
99.7
99.7
99.7
99.3
99.7
99.7
99.7
99.7
99.7
99.7
99.7
99.7
99.7
99.5
99.5
99.5
99.5
99.5
99.5
99.5
99.5
99.5
« 99.5
SO, 3
Eauip. ' Eft. (%) To
239
263
291
1,076
LS 89.6 768
LS 89.6 ' 993
3,633
8
8
172
189
68
68
119
174
430
87
79
105
153
135
96
656
1,451
1,459
1,457
1,567
5,936
Coal
Oil Gas 3
ns Btu/lo. Sulf. (») Ash (%) 10 Barrels Bt" /gal. (%) 10 KCF Btu/Ft.3 SO. NO TSP
.5
.8
.8
.6
.1
.3
.1 10,808 4.25 14.90
.4
.8
.2
.4 10,864 3.97 13.90
4
.5
.7
.5
.2
.9 11,159 3.78 12.28
.2
.0
.6
.5
.9
.5
.8 12,220 0.62 12.5
.7
.4
.5
.3 i
.0 11,173 1.2 15.1
130.6 32.6 4.3
11.3 1.8 2.1
24.4 3.9 0.4
121.1
119.6
112.4
105.1
119.5
91.6
669.3 1,020 7.9 5.9 0.3
5.7
6.9
4.7
4.4
0.9
21.8 137,043 0.3 142.5 53.5 14.1
o
Tl
z
o
o
DO
0
O
3D
m
o
-------
(341>c
Currently Enforced Emissions Limits I/
Ut ility/Puw&rplant
OHIO (Cont'd)
Dayton Power & Light
*Tait
City of Dover
Dover Municipal
City of Hamilton
Hamilton
Ohio Edison
BurgQr
Edgewater
Unit
Number
4
5
7-1
7-2
8-1
8-2
Total
1**
2»*
3«*
4
Total
7
8
9
Total
1
2
3
4
5
6
7
8
Total
11
12
13
Total
Flcll
Capac
e
:ity
(MW)
147.
147.
150.
444.
***19.
19.
23.
26.
50.
100.
63.
63.
100.
160.
160.
546.
25.
63.
105.
193.
0
0
0
0
_5
5
0
9
6
5
0
0
0
0
0
0
0
0
0
0
e^on '
Capac:
iDie county Attainment
Lty Location Status
(MW) City County SO, NO TSP
139.
139.
148.
426.
19.
19.
23.
50.
92.
66.
66.
103.
161.
161.
557.
5.
66.
104.
175.
0 Dayton Montgomery X-P - X-P
0
0
0
Dover Tuscarawas - - XX
5
1 Hamilton Butler - - X-P
6
1
8
0 Shadyside Belmont - - X-P
0
0
0 - ,
0
0
0 Lorain - Lorain X-P - X-P
0
0
0
ao.
NO
X c
llbs/10°Btu) (lbs/10°Btu)
1
1
0
0
0
0
4
4
4
4
1
1
1
No
No
No
No
No
No
No
No
3
3
. 3
.25
.25
.5
.5
.5
.5
.6
.6
.6
.6
.4
.4
.4
. Reg.
. Reg.
. Reg.
. Reg.
. Reg.
. Reg.
. Keg.
. Reg.
.4
.4
.4
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
ilbs/106Btu)
0.1
0.1
0.1
0.1
0.1
0.1
0.126
0.126
0.126
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
Averaging Boiler Data
Period Bottom
30 days Dry
Dry
Dry
Dry
Dry
Dry
30 days Dry
Dry
Dry
Dry
30 days Dry
Dry
Dry
30 days Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
30 days Dry
Dry
Dry
Firing
Pu Iver i zer
Pulverizer
Pu Iver i zer
Pulverizer
Pu Iverizer
Pulverizer
Stoker
Stoker
Stoker
Stoker
Pulverizer
Pulverizer
Pulverizer
Pulver i zer
Pulverizer
Pulver i zer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulver izer
Pulverizer
Pulver izer
Pulver i zer
* Units 7-1, 7-2, 8-1, 8-2 » DOE units 1-3 plus 7
** Retiring.
»** Net-Dept. not available from GURP File.
I/ Emissions limits apply to all fuels.
o
Tl
o
o
3)
TJ
O
3
m
O
-------
(J'ln)c
Control Equipment
Unit
Ut i 1 i ty/ Powerplant Number
iino (Cont'd)
Dayton Power & Light
Tait 4
5
7-1
7-2
8-1
8-2
City of Dover
Dover Municipal 1
2
3
4
City of Hamilton
Hamilton 7
8
9
Ohio Edison
j Burger 1
! '2
. 3
- 1
5
6
7
8
Edgewater 11
12
13
Part iculates
Equip.
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
Eff.
99
99
95
95
97
97
85
99
99
99
99
97
97
99
99
99
99
99
99
99
(») E
.5
.5
.0
.0
.0
.0
.3
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
SO., 1Q3
3uifi. " Eff. (%) Ton
261.
135.
-
-
-
380.
2.
6.
29.
37.
58.
135.
194.
81.
81.
61.
67.
117.
109.
388.
345.
1,252.
, 70.
67.
263.
401.
1979 Fuel Consumption
Coal Oil Qas
3 Suit. 3 Estimated Actual 1979
s Btu/lb. Sulf. (%) Ash (%) ° Uarrels tu /gajl. ft) 10 MCF Qtu Ft.3 Emissions (logons)
SO, NO TSP
6 . 36.3
4 39.8
27.5 1-9
26.8 1-4
85.9 4.8
86.2 4 o
6 12,249 0.64 12.0 220.6 136,074 0.22 . ^7J 1/Q20 4_g 3_4 Qa
2
0
.4
6 12,358 2.6 13.75 .3 140,112
0-5 ' 415.2
8 ' 1.9
5 . 168.7
3 12,941 0.75 12.8 2.4 137,000 0.21 583.9 1(000 .,_<, 2_8 0_lg
9 ' .
8
5
4
0
6
1
5 , ' '
8 11,926 3.4 13.2
9 80.9 11.3 7.3
6
0
5 11,902 2.5 10.7
19.1 3.6 2.9
O
Tl
z
o
o
3
S
3
-------
(34p)c
lit i I i ty/Powerpla nt
OHIO (Cont'ci)
Ohio Edison
Gorge
Niles
Sainmis
Ohio Electric Company
Gavi n
Unit
Number
1
2
Total
1 V
2 I/
3
4
Total
1
2
Total
4 3/
5
Total
1
2
' 3
4
5
6
7
Total
9
10
11
Total
1
2
Total
Name
Plate
Capac ity
(MW)
44.0
44.
88.
25.
25.
25.
25.
100.
125.
125.
250.
6.
18.
24.
0
0
0
0
0
o y
0
0
0
0
0
0
0
185.0
185.
185.
185.
318.
623.
623.
2,304.
44.
66.
66.
176.
1,300.
1,300.
2,600.
0
0
0
0
0
0
0
0
0
0
0
0
0
0
Net
Dependable County Attainment -
Capacity Location Status ~
Currently Enforced Emissions Limits 4/
SO
NO
(MWi City County SO, NO TSP (lbs/10 Btu) (lbs/10 Btd)
48
48
96
22
25
24
25
96
115
115
230
6
16
22
188
188
193
193
330
650
650
2,392
42
65
65
172
1,300
1,300
2,600
^^^ ~^ ^ ^ A
.0 Akron Summit X-P - X-P
.0
.0
.0 Springfiela Clark - - XX-P
.0
.0
.0
.0
.0 Niles Trumbull - - X-P
.0
.0
.0 Norwalk Huron -
.0
.0
.0 Stratton Jefferson. X-P - X-P
.0
.0
.0
.0
.0
.0
.0
.0 Toronto Jefferson X-P - ' X-P
.0 . ,
.0
.0 .
.0 Cheshire Gallia XX-P - XX
.0
.0
4
4
4
4
4
4
5
5
5
5
1
1
1
1
4
4
4
2
8
8
8
9
9
.07
.07
.62
.62
.62
.62
.41
.41
.41
.41
.61
.61
.61
.61
.46
.46
.46
.91 plant
.1
.1
.1
.5
.5
None '
None
None
None
None
None
None
None
None
None -
None
None
None
None
None
None
None
None
None
None
None
None
TSP
Averaqinq Boiler Data
(lbs/10 Btu) Period bottom Firing
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
.1
.1
.1
.1
.1
.1 .
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
30 days Dry
Dry
30 days Dry
Dry
Dry
Dry
30 days Wet
Wet
30 days Dry
Dry
30 days Dry '
Dry
Dry
Dry
Dry
Dry
Dry
30 Days Dry
Dry
Dry
30 days Dry
Dry
Pu Iver izer
Pulverizer
Stoker
Stoker
Pulver i zer
Pulverizer
Cyclone
Cyclone
Stoker
Stoker
Pulver izer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulver i zer
Pulver i zer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
y Mad River 1 i 2 retired in 1980
2/ Capacity data for unit 4 taken from FERC Form 67.
3/ Norwalk No. 4 - Shutdown in 1979; No. 5 retiring in 1980.
4/ Emissions limits apply to all fuels.
O
n
o
o
3D
TJ
O
3
m
O
-------
Uc)c
1979 Fuel Consumption
Estimated Actual 1979
Utility/Pow^rplant
MIO (Cont'd)
Ohio Edison
Gorge
Mad kiver
Niles .
Norwalk
Sammis
Toronto
Ohio Electric Company
Gavi n
' ESP to replace Mechanical
o
-n
z
0
o
30
O
DO
m
o
Unit
1
2
1
2
3
4
1
2
3
4
1
2
3
4
5
6
7
9
10
11
1
2
Collector
Control Equipment
Particulates SO
Equip. Eft". (%) Equip- EEf. (%)
ESP 98.0
ESP 98.0
MC 55.0
MC 55.0
BH/MC Proj. 99.3/79.0
BH/MC Proj. 99.3/80.0
*MC/ESP 70.0/Proj.99.0
MC/ESP 70.0/Proj.99.0
MC 88.0
ESP 98.0
ESP/BH 97.0/Proj.99.4
ESP/BH 97.0/Proj.99.4
ESP/BH 97. O/ Proj. 99. 4
ESP/BH 97.0/Proj.99.4
ESP 99.0/New 99.4
ESP 99.0/New 99.4
ESP 99 0/New 99.4
ESP 99,0
ESP 99.0
ESP 99.0
ESP 99.8
ESP 99.3
in 1981.
-
-
,
103
TO
140
145
285
19
20
33
82
157
277
296
573
6
17
23
351
424
425
391
516
767
1,090
3,967
114
196
217
528
3,941
4,276
8,217
Coal Oil Gas
ns Bt°/lb. Sulf. (%) Ash (%) Barrels " /gal. (%) MCF
.2
.3
,5 11,674 3.6 11.7
.9
,9
,6 .
.7
.1 11,751 1.0 12.1
.2
.3
.5 11,863 3.3 12.5
.7
.2
.9 11,591 4.0 . 6.9
.3
.5
.8
.3
.8
.4
.7
.8 11,604 2.5 12.0
.5
.6
.0 i
.1 11,837 3.2 13.4
.9 41.4
.1 24.8
.9 9,260 2.4 14.9 65.9 136,919 0.4
j
1
' ' 1 3
BtU/Ft.3 S02 NO TSP
19.0 2.6 1.4
3.1 1.4 2.9
36.0 16.1 2.2
0.2 0.2 0.2
188.5 35.7 37.4
32.1 4.8 5.3
394.5 74.0 2.45
-------
Ut ility/Powerplant
OHIO (Cont'd)
Ohio Power Company
Musk ingum
Ohio Valley Electric Coop
Kyger Creek
Orville Municipal
Vine St.
Painesville Electric Light
Painesville
Piqua Municipal
Piqua
St. Mary's Light s Power
St. Mary's
I/ Emissions limits apply to all fuels.
Unit
Number
1
2
3
4
5
Total
1
2
3
4
5
Total
12
13
Total
. 1
2
3
4
5
6
Total
4
5
6
7
Total
2
4
5
6
Total
Name
Plate
Capacity
(KM )
220
220
238
238
591
1,507
217
217
217
217
217
1,086
22
26
48
3
3
8
8
17
25
64
8
1
13
22
44
1
3
6
10
20
.0
.0
.0
.0
.0
.0
.3
.3
.3
.3
.3
.5
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
,0
.0
.0
.0
.0
.0
Net
Depend
Capac
able. County Attainment -
ity Location status -
Currently Enforced Emissions Limits I/
SO.
(MW) City County SO, NO TSP (lbs/lo"btu)
-
190
190
205
205
580
1,370
211
204
203
205
208
1,031
22
26
48
4
3
8
3
17
25
60
8
1
12
18
39
1
3
6
10
20
.0 Ueverly Morgan XX-P
.0
.0
.0
.0
.0
.0 Gallipolis Gallia XX-P - XX
.0
.0
.0
.0
.0
.0 Orrville Wayne XX
.0
.0
.0 Painesville Lake X-P - X-P
.0
.0 -
.0
.0
.0
.0
.0 Piqua Miami - i -
.0
:o
.0
.0
.0 St. Mary's Auglaize -
.0
.0
.0
.0
6.48
6.48
6.48
6.48
6.48
8.2
8.2
8.2
8.2
8.2
7.0
7.0
5.2
5.2
5.2
5.2
1.2
1.2
4.78
4.78
4.78
4.78
None
None
None
None
NO
(lbs/10 btu}
1
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
Notie
None
None
None
None
None
None
None
None
None
TSP
(lbs/10uBtu)
u
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
: o
0
0
0
.1
.1
.1
.1
.1
;l
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1-
.1
.1
.1
.1
.1
.1
.1
Averag ing
boiler Data
Period Bottom Firing
30 days Wc-t
Wc-t
Wet
Wet
Dry
30 days Wet
Ket
Wet
Ket
Wet
30 days Dry
Dry
30 days Dry
Dry
Dry
Dry
Dry
Dry
30 days Wet
Wet
Ket
Ket
30 days Not
Pu Ivor i zer
Pulverizer
Cyclone
Cyclone
Pulverizer
Pu Iver i zer
Pulverizer
Pu Iver i zer
Pulverizer
Pulverizer
Pu Ive r i zer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulve r i zer
Pulverizer
Stoker
Stoker
Stoker
Stoker
available
o
Tl
o
o
a
o
o
30
m
O
-------
(jMv)c
'j
i unit
;j Ut ility/Powerolant Number
It '
j HUG (Cont'd)
, Ohio Power Co.
t Muskingum 1
i 2
} 3
4
1
Ohio Valley Electric Coop
1 Kyger Creek 1
ji 2
- 3 '
;- 4
;. . 5
*' Orrville Municipal
i Vine Street 12
13
Painesville Electric Light
' Painesville 1
2
: 3
4
5
ij :. - 6
i
Piqua Municipal
! Piqua ' 4
5
6
I 7
Control Equipment
Particulates SC
Equip. Eff. (%) Equip.
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
BH
BH
UH
BH
-
99.5
99.5
9S.5
98.5
96.5
96.1
96.1
96.1
96.1
96.1
99.9
99.9
99.4
I/
4 I/
I/
I/
1979 Fuel Consumption Estimated Actu.il 1J74
Coal Oil Gas 3
' Eff. (S) 10 Tons Dtu/lb. sulf. (*) Ash (%) 10 Barrels BtU /gal. (%J iO MCF DtUFt.3 SO NO TSP
609.5 4.0
540.9 5.2
512.3 6.0
616.0 5.0
1,549.8 19.7
3,828.5 10,430 5.1 19.37 40.1 136,886 0.42 Jau'b ^ 3 7y-5
602.0
632.0
569.0
684.0
611.0 ,
3,098.0 11,242 3.84 14.0 214'° 46-5 7-°
,
120.0 11,500 3.2 9.0 J/ i/ V
78.0 12,500 3.0 8.0 }/!/*/
,
,/ I/ I/
j St. Mary's Light & Power
St. Mary's 2
6
98.5 11,946 1.3/2.5 12.0
(2.24)1/
V V V
lj Source: Cost and Quality of Fuels for Electric Utility Plants - 1979.
o
nn
I
3)
o
O
m
O
-------
(3-]x)c
Utility/Powerplant
OHIO (Cont'd)
City of Shelby Municipal
Light Plant
She Iby
Toledo Edison Company
Acme
Uay Shore
Unit
Number
1
2
3
4
Total
9/LP
10/LP
1VLP
12/LP
13/5
14/5
15/5
16/2
91-92/6
Total
1
'2
3
4
Total
Plate
Capa
city
(MW)
12
12
5
7
37
40
65
72
113
290
140
140
140
218
638
.5
.5
.0
.5
.5
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
Depend
Capac
aDle
ity Lo
(MW). City
12
12
5
_7
37
40
61
76
108
285
132
134
140
217
623
.5 Shelby
.5
.0
.5
.5
.0 Toledo
.0
.0
.0
.0
.0 Oregon
.0
.0
.0
.0
Bounty Attainment ^~-~
cation Status 2
NO
C
"" c
County SO2 NO TSP (lbs/lo"ntu) (lbs/10"Btu),
Richland X 9
9
9
9
Lucas X-P - X-P 1
1
1
1
3
3
3
3
3
Lucas X-P - X-P 1
1
1
1
.3
.3
.3
.3
.0
.0
.0
.0
.0/1.2-1981
.0/1.2-1981
.0/1.2-1981
.0/1.2-1981
.0/1.2-1981
.2/1.94 1981
.2/1.94 1981
.2/1.94 1981
.2/1.94 1981
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
TSP
c
(lbs/10"Btu)
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
.12
.12
.12
.12
.13
.13
.13
.13
.1
.1
.1
.1
.1
.1
.1
.1
Averag ing r * "
toiler uata
Period Bottom Firing
30 days
30 days
N/A
ti/A
N/A
Dry
Dry
Dry
Dry
Dry
30 days Dry
Dry
Dry
Dry
Not
Available
Front
Front
Front
Fulver izer
Pulverizer
Pulver i zer
Pulverizer
Pulver izer
Pulver izer
Pulverizer
Pulver izer
Pulverizer
1_ Emissions limits apply to all fules.
o
Tl
o
o
3
TJ
O
DO
m
O
-------
(3-lz)c
1979 Fuel Consumption
Control Equipment
Unit
Ut ility/Powerplant Number
OH [O (Cont'd)
City of Shelby Municipal
Light Plant
Shelby 1
2
4
Toledo Edison Company
Acme 9
10
11
12
13
14
15
16
91-92
Bay Shore 1
2
3
4
EauiD.
MC/ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
Eff.
75
99
99
99
99
99
98
97
98
98
98
99
s SO.,
(*) Equip. "
.0/99.0
.0
.0
.5 '
.5
.5
.7
.4/97.4
.5
.8
.5
.5
Coal
3
Eff. (%) 10 Tons BLu/lb. Suit. (%) Ash («) l
11.6
32.2
5.8
49.6 11,700 2.6 13.5
120.0
i
143.0
107.0
371.0 11,741 2.3 12.1
378.0
317.0
287.0
479.0
1,462.0 12,566 1.1 7.9
Barrels
94.
i
-
_
94.
4.
5.
2.
1.
15.
0
0
9
1
8
7
0
011 GaS Bnis-i
BtU/qal. (t) 10. MCF Bt"/Ft.3 SO,
I
3.8 1,000 3.15
11.4
I
8.0
1 .
688.8
206.0 540 17.3
151,137 1.2 914.0
137,029 0.3
Estimated Actual 197;>
t:o
0.44 0.05
3.7
0.5
32.2
13.2
0.7
o
Tl
z
o
o
3D
s
3
5
m
O
-------
(35)c.l
Unit
Ut i 1 icv/Poworplant Number
OKf-AIIOMA
Grand River Dam Auth.
Chouteau 1
2
3
4
5
6
Total
Oklahoma Gas & Electric
Arbuckle 1
Belle Isle!/ 1
2
3
Total
Horseshoe Lake 6
8
Total
Kuskogee ' 3A
4A
5A
Total
Mustang ""' . 1
2
3
4
Total <
Oa ag e!/ 1
2
3
Nam
O
1'late
Capa~ ~ ^"
(MW)
6
6
6
6
13
19
56
74
5?
163
443
606
173
572
572
1,317
82
63
113
253
511
.0
.0
.0
.0
.0
.0
.0
.0
To"
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
Not
Currently Enforced I-Jini;;si6nn Limits
Dependable County Attainment
Capac
i t.y ijtjo u L .L un oi.i3i.us
.My
NO ^
^ r.
T'J
p
t- Averaging
(MW) City County CO., NO TSP (lbc/lfluBtu) (lbs/10"ct!u) (lbs/10"Btu) Period
5
5
5
5
10
20
50
74
47
181
420
601
185
515
515
1,215
60
56
114
273
503
.0 Mayes - - X-P
.0
.0
.0
.0
0
.0
.0 Murray Sulphur
Oklahoma City Oklahoma - - X-P
To"
.0 Harrah Oklahoma - - X-P
.0
.0
.0 Muskogee Muskoee - - -
.0
.0
.0
.0 Oklahoma Canadian -
.0
.0
.0 . ,
.0
Ponca City Kay - - -
Nonii
None
None
None
None
None
None
None
None
None
None
None
None
1.2
1.2
None
None
None
None
None
None
None
None '
None
None
None
None
None
None
None
None
None
None
None
None
0.7
0.7
None
None
None
None
None
None
None
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
.35 i hour
.35
.35
.35
.35
.35
.2
.35
.35
.35
.2
.15
.2
.15
.15
.2
.2
.2
.2
.35
.35
.35
Boi
ISottom
Dry
Dry
Ory
Dry
Dry
Dry
N/A
N/A
N/A
N/A
N/A
N/A
N/A
Wet
Wet
Wet
Wet
N/A
N/A
Dry
Wet
Wet
ler Data
Firing
Pulv/Opp
Pulv/Opp
Pulv/Opp
Pulv/Cpp
Pulv/Opp
Pulv/Opp
Front
Front
Front
Front
Front
Front
Front
Pulverizer
Pulverizer
Pulv/Front
Pulv/Front
Front
Front
Pulv/Front
Pulv/Front
Pulv/Front
Total
I/ No SO2 or NO.X emission limits for "existing" plants are specified under new Oklahoma regulations. Only ambient air quality limits apply.
2/ Capacity ratings not available by unit.
o
Tl
o
o
3)
-0
O
3D
m
O
-------
C.I
1979 Fuel Consumption
t Control Equipment Coal Oil
Unit Particulates SO., 3 3 Suit.
! :tUity/Powerplant Number Enuip. Eff. (i) Eauip. " Eft'. (%) Tons /lb. Suit. (%) Ash (%) Barrels /qal. . (S.)
TWA (Cent.)
*' intl River Dam Auth.
Chouteau 1
2
3 '
5
6
-J"
hthoma Gas & Electric
Arbuckle 1
Belle Isle 1
2
3
Tl Horseshoe Lake 6 -
(i 8
'
Muskogee 3A . 0.0
4A ESP 99.5 902.2
5A ESP 99.7 . 1,076.4
1,978.6 8,648 0.4 5.0
Mustang :1
2 ' .
3
4
,
4 .
Osage 1
2
3
Gas
1()3MCF '
3,904.0
294.0
294.0
10,281.0
28,299.0
38,580.0
10,798.0
413.0
507.0
11,718.0
3,085.0
2,407.0
6,131.0
13,914.0
25,537.0
100.0
466.0
566.0
!tU/Ft.3
1,037
1,037
1,037
1,037
1,037
1,037
l] 'ut given on FERC Form 67.
I
1 oucce: DOE/EIA Cost and Quality of Fuels for Electric Utilities - 1979.
o
Tl
o
o
DO
0
O
Estimated Actual 1979
Emissions (10 Tonsl
so
2-
no
TSP
I/
I/
I/
20.0 38.0 0.38
I/
I/
m
O
-------
(35d)c
Currently Enforced Emissions Limits
Plate Depends le County Attainment I/ I/
Unit Capacity Capacity Location Status 2 x , Averaging
Uti Hty/PoweroU-int Nunb er (KW) (MWJ City County SO, NO TSP db s/10 Btu) (to s/10 Btu) (to s/10 Btu) Period
OKLAHOMA (Cont.)
oyiahotna Gas & Electric
Seminole 1 567.0 540.0 Ronawa Seminole - None None 0.15
2 567.0 540.0 None None 0.15
3 567.0 540.0 None None 0.15
Total 1,701.0 1,620.0
Sooner 1 567.0 515.0 Morrison Ncn le - 1.2 0.7 0.15
Oklahoma Ordinance Works
Mid-America 1 Pryor Mayes - - X-P None None 0.2
2 None None 0.2
3 None None 0.2
4 None None 0.2
5 None None 0.2
6 None None 0.2
Total 160.0 160. Oi/
Ponca City Mun. Water & Light
Ponca 2 43.0 40.0 Ponca City Kay - None None 0.1
Public Service Co. of Okla.
Northeastern ' 1 170.0 170.0 Oologah Rodgers - None None 0.2
2 473.0 470.0 . _._ None None 0.15
3 450.0 450.0 0.8-O/1.2-C 0.3-O/0.7-C 0.1
Total 1,093.0 1,090.0
I/ No SO2 or NOX emission limits for "existing" plants are specif ied' under new Oklahoma regulations. Only ambient air quality limits apply.
,2/ Net dependable capacity not available. 4
O
Tl
z
0
o
3
TJ
O
30
m
O
Boiler Data
Bottom Firinq
N/A opp. Wall
N/A Opp. Wall
N/A Opp. Wall
Wet Pulverizer
N/A N/A
N/A N/A
N/A N/A
N/A N/A
N/A N/A
N/A N/A
N/A N/A
N/A Front
N/A Front
Not Available
-------
1979 Fuel Consumption
Estimated Actual 1979
't U i ty/Powerplant
DMA (Cont.)
lanoma Gas 6 Electric
Seininole
Sooner
lahoma Ordinance Wor<
Mid-America
nca City Mun. Water &
Pone a
>lic Service Co. of O.
Northeastern
Control Equipment
Unit Particulates SO
Nuifc er Equip. Ef£. (%) Equip. ^ Elf. (*)
1
2
3 MC I/
1 ESP 99.5
s
1
2
3
4
5
6
Light
2
la.
1
2
3 ESP 99.6
Coal Oil
103 Btu 103 Btu Sulf' 103 '
Tons /lh . Sulf. (%) Ash (%) Barrels /qal. ' (%) VC]
1.6 . 28,134.
1-9 12,449
1.3 30,179
4.8 133,755 1.872/ 70,762
1,443.1 8,789 0.4 5.0 81.5 137,674 0.3
8'33
548.
958
310.
903,
168
3,773
- . ' 188
7,535.
0.7 26,449.
5.4 2,248,
5.4 8,500.0 0.39 5.8 0.7 140,200 0.55 36,232.
Gas . 3
? BtU/Ft.3 SO, NO TS?
.0
.0
.0
.0 1,037 I/
2.77 6.12 0.76
.3
.5
.3
.9
.9
.3
.2 1,000 I/
.9 1,035 I/
.0
.0
.0
.0 1,084 0.05 8.17 0.01
>t given on FERC Form 67.
-jurce: DOE/EIA Cost and Quality of Fuels for Electric Utilities - 1979.
o
o
o
3
0
O
a
5
m
O
-------
(35h)c
Ut i 1 ity/ Power plant
OKLAHOMA (Cont. )
PiMic Service Co. of
Riverside
Southwestern
.Tulsa
Western Farmers Elect
An ad a n, o
Mooreland
Name
Plate
Unit Capacity
Nunti er (KM)
Q la.
1 473.0
2 473.0
Total 946.0
1N 84.0
IS
2 84.0
3 315.0
483.0
1 33.0
2 170.0
3 95.0
4 170.0
468.0
. Coop .
1 15.0
2 15.0
3 30.0
60.0
1 55.0
2 136.0
3 135.0
326.0
I/ No SO2 or NOX emissions limits for existing plants
O
n
z
o
o
a
O
a
m
o
>
Net ' Currently Enforced Emissions Limits
Dependable County Attainment- I/ I/
(KW>. City County SO, HO TSP (In s/10 Dtu) (]hs/10 Btui) (Jns/10 Ecu) Period
455.0 Tulsa, Tulsa - - X-P None None 0.15 i hour
470.0 Hone None 0.15
925.0
80.0 Washita, Caddo - - - None None 0.2
None None 0.2
80.0 ' None None 0.2 .
310.0 None None 0.2
470.0
30.0 Tulsa, Tulsa - - X-P None None 0.35
165.0 None None 0.2
93.0 None None 0.2
165.0 None None 0.2
453.0
15.0 Anadan o, Caddo - - - None None 0.2
15.0 . None None 0.2
46.0 None None 0.2
76.0
53.0 Mooreland, Woodward - - - None None 0.2
135.0 None None 0.2
135.0 None None 0.2
323.0
are specified under new O; lahoma rgulations. Only anb ient air quality limits apply.
,?
"
, '
,
'
Boiler Data
Bottom Kirinq
N/A OPP- Wall
N/A Opp. Wall
N/A Front
IJ/A Front
N/A Front
N/A Opp. Wall
N/A Front
N/A Front
N/A Fror.t
N/A Front
N/A Front
N/A Front
N/A Opp. Wall
N/A Front
N/A Front
N/A Front
-------
1979 Fuel Consumption
Control Equipment Coal
Unit Particulates SO, 3
Utility/Powerplant Number Equip. Ef f . <*) Equip. * Et'f. (%) Tons /lb. Sulf. (%) Ash (%)
.IIOM/V (Cont.)
'ublic Service Co. o£ Okla.
Riverside 1
2
Southwestern IN
IS
2
3
Tulsa 1
' 2
3
4
.'.-stern Farmers Else. Coop.
Anadarko 1
3
4
5
6
Mooreland 1
3 '
Not given on FERC Form 67.
Total is not consistent with FERC Form 67, which gives total oil consumption at 0.028 x 103 barrels.
O
n
0
o
3
TJ
O
3
m
o
Oil
103 Btu SUU" 103
Barrels /qal. , (%) M;
13.2 17
2.9 ' 29
16.1 138,500 0.47 46
2,084
2,620
0.2 18,798
0.2 140,700 0.45 23,502
16
23.1 8,846
1,952
9.3 7,505
32.4 138,200 0.38 18,320
' 8,507
130
0.9 4,531
0.3 4,066
4,811
1.22/ 138,500 13,409
225
5,291
3,403
9,751
Gas
F "Vt.3
.0
.6
.6 1,055
.0
.0
.0
.0 1,071
.0
.0
.0
.0
.0 1,060
.0
.9
.4
.2
.9
.4 1,015
.5
.1
.2
.8 1,082
Estimated Actual 1979
Emissions (10 Tons)
-2-
HO
I/ 9.32 V
9.22 I/
I/ 3.5 I/
y y y
I/ 19.02 I/
-------
(35)c.l
Utili ty/Powerplant
Unit
Number
Name Net
Plate Dependable
Capacity Capacity
(KH) - (HW)
Location
County Attainment
Status
Currently Enforced Emissions Limits
so.
NO
TSP
City
County
S0_ NO
TSP (lbs/106utu) (lbs/l'06Btu) (lbs/106atn)
Averaging
Period
Boiler Data
Bottom Firing
Eugene Water & Electric Board
Willamette
2
1
7.5
3
Total
6.0
10.4
11.5
25.0
7.3
16.1
33.8
1.75'i-resid.
1.75%-resid.
1.75%-resid.
None
None
None
None
None
None
N/A N/A
N/A N/A
N/A N/A
Pacific Power & Light
Lincoln St.*
(inactive reserve):
9
10
11
Total
8.0
8.0
20.0
36.0
7.0
8.0
(20.0)
15.0
Portland
Multnomah
All Units:
None-gas/
0.5%-dist.
None
None
None
None
None
None
2 hrs.
N/A
N/A
N/A
N/A
N/A
N/A
o
Tl
z
o
o
* Lincoln St. Retired by 1980.
m
O
-------
Control Equipment
Uc ili ty/Powerplant
Unit
Number
Particulars
Coal
1979 Fuel Consumption
Equip. Eff. (t)
Eff. (%)
/lb. SulE. (%) Ash (%)
103 Btu , Sult-
/Barrels /gal1.
Estimated Actual 1979
Emissions (10 Tona)
SO,
TS?
HKGON (Cont'd)
Eu'jene Water & Electric Board
Willamette 1
2
3
Not Available
Pacific Power i Light
Lincoln St.
9
10
11
MC
MC
MC
Not Avail.
^4Ot Avail.
Not Avail.
12.0
10.0
11.0
33.0
137,800 0.3
244.0
299.0
318.0
861.0 1,047
1.75
o
Tl
o
O
3)
D
O
33
m
-------
Utility/Powerplant
Unit
Number
City
County
County Attainment
status
Currently Enforced Emissions Limits
2-jj x Averaging
TSP libs/10 Etu) (lbs/10 Btu) (lbs/10 Btu) Period
Boiler Dot.i
Bottom
Fir inc.
PENNSYLVANIA
Duquesne Light
Cneswick
Elrama
Total
565.3
100.0
100.0
125.0
185.3
510.3
562.0
96.0
102.0
109.0
174.0
481.0
Cheswick
Elrama
Allegheny
Washington
X
X-P
0.6/2.8*
0.6
0.6
0.6
0.6
None
None
None
None
None
O.OB
0.1
0.1
0.1
0.1
24 hrs.
24 hrs.
Dry
Dry
Dry
Dry
Dry
Pulverizer
Pulverizer
PuIverizer
Pulverizer
PuIverizer
Phillips
69.0
81.3
81.3
179.7
411.3
72.0
81.0
80.0
142.0
375.0
South Heights Allegheny
0.6
0.6
0.6
0.6
None
None
None
None
.Ua
.08
.08
..08
24 hrs.
Dry
Dry
Dry
Dry
Pulverizer
Pulverizer
Pulverizer
Pulverizer
* Proposed limit
o
Tl
o
o
30
0
O
3J
m
o
-------
(J70)c
Ut i II ty/Poworplant
PENNSYLVANIA (Cont'd)
Duquesne Light
Cheswick
Elrama
Phillips
Control Equipment
Coal
1979 Fuel Consumption
Unit Particulates
Number Equip. Eff. (%) Equip. * EEf. (%)
ESP/Vent.
ESP
ESP
ESP
1 ESP/Vent.
2 ESP
3 ESP
4 ESP
5 ESP
Btu
'/lb. Sulf. (%) Ash {%)
10'
Sulf.
Barrels
10
MCF
Estimated Actual
_Emissions (10 Tons ?
!2-
Btu/Ft. so, NO TS;
99.5
95.7/99.0
95.7
97.8
98.0
LSS
LSS
LSS
LSS
95.0/99.0 LSS
95.0 LSS
97.5 LSS
97.5 LSS
98.2 LSS
83.0
83.0
83.0
83.0
83.0
83.0
83.0
83.0
83.0
1,363
1,452.7
11,762
11,568
11,763
1.8
2.1
15.4
16.8
49.0 20.4 4.0
8.54 21.8 1.36
5.25 13.3 0.65
2.1
15.1
o
Tl
o
o
a
-o
o
a
9
-------
o
Tl
o
o
3
o
O
3
m
O
Utility/Powerolant
PENNSYLVANIA (Cont'd)
Metrop'oli tan Edison
Portland :)
Titus
Pennsylvania Electric
Conemaugh
Front Street *
Homer City
Keystone
i .
Seward
Unit
Number
1
2
Total
1
2
3
Total
1
2
Total
7
8
9
10
Total
1
2
3
Total
1
2
Total
3
12/4
14*/4
15/5
Total
Capacity
162
233
395
75
75
75
225
936
936
1,872
125
660
660
692
2,012
936
936
1,872
35
52
156
243
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
Caoacity Location Status 2 x
(,MW) City County SO,
-
158
246
404
78
78
78
234
850
850
1,700
118
606
614
657
1,877
840
840
1,680
35
45
136
216
.0 Upper Mt. Northampton
.0 Bethel
.0
.0 Reading Berks
.0
.0
.0
.0 New Florence Indiana -
.0
.0
Erie Erie -
.0
.0 Homer City Indiana -
.0
.0
.0
.0 Shelocta Armstrong X-P
.0
.0
.0
.0 Seward Indiana -J
.0
.0
NO TSP (lbs/10 Btu) (lbs/10 Btu)
X-P . 3»oil/4.0-coal
.3«oil/4.0-coal
XX-P .3%oil/3.0-coal
.3%oil/3.0-coal
,3%oil/3.0-coal
.3%oil/4.02/
.3%oil/4.0l/
X-P 3%oil/4.0l/
.3ioil/4.02/
.3%oil/4.02_/
.3%oil/4.02/
.3%oil/4.02/
.3%oil/4.02/
. . 1.2
.3%oil/4.02/
. 3%oil/4 ,Q2/
.3%oil/4.o2/
. 3%oil/4.ol/
.3%oil/4.02/
.3%oil/4.02/
1
None
None
None
None
None
None
None
None
None
None
' None
None
None
0.7
None
None
None
None
None ..
None
TH
P
Averaging
(lbs/106Btu) Period
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
U
0
0
.1 24 hr.
.1
.1 24 hr.
.1
.1
.1 24 hr.
.1
.19 24 hr.
.19
.1
.1
.1 24 hr.
.1
.1
.1 24 hr.
.1
.135 24 hr.
.122
.122
.1
Boilrsr D.-. tj
bottom Firiny
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Wet
Pulver i zer
Pulverizer
Pu Iver i zer
Pulvor izer
Pulver i zer
Pulver izer
Pulverizer
Pulver i zer
Pulver izer
Pu Iver izer
Pulver izer
Pulver i zer
Pulver i zer
Pulver izer
Pu Iver i zer
Pulverizer
Pu Iver izer
Pulverizer
Pulverizer
* Units 7/8 associated with turbine 4 (29 mw). units 9 s 10 associated with turbines 1 (16 mw), 2 (11 raw), 3 (16 mw), and 5 (53 mw).
I/ TSP limits apply to all fuels.
- 2 daily average. Thirty day average = 3.7. Annual average = 3.3
-------
(37£)c
81979 Fuel Consumption Estimated Actual 1979
Control Equipment ' Coal
Unit Particulates SO 3
: Utility/Powerplant Number Equip. Ef£. J» Equip. Eff. (%) Tons U/lb. Sulf. (%) Ash (%)
'KNNSYLVANIA (Cont'd)
Metropolitan Euison
Portland 1 ESP 99.0 346.0
2 ESP 99.0 326.0
675.0 12,524 2.1 11.4
Titus . 1 ESP 99.5 . . 194.0
2 ESP 99.5 194.0
3 ESP 99.5 . 204.0
593.0 12,565 1.3- 10.4
' Pennsylvania Electric
Conemaugh 1 ESP 99.5 1,290.0
' 2 ESP 99.5 1,390.0
; ' 2,784.0 12,136 2.4 17.1
1 Front Street 7 ESP 83.0 38.0
8 ESP 83.0 35.0
; 9 ESP 98.1 133.0
10 ESP 98.1 132.0
336.0 12,177 1.5 11.6
Homer City 1 ESP 99.5 1,410.0
2 . ESP 99.5 1,511.0
3 ESP 95.6 1,836.0
j ' 5,325.0 11,667 1.95 18.7
j
i ' Keystone 1 ESP .99.5 1,999.5
j -_. 2 ESP 99.5 . 2,170.4
3 '' 3,810.0 11,836 1.8 20.1
Seward 14 ESP 98.0 84.0
15 ESP ^ 98.0 ' 402.0
12 ESP ' 98.0 ' 87.0
573.0 12,302 2.3 15.0
S
! I/ Source: Cost and Quality of Fuels for Electric Utility Plants - 1979.
i
,
! '
<
;
O
j Tl
j z
jo
1 O
r 3
1 i "'
'' m ' ''
i; o -
;
Oil Gas 3
2 °ulf 3 ~~ Emissions (10 Tons;
Barrels tU/gal. (*) . MCF Btu/Ft.3 SO no TSP
'
25.0
27.0
52.0 136,294 0.1 28.0 6.0 1.2
20.0
16.0
17.0
54.0 136,148 0.2 13.4 5.4 0.4
29.9
69.7 13B,819^ 0.2-7 ' 116.3 24.1 1.8
2.1
1.8
4.0
4.5 '
12.8 138,831- 0.3i- 10.0 3.0 0.4
20.2
24.8
41.7
86.8 138,787- 0.2 172.9 42.9 15.0
30.2
30.6
60.8 138,770^' 0.2- 132.7 33.2 2.9
8.4
26.8
8.5 ..
43.6 138,786- 0.3- 26.7 7.6 0.5
-------
Utility/Powerplant
PENNSYLVANIA (Cor.t'd)
Pennsylvania Electric
Shawville
Williamsburg
Pennsylvania Power
Mansfield
New Castle
Pennsylvania Power & Light
Brunner Island"
Holtwood
Unit
Number
1
2
3
4
Total
1
1A
2
2A
Total
11/5
1
2
Total
1
2
3
4
5
Total
1
2
3
Total
4
17
Name
Plate
Capai
:ity
(MK)
131
131
183
183
628
40
40
8~0
33
913
913
1,827
46
50
115
133
160
505
363
405
790
1,558
75
.0
.0
.0
.0
.0
.0
.0
To"
.0
.5
.5
.0
.8
.3
.0
.7
.0
.8
.0
.0
.0
.0
.0
Net
Dependable
Capaci1
(MW)
-
127.
127.
174.
174.
602.
42.
44.
slfT
33.
825.
825.
1,650.
44.
44.
99.
100.
137.
424.
321.
378.
730.
1,42».
72.
ty
County Attainment
Location Status
Currently Enforced Emis:
SO,
City County SO, NO TSP (lbs/10
0
0
0
0
0
0
0
o'
0
0
0
0
6
0
0
0
0
0
0
0
0
0
0
Clearfield Clearfield - - 0
0
0
0
Warren Warren X-P - - 0
0
0
0
Williamsburg Blair - - XX-P 0
Shippingport Beaver X-P - X-P 0
0
New Castle Lawrence X-P - X-P 0
0
0
0
0
York Haven York - : - X-P 0
0
0
i
Holtwood Lancaster - - XX-P 0
.3%0/4
.3%O/4
.3%0/4
.3%0/4
. 3 %0/4
.3% 0/4
.3%O/4
.3% 0/4
.3%0/4
.6-oil
.6-oil
.6-0 s
.6-0 s
.6-0 s
.6-0 s.
.6-O &
. 3 SO/4
.3%0/4
.3%O/4
.3%0/4
NO
f|
" c.
Btu) (lbs/10"Btu
.0-C2/
.0-C2/
.0-C2/
.O-CV
.0-C2/
!fl-C2/
.0-C2/
.o-cl/
.O-CV
& coal
£. coal
C/2.8-C *
C/2.8-C *
C/2.8-C *
C/2.8-C *
C/2.8-C *
.o-cV
.o-ci/
.0-C2/
.O-C'2/
l
None
.None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
0.1
0.1
0.1
0.1
0.161
0.161
0.161
0.161
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
Averag ing
24 hr.
Boiler Data
ttom Firing
24 hr.
24 hr.
24 hr.
24 hr.
24 hr -
Dry
Dry
Dry
Dry
Wet
Wet
Wet
Wet
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Pulve rizer
Pulverizer
Pulver izer
Pulverizer
Pulver izer
Pulverizer
Pulver izer
Pulverizer
Pulveri zer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
* Proposed
V TSP limits apply to all fuels.
2_/ Coal SO2 limit is daily average. Thirty day average = 3.7. Annual average = 3.3.
O
Tl
o
o
a
o
o
a
m
O
-------
<37j>
1979 Fuel Consumption
Unit
Ut i H ty/Powf? rplant Number
PKNN.SYLVANIA (Cont'cl)
Pennsylvania Electric
Shauville 1
2
3
4
Warren 1
1A
2
2A
Williamsburg 11/5
Pennsylvania Power
Mansfield 1
2
New Castle 1
2
3 - '
4
5
Pennsylvania Power & LigBt--
Brunner Island 1
2
3
Holtwood 17
V
I/ Source: DOE El A, Cost iQ uality of
Control Eauinmcnt
Particulates SO.
Eouip F f f (Til Fciuio *" F f t! (%1
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
Vent.
Vent.
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
BH
Fuels f
I., t u . \u, t~~* v. - r- . . ,-,
99.7
99.7
98.2
99.6
99.4
99.4
99.4
99.4
99.3
99.8 LS 92.1 '
99.8 LS 92.1
98.0/99.0
98.0/99.0
98.0/99.0
95.0/99.0
95.0/99.0
99.0
99.5
99.5
4
99.6
or -Electric Utility Plants - 1979.
Coal
Oil Gas
lo3Tons BtU/lb. Sulf. (%) Ash (%) "Barrels BtU qal. ^t)' ."'MCP 8tu/^ 3
390.9
419.5
522.8
478.2
1,757.0 12,269 2.1 13.5
76.0
80.0
75.0
72.0
311.0 11,942 2.0 13.1
118.9 12,119 1.8 15.5
1,621.0
1,824.0
3,445.0. 11,373 3.1 14.9
73.8
87.1
247.9
255.9
242.2
907.8 12,360 1.6 10.0
953.7
1,008.2
1,834.1
3,796.0 12,497 '2.2 13.3
362.5 9,516 1.9 22.2
1
4.6
4.7
37. 1
34.3
80.7 138,623i/ 0.28i/
0.3
0.3
0.4
0.3
1.4 138,806l/ 0.2»i/
0.7 2/ 2/
47.8
1Q Q
jy * y
87.7 136,351 0.4
2.2
1.7
1.3
1.3
2 . 3
8.8 136,634 0.3
39.8
53.3
45.7
138.8 137,289 0.1
4.6 137,091 "0.2
Estimated Actual I
-------
(371
Util ity/Power plant
PENNSYLVANIA (Cont'd)
Pennsylvania Power & Light
Martins Creek
Montour
Sunbury
Philadelphia Electric Co.
Barbadoes
Chester
Cromby
Delaware
Eddystone
Unit
Number
1
2
3
4
Total
1
2
11
Total
1A/1B
2V2B
3
4
Total
3
4
Total
18
20
Total
1
2
Total
71
81
Iota1!
1
2
3
4
f late
Capacity
(MW)
156.0
156.0
850.0
850.0
2,012.0
805.0
819.0
17.2
1,641.2
75.0
75.0
104.0
156.0
410.0
66.0
66.0
132.0
50.0
80.0
130.0
187.5
230.0
417.5
156.3
156.3
312.6
353.6
353.6
391.0
391.0
uepenaaoie uounty Attainment -
(MW)
149.0
149.0
820.0
820.0
1,938.0
740.0
740.0
15.0
1,495.0
70.0
70.0
94.0
128.0
362.0
65.0
65.0
130.0 '
47.0
77.0
124.0
150.0
201.0
351.0
126.0
124.0"
250.0
301.0
334.0
380.0
380.0
City County SO, NO TSP (lbs/10 Btu) (lbs/10 Btu)
Martins Creek Northampton - - X-P .3%-0/4.0-CV
.3*-O/4.0-Cl/
.3%-0/4.0-CV
. 34-0/4. 0-CV
Washing tonville Montour - - - . 3%-O/4 ,0-Ci/
. 31-0/4. 0-CV
.3%-0/4.0-CV
Sunbury Snyder X-P - - .34-O/4 .0-cV
.3%-O/4.0-CV
.3%-0/4.0-Cl/
.3%-0/4.0-Ci/
Norristown Montgomery - - XX-P 0.3 % S
0.3 % S
Chester Delaware - - - 0.6 (0.5%S)
0.6 (0.5%S)
Phoenixville Chester - - XX-P 1.0%s-0/1.2-c2/
1.0%s/1.2-by 1982
Philadelphia Philadelphia X-P - XX-P 0.5 % S
1 0.5 % S
Eddystone Delaware - 0.6-by 1983V
0.6-by 1983V
0.5 * S
0.5 » S
1
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
TSP -'
- Averaging
(lbs/10 Btu) Period
0.1 24 hr.
0.1
0.1
0.1
0.1 24 hr.
0.1
.0.2
0.1 24 hr-
0.1.
0.1
0.1
0.1 24 hr.
0.1
0.1 24 hr.
0.1
0.1-by 1983 24 hr-
0.1
0.1 24 hr.
0.1
0.1-by 1983
0.1-by 1983
0.1
0.1
Boiler Data
Bottom firing
Dry
Dry
N/A
N/A
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
N/A
N/A
Pulverizer
Pulverizer
Tangential
N/A
Pulverizer
Pulverizer
Pu Iver izer
Pulverizer
Pulverizer
Pulverizer
Pulv/Front
Pulv/Fror.t
Pulverizer
Pulverizer
Pulver izer
Pulverizer
Pulv/Front:
Pulv/Front.
Pulv./Tan .
Pulv./Tan.
Tangential
Tangential
Total 1,489.2
1,395.0
*Only capacity data available for unit 11.
!/ Coal SC>2 limit is daily average. Thirty
2/ Coal 3C>2 limit is daily average. Thirty
V Coal .SO2 limit is daily average. Thirty
£/ TSP limits apply to all fuels.
day average = 3.7. Annual average = 3.3
day average = 0.90.
day average = 0.45.-
o
n
o
o
3
TJ
O
3J
m
o
-------
,37n)c
_19_79_ Fuel Consumption^
Control Equipment
Uni t Part iculates SO,.
Ut ility/Powerplant
KNN.SYLVA N I A (Co n t ' d )
Pennsylvania Power & Light
Mart ins Creek
Montour
Sunbury
Philadelphia Electric Co.
Barbadoes
Chester
Cromby
Delaware
Eddystone
Removal efficiency not aval
O
n
z
o
0
30
TJ
O
33
m
O
Number Equi]
1 ESP
2 ESP
3
4
1 ESP
2 ESP
IV IB BH
1PJ 2B BH
3 MC/ESP
4 MC/ESP
3 MC/ESP
4 MC/ESP
18 .
20
1 ESP
2 ESP
71 ESP
81 ESP
1 ESP/ Wet
2 ESP
3 ESP
4 ESP
lable.
D. Eft. (*) Equip. Ef£. (%)
.
99.5
99.5
99.5
99.5
99 +
99+
I/ /99.1
y /99.1
V
V
98.0
98.0
96.0
96.0
Vent. 98.6/99.0 MO 90.0
98.6
93.0
93.0
Coal Oil Gas
"'Tons Btu/lb. Sulf. (t) Ash (%) "Barrels DtU /qal. """' "'MCF Btu/Ft.3
t
329.6 52.0 '
336.3 68.3
5,051.1
4,666.4
. 665.9 12,688 2.3 12.4 120.3 138,832 0.1
2,003.2 50.3
1,937.9 . 43.3
3,941.1 12,507 1.7 12.3 93.6 137,467 0.1
766.0 2.4
-
287.0 1.5
383.6 2.4
1,436.6 11,046 1.8 17.3 6.2 137,077 0.1
1.0 138,274 0.3
353.0 147,781 0.5
300.0 7.0
0 1,261.0
300.0 13,063 2.5 9.2 1,268.0 149,687 0.8
829.0
i 835.0
1,664.0 146,401 0,5
478.0 120.0
528.0 40.0
0 1,696.0
0 974.0
1,006.0 12,842 2.4 9.0 2,830.0 147,126 0.5 .
Estimated Actual 197bi
£mir;siomi (10 Ton.:)
uot Available
134.0 35.5 2.1
52.3 12.9 1.9
0.55 0.78 0.03
18.2 5.5 2.3
2.6 3.7 0.1
50.0 15.0 5.1
-------
(37p)c
util i ty/Powerplant
PENNSYLVANIA (Cont'd)
Philadelphia Electric Co.
Richmond
*Schuylkill
Southwark
UGI Corp., Luzerne Electric
Hunlock Creek
West Penn. Power
Armstrong ;.
Hatfield
Milesburg
* Unit 23, 24 S 26 associated
V Coal SO2 limit is daily aver
Unit
Number
63/9
64/12
Total
1
23
24
26
2
3
Total
11/1
12/1
21/2
22/2
Total
5/3
7/3
8/3
Total
1
2
Total
1
2
3
Total
1
2
Total
Plate DepenaaDle county Attainment
Capacity
(MW )
.
189.8
165.0
354.8
275.0
172.5
172.5
345.0
50.0
50.0
163.2
163.2
326.4
576.0
576.0
576.0
1,728.0
23.0
23.0
46.0
with turbines 3(50 mw) &
age. Thirty-day average
capacity vocation otut
(MW) City County SO, NO
166.0 Philadelphia Philadelphia X-P
108.0
274.0
Philadelphia Philadelphia X-P
249.0
178.0 Philadelphia Philadelphia X-P
178.0
356.0
46.0 Hunlock Luzerne -
46.0
180.0 Reesedale Armstrong X-P
180.0
360.0
5S5.0 Masontown Greene -,
555.0 '
600.0
1,610.0
23.0 Milesburg Centre
23.0
46.0
9 (35 mw) . Units 2 & 3 associated with turbines
= 3.7. Annual average =3.3
.US t. 1
' f.
TSP (lbs/10 Btu) (lbs/10"Btu)
l
XX-P 0.5 % S
0.5 % S
XX-P 0.5 % S
0.5 % S
0.5 % S
0.5 % S
0.5 % S
0.5 % S
XX-P 0.5 % S
0.5 % S
0.5 % S
'
XX-P . 3*3-0/4. 0-ci/
.3%S-O/4.0-Cl/
.3%S-0/4.0-CI/
.3%S-0/4.0-Cl/
.3%S-0/4.0-Cl/
.3%S-0/4.0-Cl/
.3%S-0/4.0-Cl/
.3%S-0/4.0-cI/
~ .. 0.3% S
: 0,34. s
3 & 9 Unit 1 associated with
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None ''
None
None
turbine
TSP -'
(Ibs/flO Btu) Period
0.1 24 hr.
0.1
0.1 24 hr.
0.1
0.1
. 0.1
0.1
0.1
0.1 24 hr.
0.1
0.1
0.1
0.1 24 hr.
0.1
0.1
0.1 24 hr.
0.1
0.1 24 hr.
0.1
0.1
0.1 24 hr.
0.1
1(190 raw) .
Boi
Bottom
Dry
Dry
N/A
N/A
N/A
N/A
N/A
N/A
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
N/A
N/A
ler Data
Firing
Pulv/Tan.
Pulv/Tan.
Tangential
Tangential
Tangential
N/A
N/A
N/A
Pulv/Front
Pulv/Front
Pulv/Front
Pulv/Front
Pulverizer
Pu Ive r i zer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulveri zer
Pulverizer
N/A
N/A
2/ TSP limits apply to all fuels.
O
n
z
O
O
30
3
30
m
O
-------
j )7r)c
t
Utility/Powerplant
:tiMSYLVAf)IA (Cont'd)
Philadelphia Electric Co.
Richmond
Schuylkill
Southwark
Control Equipment
Unit Particulars SO,,
Number Equio. Eff. (%) Equio. ' Eff. (%)
.
63/g ESP 96.0
64/12 ESP 96-°
1 MC 76.0
23 ESP 90.0
24 MC 86.0
26 MC 86.0
2 MC 86.0
3 MC 86.0
11/1 ESP 99.0
12/1 ESP 99.0
21/2 ESP 99.0
22/2 ESP 99.0
1979 Fuel Consumption
Coal Oil
10 Tons Btu/lb. Sulf. (%) Ash (%) 10 Barrels Bt" /gal. (%)
i
528.0 145,585 0.5
954.0
1,071.0
592.0
53.0
1.
2,670.0 146,398 0.4
437.0
i
492.0
1
929.0 146,037 0.421/
Estimated Actual 1 QT-i
Gas , . - 1
j Emissions (10 Tons)
10 MCF BCU/Ft.3 S02 NO TSP
.
0.8 1.2 .04
3.4 5.9 0.2
1.2 2.0 .08
UGI Corp., Luzerne Electric
Hunlock Creek
West Pennsylvania Power
Armstrong
1
Hatfield
{ Milesburg
j
/ Source: DOE/EIA Cost and
1
O
Tl
z
0
1 °
30
"0
0
1 3)
m
O
6/3 ESP 99.6
7/3
8/3
1 ESP 99.5
2 ESP 99.5
"-'- ..
1 ESP 99.0
2 ESP 99.0
3 ESP 99.0
1 ESP 83.0/90.0
2 ESP 83.0/90.0
Quality of Fuels for Electric Utility Plants - 1979.
-
, '
,
207.1 2.2
7.6
1
207.1 8,884 0.7 20.7 9.8 138,800 0.12
527.1 1.5
563.7 1.7
1,090.8 11,701 2.2 14.7 3.2 138,500 0.3
772.8 . 3.8
1,506.8 1.6
1,541.2 , ' 2.7
3,820.8 11,875 2.5 18.2 8.1 141,000 ..27l/
29.3
25.3
54.6 137,550 0.19
2.9 1.9 0.15
28.1 7.4 0.98
181.58 3-1.41 3.47
03 .12 trac
«
-------
o
Tl
z
o
o
3
TJ
O
3D
5!
m
Utility/Powerplant Number
PENNSYLVANIA (Cont'd)
Wc-st Pennsylvania Power
Mitchell 1
2
3
33
Total
Spr ingdale 7
8
(MW)
149.
299
448.
74
141
215.
-
.6
.2
.8
.8
.0
.8
(MW) City County
178
291
469
86
137
223
.0 Courtney Washington
.0
.0
.0 Springdale Allegheny
.0
.0
NO
SO, NO TSP (lbs/lo"Btu) (lbs/10"Btu)
X-P 0,
0
0
0.6 by
X - X 0
0
(
&!/
.6V
.6V
8/21/8 2i/
.6
.6
None
None
None
None
None
None
TSP
(lbs/lo"btu) Period
0.
0.
.li/ 24 hr.
.li/
O.lV
0
.IV
.08 2« hr.
.08
Bottom Firino
N/A
N/A
N/A
Dry
N/A
N/A
Front
Front
Pulverise-:
Front
Front
* Units 1,2, 3 associated with turbines 1 and 2. Unit 33 associated with turbine 3.
V SO2 and TSP limits apply to all fuels.
-------
Control Equipment
Coal
1979 Fuel Consumption
Ut illty/Powcrplant
PENNSYLVANIA (Cont'd)
West Pennsylvania Power
Mitchell
Spr inqdale
Un i t Pa r t iculates _
Number Equip. Eff. 1%) Equip. E£f. U)
1
2
3
33
ESP
ESP
ESP
ESP
ESP
ESP
95.0
95.0
95.0
99.5
95.0
98.0
92.4
806.2
898.6
13,068
1.9
7.3
110.7
3.1
91.6
294.7
96.8
162.2
259.0
148,073 0.52
151,691 0.2 .
Estimated Actual 19", J
Emissions (IQ^Ton.-:)
SO
'2-
NO
9.4
8.9
16.7
38.1 1,050
29.63 7.91 0.58
0.39 0.57 .05
o
n
o
o
3)
-0
O
m
O
-------
(38)c
Unit
Utility/Powerplant Number
RHODE ISLAND
Narragansett Electric '"o.
Manchester 6
7
12
Total
South Street 121
122
Total
Capacity
(K
40
46
46
132
62
62
W)
.0
.0
.0
.0
.5
.5
Capacity' Location Status 2-
(MW) Citv County SO., NO TSP (lbs/10 Btu)
.
44
47
.0 Providence Providence - - X-P
.0
48.0
139
50
50
.0
.0 Providence Providence - - X-P
.0
1.
1.
1.
1.
1.
10
10
10
ip
10
NO
(lbs/10bBtu)
1
None
None
None
None
None
TS
Averaqinq Boiler D.-'.to
(lbs/10°Btu) Period Bottom
0.1
0.1
0.1
0.1
0.1
suifur-max N/A
N/A
N/A
Dry
Dry
Firing
Front
Front
Front
Pulv/Fror.
t
Pulv/Front
* DOE lists units 9, 10, 11. DOE data does not correspond exactly to FERC capacity data.
** Steam turbine capacity only.
I/ Emissions limits apply to all fossil fuels.
o
O
o
3)
"0
O
a
m
o
-------
!38b)c
Ut ility/Powerplant
IIODK ISLAND (Cont'd)
Narragansett Electric
Manchester
1979 Fuel Consumption
Estimated Actujl 157»
Control Equipment
Coal
Part iculates
Unit
Number Equip. EfC. (t)
6
7
12
MC
MC
MC
85.0
85.0
85.0
10
Bt"
Eff. It) Tons /lb. Sulf. (%) Ash
10
Barrels
206.4
124.9
167.8
499.1
_°ii SiS Emissions U03Tonsi
-L^ Sm' *3.c, Pt"/Ft.3 ^
747.4
1.0U4.1
147,967 0.94 1,751.5 1,038
-2-
2.2 4.51 0
South St.
121 MC/ESP
122 MC/ESP
86.0/90.0
86.0/90.0
0.2
6,847 ' 1.0
23.7
206.9
199.2
406.1 .148,437 0.96
1.7 0.9
Experimental Fuel: ECO II
o
Tl
o
o
JO
TJ
O
3
a
o
-------
(39?
Unit
Utilitv/Powerplant «>«,,.
SOUTH CAROLINA
Carolina Power & Light
Robinson i
Du k e Powe r
Lee ^
2
3
Total
South Carolina Electric & Gas
Canadys ^
2
3
Total
Hagood ;L
2
3
Total
McMeekin !
2
. Total
Urquhart 1
2
3
---. Total
Wateree ^
2
Tota;.
V Emissions limits apply to all fuels.
0
n
z
0
o
3
o
O
DO
>
m
0
Name
Plate
Capacity
(. KB)
206.6
90.0
90.0
175.0
355.0
136.0
136.0
217.6
489.6
25.9
25.9
46.0
97.8
146.8
146.0
292.8
75.0
75.0
100.0
250.0
335.9
385.9
771.8
Net
Dependable
Capacity Location
- . City County
174.0 Hartsville Darlington
78.0 Pelzer Anderson
78.0
167.0
323.0
125.0 Canaays Colleton
125.0
172.0
422.0
24.0 Charleston Charleston
24.0
46.0
94.0
126.0 Lexington Columbia
126.0
252.0
75.0 ' Augusta Aiken
75.0
100.0
250.0
360.0 Eastover Richland
360.0
720.0
s
r
r-minfy an-.-, , Tn"nt Currently Enforced Emissions Limits i/
Status 2 NO« TSP
SO NO T<;D MI,, /-.,i6n^ 6 f, Averaging Boiler Data
_b02 J^ TSP_ .dbs/10 Btu) (Ibs/W Btu) (lbs/106Btu) Period 5^^ Firinq
_ Absolute
5 Nor
-------
1979 Fuel Consumption
Control Equipment
Unit
: i 1 i tv/Powerplant Number
CAROLINA (Cont'd)
.olinn Power & Light
Ko b i. n so n 1
:e Power
Lee 1
2 '
3
ith Carolina Elec. & Gas
Canadys 1
2
3
UOQOOd 1
2
3
McMee kin 1
2
Urquhart . 1
2
.3
w,,teree 1
2
Part iculates
Equip.
MC/ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
Eff.
85
99
99
99
99
99
99
99
99
99
99
99
99
99
4
{%) Equip.
.0/99.4
.0
.0
.0
.6
.6
.6
.9
.9
.6
.6
.6
.0
.0
SO 3
' Ef£. (%) " To
"
367
155
156
353
666
226
313
246
786
319
321
640
192
183
176
551
708
873
1,582
Coal
Oil
r.ar
3 Sulf 3
Dtu 10 Btu 10 Btu 3
ns /lb. Sul£. (4) Ash (%) Barrels /qal. (%) MCF /Ft.
.0 12,250 1.5 14.4
.6
.8
.9
.3 11,896 1.13 13.83
.0
.5
.7
.2 12,308 1.43 10.78
.8
.1
.8 12,382 1.23 10.4
.3
.4
.2
.9 12,616 1.42 10.0
.8
.4
.1 12,636 , 1.35 ' 9.22
14
1
1
2
5
1
1
5
9
1
3
1
6
0
1
2
0
0
0
1
27
30
57
1
.0 138,000 0.2
.2
.3
.7
.3 140,000 (est.) 0.2
.5
.1
.8
.4 136,166 0.44
.7
.2
.2
.1 148,488 2.1
.9
.0
.0 137,063 0.29
.3
.3
.6
.3 138,914 0.14
.5
.0
.5 136,214 0.22
165.
10.
7.
y,
27
43
328
20
393
122
89
156
368
303
343
646
324
478
454
1,258
.0
.2
.0
.9
.2
.4
.3
.1
.8
.4
.9
.6
.9
.0
.3
.3
.7
.8
.9
.3
1,075
l.OOO(est)
1,079
1,077
1,077
1,071
Estimated Actual 1979
Em i:; n ionr: ( 10 Ton::)
SO HO TSP
11.0 3.3 0.2
Not Available
22.48 11.79 3.96
.04 0.2
7.88 5.77 2.84
12.54 8.52 .05
42.72 14.24 2.48
o
Tl
z
o
o
3
-0
O
3J
m
O
-------
(39d)c
Unit Capacity Capacity Location
Utilitv/Powerplant Number (KK) (MW) Citv County
SOUTH CAROLINA (Cont'd)
South Carolina Electric i Gas
Williams 1 632.7 580.0 Goose Creeks Berkeley
South Carolina Public Service
Grainger ' 1 82.0 82.0 Conway Horry
2 82.0 82.0
Total 164 0 164.0
Jeffries 1 50.0 45.0 Moncks Corner Berkeley
2 50.0 45.0
3 173.0 150.0
4 173.0 150.0
Total 446.0 390.0
Kinyah 1 315.0 260.0 Georgetown Berkeley
2 315.0 280.0
Total 630.0 540.0
1' Emissions limits apply to all fuels.
*
O
Tl
o
0
o
m
i-uuiiLy HLidiiuueui SQ NQ T;jp
SO NO TSP (lbs/10 Btu) (lbs/10 Btu) (lbs/10 Btu) Period Bottom Firing
- - - 3.5 None. 0.32 Absolute N/A Tangential
Limits
- 3.5 None 0.6 Ury Pulverizer
3.5 None 0.6 Dry Pulverizer
3.5 None 0.6 . N/A Front
3.5 None 0."6 N/A Front
3.5 None 0.6 Dry Pulverizer
3.5 None 0.6 Dry Pulverizer
- 2.2 None 0.4 °ry Pulverizer
1.2 0.7 0.1 Dry Pulverizer
i
-------
: ill ty/Powernlant
Unit
Number
CAROLINA (Cont'd)
.ith Carolina Electric 4 Gas
Wi LIiams 1
1979 Fuel Consumption
Control Equipment
Oil
Estimated Actual 1979
Part iculates
quip. Eff. (%|
85.0
Eff. (%)
/lb. Sulf. (%) Ash (%)
Barrels
/qal.
/Ft. SO, l.'O TS?
3,333.4
149,252 1.97
11.22 7.33 0.3
uth Carolina Public Service
Oi-ainger
Jeffer ies
Winyah
ESP
ESP
MC
MC
ESP
ESP
ESP
ESP
98.0
98.0
85.0
85.0
97.0
97.0
99.0
99.0
69.0
140.7
159.7
307.5 12,122
268.8
352.9
621.5 11,746
642.3
675.9
1,318.2 12,101
1.57 11.43
1.47 12.85
1.07 11.01
13.4
9.0
23.2
147,453 2.31
5.1 1.8 0.32
22.3 5.4 1.5
29.9 12.5 0.51
o
Tl
o
o
39
s
9
m
O
-------
(Jt i 1 i tv/PowL- rpla nt
SOUTH DAKOTA
Name
Plate
Uni t Capacity
Number (MW)
Net
Dependable
Capacity
(MW)
Currently Enforced Emissions Limits
County Attainment
Location Status
City County SO,, NO TSP
SO., i/ NO
' 6 * 6
(lbs/10 Btu) (lbs/10 Btu)
1
TSP i/
Ubs/ig6Btu)
Averag ing
Period
Ijo i 1 o r Da t u
Bottom Firing
Black Hills Power s. Light
French
Kirk
2(5.0
5.0
5.0
17.0
Total 32.0
22.0
5.0
5.0
5.0
1C.U
31.0
Rapid City Pennington
Deadwood Lawrence
3.0
3.0
3.0
3.0
3.0
None
None
None
None
None
0.3 Limits = max. Wet Cyclone
0.3
0.3
0.3
0.3
Dry
Dry
Dry
Dry
Stoker
Stoker
S to k c- r
Stoker
Northern States Power
Pathf inder
Ottertail Power
Big Stone
75.0 65.0 Sioux Falls Minnehaha
414.0 430.0 Big Stone Grant
3.0
3.0
0.3
0.3
Cyclone
Cyclone
1^ SO2 and TSP limits apply to all fuels.
O
Tl
z
o
o
3
T)
O
m
o
-------
1979 Fuel Consumption
Ut illty/Powecplant
SOUTH DAKOTA (Cont'd)
Dljc'K Hills Power & Light
French
KirK
Northern States Power
Pathfinder
Ottertail Power
Big Stone
Control Equipment
Coal Oil Gas
unit Participates SO .... 3 3 Bt(J Suit. 3
Number Equip. Eff. (%) Equip. * Eff. (%) " Tons ""Vlb. Sulf. (%) Ash (») " Barrels /qal. (%) " MCF "'""/Ft."'
-
1 ESP 92.3
1 ESP 97.5
2 . ESP 97.5
3 ESP 97.5
4 ESP 97.5
1
l
98.7 8,041 0.4 6.2 22.9 135,000 .03 22.7 932
81.5
75.1.
156.6 .- 8,044 0.45 6.3
23.3 150,236 1.11 79.0 990
Estimated Actual 197'j
Linissions (10 Ton;:)
SO NO TS?
2 x
1.4
0.2
ESP 98.8
2,429.5 6,158 0.69 7.27 36.4 137,988l/ 0.5
.09 .21
38.7 10.6 0.3
i/ Source: DOE/EIA Cost and Quality of Fuels for Electric utilities - 1979.
o
Tl
z
o
o
a
m
D
-------
_Uit iJ. i ty/Pow o rpla nt
TKNNKSf.EE
Tennessee Valley Authority
Allen
Bull Run
Cumberland
Gallatin
John Sevier
Johnsonvilie
.
Un i t
Number
1
2
3
Total
1
1
2
Total
1
2
3
4
Total
1
2
3
4 '
Total
1
2
3
4
5
6
7
8
9
10
Total
r-Lctct;
Capin~ ' *" '
-^Y
(MW)
330.0
330
330
990
950
1,300
1,300
2,600
300
300
328
328
1,256
223
203
200
200
826
125
125
125
125
147
147
173
173
173
173
1,486
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
utjpenuduie Bounty rtLta j.mut? lit
Capacity Location Status
(MW) . City County SO, NO TSP
293.0 Memphis, Shelby - - X-P
293.0
293.0
879.0
905.0 Clinton, Anderson - - XX-P
1,275.0 Cumberland, Stewart -
1,275.0
2,550.0
261.0 Gallatin, Sumner - - XX-P
261.0
288.0
288.0
1,693.0
203.0 Rogers-ville, Hawkins -
203.0
203.0
203.0
812.0
125.0 New Johnsonville, Humphreys X-P -
126.0
125.0
125.0
125.0
125.0
150.0
150.0
150.0
150.0
1,351.0
SO, N0._
" c
TSP
f
(lbs/10uBtu) (lbs/10"Btu) (Ibs/10u6tu)
4
4
4
4
5
5
5
5
5
5
5
4
4
4
4
4
3
3
3
3
3
3
3
3
3
3
3
.0 Coal/2.7 Oil
.0 Coal/2.7 Oil
.0 COal/2.7 oil
.0
-02/
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.4
.4
.4
.4
.4
.4
.4
.4
.4
.4
.4
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
.1
.1
.1
.11
.1
.1
.1
.1
.1
.1
.1
.11
.11
.11
.11
.11
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
rtv^r ag ing lio
ner uata
Period Bottom Firing
1 hr. Wet
Wet
Wet
1 hr. Dry
1 hr. Dry
Dry
1 hr. . Dry
Dry
Dry
Dry
1 hr. Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
n
ury
Drv
LJL y
Dry
Cyclone
Cyclone
Cyclone
Pulverizer
Pulver izer
Pulverizer
.Pulverizer
Pulver i zer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulver izer
Pulverizer
Pulverizer
I/ For counties other than Shelby, emi'ssions limits apply to all fossil fuels.
2/ Cumberland 503 limit goes to 4.2 after 12/31/82.
O
Tl
o
o
3D
TJ
O
3
5
m
O
-------
(41b)c.2
197'J Fuel Consumption
Estimated Actual 1979
Unit
Ut il i ty/Powerplant Number
TENNESSEE (Cent.)
Tennessee Valley Authority
Allen 1
2
3
Bull Run 1
Cumberland 1
2
Galla'tin 1
2
3
4
John Sevier . 1
2
3
4 .
Johnsonville . 1
2
"-' -. 3
4
5
6
7
8
9
10
Control Equipment
Particulates SO^
Equip.
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
MC/ESP
MC/ESP
MC/ESP
MC/ESP
MC/ESP
MC/ESP
MC/ESP
MC/ESP
MC/ESP
MC/ESP
Eft", (%) Equip. ' Ef£. (%)
99.0
99.0
99.0
99.9 +
99.0
99.0
99.9 +
99.9 +
99.9 +
99.9+
99.8 - . -
99.8
99.8
99.8
86.0/99.9
86.0/99.9
86.0/99.9
86.0/99.9
86.0/99.9
86.0/99.9
85.0/99.8 -
85.0/99.8 - - .
85.0/99.8
85.0/99.8
in3
1U
To
527
497
546
. 1,570
1,978
2,398
2,469
-------
(4 Id} c. 1
Cu C c G n tly En tor cud Em i r: s i ona r. i »i i t s I/
UtiIity/Powerplnnt
TENNESSEE (Cont. )
Tennessee Valley Authority
K i n
-------
C)c.2
1979 Fuel Consumption
Control Equipment
Unit
Ut i 1 i ty/Powerplant Number
MKSSKE (Cont.)
Tennessee Valley Authority
Kingston 1
2
3
.4
5
6
7
8
9
Watts liar A
B
C
D
Part iculates
Equip.
MC/ESP
t-C/ESP
MC/ESP
MC/ESP
MC/ESP
MC/ESP
MC/ESP
MC/ESP
MC/ESP
ESP
ESP
ESP
ESP
Coal Oil Gas
SO. ,_3 _.... ,«3 _.. Sulf. ,_3 .
Eff. (4) Equin. . EEf. (%) Tons /lb. Suit. (%) Ash (%) Barrels /qal., (%) MCF /Ft.
85.0/99,
85.0/99.
85.0/99,
85.0/99.
85.0/99.
85.0/99
85.0/99
85.0/99.
85.0/99.
95.0
95.0
95.0
95.0
.9 +
.9 +
.9 +
.9 +
.9 +
.9 +
.9 +
.9 +
.9 +
_
-
-
-
281.3
412.7
149.0
.412.4
628.9
473.4
524.8
483.3
619.2
3,985.0 11,550 1.4 14.7 26.2 137,800 0.5
75.7
83.2
103.7
90.3
Estimated Actual 1979
jSgu s s i on s {10 Tons)
SO
2-
103.9
0.3
352.9
11,410
2.0
10.9
1.8
138,800 0.5
o
n
z
o
o
3
o
O
3
5
m
-------
(42)c.2
Unit
Ut il ity/Powerplant ' Number
TEXAS
City of Austin Electric Dept.
Docker Creeki/ 1
2
Holly St.V 1
2
3
4
Total
SeaholmV 5
6
7
8
9
Capacity
(MW)
352
436
788
113
113
190
212
628
25
20
20
20
40
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
Capacity Location
(MW)
325.
422.
747.
100.
100.
165.
190.
555.
20.
20.
20.
20.
40.
City County
0 Austin Travis
0
0
0 Austin Travis
0
0
0
0
0 Austin Travis
0
0
0
0
Status 2 -
SO,, NO TSP (lbs/10
- - 440ppm/0
440ppm/0
- - - 440ppm/0
440ppm/0
440ppm/0
440ppm/0
- - - 440ppm/0
440ppm/0
440ppra/0
440ppm/0
440ppm/0
I/
Btu)
.6%S
.6%S
.6%S
.6%S
.6%S
.645
.6%S
.6*3
.6%S
.6%S
.6%S
NOX 2,
(lbs/10 Btu)
0
0
0
0
0
0
0
0
0
0
0
.7 Oil/Gas
.7 Oil/Gas
.7 Oil/Gas
.7 Oil/Gas
.7 Oil/Gas
.7 Oil/Gas
.7 Oil/Gas
.7 Oil/Gas
.7 Oil/Gas
.7 Oil/Gas
.7 Oil/Gas
I
2^-. -/ Averaqinq
(lbs/10bBtu)' Period
0
0
0
0
0
0
0
0
0
0
0
.1
.1
.1
.i
.1
.1
.1
.1
.1
.1
.1
Entire State:
Oil/Gas SO2 - 30 min.
Oil/Gas NOX - 2 hrs.
TSP - 2 hrs.
Oil/Gas
Oil/Gas
Oil/Gas
Oil/Gas
Oil/Gas
Oil/Gas
Oil/Gas
Oil/Gas
Oil/Gas
Boiler Data
Bottom Firing
M/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N'/A
Tangential
Tangential
Front
Front/Opp.
Front
Front
Front
Front
Tangential
Total
120.0
J_/ Texas Sulfur standard for all existing oil-fired plants is 440 parts per million. This standard has been translated to approximately 0.6% Sulfur for
Calculation purposes. There is no SC>2 limit for existing gas-fired plants.
2_/ Foe all o£ Fort worth/Dallas and Houston/Galveston Air Quality Control Regions, NOX standards for gas-fired units are:
Front-fired: . 0.5 Ibs./rorofltu
Opposed-fired: 0.7 Ibs./mrnBtu
Tangential-fired: "0-. 25 Ibs ./mmEtu
.All units listed at maximum standard
3/ In Texas, the maximum limit for any unit 4is 0.1 Ibs./mmBtu. Specific limits for units with heat rates under 2500 mmBtu/hour are calculated
by: Ibs/hr = .048Q-62 where Q = stack effluent flow rate. We have assumed 1000 mmBtu/hr as a heat rate, and applied the equation above to
all units less than 250 Mw nameplate.
4_/ Sulfur dioxide limit for these plants listed as 1.6 Ibs./mmBtu.
O
o
o
3)
0
O
X
m
-------
1979 Fuel Consumption
i
'
i
|
I
. i 1 i ty/Powerplant
(Continued)
:y of Austin Electric
Decker CreekJ/
Holly St. I/
Seaholmi/
Control Equipment . Coal Oil Gas
Unit Particulates SO 1Q3 1Q3 Dtu ' Sulf. 3
Number Equip. Eff. (%) Equip. " E£f. (%) " Tons ""/Ib. Sulf. (%) Ash (%) " Barrels """ /qal. (%) iu MCF ul"u/Ft.J
I
Dept.
1
25,884.1 1,016
1 - - - -
2 ' -
3
4 -
8,779.2 1,009
5
6 - -
7 -
8
9 -
Estimated Actual 1979
Emissions (10 Tons)
1,143.2 1,013
2.3
1.3
0.5
i ir.umption data taken from Cost s, Quality of Fuels for Electric Utility Plants - 1979. Estimated actual emissions are taken from 1978 copies of Form 67.
o
o
o
3
o
O
m
O
-------
Uti l
TEXAS (Continued)
Brazos Electric Power
Miller
North Texas
Unit
Number
Total
Brownsville Publ. Utilities Bd.
*SiRay (Brownsville) 4
5
6
Total
* Net Dependable data for all units not available, Naraeplate capacity used instead.
Capacity
(MW)
75
114
216
405
19
19
38
76
6
25
22
53
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
Capacity Location Status
(MW) City County SO., NO TSP
75
116
200
391
18
18
40
76
6
25
22
53
.0 Gordon Palo Pinto -
.0
.0
.0
.0 Weatherford Parker -
.0
.0
.0
.0 Brownsville Cameron
.0
.0 - X-p
.0
so..
(lbs/10 Btu)
None
None
None
None
None
None
None
None
None
NO
(lbc/106Utu)
None
None
None
0.7 gas
0.7 gas
0.7 gas
None
None
None
Averaging
(Iba
0
0
0
0
0
0
0
0
0
/iO Btu) Period
.1
.1
.1
.1
.1
.1
.1
.1
.1
9as Entire State:
yds S02 - 30 min.
9as NOj, - 2 hrs.
TSP - 2 hrs.
gas
gas
gas
gas
gas
gas
Bo i Irr Dn ta
Bo t torn
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
fir in.]
Front
Front
Front
Front
Front
Front
Front
Front
Front
O
Tl
z
o
O
3
0
O
m
O
-------
1979 Fuel Consumption
Control Equipment , ' Coal Oil
Unit Particulates SO 3 3 Sulf.
;ility/Powerplant Number Equip. Eff. {%) Equip. ' Eff. (%) Tons /lb. Sulf. (%) Ash (*) Barrels /qal. (%)
(Continued) * '
.i;:os Electric Power
Miller 1
2
3
North Texas 1
2
3
jwnsville
Si Ray . 4
5
6
RC Form 67 did not provide consumption data for Unit 4. It is unclear whether Unit 4 consumed the 31 x 10^ MCF unaccounted for in the total, or if
it natural gas was delivered and never consumed.
' '
io3MCB
1,491.
4,678.
9,253.
15,423.
8.
11.
35.
54.
Not Avail
1,646.
1,364.
3,741.
Gas
BtVt.3
6
2
4
1 1,024
1
7
j_
9 1,109
.I/
0
0
0 1,027
Estimated Actual 1979
Emissions (10 Tons)
SO., HO TSP
.01 3.0 0.12
1,109 trace trace trace
Not Available
o
o
o
3
TJ
O
2)
5!
m
O
-------
<42d)c
Un i t
Ut i li ty/Powerplant Number
TEXAS (Cont'd)
City of Bryan
Bryan 1
3
4
5
6
Total
Dans by 1
Central Power 5 Light
Bates 1
2
Total
Davis 1
2
Total
Joslin 1
La Palma *3
. 5
6
7
Total
Laredol/ : _-, 1
2
3
Total
t
Lon Hill 1
2
3
4
Total
f lace
Capacity
(MW)
5.0
13.0
24.0
25.0
54.0
156.0
105.0
75.0
114.0
189.0
353.0
351.0
704.0
261.0
10.0
23.0
23.0
163.0
219.0
35.0
38.0
105.0
178.0
75.0
75.0
163.0
261.0
574 .0
uepenaaoie
Capac;*~" T ---
icy Liocation
(MW) City County
-
5
12
22
25
50
114
100
74
110
184
325
312
637
240
10
26
26
150
212
36
36
105
177
72
70
163
240
545
.0 Bryan Brazos
.0
.0
.0
.0
.0
.0 Bryan Brazos
.0 Mission Hidalgo
.0
.0
.0 Corpus Nueces
.0 Christi
.0
.0 Point Comfort Calhoun
.0 San Benito Cameron
.0
.0
.0
.0
.0 Laredo Webb
.0
.0
.0
.0 Corpus Nueces
.0 ' Christi
.0
.0
.0
SO, NO TSP (lbs/10
- - - 440ppm/0
440ppm/0
440ppm/0
440ppm/0
440ppm/0
- 440ppm/0
X-P 440ppm/0
440ppm/0
X-P 440ppm/0
440ppm/0
- - - 440ppm/0
X-P . None
None
None
None
- - - None
None
None
i
X-P None
None
None
None
NO
Btu) (lbs/10°Btu
.6SS
.6%S
.645
.6%S
.6%S
.6%S
.6%S
.643
.6%S
.6%S
.6%S
'
None
None ,
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
TSP
Averaging
Boil*
) (lbs/10 Bfu) Period Bottom
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
o..
0.
0.
0.
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
oil/gas
oil'qa- Entice State:
oil/gas s°2 - 30 min.
oil/gas N°x - 2 hrs-
oil/gas TSP * 2 hrs-
oil/gas
oil/gas
oil/gas
.
oil/gas
oil/gas
oil/gas
oil/gas
oil/gas
oil/gas
oil/gas
gas
gas
gas
gas
gas
gas
gas
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
=r DC: to
Firina
Front
Tangential
Front
Front
Front
N/A
Front
Front
Tangential
N/A
Opp. Wall
N/A
Front
Front
Front
Front
Front
Front
Front
Front
Front
Front
* Consumption data not available for unit 3.
I/ Unit 3 lists SC>2 limit as 0.8 Ibs.SO2/mmBtu. Texas state regulations have no SO2 limit for gas fired units.
O
Tl
o
o
3
-0
O
x
m
O
-------
)c
1979 Fuel Consumption
Estimated Actual 1979
Unit
Jt ility/Powerplant Number
; (Cont'd)
ty of Bryan
liryan 1
3
4
5
6
j Dansby 1
I ntral Power £ Light'
Hates 1
2
Davis 1
2
,
Joslin 1
La Palma 5
16
7
Laredo I
2
3: -, .
l.o n Hill ' 1
2
3
4
Control Equipment Coal Oil
Particulates SO 3 3 Sul£.
Equip. Eff. (%) Equip. ' Eff. (%) Tons /lb. Sulf. (%) Ash (%) Barrels /gal. (%)
-
10.0 141,000 0.2 l.
22.9 144,000 0.4 2,
0.4 2,
5.9 6,
6.4 147,900 0.7 3,
12.0 13,
5.5 15,
17.5 147,900 .0.7 28,
123.5 140,000 0.22 15,
' 10,
11,
4,
4,
1
4,
13,
17,
jjtja ^^ issions (10 Tor*i)
MCF ' BtU/Ft.3 SO, NO TSP
919.5 1,062
494^2 1,016 - -
716.4
218.2
934.7 1,061 trace 1.7 0.7
294.6
560.3
852.9 1,049 I/ .01 5.6 0.2
628.6 1,047 .01 3.0 .12
479.7
343.2
277.5
100.5 1,069 trace 2.1 .08
430.7
238.8
317.0
985.5 1,089 .01 8.4 0.3
113.5
99.9
123.8
492.1
833.2 1,062 I/ .01 3.5 .13
content of gas consumed by Davis and Lon Hill'plants estimated from data in Cost & Quality of Fuels for Electric Utility Plants-1979.
o
Tl
z
o
o
9
-0
O
J)
m
O
-------
_ Utility/Poverplant
TEXAS (Cont'd)
Central Power 6 Light Co.
Nueces Bay
Victoria
Dallas Power & Light
Dallas
Lake Hubbard
Mountain Creek
North Lake
Parkdale
Unit
Number
*3
*4
5
6
7
Total
5
6
7
8
Total
3
9
Total
1
2
Total
2 .
3A
3B
6
7
8
Total
1
2
Total
1
2
3
Total
Capaci
(MW)
15.0
15.0
35.0
180.0
351.0
596.0
36.0
75.0
180.0
261.0
554.0
88.0
75.0
163.0
396.5
531.0
927.5
31.2
75.0
135.8
136.0
580. 5
958.5
176.8
170.5
361.4
706.7
79.6
125.0
136.0
340.6
Name Net
Plate Dependable
Capacity
|HW)
Location
City
County
16.0
16.0
34.0
175.0
325.0
566.0
36.0
73.0
170.0
240.0
519.0
75.0
70.0
145.0
375.0
515.0
890.0
33.0
70.0
115.0
125.0
550.0
893.0
175.0
175.0.
350.0
700.tt
87.0
115.0
125.0
327.0
Corpus
Christi
Victoria
Nueces
Victoria
Dallas
Garland
Dallas
Dallas
Dallas
Dallas
Dallas
Dallas
Dallas
Dallas
uounty Attainment
Status 2 ~
SO, NO TSP (lbs/10 B
X-P 440ppm/0
440ppm/0
440ppm/0
440ppm/0
440ppm/0
- - - None
None
None
None
X-P 440ppm/0
440ppm/0
X-P 440ppm/0
440ppm/0
X-P 440ppm/0
440ppm/0
440ppm/0
440ppm/0
440pptn/0
; 440ppm/0
' - X-P 440ppm/0
440ppm/0
440ppm/0
X-P 440ppm/0
440ppm/0
440ppnv'0
NO
ituL
.6%S
.6%S
.613
.6iS
.6%S
.6%S
.6*3
.645
.643
.643
.6*3
.6%S
.643
.6*3
.6«S
-6%S
.6%S
.6%S
.6%S
.6%S
.6%S
(lbs/106Btu)
1
None
None
None
None
None
None
None
None
None
0
0
0
0
Q
0
0
0
0
0
0
0
0
0
0
0
.7
.7
.7
.7
.7
.7
.7
.7
.7
.7
.7
.7
.7
.7
.7
.7
gas/oil
gas/oil
gas/oil
gas/oil
gas/oil
gas/oil
gas/oil
gas/oil
gas/oil
gas/oil
gas/oil
gas/oil
gas/oil
gas/oil
gas/oil
gas/oil
TSP
nvcLavj&lll
(lbs/lp Btu) Period
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
' 0
0
0
0
0
0
0
0
0
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
'.1
.1
.1
.1
4 DUI.L
Bottom
oil/gas Entire state. N/ft
01^9as s _ 3 m.n_
oil/gas N0 _ 2 hrs_
oil/gas TS£ _ 2 nrs. N/A
on/gas N/A
'" K
III
oil/gas
oil/gas
oil/gas
oil/gas
oil/gas
oil/gas
oil/gas
oil/gas
oil/gas
oil/gas
oil/gas
oil/gas
oil/gas
oil/gas
oil/gas
oil/gas
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
et uaca
Firing
Front
Front
Front
Opp. wall
Opp. Wall
Front
Front
Opp. Wall
Opp. Wall
Front
Front
Opp. Wall
Opp. Wall
Front
Front
Front
Front
Front
Tangential
Opp. wall
Opp. Wall
Opp. Wall
Front
Front
Front
* Only capacity data available foe units 3 & 4.
O
o
O
30
TJ
O
33
-------
t
1
1
1
1
i
t *
3 1
i :
3
, «
i
; ,
:
i
I
I
|
|
'3 ;
,{
1
1
I
*
1 !
1
! '
3 i
i
i
1'
,
1 <
L i
l ?
I
!
J
'
'
i
i
" i I i ty/Powerpl ant
(Cont'd)
itral Power S. Light Co.
Nueces Day
Victoria
Llns Power & Light
Dallas
Lake Hubbard
Mountain Creek
North Lake
Parkdale
O
Tl
z
o
0
-o
o
DO
m
O
Control Equioment Coal
Unit Participates SO, 3
NuT.bor EauiD. Eff. (%) Equip. " Eff. (%) Tons /lb. Sulf. (%) Ash (%
.3
4
5
6
7 '
5
6
7
8
3
9
1
2
2
3A
3B
6
'7-..
8
. 1
1 «
2
3
1
2
3
1979 Fuel Consumption Estimated Actual 1979
Oil Gas . 3
103 Btu -"!£ 10- Bt 3
) Barrels /qal. (*) MCE1 " /Ft. SO, CO TSP
i
- -
- -
3.7
5,188.6
8.9 16,204.9
8.9 147,300 0.7 21,396.8 1,039 0.1 4.2 0.16
472.0
1 .
4,028.3
11,399.5
15,899.9 1,038 trace 3.1 0.12
'
3.9 142,857 0.4 2,438.3 1,015 0 0.5 0
55.3 142,857 0.3 26,599.4 1,040 Not Available
6.1 142,857 0.4 6,172.9 1,003 0 1.0 0
70.1 142,857 0.4 21,210.4 1,047 0 4.0 0
15.1 142,857 0.4 4,927.0 1,030 0 1.0 0
-------
(421JC.1
Utility/Powerplant
TEXAS (Cont'd)
Denton Municipal Utilities
Spencer (Denton)
El Paso Electric
Newman
City of Garland Mun. P S L
C. E. Newman
Olinger
Greenville Municipal P''& JL
Greenville
Unit
Number
Total
Total
Total
Total
Total
Name
Plate
Capacity
(MW )
13.0
13.0
32.0
67.0
65.0 '
190.0
81.6
81.6
102.6
265.8
7.5
7.5
18.8
18.8
44.0
96.6
75.0
113.6
156.6
345.2
18.0
25.0
42.0
< 85.0
Net
Dependable
Capacity
-------
- ' 1979 Fuel Consumption Estimated Actual 1979
Control Equipment Coal
Unit Particulates SO, 3 1Q3
ty/Powerplant Number Equip. Eff. (%) Equip. Eff. (%) *" Tons """/lb. Sulf. (%) Ash (%) " Barrels
mt'd)
i Municipal Utilities
ncer (Denton) 1 ~
2
3 3.3
4 '3.6
5 6.0
13.0
^0 Electric
.n,an 1 44.2
1 2 11-0
3 2.1
59.4
'
' Jf Garland Mun. P & L
E. Newman 1
2
3
4 . ' .
5
3.2
inqer I/ 1
2
3
160.3
ville Municipal P i L ""'-.
78 data: Greenville 1 ' 0.6
2 .3.6
3 4.7
Oil Gas 3
BtU /gal. (I) 10 MCF BtU/Ft.3 SO. NO TSP
1
2.8
334.6
1,143.5
1,533.8
139,680 1.0 or 3,134.4 1,060 Not Available
less
3,239.0
4,331.0
3,691.0
153,409 0.3 10,920.0 1,024 0.1 5.3 0
144,000 0.2 448.6 1,025 Not Avail. 0.1 Not Avail
Not
145,299 0.54 13,923.7 1,048 0.1 1.2 Avail.
473.1
342.4
Not 1,774.0
16.3 145,000(est) Avail. 2,594.0 ' 1,038
Not Available
rjrce of fuel data: Cost and Quality o£ Fuels for Electric Utility Plants - 1979
o
Tl
o
o
3
T)
O
m
O
-------
(42p)c
Utility/Power plant
TEXAS (Cont'd)
Gulf State Utilities
Lewis Creek
Neches
Name Ne t
Plate Dependable
Unit Capacity Capacity
Location
Sabine
Houston Lighting & Power
Uer tron
Cedar Bayou .
Clarke
Number
1
2
Total
3
4
5
6
7
8
Total
1
2
3
4
5
Total
1
2
3
4
Total
1 + aux.
2
3
Total
1
2
3
4
(KW)
271.0
271.0
542.0
25.0
50.0
75.0
75.0
114.0
114.0
453.0
239.0
239.0
473.0
592.0
507.0
2,060.0
188.0
188.0
225.0
225.0
826.0
765.0
765.0
750.0
2,280.0
30.0
30.0
75.0
75.0
(MW) City
265.0 Willis
265.0
530.0
27.0 Beaumont
46.0
66.0
66.0
111.0
111.0
427.0
230.0 Bridge City
230.0
430.0
568.0
480.0
1,938.0
177.0 Deer Park
177.0
235.0
235.0
824.0
750.0 Eldon
750.0
750.0
2,250.0
44.0 Houston
44.. 0
82.0
82.0
County
Montgomery
Jefferson
Orange
Ha r r i s
Chambers
Harris '
Total
210.0
252.0
County Attainment
Status 2
SO NO TSP (lbs/10 Btu)
- 440ppm/0.6%S
440ppm/0.6%S
- - - 440ppm/0.6%S
440ppm/0.64S
440ppm/0.6%S
440ppm/0.6%S
440ppro/0.6%S
440ppm/0.6%S
- 440ppin/0.6%S
440ppm/0.6%S
440ppm/0.6%S
440ppm/0.6%S
440ppm/0.6%S
X-P 440ppm/0.6%S
440ppm/0.6%S
440ppm/0.6%S
440ppm/0.6%S
- - - 440ppm/0.6%S
440ppm/0.6%S
440ppra/0.6%S
- ' - X-P 440ppm/0.6%S
440ppm/0.6%S
440ppm/0.6%S
440ppra/0.6%S
NO^ TSP Avsraqing
(lb-/106Btu)
-------
1979 Fuel Consumption
Control Equipment
Unit Particulates SO
': ili ty/Powerplant Number Equip. Erf. (%) Equip. Eff. (%)
(Cont'dJ
it State Utilities
Lowis Creek 1 - - - -
2 - - -
Neches 3 - - - -
4 . -
5 -
6 - - - . -
7 -
8 - - - -
Sabine 1 -
2 - - - -
3 -
4 -
5 ESP 95.0
iston Lighting S Power
Dertron 1 - - - -
2 _
3 . -
4 - - - . -
Cedar Bayou 1 + aux. - - -
2-', . - - -
3
Clarke 1 - - - -
2 - - - -
3 _ '_
4 -
Coal Oil Gns t
3 2 Sulf i Emissions (10 Tons)
10 Tons BtU/lb. Sulf. (%) Ash (%) 10. Barrels BtU/qal. (t) 10xrp ' Btu/pt-.3 qn Kn TC=
l
17_5 137,299 . O-3 29,903 1,034 .03 ' 58.4 0.15
.
.
18.1 139,240 0.3 28,351.0 1,043 I/ 55.3 0.1
*
49.5 143,869 0.3 72,997.0 1,044 0.1 142.5 0.4
52.2 15,022.7
1 1
36.0 22,763.2
1 I
88.2 144,364 0.75 37,785.9 1,038 jy 1/ 1/ '
203.5 38,438.8
275.2 42,672.8
342.9 44,170.1
821.6 147,071 0.86 125,281.7 1,056 2.4 24.1 0.3
1 - . '
-
I/ Not Available
o
n
o
o
3)
"0
O
0.8
151,773 2.6 3,628.7 1,051
I/ I/
I/
m
-------
(42t)c-l
Ut i 1 i ty/Powe rpla nt
TEXAS (Cont'd)
Houston Lighting & Power
Deeowater
.Gable Street
Greens Bayou
Parrish
Robinson I/
Total 2,316.0 2,197.0
I/ Unit 4 has SO2 limit listed in Form 67 as O.Slbs/mmBtu.
Uni t
Number
1
2
3
4
5
6
7
8
9
Total
6
7
Total
1
2
3
4
5
Total
1
2
3
4
5
6
Total
1
2
3
4
Plate
Capacity
(MH)
147.0
188.0
335.0
20.0
33.0
53.0
75.0
75.0
113.0
113.0
446.0
822.0
188.0
188.0
299.0
581.0
734.0
734.0
2,724.0
485.0
485.0
581.0
765.0
uepenaaoie
Capa
(M
(J i. i.y Lfj^a (_ J.UI1
tt) City County
Pasadena Harris
159.0
177.0
Bounty Attainment
SO, NO TSP (lbs/10 Btu) (1
X-P None
None
None
None
None
None
None
None
440ppm/0.6%S
NO.. TSP Avcraoin
bs/10 Btu) (lbs/10 Btuf Period
0.7 gas 0.1 gas
0*7 qas 0*1 gas ^2 ~ 30 min.
0.7 gas 0.1 gas _ * ^h*
0.7 gas 0.1 gas ~ rs
0.7 gas 0.1 gas
0.7 gas 0.1 gas
0.7 gas 0.1 gas
0.7 gas/oil 0.1 oil/gas
336.0
26.0 Houston Harris
36.0
X-P 440ppm/0.6%S
440ppm/0.6%S
None 0.1 oil/gas
None 0.1 oil/gas
62.0
72.0 Houston Harris
72.0
112.0
112 .0
413.0
781.0
177.0 Thompsons Fort Bend
177.0
278.0
565.0
660.0
660.0
X-P None
None
None
None
440ppm/0.6%S
- - - 440ppm/0.6%S
440ppm/0.6%S
440ppm/0.6%S
None
1.2 coal
1.2 coal
0.7 gas 0.1 gas
0.7 gas 0.1 gas
0.7 gas 0.1 gas
0.7 gas 0.1 gas
0.7 gas/oil 0.1 oil/gas
0.7 gas/oil 0.1 oil/gas
0.7 gas/oil 0.1 oil/gas
0.7 gas/oil 0.1 oil/gas
0.7 gas 0.1 gas
0.7 coal 0.1 coal/gas
0.7 coal 0.1 coal/gas
2,517.0
441.0 San Leon Galveston
441.0
565.0
750.0
X-P None
None
None
440ppm/0.6%S
0.7 gas 0.1 gas
0.7 gas O.I gas
0.7 gas 0.1 oil
0.7 gas/oil 0.1 oil/gas
Boiler Data
Bottom
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
Dry
Dry
N/A
N/A
N/A
N/A
Firing
Front
Front
Front
Front
Front
Front
Front
Front
Front
N/A
N/A
Front
Front
Front
Front
Tangential
Front
Front
Front
Tangential
Pulverizer
Pulverizer
Opp . Kail
Opp. Wall
Opp. Wall
Opp. Wall
o
Tl
o
o
3
3
a
m
O
-------
1 L ty/Powerplant
Control Equipment . Coal
Unit Particulates SO 3
Number EquiD. E£f. (%) Equip. Eff. (%) Tons "/lb. Sulf. (%) Ash (%)
Cont'd)
Lon Lighting & Power
'.cpwater 1 - - - -
2
3 _
4 _
5 -
6 - - - - .
7
8
9
a&le Street (No information available)
i reens Bayou' 1 ' - - -
1 2 -
4 _
irrish 1 - - - -
2 - - - -
3 .- -
4 -
5 ESP 99.8 " 1,202.7
(,. ESP 99.8 1,613.5
2,816.2 8,342 0.45 6.2
jbinson 1 - - - -
2 ----- '
3 ______
iur content of oil is from Cost & Quality of Fuel - 1979
: content of gas is
|
O
n
o
o
3
o
'. 1
m
j O
from Cost & Quality of Fuel - 1979
f
1979 Fuel Consumption Estimated Actual 1979
Oil Gas , . . no3T
Barrels BtU /qal. (%) 10 KCF BUU/Ft.3 SO, NO TSP
l
205.6
0.2 8,405.'4
0.2 147,619 1.9 8,611.1 1,036 Hot Avail. 0.9 Not Available
5,860.6
117.4 22,725.9
117.4 148,470 0.98 28,586.5 1,043 0.6 3.2 trace
0.5 15,671.3
1
0.5 13,911.8
34,247.6
9,193.4
- 10,019.5
1.0 147,639 2.4 83,043.6 1,042 25.7 14.0 .23
29,664.7
26,734.4
32,501.5 '
175.9 32,074.8
175.9 146,952 0.751/120,975.5 1039J/ 0.4 29.1 trace
-------
(42x)c.l
Util i ty/Powerpl.ant
TKXAS (Cont'd)
Houston Light ing & Power Co.
Webster
Whar ton
Lower Colorado River Authority
Fayette (Seymour Jr . )
Ferguson
Gideon
Lubbock Power & Light
Holly Avenue
Plant 12
''' . ,
Medina Electric Corp.
Pearsall
San Antonio Public Serv. Board
Braunig
Uni t
Number
1
2
3
Total
1
2
Total
1
1
1
2
3
1 .
2
Total
4
5
6
7
Total
1
2
3
Total
1
2
3
Total
I/ NO* limits for oil & gas are 0.3 and 0
SC>2 limits for oil and gas
2^^Braunig TSP limit given as
O
n
z"
0
o
-o
o
3
m
O
are 0.7 anc
180 Ib/hr.
Name Net
Plate Dependable C
Capacity
(MW)
113.0
113.0
389.0
615.0
75.0
248.0
323.0
600.0
446.0
136.0
136.0
390.0
662.0
50.0
56.3
106.3
11.5
11.5
25.0
25.0
73.0
25.0
25.0
25.0
75.0
225.3
251.6
417.0
893.9
capacity Location
(MW) City County
-
112.0 Webster Harris
112.0
375.0
599.0
71.0 Houston Harris
234.0
305.0
550.0 LaGrange Fayette
430.0 Marble Falls Llano
140.0 Bastrop Bastrop
140.0
340.0
620.0
48.0 Lubbock Lubbock
53.0
101.0
11.5 Lubbock Lubbock
11.5
23.0
23.0
69.0
25.0 Pearsall Frio
25.0
25.0
75.0
200.0 San Antonio Bexar
220.0
390.0
810.0
. Currently Enforced Emissions Limits
,ounty Attainment!
"in,- S0- NL)
SO, NO TSP (lbs/10 Btu) (lbs/10 Btu)
X
X-P None 0.7 gas
None 0.7 gas
None 0.7 gas
X-P None 0.7 gas
None 0.7 gas
1.2 coal I/ 0.7 coall/
- - None None
- - 440ppm/0.6%S None
None None
440ppm/0.6%S None
- - - . None None
440ppm/0.6%S None
- - - 440ppm/0.6%S None
None None
None None
None - None
i
*
- - - 440ppm/0.64S None
440ppra/0.6lS None
440ppm/0.6»S None
X-P 440ppm/0.6%S None
440ppm/0.6%S None
440ppm/0.6%S None
TSI'
6 Averaging
i
Entire State:
0.1 gas So2 _ 30 rain.
0.1 gas N0j( _ 2 hrs
0.1 gas TSP _ 2 hrs.
0.1 gas
0.1 gas
0.1 C/0/G1/
0.1 gas
0.1 oil/gas
0.1 gas
0.1 oil/gas
0.1 gas
0.1 oil/gas
0.1 oil/gas
0.1 gas
0.1 gas
0.1 gas
0.1 oil/gas
0.1 oil/gas
0.1 oil/gas
0.09 oil/gas 2/
0.09 oil/gas 2/
0.1 oil/gas
Boile
Bottom
N/A
N/A
N/A
N/A
N/A
Dry
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
r Data
Fi r i nc
Front
Front
Opp. Wall
Front
Tangential
Pulver izer
Tangential
Front
Front
Tangential
Front
N/A
Front
Front
Front
Front
Front
Front
Front
N/A
N/A
N/A
.21bs/mm BTU.s respectively.
0 . 31bs/mra
S 190 Ib/hr
BTU's respectively.
for units 1 S 2, respectively; stated
, '
/
figure is derived.
I
'
i
-------
I.1
unit
'Jt i Ii ty/ Power pi ant Number
I (Cont't)
iu.r;ton Light ing & Power Co.
Webster
Wharton
»>wer Colorado River Authority
Fayette
f
Ferguson
Gideon
ubbock Power & Light
it Holly Avenue
Plant 12
t
\\
1!
81
i edina Electric Corp.
H Pearsall
!
0
|
*; >m Antonio Public Service Bd.
- Braunig
£
Not Available
O
n
z
o
o
a
TJ
O
3
^
m
O
i
2
3
1
2
1
1
1
2
3
1
2
4
5
6
7
1
2
3
1
2
3
.^
1979 Fuel Consumption
Control Equipment ' Coal Oil Gas
Particulates SO, 3 3 Sulf. 3,
Equip. Eff. (%) Equip. Eff. (%) Tons /lb. Sulf. (S) Ash (%) Barrels /yal., (%) MCF /Ft.
-
- - - 4,493.4
_ '|
- - - 19,345.0
23,838.4 1,035
- - - - 1,333.0
- 14,318.8
15,651.8 1,042
ESP 99.6 - - 982.4 9,633 0.4 3.9 63.8 141,000 0.3
- - - 10,499.1 '1,024
- 7.4 2,781.0
- - 4,606.0
- 6.8 - 10,667.0
- - - - 14.3 142,008 V 18,054.0 1,082
- - 3,007.1
- 8.7 1,772.6
8.7 138,000 0.3 4,779.7 1,016
- 2.5 207.2
- - 442.6
- - 1,295.9
- - 993.1
2.5 138,000 0.3 2,938.8 1,016
-
* - - - 61.2 850.6
- ' - 15.0 1,119.5
- - - - 35.9 425.0
112.1 144,000 0.6 2,395.1 1,050
- - 105.2 '972.3
- 184.0 3,624.4
- - - - 9.1 4,450.9
298.3 146,000 0.53 9,047.6 1,051
'
'
'
1
Estimated Actual 1979
On issions (10 To n c )
SO, NO TSP
I/ 3.5 I/
I/ 1.5 I/
9.6 8.8 0.1
I/ 1.3 1 /
I/ 3.0 0.1
V 1.65 I/
I/ 0.8 I/
I/ I/ I/
.53 2.42 .05
-------
!2z.2)c.l
Un i t
Ut il ity/Powerplant Number
'KXAS (Cont't)
San Antonio Public Service Bd .
Deely 1
2
Total
Leon Creek (Standby) 1
2
3
4
Total
Mission Road (Standby) 1
2
3
Total
Sommers 1
2
Total
Tuttle 1
2
3
4
Total
S. Texas Electric Coop :,..
Rayburn ' 3
Southwestern Electric Power
Knox Lee 1
2
3
4
5
Total
Lone Star 3/ 1
Welsh 1
f late
Capa~ : """
uicy
(MVJ)
447
447
894
37
37
.0
.0
.0
.5
.5
75.0
113.6
263
25
25
113
163
446
446
892
75
113
113
191
493
25
33
33
33
75
324
498
50
511
.6
.0
.0
.6
.6
.4
.4
.8
.0
.6
.6
.7
.9
.0
.0
.a
.0
.0
.0
.0
.0
.0
Capac
Aty Liocation
(MK) City County
418.0 San Antonio Bexar
418.0
836
26
26
59
85
196
20
20
80
120
400
400
800
59
80
85
140
364
26
36
38
36
83
351
544
50
528
.0
.0 San Antonio Bexar -
.0
.0
.0
.0
.0 San Antonio Bexar
.0
.0
.0
.0 San Antonio Bexar
.0
.0
.0 San Antonio Bexar
.0
.0
.0 ' ' .
.0
.0 Nursery Victoria -
.0 Longvi'ew Gregg -
.0
.0
.0
.0
.0
.0 Avinger Morris
.0 Pittsburg Titus
SO, NO TSP (lbs/10 Btu)
X-P 1.2 coal!/ 0.
1.2 coal!/ 0.
X-P 440ppm/0.6lS
440ppm/0.6»S
. 440ppm/0.6%S
440ppm/0.6%S
X-P 440ppra/0.6%S
440ppm/0.6%S
440ppm/0.6%S
X-P 440ppm/0.6%S
440ppm/0.6%S
' - X-P None
440ppm/0.6%S
None
None
None
- - ' None
None
None
None
440ppm/0.6%S
440ppm/0.6%S
1.2 coal!/ 0.
NO
(lbs/10 Btu)
.7 coal!/
.7 coal!/
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
.7 coal!/
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
TSP
£ Averagu
ng Boiler
(lbs/10°Btu) Period Bottom
Da ta
Fi ring
i
Entire State:
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
SO2 - 30 min.
coal/oil_i/NOx - 2 hrs. Wet
coal/oil!/TSP - 2 hrs. Wet
oil/gas
oil/gas
oil/gas
oil/gas
oil/gas
oil/gas
oil/gas
oil/gas
oil/gas
gas 2/
oil/gas 2/
gas 2/
gas 2/
gas
gas '
gas
gas
gas
oil/gas
oil/gas
coal/oil
H/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A '
Dry
Pulver izer
Pulver izer
Front
Front
Front
Front
Front
Front
Front
N/A
N/A
Front
Front
Opp. Wall
Opp. Wall
Front
Front
Front
Front
Front
Front
Front
Pulverizer
/ S02 limit for oil is 0.3 Ibs/mmBTU's. NOx limit for oil is 0.3 Ibs/mra BTU's
:/' Tuttle TSP limit given as 95 Ib/hr, 113 Ib/hr, 117 Ib/hr & 154 Ib/hr for units I,2,3i4,
/ Lone Star listed SO2 limit as 0.8 Ibs/mmBTU's in Form 67.
respectively;
o
Tl
o
o
no
TJ
O
3
m
o
-------
1979 Fuel Consumption
Estimated Actual 1979
It y/1'oworplant
'jnt 'dj
-ntonlo Publ. Service Bd
o ly
on Creek (Standby)
;sion Road (Standby)
.
-------
2v..6)c.l
i
!unit
Utility/Powerplant Number
-'.AS (Cont a)
Southwestern Electric Power
wilkes 1
2
3
Total
I
$. Southwestern Public Service
' Celanese ' 2
Denver City 2
3 Standby
4
Total
|j East Plant (Cold Reserve 3
^ Status) 4
.1 5
Total
Harrington I/ 1
2
Total
Jones 1
2 '
Total
Moore 2
:. . 3
1 ''-. Total
j
Nichols 1
| 2
3
Total
Plant X 2
4
Total
Name
Plate
Capacity
179
351
351
881
37
10
20
50
80
12
12
36
61
360
343
703
247
247
495
19
49
68
113
113
247
474
98
98
190
386
.5
.0
.0
.5
.0
.0
.0
.0
.0
.5
,5
.0
.0
.0
.0
.0
.5
.5
.0
.2
.0
.2
.6
.6.
.5
.7
.0
.0
.0
.0
Net
Dependable ' County Attainment Currently Enforced Emissions
Capacity Location Status 2 x
(KW) City County SO, NO
177
351
351
879
30
11
19
49
80
12
12
39
63
317
317
634
244
244
488
20
49
69
106
106
244
456
106
106
200
412
X
.
.0 Avinger Marion - - -
.0
.0
.0
.0 Hutchinson
.3 Denver City Yoakum
.5
.5
.3
.4 Amarillo Potter
.4
.0
.8
.0 Amarillo Potter
.0
.0
.0 Lubbock Lubbock -
.0
.0
.0 Sunray Moore - -
.5
.5
.0 Amarillo Potter
.0
.0
.0
.0 Amherst Lamb,. - -
.0
.0
.0
TSP (lbs/10 Btu) (lbs/106Btu)
' 440ppm/0.6%S
None
None
1.2 coal 0.7
None
None
None
440ppm/0.6%S
440ppm/0.6%S
440ppm/0.6%S
1.2 coal 0.7
1.2 coal 0.7
440ppm/0.6%S
440ppm/0.6%S
None
None
- . None
None
1 None
440ppm/0.6%S
440ppm/0.6$S
440ppm/0-6%S
None
None
None
coal
None
None
None
None
None
None
coal
coal
None
None
None
None
None
None
None
None
None
None
Limits
TSP
(lbs/10 Btu) Averaging
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
i
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
Period
.
oil /fj»<= Entire State:
gas SO2 - 30 min.
gas NOj( - 2 hrs.
TSP - 2 hrs.
coal
gas
gas
gas
oil/gas
oil/gas
oil/gas
coal/gas
coal/gas
oil/gas
oil/gas
gas
gas
gas
gas
gas
oil/gas
oil/gas
oil/gas
Boiler Data
Bottom Firinq
N/A
N/A
N/A
Not Available
N/A
N/A
N/A
N/A
N/A
N/A
Wet
Wet
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
Tangential
Opp . Wall
Opp. Wall
Not Available-
Front
Front
Tangential
N/A
N/A
N/A
Pulver i zer
N/A
N/A
Front
Tangential
Tangential
Tangential
Tangential
Tangential
Tangential
Tangential
' ._/ NOX standard for new gas-fired units is 0.21bs/mm BTU's.
o
T1
z
o
o
3
0
O
3
5
m
o
-------
4/z.8)c.l
1979 Fuel Consumption
Estimated Actual 197s
»
k
I Unit
[ ut i 1 i ty/Powerplant Number
| RXAS (Cont'd)
(Southwestern Electric Power
Wilkes 1
1 ' '
Southwestern Public Service
Celanesei/ 2
8
Denver City (Standby) 2
3
1
East Plant (Cold Reserve)
1
| Harrington 1
,!
Jones 1
i
Moore 2
3
Nichols 1
L~: . 2
'3
' Plant X 2
3
1 . «
1
Control Equipment ' Coal Oil
Particulars SO 3 ' 3 Suit. 1
Equip. E£f. (») Equip. Eff. (%) " Tons ""/Ib. Sul£. (%) Ash (%) " Barrels """ /gal. (i)
9.7 '
23
16
9.7 146,000 0.1 49
3
3
PS/ESP 50.0/95.0 L.,101.9
MC 98.6 985.9
2,087.8 8,9B9 0.42 6.07
8
15.0 7
23.0 137,4'46 0.35 16
4
4
6
6
14
27
3.5 2
0.1 ~3
1.2 8
4.8 139,000 0.34 14
Gas . '. 3
0 Dtu 3
MCF /Ft. SO, HO TSP
9.9
,175.0
,607.0
,706.0 955 0.33 96.95 0
,149.0
,149.0 1,016 0.61 0.19 0
130.5
201.8
332.3 937.0 10.9 10.02 5.28
,690.0
,911.0
,601.0 1,029 .02 2.11 0
467.0
,518.0
,985.0 931 0 .36 0
,628.0
,221.0
,979.9
,828.0 966 0 3.94 0
,630.7
,212.5
,254.6
,097.8 1,000 0.1 1.99 0
I/ No consumption or fuel data available.
o
Tl
z
o
o
33
TJ
O
33
m
O
-------
(42z.10)c.l
Ut ility/Powerplant
TEXAS (Cont'd)
Texas Electric Service
Big Brown
Eagle Mountain
Handley
Martin Lake
Monticello
Unit
Number
Total
Total
Total
Total
Total
1
'- 2
3
Total
Plate
Capacity
1
(MW
593
593
,186
J
.0
.0
.0
123.0
1
2
1
188
396
707
248
387
635
44
75
405
455
455
,434
793
793
3793
,379
593
593
793
,979
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.3
.3
uepcnaaoie
Capacity Location
(MW)
575
575
1,150
115
175
375
665
240
375
615
45
80
400
425
425
1,375
750
750
750
... 2,250
575
575
750
1,900
Citv County
.0 Fairfield Freestone
.0
.0
.0 Saginaw Tarrant
.0
.0
.0
.0 Graham Young
.0
.0
.0 Fort Worth Tarrant
.0
.0
.0
.0
.0
.0 Tatum Rusk
.0
.0
.0
.0 Mt. Pleasant Titus
.0
.0
.0
county Attainment
SO NO TSP (lbs/10 Btu)
3.0 coal
3.0 coal
XX-P 440ppra/0.6»S
440ppm/0.6%S
None
- - - None
440ppm/0/6»S
- XX-P None
None
None
440ppm/0/6%S
440ppm/0.6%S
- - - 1.2-C/0.8-0
1.2-C/0.8-0
1.2-C/0.8-X)
3.0 coal!/
3.0 coali/
1.2 1/
NO
(lbs/10 Btu)
None 0
None 0
0.7 oil/gas
0.7 gas/oil
0.7 gas
None
None
0.7 gas
0.7 gas
0.7 gas
0.7 oil/gas
0.7 gas/oil
0.7-C/0.3-O
0.7-C/0.3-O
0.7-C/0.3-O
None 0
None 0
0 . 7i/ 0
TSP Avpraa ina
(l1bs/10°Btu) " Period
.1
.1
0
0
0
0
0
0
0
0
0
0
0
0
0
Entire State
gas/0.3 coal S02 . 30 mln
gas.0..3 coal No.. _ > hrs.
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
TSP - 1 hr;
oil/gas
oil/gas
gas
gas
oil/gas
gas
gas
gas
oil/gas
oil/gas
coal/oil
coal/oil
coal/oil
.l-oil/0.3 coal
.1
.1
oil/0.3 coal
coal/oil
Boiler Data
ttom Firinq
Dry
Dry
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
Dry
Dry
Dry
Dry
Dry
Dry
Pulverizer
Pulverizer
Front
Front
Opp. Wall
Front
Front
Front
Front
Opp. Wall
Opp. Wall
Opp. Wall
Pulverizer
Pulverizer
PuIver izer
Pu Iver izer
Pulverizer
Pulveri zer
I/ SO2 limit for oil is 440 ppm/0.6%S for units 1 s 2; 0.8 Ibs/mmBTU's for unit 3.
NOx limit for oil is 0.3 Ibs/mmBTU's for unit 3.
o
Tl
o
o
3
0
O
3
m
O
-------
(l2v..T.2)c
1979 Fuel Consumption
Control Equipment Coal Oil Gas
Unit Particulars SO 1(,3 1()3 Btu Suit. 3
Ut ilitv/Powevplant Number Equio. Ef£. (*) Equip. Eff. (%) Tons /lb. SulE. (%) Ash (») Barrels /qal. (%) MCF /Ft J
1 .
? '-'EX AS (Cont'd) . I
i Texas Electric Service
| Bit) Urown 1 ESP 97.3
ll 2 ESP 97.3 - -
J 5,064.0 6,914.0 0.67 13.1 933.0 1,079
J
1 Eagle Mountain 1 - 43.0 1,591.0
2 - - - - - 134.0 5,033.0
3 ----- - 4,480.0
177.0 142,857 0.58 11,104.0 1,059
Graham 1 - 7,869.0
; 2 132.0 ' 9,824.0
132.0 142,857 0.49 17,693.0 1,074
Handle'y 1 - 350.0
2 - - - - - 1 '
1 3 - 12,902.0
I 4 35.0 5,540.0
5 - - - - 69.0 8,544.0
104.0 139,525 0.22 27,336.0 1,057
t Martin Lake 1 ESP 99.4 LSS .71.0
2 ESP 99.4 LSS "71.0
3 ESP 99.4 LSS 71.0
10,104 6,767.0 0.92 11.5 220.0 140,262 0.2
Monticello '. 1 ESP/BH 98.6/99.9
2 ESP/BH 98.6/99.9
--'. -. 3 ESP 99.5 LSS 74.0
Estimated Actual 197y
Emissions (10 Tons)
SO, NO TSP
64.5 21.7' 6.1
0.3 3.9 0.4
0.23 2.4 .09
0.6 3.5 -0.14
39.6 41.2 1.6
6,096.0 0.57 17.6 504.0 140,571 0.2
41.6 34.8 9.7
o
Tl
o
o
3)
0
O
a
5
m
o
-------
Unit
Ut il ity/Powerplant Number
TEXAS (Cont'd)
Texas Electric Service Co.
Morgan Creek 2
3
4
5
6
Total
.North Main I/ 0
1
24
Permian Basin 1
2
3
4
5
6
Total
Wichita Falls 6
' 7
Total
Texas Power and Light
Collin 1
DeCordova 1
Lake Creek 1
2
Total
River Crest 1
Stryker Creek 1
2
Total
Trading House Creek " 1
2
Total
Name
Plate
Capacity
(MW)
18
46 u
.0
n
75.0
170
518
827
20
15
81
116
13
13
13
13
115
536
703
13
13
26
156
799
80
236
316
113
177
527
704
581
799
1,380
.0
.0
.0
.0
.0
^
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
Net
Dependable Count}
Capacity Location
(MW) City County SO,,
*
22
44
70
.0 Colorado City Mitchell
Q
.0
175.0
500.0
811
24
24
S£
121
13
13
13
13
115
540
707
13
13
26
153
775
87
230
317
110
175
500
675
565
775
1,340
.0
.0 Fort Worth Tarrant
.0
.0
.0
.0 Monahans Ward
.0
.0
.0
.0
.0
.0
.0 Wichita Falls Wichita
.0
.0
.0 Frisco Collin
.0 Granbury Hood
.0 . Riesel McClennan
.0
.0 .
.0 Bogata . Red River
.0 Pusk Cherokee
.0
.0
.0 Waco McClennan
.0
.0
.^ . ,_ Currently Enforced Emissions Limits
Status 2
NO TSP (lbs/10 Btu)
None
None
440ppm.0.6%S
440ppm/0.6%S
XX-P None
440ppm/0.6%S
440ppm/0.6%S
- - None
None
None
None
None
440ppm/0.6%S
- " None
None
440ppm/0.6%S
440ppm/0.6%S
- - None
440ppm/0.6%S
440ppm/0.6%S
440ppm/0.6%S
None
440ppm/0.6%S
440ppm/0.6%S
NO
TSP
Averaqinq
Boiler Data
(lbs/105Btu) (lbs/106Bti5) Period Bottom
'
None
None
None
None
0.7 gas
0.7 gas
0.7 gas/oil
None
None
None
None
None
None
None
None
0.7 oil/gas
0.7 oil/gas
None
None
None
None
None
None
None
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
.1
.1
.1
.1
.1
.1.
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
gas
Entire State:
gas S°2 - 30 ">in-
lLi "Ox - 2 hrs.
oil TSP - 2 hrs.
gas
gas
oil/gas
gas
gas
gas
gas
gas
oil/gas
gas
gas
oil/gas
oil/gas
ga_s
oil/gas
oil/gas
oil/gas
gas
oil/gas
oil/gas
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
Firing
Front
Front
Front
Front
Opp. Wall
Front
Front
Front
Front
Front
Front
Front
Opp. Wall
N/A
N/A
N/A
Tangential
Opp. Wall
Front
Front
Front
Front
Tangential
Opp. Wall
Opp . Wa 1 1
I/ Units 0 and 1 not operated during 1979.
o
O
o
3D
TJ
O
3
m
O
-------
I2z.l6)c.l
Ut il ity /Power pi ant
-:XAS (Cont'd)
Texas Electric Service
Morgan Creek
North Main
Permian Basin
i
i
!
>
Wichita Falls
i
i
; Toxas Power & Light
1 Collin
DeCordova
> Lake Creek
i
, River Crest
j Stryker Creek
i Trading House Creek
>
i I Wichita Falls did not
t
/ Not Available
j
0
i _
] z
! o
O
3
-o
O
DO
m
o
Control Equipment Coal
Unit Particulates SO, 3
Number Equin. Eff. (%) Equip. * Eff. (%) Tons /lb. Sulf. (%) Ash (%
Co.
2
3
4
5
' 6
0
1
24
1
2
3
4
5
6
6 I/
7
1
1
1
2 <
1
1
2
1
2
burn fuel in 1979.
1
1
.. '
,
1979 Fuel Consumption Estimated Actual 1973
Ol1 Gas Eroi'sions (103Tons)
103 Btu Sul£. ,03 ,
) Barrels /gal. (%) 10>«CF BCU/Ft. SO, HO TSP
2,236.0"
1
3,609.0
5.0 5,335.0
132.0 21,519.0
137.0 142,857 0.53 32,699.0 1,041 0.24 8.2 0.19
_
-
63.0 824.0
63.0 142,857 0.60 824.0 1,055 .11 0.2 .02
I>
65.0
1
4,342.0
455.0 17,713.0
456.0 142,857 0.6 22,120.0 1,046 .77 3.1 0.21
15.2 141,535 0.5 2,018.9 985 .02 3.9 2/
11.8 133,950 0.1 17,581.4 1,056 2_/ 34.3 2/
_ 558.7
15.6 3,622.5
15.6 134,311 0.2 4,181.2 1,027 .01 8.2 2/
26.4 144,500 0.5 1,123.1 1,083 .04 2.2 2/
1.1 842.2
- 19,668.1
1.1 138,000 0.2 28,069.3 1,020 2/ 55.7 2/
44.1 21,053.7
68.5 23,705.2
112.6 136,225 0.2 44,758.9 1,030 .07 87.5 2/
.
f
-------
(42z.l8)c.l
Uni t
Utility/Powerplant Number
TEXAS (Cont'd)
Texas Power & Light
Trinidad 7/5
8/5
9/6
Total
Valley 1
2
3
Total
west- Texas Utilities
Abilene 5/3
6/4
7/4
Total
Concho 3*
4
Total
Fort Phantom 1
2
Total
Lake Pauline 1
2
Tota 1
Oak Creek :.t. 1
Paint Creek 1
2«*
3
4
Total
Rio Pecos 5
6
Name Net
Plate Dependable Coun
Ca J" ~ """ * "~ '
69
239
308
199
581
396
1,176
7
19
~2?
38
15
53
157
190
347
19
20
39
75
30
33
50
105
218
33
88
£JdC11
(MW)
.0
.0
.0
.0
.0
.0
.0
.5
.0
7s
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
:y i_ap
acity , LiOCdtiun
(MW) City County SO,
70
240
310
175
550
375
1,100
7
19
~2?
36
15
51
155
200
355
19
27
46
81
34
34
53
110
231
A
f
.0 Trindad 'Henderson
.0
.0
.0 Savoy Fannin
.0
.0
.0
.5 Abilene Talon -
.0
7s
.0 San Angelo Tom Green -
.0
.0
.0 Abilene Jones
.0
.0
.0 Quanatt Hardeman -
.0
0
.0 Blackwell Cooke -
.0 Haskell Haskell
.0
.0
.0
.0
36.0 Girvin " Crockett
95
.0
.... . t Currently Enforced Emissions Limits
NO
a
NO TSP (lbs/10 Btu) (lbc/lo"Btu)
None
NOne
440ppm/0.6%S
None
440ppm/0.6%S
None
- - None
None
None
440ppm/0.6%S
440ppra/0.6%S
' 440ppm/0.6%S
440ppm/0.6%S
440ppm/0.6%S
440ppm/0.6%S
440ppm/0.6%S
- None
None
' 440ppm/0.6%S
440ppm/0.6%S
None
None
t
None
None
None
0.7 gas
0.7 gas/oil
0.7 gas
None
None
None
None
None
None
None
None
None
0.7 oil/gas
None
None
None
None
None
None
TSP
.
Boil'
(lbs/10ubtu) Period bottom
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
.1
. 1
.1
.1
.1
.1
.1
.1
,
gas Entire State:
gas S02 - 30 min.
oil/gas MOX - 2 hrs.
TSP - 2 hrs.
gas
oil/gas
gas
'
gas I/
gas I/
gas I/
oil/gas 2/
oil/gas 2_/
oil/gas 3/
oil/gas
oil/gas 4/
oil/gas 4_/
oil/gas 5/
gas 6/
gas
oil/gas (>/
oil/gas 6/
gas y
gas y
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
er Data
Fi ring
Front
Front
Tangential
Front
Opp. Wall
Opp. Wall
Front
Front
N/A
Front
Front
Front
Front
Front
Front
Front
Front
Front
Front
Front
Front
Front
San Angelo
Total
121.0
85.0
131.0
103.0
San Angelo Tom Green
440ppm/0.6%S
None 0.1 oil/gas 8/
*Only capacity data available for Unit 3.
**Only capacity data available for Unit 2.
I/ Abilene TSP limits given as 38 Ibs/hr for all units
2/ Concho TSP limits given as 33 Ibs/hr. for both units
V Fort Planton 12 SO2 limit given as 1.6 Ibs/mm BTU's; 81 TSP limit given as 159 Ibs/hr.
4/ Lake Pauline TSP limits given as 17 Ibs/hr.
5_/ Oak Creek TSP limit given as 104 Ibs/hr.
o
Tl
o
o
31
TO
O
X
6/ Paint Creek TSP limits given as 72 Ibs/hr, 81 Ibs/hr &
123 Ib/hr for units 1, 3 s 4, respectively.
7/ Rio Pecos TSP limits given as 87 Ibs/hr & 122 Ibs/hr for
units 5 & 6, respectively.
8/ San Angela TSP limit given as 163 Ibs/hr;
N/A
Front
m
O
-------
1
3 ) c . 1
1979 Fuel Consumption Estimated Actual 1979
Control Eauipment Coal
Unit Particulates SO, __ 1Q3 Dtu 1Q3
ility/Powerplant Number Equip. Eff. (%) Eauip. ' Eff. (%) Tons /lb. Sulf. (%) Ash (%) E
(Cont'd)
in Power & Light
Tr inidad 7
8
9
Valley 1
2
[ 3 .
«
] t Texas Utilities
1 '\hi lene 5
, 6
5 7
i
J .'oncho 4
1
| Tor t Pha ntom 1
;| 2
j!
i'
[| l..ike Pauline 1
i 2
if
.1 Oak Creek 1
! Paint Creek 1
1 r -'-..
1 3
i . 4
'; kio Pecos . 5
6
San Angelo 1
1
j
i
: / Not Available
-r .
i;
0
n
z
o
o
DO \ - .
TJ
i O
DO
^ - ' '
m
CJ
Oil Gas 3
q i£ ., Emissions (1C Tons)
iarrels tu /gal. (*) MCF Btu/Ft. SO, NO TSP
X
1 208.5
1
0.3 2,782.7
0.3 138,000 0.2 2,991.2 1,023 I/ I/ i/
869.1
63.6 20,178.7
7,178.5
63.6 136,400 0.5 28,226.4 1,025 0.2 55.2
0..9
2.3
2.3
5.5 1,094 N/A. .03 I/
0.2 144,653 0.4 330.5 1,102 N/A .05 I/
23.0 7,322.9
52.4 13,315.5
75.4 145,382 0.69 20,599.7 1,023 0.17 2.01 I/
10.3 144,801 0.4 432.6 1,123 0.01 0.02 I/
10.3 145,045 0.65 3,776.8 1,048 0.54 .13 .02
327.2
-
11.4 1,766.0
7.6 3,702.4
19.0 143,258 0.39, 5,795.6 1,073 .03 1.01 I/
.,3,078.0
6,660.0
9,738.0 949 N/A 1.98 I/
7.6- 140,473 0.2 6,410.7 1,058 0.4 0.63 I/
i
-------
(43)c.2
Unit
Ut i li ty/Powerplant Number
UTAH
Utah Power & Light
Carbon 1
2
Total
Gadsby 1
2
3
Total
Hale 1
2
Total
Hunter 1
2
Total
Hunt ing ton 1
2
Total
Capacity
(>!
75
114
189
69
69
114
252
15
45
60
400
400
800
415
400
815
W)
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
Capacity Location Status
(MW) City County SO., NO
66
105
171
66
75
105
246
18
45
63
446
400
846
415
415
830
'
.0 Helper Carbon - -
.0
.0
.0 Salt Lake City Salt Lake X
.0
.0
.0
.0 Orem Utah
.0
.0
.0 Castle Emery - -
.0
.0
.0 .Hunt ing ton Emery - -
.0
.0
so, '
TSP (IDS/10
2
2
X
2
2
X
1
1
1
2
.0-c/l.
.0-c/l.
1.7
.'0-c/l .
.0-c/l.
2.0
2.0
.2-C/O.
.2-C/O.
.2-c/O.
.0-c/l.
Btu)
7-0
7-0
-o
7-o
7-0
8-0
8-0
8-0
7-o
NO
x
TSP \/
(IDS/10 Bt,u) (lbs/10 Bt'u)
None .
None
None
None
Hone
None
None
0.7-c/O.S-o
0 . 7-c/O . 3-o
0.7-C/0.3-0
None
None
None
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
Period Bottom Firing
Not Dry
Specified Dry
Not H/A"
Specified Dry
Not Specified Dry
Dry
Continous Dry
Continuous Dry
Pulverizer
Pulverizer
Front-o/Opn.-g
Pulverizer
Stoker
Pulver izer
Pulverizer
Pulverizer
Jordan (Standby Only}
25.0
24.0 Salt Lake City Salt Lake X
1.7
None Not N/A
Specified
N/A
I/ Emissions limits apply to all fuels.
O
-n
o
o
3
TJ
O
3D
m
O
-------
h)c.2
.1979 Fuol Consumption
'' u't i I i ty/Powerplant
II ~
'' IJ (Cont.)
'> 'Jtah Power & Light
! Carbon
Gadsby
I Muntington
Control Eauipiaent
Unit Participates
Number Equip. Erf. ('*)
1 MC 75.0
2
i
2 ESP 97.0
3 ESP 97.0
1
2
1 ESP 99.6
2' ESP 99.6
1 ESP 99.5
2 ESP 99.5
SO, 1Q3
Kquip. ' Eft:, ('i) J"" To
215
315
530
" -
178
226
405
88
LS 80.0
LS 80.0
1,054
LS 80.0 1,020
LS 80.0 1,038
2,059
Coal
Oil <:.-,*
ns Utu/lb. Sulf. (%) fish (%) "barrels BtU /gal. , ^ ' ^ vcr Btu/^ 3
.1
.5
.7 11,571 0.61 10.17
.8
.1
.1 11,549 0.58 9.8
.2 11,443 0.59
.4 11,287 0.65 9.9
.5
.5
.0 H-,966 0.47 10.03
2.4
1.4
3.8 140,000 0.3
160-8 3,440.3
130.3
lbU.8 IbO.OOO 0.4 4,490.4 964
977.5 935
29.3 140,000 0.3
28.2
26.5
54.8 140,000 0.3
Emissions (10 Tons)
SO., NO TSP
2.98 3.63 0.62
3.54 3.33 0.47
0.28 0.76 0.14
12.27 15.44 1.57
o
T1
z
o
o
a
-Q
O
m
O
-------
(J4JC.1
Unit
Utility/Powerplant Number
VERMONT
Burlington Electric Dept.
Moran I/ 1
2
3
Total
Capacity Capacity
(MW) (MW)
10.0
10.0
10.0
30.0
10.0
10.0
10.0
30.0
Location Status 2
City County SO NO TSP (lbs/10 Dtu)
2 x
Burlington Chittenden - - XX-P 2.0*S
2.0%S
2. ms
NO
(lbs/106Btu)
I
None
None
None
TSP
(lbs/106Btu)
O.I
0.1
0.1
Averag ing
Period
1 hr.-TSP
Absolute-
sulfur
Bottom
Dry
Dry
Dry
Fi ring
Stoker
StoKor
Stohc-r
I/ Emissions Limits apply to all Fuels.
o
Tl
o
o
a
-0
o
3
51
-------
1979 Fuel Consumption
Control Equipment
Coal
Oil
Part iculates
Number Equip. Eft. (%) _Eguip. *" Eff. (%) " Tons Btu/lb. Suit. (%) Ash (%) Barrels /gal. (4) 10 MCF Btu/Ft.3
10
Estimated Actual 1979
K^iisnionr: (10 Toni;)
'. irlington Electric Dept.
' Mocani/
MC
MC
MC
93.5
93.5
93.5
12.5 12,850 1.542/ 9.0 11.5 138,000 0.351/ 0.5 1,000
Not Available
loran also burned 62.4 x 103 tons of wood, with 4,200 Btu's/lb. and less than 1% ash content.
'ource: Cost and Quality of Fuels For Electric Utility Plants - 1979. Form 67 lists 4.0% Sulfur coal, and no sulfur content for oil.
o
Tl
z
o
o
O
a
5
m
O
-------
(45)c.l
Ut i 1 i ty/Powerpla nt
VIKGINA
Appalachian Power Corp.
Clinch River
Glen Lyn
City of Danville W, GSE
Brantlyl/
Name
Plate
Number (MK)
1 238.0
2 238.0
3 238.0
Total 714.0
5 111.0
6 225.0
Total 336.0
1 6.0
2 11.0
3 11.0
Total 28.0
Not
Currently Enforced Emissions Limits
Dependable County Attainment 2/
(MK) City
235.0 Cleveland
235.0
235.0
705.0
100.0 Glen Lyn
235.0
335.0
7.0 Danville
12.0
12.0
31.0
County SO, NO TSP (lbs/10 Btu)
Russell - - 2.64
2.64
2.64
Giles - - - 2.64
2.64
Pittsylvania - - - 2.64
2.64
NO
(Ibs/lQ Btu)
None
None
None
None
None
None
None
TSP - Period
(lbs/10 Btu)
0.11 1 hr.
0.11
0.11
0.13 1 hr.
0.13
0.21 1 hr.
0.2i
Boiler Da ta
Bottom Fir inq
Dry
Dry
Dry
Dry
Dry
Dry
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pu Iver i zer
1^ All Brantly boilers to retire in 1980. S02 limits given on Form 67 as 257 Ibs S02/hr., 404 Ibs/hr. and 404 Ibs./hr. for units 1, 2 and 3
respectively. Stated figures are derived.
2/ SO2 limits apply to all fuels burned unless otherwise indicated.
3_/ TSP limits apply to all fuels burned.
o
Tl
z
o
o
39
s
DO
3
o
-------
(4Sb)c
1979 Fuel Consumption
Unit
ut il i ty/Powerplant Number
VI HOIS' I A
Appalachian Power Co.
Clinch River 1
2
3
Glen Lyn (1978 data) 5
6
City of Danville W, GSE
Brantly 1
2
3
Control Euuipment
Participates SO.
ESP
ESP
ESP
ESP
ESP
MC
MC
MC
..3
Eff. (%) Equip. ' Eff. (») To
98.9
99.6
99.6
99.9
99.9 +
84.0
84.7
84.7
566
533
553
1653
214
477
691
3
13
8
24
Coal
oil
ns BCU/lb. Sulf. (4) Ash (*) Barrels U /gal. (I)
.1
.9
.8
.8 12,125 0.75 15.85
.3
.1
.4 11,539 . 1.25 17.93
.1
.0
.8
.9 13,200 0.9 7.5
2.0
1.8
2.1
5.9 137,801
28.1
38.5
66.6 137,747
Gas 3
3 - E:Ubbions (10 Tor.:;)
18MCP BtVt.3 S02 NO
24.81 14.88 1.26
15.3 6.2 0.11
64.5
272.8 .
184.5
521.8 1,048 0.41 0.24 0.24
o
Tl
o
3D
TJ
O
m
o
-------
(45d)c.l
Utility/PowerpIant
Unit
Number
Location
County Attainment
Status
Currently Enforcc-d Emissions Limits
NO
Averag ing
Boiler Data
City
County
S02 NO TSP (lbs/10 Btu) (lbs/10 Btu) (lbs/10 Bt.u) Period Bottom Firing
VIRGINIA
Potomac Edison
Riverton
'Potomac Electric Power
Potomac River V
VEPCO
Bremo Bluff
Chesterfield!/
Portsmouth!/ '.
34.5
1
2
3
4
5
Total
3
4
Total
1
2
3
4
5
6
Total
1
2
3
4
Total
92
92
110
110
110
514
69
185
254
63
69
113
188
359
694
1486
113
113
185
239
650
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
86.0
66.0
102.0
102.0
102.0
458.0
64.0
172.0
236.0
57.0
63.0
103.0
171.0
337.
654.0
1385.0
108.0
108.0
161.0
215.0
592.0
39.0 Front Royal Warren
86.0 Alexandria Alexandria
64.0 Bremo Bluff Fluvanna
57.0 Chester Chesterfield
108.0 Chesapeake Chesapeake
- 2.64
1
1
1
1
1
2
2
1
1
1
1
1
1
1
1
1
1
.52
.52
.52
.52
.52
.64
.64
.0%S
.0%S-0
.OS
.0%S-0
.0%S-0/1.5%S-C
.0%S-O/1.5%S-C
.OS%-0
.OS%-0
.04S-O
.0%S
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
0.2
0.13
0.17
0.11
0.11
0.11
0.1465
0.1465
1 hr.
1 hr.
1 hr.
0.77
0.50
0.22
0.12
0.1 coal
0.1 coal/
0.11-oil
1 hr.
N/A
Dry
Dry
Dry
Dry
Dry
Dry
Dry
N/A
N/A
N/A
N/A
N/A
N/A
0.1U3
0.206
0.099
1.053
1 hr.
N/A
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Tangential
Tangential
Tangential
Tangential
o-Tangential
o-Tangential
Tangential
Tangential
Front
Tangential
I/ TS? limits were given in Ibs/hr. as follows: 115.3-unit 1, 115.3-unit 2, 114.2-unit 3, 114.2-unit 4, 114.2-unit 5. Stated figures derived..
2/ Chesterfield operating onaer variance; TSP limits are usually 0.1 lbs/106 Btu. Variance TSP limits were given in Ibs/hr. as follows: 440-unit 1,
317-unit 2, 222-unit 3 and 200-unit 4.
317-unit 2, 222-unit 3 and 200-unit 4.
V Portsmouth Units 3i4 convering Co coal in 1982. Portsmouth operating under a variance until 6/1/82. .,
TSP limits were given in Ibs/hr. as follows: Ill-unit 1, 222-unit 2, 159-unit 3 and 2263-unit 4. Unit K4 sulfur limit is 1.0% for coal.
TSP limit is normally .104 lbs/106 Btu. Variance
o
TI
z
o
o
DO
T3
O
m
O
-------
,*
i
r
$
,;;
5
t
|
f
ii
I;
1
i
i
,i
M
i.
I
i
[
|
1
|
i
i
f)C.l
Control Equipment
Unit Particulates SO
ut i 1 i ty/Powerplant Number Equip. EtC. ("&} Eciuip. Eft". (%)
'.INI A
f'.'toinac Edison
Riverton 1 MC 85.0
Potomac Electric Power
Potomac River 1 ESP 99.5
2 ESP 99.5
3 ESP 99.5
4 ESP 99.5
5 ESP 99.5
i
VliPCO
Bremo Bluff 2/ 3 ESP 94.2
4 ESP 99.8
Chesterfield 1 MC 80.0
1978 fuel consumption 2 ESP 70-°
3 M2/ESP 70.0/72.0
4 ESP 75.1
5 ESP 75.0
6 ESP 99.2
Portsmouth 2/ 1 MC 65.0
~ '2 MC 65.0
. . 3 MC 65.0
'"4- ESP 70.0
Source: Cost & Quality of Fuels for Electric Utility Plants - 1979.
4
Source of fuel consumption: VEPCo
Not Available
0
n
z
o
o
TJ
o -
m
O
1979 Fuol Consumption Estimated Actual 1'37-J
Coal Oil Gas i
3 -, «,,])- 3 Emicsionn (10 Tons)
10 Btu 1(J Btu «-!"*- in n*- 7 "~~ ~~ '
Tons /lb. Sulf. (») Ash (4) Barrels /yal. ( (%) lu MCF tU/Ft. SO HO TSP
'
41.2 138,443 0 . 2 1/ _03 _Q9 3/
188.9
180.6
195.9
242.4
248.7
1064.5 12,898 0.74 b.45 . 3/ 9_5jj Q 24
198.4
482.8
681.2 12,364 1.0 11. l I/ V 3_/
340.5
572.8
727.6
176.5
288.3
670.8 478.2
'959.1 12,592 1.1 9.1 2295.6 149,611 1.7 3/ 3/ 3
583.0
961.8
1460.3
257.5
57.3 13,U50 1.0 8.8 3262.6 148,312 1.6 3/ 3/ 37
, .
'
.
..^^^^^^v^^-..^.^..
'
-------
(45h)c.l
Ut11i ty/Power plant
Unit
Number
Location
Citv
County
County Attainment
Status
Currently Enforced Emissions Limits
NO
TSP
Averaging
< r " c ' 6
SO, NO.. TSP (lbs/10 Btu) (Ibs/lO Btu) (lbs/10 Btu) Period
Boiler Data
ttom Firinq
VEPCO
Possom Point
69.0
69.0
114.0
- 239.0
845.0
Total 1336.0
62.0
62.0
100.0
213.0
8-15.0
1282.0
Dumfries
Prince William -
,06
.06
.06
,06
0.8
None
None
None
None
0.3
0.1
1 hr.
Tangential
Tangential
Tangential
Tangential
Tangential
188.0
188.0
882.0
Total 1258.0
155.0
155.0
845.0
1155.0
Yorktown
2.64
2.64
2.64
None
None
None
0.1
0.1
0.1
1 hr.
Tangential
Tangential
Tangential
o
Tl
z
o
o
3
TJ
O
3D
m
O
-------
(45j}c
1979 Fuel Consumption
Control Equipment
Unit Particulates SO., ,,,3
Ut il i ty/Powerplant Number Equip.
VIRGINIA
VEPCO
Possum Point 1 ESP
2 ESP
3 ESP
4 ESP
5 MC
Yorktown I/ 1 ESP
2 MC
3 MC
Eff. (%) Equip. ' Eft". (%) " Tons """^
72.0
72.0
72.0
72.0
91.0
72.0
84.0
91.0
Coal Oil Gas
/lb. sulf. (%) Ash (%) ^Barrels BtU /qal. S""' ^MCF Btu/Ft.3
488.9
597.5
952.9
1952.4
4661.8
8653.5 149,517 1.3
1236.8 ' ' 0.7
891.6 O.S
5977.7
Estimated Actual I'Jl'j
Emissions (10 Ton?.)
SO,
NO
TSi=
H106.1 147,b85 1.6
1.2 1.236
43.1 20.1 0.19
2/
I/ Source of fuel consumption data: VEPCo
2/ Not Available
o
Tl
z
o
o
3
T3
O
30
m
O
-------
(46)c.l
ii-y
Ut ility/Powerplant Number (MW)
WASHINGTON
Pacific Po«ier & Light
Centralia 1 665.
2 665.
Total 1330.
Puget Sound Power & Light
Shuffleton 1 44.
2 44.
88.
0
0
0
0
0
0
(MH) City County
650.0 Centralia Lewis
650.0
1300.0
43.0 Renton King
43.0
86.0
SO., NO TSP
Status 2 x Averaging
SO, NO TSP (lbs/10uBtu) (lbs/10uBtu) (lbs/10uBtu) Period
- 500 ppm S02 . 0.6 0.02 grains Unspecified
per SCF
500 ppm SO2 0.6 0.02 grains
per SCF
X-P 2%S None 0.1 grains Unspecified
per SCt'
2%S None 0.1 'grains
per SCF
Boiler Data
Bottom Firing
Dry Pulverizer
Dry Pulverizer
N/A
N/A
17 Emissions limitations apply to all fuels.
o
Tl
o
o
3
0
O
3
m
O
-------
(40b)£.
Unit
Ut ility/Powcrplant Number
1
j .'ASH I NC TON
Pacific Power & Light
Centralia 1
2
1
.j Puget Sound Power & Light
' Shuffleton 1
i
1979 Fuel Consumi-tt ion list i ma ted Actual 1979
Control Equipment Coal Oil Gas ... ,,,,3
Particulates SO, 3 IQ3 u bulf. 3,
Eauip. Eff. (t) Equip. Eff. (%) ^" Tons ""Vlb. Sulf. (%) Ash (t) *" Barrels "'" /qal. (*) " MCF """"/Ft."" SO., NO TSIJ
ESP 99.4 - - 2834.0 7.0
ESP 99.4 - - 2332.0 17.0
. 5166.0 7,635 0.86 15.6 24.0 141,000 0.3 88.3 46.5 1.0
o
Tl
o
o
3)
480.0
151,300 1.71
2.4 1.1 0.2
m
o
-------
(47>c.l
Utility/Power plant
WEST VI RSI HI A
Allegheny Power
Pleasants
Appalachian Power Co.
J .E. Amos
Kanawha River
Unit
Number
1
. 1
2
3
Total
1
2
Name
Plate
Capacity
626.0
816.3
816.3
1300.0
2932.6
213.0
213.0
426.0
Net
Dependable
Capacity Location
(I'M) City County
-
626.0 Willow Island Pleasants
800.0 St. Albans Putnam
800.0
1300.0
2900.0
210.0 Glasgow Kanawha
205.0
415.0
_ . Currently Enforced Emissions Limits '
°U" "status""1" 2-- ^x
SO NO TSP (lbs/10 Btu) (lbs/10 Btu)
2 x i
1.2 None
- - 1.6 None
1.6 None
1.6 None
X 1.6 None
1.6 None
TSP
Averaging
(lbs/10 BtJ) Period
.05 24 hr-SO2
7 days-TSP
.05 24 hr SO2
°5 7 days-TSP
.05
.05 24 hr SO2
.05 7 days-TSP
Bottom
Dry
Dry
Dry
Dry
Dry
Dry
Firing
Pulverizer
Pulver izer
Pulver izer
Pul ver i zer
Pulverizer
Pulverizer
V Emissions standards apply to all fuels.
O
-n
o
O
31
TJ
O
a
m
O
-------
(47b)c.l
Utility/Powerplant
WEST VIRGINIA
Allegheny Power
Pleasants
Appalachian Power
J.E. Ainos
Kanawha River
1979 Fuel Consumption
Control Equipment
Coal
Oil
Particulates
ESP
ESP
ESP
ESP
ESP
ESP
99.5
99.7
99.7
99.5
99.8
99.8
SO,
Unit
Number Equip. Eff. (t) Equip. f Eff. (%)
103 Btu 103 Btu Sult'
Tons /lb. Sulf. (%) Ash (%) Barrels /gal. (%)
2246.2
2027.1
3344.9
7618.2
421.1
495.3
916.4
11,840 0.81 13.46
11,468 0.74 15.91
37.8
36.4
50.4
124.4
1.7
2_.7
4.4
i0 MCF Bt"/Ft.3
Estimated Actual 1979
Emissions (10 Tons)
SO, HO TS?
LS 90.0 753.8 12,414 3.0 12.8 28.8 141,000 0.3V
137,587 Not
Avail.
136,809 Not
Avail.
43.0 6.8 0.47
123.4 68.6 1.7
13.56 8.24 0.3
I/ Source: Cost and Quality of Fuels For Electric Utility Plants - 1979.
-n
o
o
3
o
O
31
m
0
-------
(47d)c.l
Utility/Powerplant
WEST VI IS I HI A
Control Operating Co.
Philip Sporn
Monogahela Power Co.
Albright
Fort Martin
',
Ha r r i son
Rivesville
-
Willow Island ."-"- -.
^ '
Ohio Power
Hammer .
Mitchell
VEPCO
Mt. Storm
I/ Emissions standards apply to
0
Tl
z
o
o
3J
o
O
30
m
O
Unit
Number
1
2
3
4
5
Total
1
2
3
Total
1
2
Total
1
2
3:,
Total
7
8
Total
1
2
Total
«
1
2
3
Total
1
2
Total
1.
2
3
Total
all fuels.
Name
Plate
Capacity
(MM)
153.
153.
153.
153.
496.
=1108.
69.
69.
140.
178.
576.
576.
1052.
684.
684.
684.
2053.
35.
74.
109.
50.
165.
215.
238.
238.
238.
714.
816.
816.
1632.
570.
570.
555.
1695.
0
0
0
0
0
0
0
0
3
3
0
0
0
0
0
0
0
0
8
8
0
0
0
0
0
0
0
0
0
0
0
0
0
0
Net
Dependable Count;.1 Attainment
Capacity Location Status
(MN) City County SO NO TSP
-
145.
145.
145.
145.
440.
1020.
76.
76.
140.
292.
552.
555.
1107.
640.
640.
640.
1920.
48.
94.
142.
58.
188.
246.
210.
210
210
630.
660
800.
1460.
558
558.
550
1666.
2 x
0 New Haven Mason - -
0
0
0
0
0
0 Albright Preston -
0
0
0
0 Maidsville Monongahela - - -
0
0
0 Haywood Harrison -
0 '
0
0
0 . Rivesville Marion - - X-P
0
0
0 Willow Island Pleasants -
0
0 j;
& Moundsville Marshall X
0
0
0
0 Moundsville Marshall - - X
0
0
0 Mt. Storm Grant - -
0 .
0
0
Currently Enforced Emissions Limits-'
SO,
(lbs/10 Utu)
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.1
3.1
5.12
5.12
5.12
3.2
3.2
2.7
2.7
6.8
6.8
6.8
7.5
7.5
2.7
2.7
2.7
NO..
(lbs/10^Btu)
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
TSP
Averaainq
(lbs/10 Btu)
.05
.05
.05
.05
.05
.05
.05
.05
.05
.05
.05
.05
.05
.05
.05
.05
.05
.05
.05
.05
.05
.05
.05
.05
.05
Period
24 hr S02
~ days-TSP
24 hr SO2
7 days-TSP
24 hr SO2
7 days-TSP
24 hr S02
7 days-TSP
24 hr SO2
7 days-TSP
24 hr SO2
7 days-TSP
24 hr SO2
7 days-TSP
24 hr -SO2
7 days-TSP
2-1 hr SO2
7 days-TSP
Boiler Data
Bottom
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Wet
We t
Wet
Wet
Dry
Dry
Dry
Dry
Dry
Fi ring
Pulver i ze
Pul ver i ze
Pul ver ize
Pulver ize
Pulver ize
Fulver i zer
Pulverizer
Pulverizer
Pulver i zer
Pulverizer
Pulver i zer
Pulver i zer
Pulverizer
Pulverizer
Pulverizer
Pulver i zer
Cyclone
Cyclone
Cyclone
Cyclone
Pulver izer
Pulverizer
Pulverizer
Pul ver izer
Pu Iver i zer
-
-------
1979 Fuel Consumption
Estimated Actual 1979
j Control Equipment
1 i
j Utility/Powerplant Ni
j
I WEST VIRGINIA
Central Operating Co.
Philip Sporn
1
I
;
j Monongahela Power Co.
Albright
1
H
i ' .
1
] Fort Martin
.
j Harrison
i
1
Rivesvil le
tf
Willow Island
,\ Ohio Power
i Kammer
,'
!'
i
i Mitchell
iS
'i
, VEPCO
\ Mt. Storm I/
*'
!i
^
\\J Source: Cost and Quality of
'( :/ Sou^cJ of fuel data : VEPCo
i" ?
\ 0
i 0
1 X
!! -o
1 0
1 §
m
O
Jnit
mber _
1
2
3
4
5
1
2
3
1
2
1
2
3
7
8
/
1
2
1
2
3
1
2
1
2
3
Fuel For
Particulates SO_
:quip.
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
4
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
Electric
Eff. (%) Equip. Eff. (%)
99.7
99.7
99.7
99.7
99.7
99.7
99.7
99.7
99.0
99.0
99.5
99.5
99.5
99.7 - . -
99.7
99.7
99.5
99.4
99.4
99.4
99.8
99.8
99.8
99.7
99.5
Utility Plants - 1979.
Coal
10 Tons Btu/lb. Sulf. (%) Ash (%) 10 Barrels
248.8
306.3
183.0
333.7
891.2
1963.0 11,386 0.97 15.36
255.9
253.4
337.1
846.4 11,893 1.8 "13.8
1470.7
1497.2
2967.9 12,113 1.9 12.7
891.2
802.9
1529.3
3223.4 12,666 2.6 9.5
97.1
270.0
367.1 11,786 1.3 14.7
154.7
361.9
516.6 11,817 1.2 15.4
635.3
614.7
590.9
1841.0 11,792 4.34 14.64
1692.8
1691.8
3384.6 11,767 3.33 14.03
974.6
1272.0
834.4
3081.0
ll,4;iO 1.9 18.6
10.0
15.5
7.4
8.8
23.5
65.2
0.8
0.6
2.6
4.1
13.9
8.7
22.6
0.1
1.5
3.8
5.5
2.0
1.3
3.3
1.8
4.1
5.9
0.8
1.0
1.1
2.9
52.2
64.9
117.1
Oil Gas Emission-; (lO^Tons)
BtU /!. S(%)' 103MCF ""/Ft.3 SO. ^ TSP
136,551 Not ' 35.7 17.7 24.1
Avail.
141,000 0.3 ... 28-9 7'6 °-5
141,000 0.5 107.1 2G.7 3.4
17.8
22.6
28.9
106,662 0.31/ 69.3 1,000 159.2 29.0 3.5
141,000 0.3V . 9.2 3.3 0.11
'
141,000 0.3V H-8 U-3 °'3
138,620 0.34 159.8 50.6 0.32
139,985 0.34 225.4 30.5 0.95
.
102.15 26.38 1.29
'
-------
(48)c.l
Utility/Powerplant
WISCONSIN
Dairyland Power Corp.
Name Net
Plate Dependable
Unit Capacity Capacity
Number (Mw) (MW)
Location
City
County
Alma
Genoa f6
Madgett (Alma 16)
Stoneman
1
2
3
4
5
Total
1
1
1
2
Total
15.0
15.0
15.0
54.0
81.0
180.0
345.6
350.0
15.0
30.0
45.0
20
21
20
61
86
208
' 350
350
21
36
57
.0 Alma
.0
.0
.0
.0
.0
.0 Genoa
.0 Alma
.0 Cassville
.0
.0
Buffalo
Vernon
Buffalo
Grant
SO, NO TSP
-
-
_
so.
2 6
(lbs/10 Btu)
None
None
None
None
None
None
1.2
None
None
NO
(lbs/10 Btu)
None
None
None
None
None
None
0.7
None
None
TSP &
(lbs/10 Btu) Period
0.6 Not
0.6 specified
0.6
0.6
0.6
0.6
0.1
O.b
0.6
Bottom
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Firing
Pulver i zer
Pul ver i zer
Pulve r i zer
Pul ve r i zer
Pulverizer
Pul ver i zer
Pul ver i zer
Pulverizer
Pulver i zer
I/
TSP limits apply to all fuels.
o
Tl
z
o
o
30
s
3
m
O
-------
(4Bb)c
1979 Fuel Consumption
Control Equipment
Oil
Ut ility/Powerplant
WISCONSIN
Dairyland Power Corp.
Alma
Genoa #6
Madgett (Alma 16)
Stpnentan
Unit
Number Equip.
Part iculates
Eff. (»)
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
99.5
99.5
99.5
99.5
99.5
99.0
99.6
99.5
99.5
10
21.3
30.2
26.7
172.8
224.4
476.1
940.9
101.0
48.3
52.1
100.4
9,849
10,130
8,528
10,876
2.7
2.7
0.39
3.5
11.8
12.4
4.8
11.9
Barrels
0.1
0.4
0.3
0.9
1.2
2.8
4.7
26.4
0.9
0.9
1.9
/qal.
140,000 0.3
140,000 0.3
140,000 0.31
140,000 0.3
Estimated Actual 197'J
Emissions (10 Tons)
SO
2-
NO
TSP
25.7
50.8
0.8
6.6
4.3
8.5
0.6
0.9
0.2
0.9
0
0.3
o
o
o
3)
0
O
m
O
-------
(48d)c
Ut i1i ty/Powe rpla nt
WISCONSIN
Lake Superior District Power
BayfrontV
Madison Gas 6 Electric
Blount St.
Manitowoc Public Utilities
Manitowoc
MarshEield Electric s Water
wildwood
Name
Plate
Uni "
.t (Japa
city
Number (MW)
1
2
3
4
5
1
2
3
4
5
6
7
3
4
5
6
1
2
3
4
5
Total = 82
10
5
38
20
20
50
50
Total = 193
10
10
25
25_
Total = 70
4
3
6
16
22
Total = 51
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
Net
Dependable ' County Attainment
Capac " ' -~--..-
icy upcacion acacus
(MW) City County SO NO TSP
84"
10
5
30
21
21
45
45
177
10
10
25
25
70
3
2
5
13
19
42
2 x
Ashland Ashland - -
To"
.0 Madison Dane X-P - XX-P
.0
.0
.0
.0
.0
.0
.0
.0 Manitowoc Manitowoc - - XX-P
.0
.0
.0
.0
.0 Marshfield wood - - XX-P
.0
.0
.0
JL . '
.0
Currently Enforced Emissions Limits .,
S°2
NO
* r
(lbs/106Btu) (lbs/10°Btu)
None
None
None
None
None
None
None
None
None
None
None
None
None ..
None
None
None
None
None
None
None
None
{
None
None '
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
tsv -'
£
(lbs/10uBtuJ
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
.6
.6
.6
.6
.6
.6
.6
.6
.6
.6
.6
.6
.6
.6
.6
.6
.6 '
.6
.6
.6
.6
Averaging Boil< ~ '
Period Bottom
Not Dry
Specified H/A
Dry
Dry
Wet
N/A
N/A
Wet
Wet
Dry
Dry
Dry
Dry
Dry
Dry
Dry
N/A
N/A
N/A
Dry
Dry
e r ua c n
Firing
Stoker
Front
Stoker
Stoker
Cyclone
Front
Front
Pul ver i
zer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Stoker
Stoker
Stoker
Stoker
N/A
Front
Front
Stoker
Stoker
I/ Bayfront boilers 1-5 associated with turbines 1(5 row) , 2(5 raw), 3(5 raw), 4(20 mw), 5(20 raw), 6(27 mw) .
2/ TSP limit applies to all fuels.
o
Tl
z
o
o
3
s
3)
m
o
-------
1979 Fuel Consumption
F.stim.it»ti Actual 1979
Unit
Ut ility/Powerplant Number
W JONSIN
Lake Superior District Power
Bayfront 1
2
3
4
5
Madison Gas & Electric
Blount-St. 1
2
i 4
( 5
! 6
i 7
1
t
i
i Manitowoc Public Util.
Manitowoc 3
4
5
6
'
j Marshfield Electric s Water
1 wildwood , ' 1 *
1 ' ' 2
^ "'' ' 3
'I 4 '
P 5
:
i
i
i
Control Equipment
Coal
Oil r.;>
-------
(4Bh)c
litility/Powerplant
..ISCONSIN
Menasha Electric & Water
Menasha
Minnesota Power & Light
Winslow
Number (MW)
1
2
3
4
Total =
2
3
TcrtD.1 =
4.0
4.0
8.0
14.0
30.0
13.0
13.0
26.0
Capacity Location Status 2
(MW) City
-
5.0 Menasha
5.0
9.0
15.0
34.0
13.0 Superior
13.0
26.0
County SO NO TSP (lbs/10 Btu)
2 x
Winnebago - - XX-P None
None
None
None
Douglas - - - None
None
N0x
(lbs/10 Btu)
None
None
None
None
None
None
TSP ^
(lbs/106Btu)
0.6
0.6
0.6
0.6
.15
.15
. Period Bottom Firing
Not Dry
Specified Dry
Dry
Dry
N/A
N/A
Stoker
Stoker
Stoker
Stoker
N/A
N/A
Wisconsin Electric Power
Commerce
15
35.0
31.0 Milwaukee Milwaukee
0.15
N/A
| I/ TSP limit applies to all. fuels.
O
n
0
O
3
T3
O
m
O
-------
1979 Fuel Consumption
Utility/Powecplant
i COM31 n
'; Mfiii-iia Electric I Water
Minnesota Power & Light
winslow
Wisconsin Electric Power
Commerce .
Actual 1979
Emissions {10 Tons)
NO TSP
1 MC/ESP Not Avail.
2 MC/ESP Not Avail.
3 MC/ESP Not Avail.
4 MC/ESP Not Avail.
85.0
32.8 12,500
2.1
7.4
7.0
66.5
73.5
26.0
35.5
150,897 1.71 35.5 994
136,196 0.2 1,977.0 1,016
1.12 0.25 0.14
0.44 0.24 .01
.40 .02
o
Tl
z
o
o
3
s
9
5
m
O
-------
<481>c
Utility/Powerplant
HISCONS in
Wisconsin Electric Power
LakeGide
North Oak Creek
Port Washington
South Oak Creek
Valley
Unit
Number
1
2
3
4
5
6
7
8
9
10
11
12
Total
1
Name
Plate
Capai ' '
city
IMW)
20
20
30
30
30
30
7
a
60
8
60
8
= 311
120
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
Net
Dependable
Capac i ' "
-------
(48n;c
1979 Fuel Consumption
Unit
Ut ili ty/Powerplant Number
WISCONSIN
Wisconsin Electric Power
Lakeside 1
2
3
4
5
6
6
8
9
10
11
12
North Oak Creek 1
2
3
4
Port Washington 1
; 2
i 3 '
; 4
i 5 '
1 ; '
| South Oak Creek ." ' 5
6
7
! 8
j
i
(
Valley 1
I 2
Control Equipment
Particulates SO- . 3
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
Eff. (%) Equip.
99.5
99.5
99.0
99.0
99.2
99.2
99.2
99.2
99.2
99.5
99.5
99.0
99.0
99.0
99.0
' Eff. (%) " To
264
246
93
282
885
130
134
165
148
132
710
325
347
484
502
1658
315
* 341
Coal
Oil ass
ns Btu/lb. Sulf. (%) Ash (%) "barrels BtU /qal. &\v' ^ MCF Btu/
.0
.0
.0
.0
.0 11,440 2.1 9.4
.0
.0
.0
.0
.0
.0 12,212 2.9 10.9
.0
.0
.0 ,.
.0
.0 11,445 2.1 9.3
.0
.0
240
5
5
3
5
18
9
4
3"B
10
61
t
Estimated Actual 1979
3
"t. SO, HO TSP
.0 137,276 0.3 9153.0 1,013 0.22 1.9 .08
.0
.0
.0
.0
.0 138,114 0.3
.0
.0
.0
.0
.0 138,033 0.3
134.0
108.0
35.3 8.0 1.0
39.1 6.4 0.6
67.5 14.9 5.2
656.0
11,490
2.9 10.2
1,017
36.4
5.9 0.7
o
n
o
o
a
o
§
3
m
O
-------
(48p)c
Ut i1i ty/Powe cpla nt
WISCONSIN
Wisconsin Power & Light
Black Hawk
Columbia
Dewey Nelson
Edgewater
Rock River
Wisconsin Public Serv. Corp.
Pulliam
Unit
Number
3
4
Total
1
2
Total =
1
2
Total
1
2
3
4
Total
1
2
Total
x
,2
3
'4
5
,6
7
8
Total
1
2
Total
Name
Plate
Capacity
25.0
25.0
= 50.0
556.0
556.0
1112.0
113.6
113.6
= 227.2
30.0
30.0
66.0
351.0
= 477.0
75.0
75.0
= 150.0
10.0
10.0
30.0
30.0
50.0
63.0
75.0
125.0
= 393.0
60.0
75.0
= 135.0
Net
Dependable
Capacity Location
(MW) City County
-
25.8 Beloit Rock
26.7
52.5
517.5 Portage 'Columbia
527.0
1044.5
105.5 Cassville Grant
103.6
209.1
17.0 Sheboygan Sheboygan
31.2
73.3
323.5 .
445.0
77.6 Beloit Rock
78.7
156.3
8.0 Green Bay Brown
8.0
29.0
28.0
50.0
65.0
81.0
127.0
396.0
64.0 Rothchild Marathon
84.0
148.0
Currently Enforced Emissions Limits , ,
County Attainment
Status 2
SO NO TSP (lbs/10 Btu)
2 x
' - - X-P None
None
X-P None
0.8 oil/1.2 coal
- - - None
None
- - - None
None
None
None
X-P None
None
XX-P None
None
None
None
None
None
None
None
X-P - XX-P None
None
NO
(lbs/10 Btu)
None
None
None
0.3 oil/0.7
None
None
Hone
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
TSP -/
(lbs/106Btu)
1
0.6
0.6
0.6
coal 0.1
0.6
0.6
0.6
0.6
0.6
0.6
0.6
0.6
0.3
0.3
0.3
0.3
0.3
0.3
0.3
0.3
0.6
0.6
Averaging Boiler Data
. Period Bottom
Not Dry
Specified Dry
Dry
. Dry
Wet
Wet
Wet
Wet
Wet
Wet
Wet
Wet
N/A
N/A
Dry
Dry
' Dry
Dry
Dry
Dry
Dry
Dry
Firing
Pulver izer
Pulverizer
Pulver i zer
Pulverizer
Cyclone
Cyclone
Pu Iver izer
pulverizer
Cyclone
Cyclone
Cyclone
Cyclone
Front
Front
Pu Iver i zer
Pulverizer
Pulverizer
Pulver i zer
Pulver i zer
Pulverizer
Pulver i zer
Pulverizer
I/ TSP limit applies to all fuels.
o
Tl
z
o
o
3D
TJ
O
3D
m
D
-------
1
1979 Fuel Consumption Estimated Actn.il 1Q7Q
I Unit
'j Utility/Powerplant Number
:j iCOHS IN (Cont'd)
; Wisconsin Power &
Black Hawk
i
Columbia
.
Dewey Nelson
j
1 Edgewater
\
i
'
Rock River
!
j Wisconsin Public
j Pulliam
1
!
I
1
'
t
Weston
I
!
1
_
O
m
z
0
o
3D
-o
O
?
Light
3
4
1
2
1
2
1
2
' 3
4
1
2
Service Corp.
1
2
' .". 3
4
5
6
7
8
1
2
-
t
Control Equipment
Particulates 5O_
Equip. E££. (%) Equip. - ' Eff. (%)
HC/ESP
M:/ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
(
-,
i _
' ESP
ESP
ESP
ESP
ESP
ESP
ESP
ESP
88.0/99.5
88.0/99.5
99.5
99.5
99.5
99.5
90.0
90.0
99.5
99.0
99.5
99.5
-
_
98.0
98.0
97.0
98.0
92.0 - ' -
97.0
99.0
99.0
.
Coal
Tons U/lb. Sulf. (%1 Ash (Al Barrels
27.8
29.5
57.2 10,720 2.7 10.85
2,084.7
1,681.7
3,766.4 8,516 0.52 6.4
285.0
273.8
558.8 10,728 4.11 10.15
23.1
128.3
914.2
1,065.7 10,820 3.01 9.53
90.0
148.9
239.0 10,780 2.93 11.15
-
-
39.0
41.5
91.5
169.1 !
236.3
311.6
8B9.0 11,763 3.23 12.2
104.8
221.0
325.9 11,391 3.42 10.95
0.8
0.9
1.7
28.2
17.8
46.0
0.3
0.3
0.9
1.8
0.8
0.9
3.9
1.5
2.4
3.8
-
-
2.5
2.5
2.9
2.4
3.8
3.6
17.6
4.1
2.2
6.3
uil Gas 3
i P Emissions (10 Tons)
Btu , Suit- 10 Btu 3
/gal., (%J MCF /Ft. SO, HO TSP
35.3
33.9
144,120 0.3 69.2 1,009 3.0 0.51 .02
144,120 0.3 36.7 33.9 0.87
142,000 0.3 36.3 15 .0 0.24
144,120 0.3 60.9 28.81 0.14
57.3
151.1
144,120 0.3 208.1 999 13.3 6.6 0.25
11.7
.L
i -
-
-
'
-
-
138,000 0.3 11.7 1,019 54^56 8.55 1.65
138,000 0.3 16.6 2.5 0.8
'
,
-------
(49)c.l
Unit
Util ity/Powerplant Number
WYOMING
Black Hills Power & Light
Os age 1
2
3
Total
Simpson 1
3
4
5
Total
Pacific Power & Light
Bridger 1
2
3
' 4
Total
Johnston 1
2
3
4
Total
Wyodak / ';_. / 1
Utah Power t Light
Naughton 1
2
3
Total
Name
Plate
Capacity
(MM)
12.0
12.0
12.0
36.0
3.0
2.0
2.0
20.0
27.0
500.0
500.0
508.0
508.0
2,024.0
114.0
114.0
230.0
330.0
788.0
331.9
163.0
218.0
330.0
711.0
Net
Currently Enforced Emissions
Dependable County Attainment
Capac
ity location status
SO^
' t
tMW) City County S00 NO TSP (lbs/10"stu)
10
10
10
30
2
1
2
18
23
500
500
500
500
2,000
100
100
220
330
750
330
160
220
330
710
.0 Osage Weston -
.0
.0
.0
.0 Gillette Campbell
.0
.0
.0
.0
.0 Rock Springs Sweetwater - - X-P
.0
.0
.0
.0
.0 Glenrock Converse - -
.0
.0
.0
.0
.0 Gillette Campbell -
.0 Kemiaer Lincoln - -
.0'
A
1.2
1.2
1.2
1.2
1.2
1.2
1.2
0.3
0.3
0.3
0.2
1.2
1.2
1.2
0.5
0.5
1.2
1.2
0.5
0
0
0
0
0
0
0
0
0
0
0
0
0
0
NO
ff
Lim
its
TSP I/
-: «v c i a y i. My
(lbs/10 Btu) (Ibs/10"l3tu) Period
0.75
0.75
0.75
.6 oil/0.75 coal
0.75
0.75
.46 oil/0.75
.46 oil/0.75
.46 oil/0.75
.46 oil/0.75
coal
coal
coal
coal
.3 oil/0.7 coal
.46 oil/0.75
.46 oil/0.75
.46 oil/0.75
.46 oil/0.75
.46 oil/0.75
.46 oil/0.75
.46 oil/0.75
.46 oil/0.75
coal
coal
coal
coal
coal
coal
coal
coal
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
.332/ 2 he.
.332/
.332/
.353/ 2 hr.
.353/
.3537
.35V
.1 2 hr.
.1
.1
.1
.3 2 hr.
.3
.25
.21
.1 2 he.
.246 2 hr.
.238
.221
Bo " ' " "
L t e r u d n a
Bottom Firing
Dry
Dry
Dry
Dry
Dry
Dry
Wet
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Dry
Stoker
Stoker
Stoker
Pulverizer
Stoker
Stoker
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pulverizer
Pu Iver izer
Pulver izer
Pulverizer
I/ SO2 limit for existing plants applies only to coal. TSP limit applies to oil and coal.
2_/ Osage TSP limit given as 60 micrograms/cu. meter of gas flow; stated limit derived using State SIP formula.
3_/ Simpson TSP limit given as 60 micrograms/cu. meter of gas flow; stated limit derived using State SIP formula.
o
Tl
o
O
3
0
O
3J
£1
m
o
-------
(49b)c
1979 Fuel Consumption
Unit
Ut ility/Powerplant Number
WYOMING (Cont'd)
Black Hills Power & Light
Osage 1
2
3
Simpson 1
3
4
5
Pacific Power & Light
Bridger 1
2
3
4
Johnston 1
2 .
3
4
Wyodak /I
Utah Power 6 Light
Naughton 1
2
3
Control Equipment
Particulates _ SO.
Equip.
MC
MC/ESP
MC
_
MC
MC
ESP
ESP
ESP
ESP
ESP
ESP
' ESP
MC/ESP
Vent.
ESP
MC/ESP
MC/ESP
ESP '
Eff. (%) Equip. '
91.0
91.0/98.9
91.0
_
20.0
20.0
99,0
99.3
99.3
99.3
99.3 NaS
99.6
99.6
82.0/99.6
99.8 - -
99.4 NACS
80.0/97.0
80.0/97.0 - -
98.0
T
Eff. (%) To
79
79
79
238
0
0
113
114
1,649
1,407
1,559
91.0 125
4,740
572
633
1,151
1,425
3,781
70.0 1,673
559
767
1,178
2,505
Coal
Oil , Gas
Btu 103 Btu' Sul£- io3 l
ns /lb. Sulf. (») Ash {») Barrels /gal. (%) MCF
.9
.8
.0
.7 8,044 0.45 6.3
.3 -
.4 - -
_
.8 - -
.5 8,049 0.45 6.2
.0
.0
.0
.0
.0 9,351 0.5 12.0
.0
.0
.0
.0
.0 7,739 0.4 9.5
.0 7,947 0.5 . 7.1
.2
.5
.8
.5 9,690 0.51 7.25
0.1
-
-
1.8
1.9 135,000 0.3
23.0
25.0
20.0
2.0
70.0 138,060 0.3
1.0
1.0
6.0
8.0
16.0 137,558 0.3
23.0 138,272 0.3
2.2
3.7
2.7 . 82.6
8.5 140,000 0.3 82.6
Estimated Actual Ia7:i
3
Emissions (10 Tono)
BtU/Ft.3 SO, .NO TS?
1.8 Not Avail. 0.1
1.2 1.7 .C'.,
45.0 45.5 2.0
29.2 34.6 1.5
15.6 15.1 0.5
851 26.98 23.24 3.5
o
o
o
3
3
9
D
-------
Chapter Two
-------
CHAPTER 1WO
SURVEY OF STATE ENFORCEMENT AGENCIES
This section reports the results of an ICF survey of state air pollution
control enforcement agencies. The agencies were contacted for the purpose of
determining:
1.) the currently enforced emissions standards
2.) the actual methods used to assess compliance
(accepted calculations, approved sampling
techniques, etc.)
3.) the stringency of enforcement procedures
4.) the reporting requirements placed on utilities
5.) the consistency of enforcement procedures across
states, and
6.) the extent of reliance on continuous monitors
for enforcement procedures.
The results of the survey vary widely among the states, due in part to the
quality of the information provided Dy the enforcement officials. Very few
field representatives responded to our telephone survey and these are the
individuals most knowledgeable about the actual state enforcement practices.
For those representatives we did survey, the data obtained did not conflict
substantially with the information given by state administrative officials
contacted. There is of course the problem of identifying how the actual
enforcement practices are carried out on a day-to-day basis versus what
individuals are willing to admit in a telephone survey.
Overall the results show that while most states place the burden of
proving compliance on the utilities, the individual state assessments of
compliance were not consistent. Rarely was detailed information available on
ICF
INCORPORATED
-------
-2-
the frequency of sampling, the actual product sampled (burn, purchases,
composite sample, etc.), the permitted exceedences, or the assumed averaging
time for continuous operations. The common use of EPA test methods 5, 6, and
7, however, indicates that some consistency does exist in stack testing
practices, pew states require continuous monitors on existing plants and
hence few based their enforcement practices on the results of monitoring.
This survey was undertaken only to establish how states are approaching
enforcement issues. The results should therefore be viewed as intended; i.e.,
as a first attempt to characterize state enforcement practices. No attempt
was made to determine consistency with federal enforcement requlations, and
the results should not be construed as indicating compliance or non-compliance
with such regulations.
ICF
INCORPORATED
-------
State
Alabama
Effective Date of Regulations:
As Per State - 1/18/72 (Rev.
2/13/80)
As Per EPA
Standards Established:
24 hour average
Fuels Analysis;
Method
Purchases or burn
Frequency
Conducted by
Requirements
Stack Tests;
Compliance
Frequency
Conducted By
Requirements
Continuous Monitors:
Current AS1M procedures
As burned
Not specified
Utility
Meet SC>2 & NOX emissions rate over a 24-hour
average
TSP sampled & reported biannually, S02 & NOX
summarized monthly, reported biannually
Utility, with State observation
Required for NSPS (All plants constructed after
8/17/71) and Existing (Plants built prior to
8/17/71: ^ for opacity if oil- or coal-fired;
' for SC-2 if FGD equipment is used.
In Existence
Tombigbee #2, #3 (assumed)
Widows Creek, #7 (assumed)
ICF
INCORPORATED
-------
2-2
State
Arizona
Standards Established:
Effective Date of Regulations:
AS Per State -5/14/79
Rev. 10/2/79
As per EPA -Approval is
pending
3 hour average
Fuels Analysis
Method
Purchases or burn
Frequency
Conducted by
Requirements
Stack Tests:
Compliance
Frequency
Conducted By
Requirements
Continuous Monitors
Not required
In Existence
Meet 3-hr, average for SC>2 & NOX
Not specified
Utility or independent consultant, with State
observation.
NSPS and Existing Plants: ' for SC>2 if FGD
equipment is used in oil- or coal-fired units;
2) for NOX if 1,000 mmBtu and so required
by the Director of the Dept. of Health Services
Apache #2,3
Cholla #1,2
Coronado #1
ICF
INCORPORATED
-------
2-3
State
: California
Standards Established:
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors:
In Existence:
Effective Date of Regulations:
AS per State - 12/1/77
Rev. 1/1/80
As Per EPA - Unknown
Standards differ by Air Pollution Control Districts
Requirements differ by APCD
Requirements differ by APCD
Requirements differ by APCD
ICF
INCORPORATED
-------
2-4
State
Colorado
Standards Established;
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors;
in Existence:
Effective Date of Regulations:
As per State - 1/30/79
As Per EPA - 1/30/79
2 hour average
Physical sampling
Purchases
Reporting to State
- undefined
Utility
- annual collection by utility
Calculated emissons only
actual test required only in cases of suspected
violation
Only on NSPS Plants
N/A ,
ICF INCORPORATED
-------
2-5
State
: Connecticut
Standards Established;
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors;
In Existence:
Effective Date of Regulations:
AS per State - 12/14/79
As Per EPA - 12/14/79
Maximum
Physical sampling
Purchases
Undefined
1.) utility with occasional spot checks by state
2.) 11 fuel sales organizations
Not required
Bridgeport (S02)
American Chemical (NOV)
A
ICF
INCORPORATED
-------
2-6
State
Delaware
Standards Established;
Fuels Analysis:
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors:
Effective Date of Regulations:
As per State - 7/17/73
Rev. 5/1/80
As Per EPA - Conditional
approval only
1 hour average
Not specified.
Not specified.
"Periodic"
Division of Environmental Control
Meet: One hour averages from 4 or more data points
(EPA Methods: 6 (S02) & 7(NOX))
"Periodic"
Utility
Must report TSP emissions, if when averaged over a
3 hour period, they exceed standard.
NSPS and Existing Plants: 1) for opacity of oil-
or coal-fired; 2) for S02 if FGD equipment is
used; 3) for NOX if 1000 mmBtu if in a
nitrogen dioxide Priority I area.
in Existence:
ICF
INCORPORATED
-------
2-7
State
Florida
Standards Established;
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors;
Effective Date of Regulations:
As per State - 1/18/72
Ref. 7/2/79
As Per EPA - 2/29/80 - For
FP&L variances
Other Rev. -
Approval Pending
2 hour average
Not required
Undefined
Utility; supervised by State
Opacity - required on all sources except existing
sources meeting standards without controls.
SO2 - required on all sources with control
equipment.
NOX - required on all new sources.
in Existence:
ICF
INCORPORATED
-------
2-8
State
Georgia
Standards Established;
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors;
In Existence:
Effective Date of Regulations:
AS per State - 3/6/78 Rev.
4/9/79
As Per EPA
Sulfur in fuel: Maximum
Emissions: 1 hour average
Sampling
As burned
Daily
Utility
For reporting purposes, daily results are
aggregated by week, averaged over the month and
reported monthly.
Must meet 1 hr. average for TSP & SC>2
Annually
Utility or independent consultant; spot tests by
state.
For all NSPS plants: SO2, NOX, & TSP.
For opacity: if oil- or coal-fired; for SC>2 if
using FGD equipment.
ICF
INCORPORATED
-------
2-9
State
Illinois
Standards Established:
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors;
in Existence:
Effective Date of Regulations:
As per State - 6/12/80
As Per EPA - Approval pending
Emissions - 1 hr. maximum
Sulfur in fuel - 2 month average
Low Sulfur Coal/Solid Fuel only
Physical sampling
Burn
Daily
Utility
95% of samples must be less than or equal to 1.2
(mean)
Undefined
Utility, observed by EPA
Not required
ICF
INCORPORATED
-------
2-10
State
Indiana
Standards Established:
Fuels Analysis:
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors:
Effective Date of Regulations:
As per State - 3/26/74
Rev. 1/7/80
As Per EPA - Approval Pending
Emissions: 3 hour average
Sulfur in fuel: 30-day average
Sampling
Not specified
Not specified
Utility; spot tests by State & EPA
Meet 3 hr. average for NOX & TSP
(EPA Methods: 6(S02; 1-5(TSP & 7(NOX))
Not specified; results reported quarterly
Utility; spot tests by State & EPA
NSPS and for all plants: 1) Opacity if oil- or
coal-fired; 2) for SC>2 if FGD equipment is used;
3) for NOV if 1000 mmBtu and Director of the
J\
EPA determines its necessity to meet national
standards
In Existence:
ICF
INCORPORATED
-------
2-11
State
Iowa
Standards Established i
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors;
In Existence:
Effective Date of Regulations:
AS per State - 6/15/77
Rev. 7/25/79
As Per EPA - 6/77
2 hour average
Not specified
Not specified
As requested by Director of Environmental Quality
Department
Utility
Monthly submittal of estimated emissions rates and
fuels use
Meet TSP & S02 maximum 2 hr. average
Not specified
Utility, spot tests by the State
Reports on opacity emissions (recorded by
continuous monitors) in excess of allowable limits
must be submitted quarterly.
Reuired for: opacity for all coal-fired plants
250 mmBtu; opacity, NOX, SC>2 for NSPS plants
ICF INCORPORATED
-------
2-12
State
Kansas
Standards Established;
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors:
In Existence:
Effective Date of Regulations:
AS per State - 1/1/74
AS Per EPA - 1974
1 hr. maximum
Sampling
Not specified
Daily
Utility or independent consultant, with State
observation.
Monthly reports with weekly composites of daily
samples.
Meet 1 hour maximum
Once a year for TSP; not specified for S02
Utility or independent consultant, with State
observation & spot tests.
Required for NSPS plants
ICF
INCORPORATED
-------
2-13
State
Kentucky
Standards Established;
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests:
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors;
In Existence:
Effective Date of Regulations:
AS per State - 6/29/79
As Per EPA - Approval Pending
Emissions: 24 hour average, unless otherwise
specified;
Sulfur in fuel: monthly average
Optional - substitute for monitoring of SC-2
emissions
Physical sampling
N/A - probably burn
Daily
Utility or contractor
Report quarterly
Required to demonstrate compliance at time of
permitting or after complaints; in other cases
utility may conduct stack tests or use fuel
samples.
Arithmetic mean of three test runs
Utility of State
Regulations require quarterly reports (not
enforced)
Required for opacity, all units 250 mmBtu/hr.
optional for SC-2 on existing plants required for
SC>2, NOX, 002 on a11 new Plants-
Green - SO2r TSP, NOX
Cane Run 4,5,6
ICF
INCORPORATED
-------
2-14
State
Louisiana
Effective Date of Regulations;
AS per State - 1972
As Per EPA - 1972
Standards Established;
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests:
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors:
in Existence:
Sulfur in fuels-maximum
Emissions: average
Sampling
Purchases
Each Lot
Utility
Utility must maintain records which prove
compliance
Meet standard "on average" prior to permitting
Random
Utility, witnessed by state
Not required on existing plants
ICF
INCORPORATED
-------
2-15
State
Maine
Standards Established:
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors;
in Existence:
Effective Date of Regulations;
As per State - 5/7/79
Rev. 9/79
As Per EPA - 1979
Sulfur in fuel-maximum
Emissions - 2 hour average
Sampling
As purchased
Each fuel shipment
Suppliers
Central Maine Power does own fuels analysis
Must meet 2 hr. average for TSP - EPA Method 5
used.
Every 2 years
Utility, with State observation
None required
ICF
INCORPORATED
-------
2-16
State
Maryland
Standards Established;
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors;
In Existence:
Effective Date of Regulations:
As per State - 7//18/80
As Per EPA
Fuel: absolute maximum
Stack Tests: 1 hour average
Physical Sampling
Sent to State monthly
Utility
Three 60 minute samples.
Judgemental, depending on likelihood of SIP
violation
Utility
Opacity: Smith (11) , Wagner (1-3), and all units
at Morgantown, Dickerson, Crane, and Chalk Point
S02: All plants with 16/famBtu emissions limits
ICF
INCORPORATED
-------
2-17
State
Massachusetts
Standards Established;
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors;
In Existence:
Effective Date of Regulations;
As per State - 10/5/79
As Per EPA
Sulfur in fuel: maximum
Emissions: one hour
Physical Sampling
As Purchased
State
On facilities larger than 100 mmBtu per hour
Three tests for 60 minute intervals
Sporadic
Utility
Opacity - all units SO2 and NOX - none
ICF
INCORPORATED
-------
2-18
State
Michigan
Standards Established;
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests:
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors:
Effective Date of Regulations;
AS per State - 2/18/80
As Per EPA
Sulfur in fuel: maximum
Emissions: 1 hour average
Not specified
Not specified
Annual testing by state, more frequently by utility
State/utility or independent consultant
Meet 3 samples at full load; minimum sample time
60 minutes (EPA Methods 5(TSP), 6(803 & 7(NOX))
Not specified
Utility, with State observation
For NSPS plants and existing plants for: 1)
opacity, 2) SC>2, if FGD equipment is used; 3)
NOX, if 1000 mmBtu, is subject to a NOX
standard, and is determined by the EPA to require
a NOX control strategy
in Existence:
ICF
INCORPORATED
-------
2-19
State
Minnesota
Standards Established;
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors;
in Existence:
Effective Date of Regulations:
AS per State - 11/24/76
As Per EPA
1 hour average
Modified ATSM; blended sampling of coal
As burned for coal; from storage tank for oil
4 times daily for coal; daily for oil
Minnesota Pollution Control Agency
Coal - Monthly reporting
Oil - Quarterly reporting
Meet: - S02:
- TSP:
Each sample 20 minute minimum.
Mean of 2 30-minute samples
required
4 samples of 15-minutes each
Each run 60 minute minimum
(EPA Method: 5:TSP; 6:S02; 7:NOX)
Not specified
Utility or independent consultant, with State
observation
Required for NSPS plants: SC>2, NOX, Opacity
ICF
INCORPORATED
-------
2-20
State : Mississippi
Standards Established;
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors;
in Existence:
Effective Date of Regulations:
As per State - 1/78
As Per EPA - Unknown (Status;
Approved)
1 1/2 hour average
None required
Meet: 3 runs of 1 1/2 hr. minimum
Once every 3 years by State. More often by
utility.
Mississippi Air Enforcement/utility
Required for NSPS plants only: NOX, SO2 &
Opacity
ICF
INCORPORATED
-------
2-21
State
Missouri
Standards Established;
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors;
in Existence:
Effective Date of Regulations:
AS per State - 2/11/79-Particulate
3/11/78 - S02
As Per EPA - Unknown (Status:
Approved)
SO2: 3 hour average
TSP: 1 hour average
NOX: maximum
Composite sampling
As burned for coal
Not specified
Utility or independent consultant
Meet: 3 hr. average SO2; 1 hr. average TSP (EPA
Method 6 for S02; ASME Power Test Codes - PTC-27
for TSP
Not specified
Utilities/Independent Consultants
Required reporting semiannually
Required for NSPS plants only: S02, NOX &
opacity
ICF
INCORPORATED
-------
2-22
State
Montana
Standards Established;
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors:
In Existence:
Effective Date of Regulations:
AS per State - 4/79
As Per EPA - Unknown
(Status: Approved)
1 hour maximum (implied)
Sampling
Burn
Not specified
Utility
TSP - Meet standard with average of 3 runs
Not specified
Utility (through independent contractor)
Required on New Sources
Colstrip (opacity and 802)
Corette (opacity)
ICF
INCORPORATED
-------
2-23
State
Nebraska
Standards Established;
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors;
In Existence:
Effective Date of Regulations:
AS per State - 5/20/80
As Per EPA - 5/20/80
Sulfur/SC^: maximum
Particulate Emissions: 1 hour average
Sampling
Burn and purchases
Not specified
Utility
EPA Method 5 and Method 9
Monitored - 6 minute averages
Utility
Reuqired for opacity on all plants 250 mmBtu.
ICF
INCORPORATED
-------
2-24
State
Nevada
Standards Established;
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors;
In Existence:
Effective Date of Regulations:
As per State - 4/80
As Per EPA - Unknown
(Status: Approved
Except for Gardner)
SC>2 & TSP: 1 hour maximum
Not specified
Not specified
Yearly for SC>2» if coal-fired unit
Utility or independent consultant, observed by
State
Meet 1 hour maximum
Yearly for S02 in coal-fired units; yearly for
TSP
independent consultants; observed by State
Required for NSPS only: SC>2, NOX, & Opacity
ICF INCORPORATED
-------
2-25
State
New Hampshire
Standards Established;
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors;
In Existence:
Effective Date of Regulations:
AS per State - 4/20/74 TSP I
3/22/75 S02
As Per EPA - Unknown
Sulfur in fuel: Maximum and 3-month average (coal)
Emissions: 1 hour maximum
AS1M
As purchased for sulfur content
On each delivery
Supplier. May be spot tested by State
Fuel must meet percent sulfur standard before
entering state
Meet 1 hour maximum (TSP-EPA Method 5)
i
AS directed by State
Utility - may be observed by State
Required for NSPS only: NOX, S02 & Opacity
ICF
INCORPORATED
-------
2-26
State
New Jersey
Standards Established;
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors;
in Existence:
Effective Date of Regulations:
As per State - Sulfur-6/14/79,
9/15/78
Part. 10/12/77
As Per EPA - unknown
Sulfur in fuel - maximum; except for England plant.
Emissions: 1 hour maximum
Physical sampling
Monthly report - purchases; samples - burn
10-15 minutes
Utility
BL England: Standard deviation of 0.2% S permitted
from mean of 3.5%
AS requested by Dept. of Environmental Protection
Not required.
ICF
INCORPORATED
-------
2-27
State
: New Mexico
Standards Established:
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors;
In Existence:
Effective Date of Regulations:
AS per State - 12/15/78
11/16/79-Coal S02
As Per EPA - Unknown
S02: 1 hour average
Sulfur and heat content of fuels: daily average
TSP/NOX: 1 hour average
Oil
Physical sampling
Not specified
Sporadic
State
Quarterly reports of daily average sulfur content
(%) and heat content.
EPA Method 5. Minimum of 20 cubic feet per run.
Average of 3 runs.
At least once per year. (Four Corners does their
own, at least once per month.)
State
Quarterly reports of hourly SC-2 concentratons
Not required
San Juan - SC>2» opacity, NOX
ICF
INCORPORATED
-------
2-28
State : New York
Standards Established:
Fuels Analysis:
Method:
Purchases or Burn:
Effective Date of Regulations:
AS per State - 3/24/79
As Per EPA - Original-unknown
variances 3/80,
4/80,8/80
Sulfur in fuel: Maximum
SC>2 Emissions: Maximum and 30-day average
TSP: 1 hour average
Oil-composite sampling
coal- composite sampling or gross sampling
apportioned by calculation
Burn
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors!
In Existence:
Not Specified - at least by lot received
Utility
1) Monthly reporting of quarterly/weight of fuel
burned; sulfur content of samples exceeding
allowable; weighted average of sulfur or SO2 for
the month.
2) Sampling results must be reproducable by State
Continuous monitoring results may be substituted
for fuels analysis
Not required
ICF
INCORPORATED
-------
2-29
State
North Carolina
Standards Established;
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors;
In Existence:
Effective Date of Regulations:
AS per State - 6/1/80
As Per EPA - unknown
(Status: Approved)
One hour average
AS1M Method D2234; and D270
Dry Basis
Weekly reports to state
Utility
EPA Method 5 (3 one-hour runs)
Annually
Utility
Opacity: All CP & L Plants
Opacity: Belews Creek 1,2; Marshall 1-4; Allen
1-5; Cliffside 5
ICF
INCORPORATED
-------
2-30
State
North Dakota
Standards Established;
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors;
In Existence:
Effective Date of Regulations:
As per State - unknown
As Per EPA - Unknown
802: 20 minutes
TSP/NOX: 1 hour
Part: EPA Method 5 using 60 minute samples;
SC>2: Minimum of two twenty minute samples;
Arithmetic mean used.
At plant start-up NO repeats
Utility
Coal Creek: S02» NOX, opacity
Minnkota: S02» NOX, opacity
Leland Olds: SC^r N0x' opacity
All other units: opacity
ICF
INCORPORATED
-------
2-31
State
Ohio
Standards Established;
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors!
In Existence:
Effective Date of Regulations:
As per State - 11/14/79
As Per EPA - Not yet Approved
Continuous monitoring: daily calculations using
30-day arithmetic average.
Fuel analysis: arithmetic average of preceding
thirty consecutive twenty-four hour sample analyses
For Sulfur
Arithmetic average of preceding thirty consecutive
samples
Daily
independent lab
For Particulates
Three runs, one hour per run
At discretion of field officers.
three years.
Contractor hired by utility
usually one per
Most plants have opacity monitors. Only
Conesville has S02 monitors.
ICF
INCORPORATED
-------
2-32
State
Oklahoma
Standards Established;
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors:
In Existence:
Effective Date of Regulations:
AS per State - 4/1/78
As Per EPA
SC>2 and TSP: one hour average
Physical sampling
As purchased
Done with initial purchase
Utility, reported to State
S02t Part: 3 consecutive 60 minute tests
NOX: 12 grab samples over 15 minutes
When plant goes on line, NSPS plants must retest
regularly
Utility
Must be installed to record S02/ except for
gaseous fuel containing less than 0.1 percent
sulfur.
NSPS plants must have NOX and opacity monitors
as well.
NSPS Plants:
Sooner
Muskogee
Ponca City
Oolagah
ICF
INCORPORATED
-------
2-33
State
Oregon
Standards Established;
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors;
In Existence:
Effective Date of Regulations:
AS per State - 3/1/72
Rev.1/14/80
As Per EPA - 1972
Absolute limits
Boardman Only
Sampling for S02 and Ash
Purchases (Trainloads) and burn
On arrival at plant; weekly at least for burn
Utility
None
2 out of 2 tests for existing/3 out of 3 for NSPS
in permit - TSP quarterly, S02 continuous
Utility or consulting firm
Annual on NOX & 00
Only required on new sources.
Boardman
ICF
INCORPORATED
-------
2-34
State : Pennnsylvania
Standards Established:
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors;
In Existence:
Effective Date of Regulations:
AS per State - 8/29/77
As Per EPA - unknown
Sulfur in fuel - maximum
SC>2 Emissions: daily maximum, daily average,
monthly average
TSP Emissions: Not Specified
Sampling
Burn (from tank or conveyor)
Not specified
State - laboratories in Norristown and Harrisburg
Meet standard within 10 percent in one-hour test
Not specified
State team or utility
Required on all plants by 2/1/81.
Pennsylvania Electric plants - submit monthly
reports of daily averages.
ICF INCORPORATED
-------
2r-35
State
Rhode Island
Standards Established;
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors:
In Existence:
Effective Date of Regulations:
AS per State - 9/79
As Per EPA - Unknown
Sulfur in fuel: maximum
Sampling at Rhode island Ports
As Purchased
Ra ndom
State inspectors
Not required
Periodic
Consulting firm hired by utility/monitored by State
(20% opacity standard determines if testing should
be done)
None in State
ICF
INCORPORATED
-------
2-36
State
South Carolina
Standards Established;
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors;
in Existence:
Effective Date of Regulations:
AS per State - 5/29/78
Rev. 10/79
AS Per EPA - unknown
(Status: Approved)
SC>2 & TSP: 1 hour maximum
None required
Not specified (EPA Methods 5 (TSP) & 6 (S02))
Every two years
Utility, with State observation
Opacity emissions reported quarterly
Required for NSPS plants: Opacity, S02 & NOX
and 1) opacity for oil & coal-fired units.
ICF
INCORPORATED
-------
2-37
State
South Dakota
Standards Established;
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors;
In Existence:
Effective Date of Regulations:
As per State - 7/28/80
AS Per EPA - Not Approved yet
Maximum
Not Required
Do not exceed standards
At time of permitting; at State's request
thereafter
Utility (Contractors)
Not required on existing plants
ICF
INCORPORATED
-------
2-38
State
Tennessee
Standards Established;
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors;
In Existence:
Effective Date of Regulations;
AS per State - 12/6/79
As Per EPA - Unknown
One hour average
Not required
Particulates: 3-60 minute samples '
S02i 2-20 minute samples taken at 30 minute
intervals. Three sets required. Utility (for own
check) then does 1-35 minute sample
NOX: 4 grab samples taken at 15 minute intervals.
Utility, state observes
Continuous Minotors at each plantJ/
Plant
Allen
Bull Run
Cumberland
Gallatin
John Sevier
Johnsonville
(Units 7-10)
Kingston
Walter Bar
;o2
3
4
2
2
2
4
2
2
Opacity
3
4
2
2
2
4
2
2
°2
3
4
2
2
2
4
2
2
I/ usually one per stack
ICF
INCORPORATED
-------
2-39
State
Texas
Standards Established;
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors;
In Existence:
Effective Date of Regulations:
As per State - May 6, 1979
As Per EPA - unknown
TSP & NOX: Two hour average
SC>: 30 minute average
Physical Sampling
N/A
Sporadically
Utilities
EPA Method 5 (3 runs)
Done before coal unit comes on line. Sporadic
otherwise
Utility with state observers initially, state
subsequently
Only done on coal units.
Harrington: Opacity, S02» NOX
Fayette - Opacity, S02» NOX
ICF
INCORPORATED
-------
2-40
State
Utah
Standards Established;
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors;
In Existence:
Effective Date of Regulations:
As per State - 2/80 - Rev.
As Per EPA - unknown
One hour average
Not required
EPA Method 5.
Within 6 months of start-up. At least once every
five years (possibly more required thereafter).
Utility or Contractor hired by utility. State
observes.
Required for opacity, required for S02 on
scrubbed sources
Huntington and Hunter
ICF
INCORPORATED
-------
2-41
State
Vermont
Standards Established;
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors;
In Existence:
Effective Date of Regulations:
As per State - 11/4/79
As Per EPA - Unknown
Sulfur in fuel: absolute maximum
Particulates: per hour
As purchased
With each shipment of coal
Utility. State examines results sporadically.
EPA Method 5. Three sixty minute tests.
Not routine. When there is a suspicion of a SIP
violation
Utility
Not required
None
ICF
INCORPORATED
-------
2-42
State
Virginia
Standards Established;
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors;
In Existence:
Effective Date of Regulations:
As per State - 11/30/79
AS Per EPA
1 hour average
Not required
3 runs required, using EPA Methods 5(TSP) &
6(S02)
Meet: Arithmetic mean of 3 used for compliance
check
Undefined
Utility, or by State if plant found out of
compliance
Quarterly reporting required.
Required for NSPS plants: Opacity, S02 & NOX
ICF
INCORPORATED
-------
2-43
State
: Washington
Standards Established;
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors;
In Existence:
Effective Date of Regulations:
As per State - unknown
As Per EPA - Unknown
Opacity: limit may not be exceeded for more than
fifteen minutes out of any eight hour period
State examines results periodically
Contractor hired by utility
EPA Method 5.
Annually at Centralia. Less frequently at
Shuffleton.
Utility for Centralia, Contractor for Shuffleton.
Centralia: Opacity
ICF
INCORPORATED
-------
2-44
State
: West Virginia
Standards Established;
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors;
in Existence:
Effective Date of Regulations:
AS per State - 9/1/74
As Per EPA - unknown
(Status: Approved)
S02' 24-hour average
TSP: 7 day average
Not specified
Not specified
AS required by the Director of the W. VA. Air
Pollution Control Commission
Utility
Monthly reporting of fuel data required
Meet for TSP: 3 runs of 4 samples each over a
7-day period required.
For S02: Continuous 24-hr, averaging time. May
exceed limit by 10% once each month.
undefined
Utility with State observation & spot tests
Not required
ICF
INCORPORATED
-------
2-45
State
Wisconsin
Standards Established;
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors;
In Existence:
Effective Date of Regulations:
AS per State - Jan., 1980
As Per EPA - unknown
Not specified in SIP
Not specified
AS purchased
Not specified
Utility
Annual Reports
EPA Method 5. Three two hour tests. Ambient
readings taken in area.
Coal plants at start-up. Possibly later on as well
Utility
Columbia #2: S02» NOX, opacity
Pulliam: opacity
ICF
INCORPORATED
-------
2-46
State
Wyoming
Standards Established;
Fuels Analysis;
Method:
Purchases or Burn:
Frequency:
Conducted by:
Requirements:
Stack Tests;
Compliance:
Frequency:
Conducted by:
Requirements:
Continuous Monitors:
in Existence:
Effective Date of Regulations:
AS per State - 1/25/79
As Per EPA - Uknown
S02 & TSP: 2 hour average
Not required
EPA Method 6
Judgmental, depends on likelihood of violation
May be by state, utility, or contractor
All existing coal units must monitor stack gas
opacity NSPS units monitor SC>2» particulates,
and NOX.
ICF
INCORPORATED
------- |