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APPENDIX C
DOCUMENTATION OF THE COMPUTER ROUTINE USED
FOR THE MAINE POINT SOURCE INVENTORY
As described in Section 3, one "generic" problem with the Maine point
source inventory was resolved using a computer routine. Specifically, the
year of record for the point source data was originally reported as 1980,
although the inventory actually reflects 1979 data. The routine used to
perform this correction is provided as follows.
102
-------
TABLE C-l. DOCUMENTATION OF THE COMPUTER ROUTINE USED
FOR THE MAINE POINT SOURCE INVENTORY
00000020 /*JCBPAR« LINCS=20
00000030 //FIX79 EXEC GCAEZT1
OOOC0040 //FILES DD DSN=il ft INE»UNITsSYSDA.DISP =< .PASS > .
OOOOOC5C '// OCB=(RE.CFK=FB.LRECL=80.BLKSIZE = 8000> t
OCOOCCEC // SPACE=.RLSE>
OC-CCCC70 //NECS DO UNI T=TAPE 16,VOL = « .RETAIN.SER= GCA3P9>»
00000060 // LABEL = (2«fcLPI»DISP=OLD,
OOOOOOSO // DCB=CHECFM=FB,LRECL=80.BLKSIZE=1600>
00000100 FILE NEDS
0000011C YP1 20 2 N YR2*6 16 2 N CD'TYP 80 1 N
OOOOC120
OOOOC130
00000110
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000001-70
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IF CD*TYP EQ 1 AND YR1 NO 79
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CCLNT = CCUNT * 1
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IF CC*TYP NO 1 AND YR2*6 NQ
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CCLNT = COUNT * 1
THEN
79 THEN
9000C22C IF FILE EQ FILE
00000230 URITC
000002*0 FINALS COUNT
00000250 //CCFY EXEC PG^=IEEGENEP,COND=(4.LT)
0000026C //SYSIN DO DU^HY
OOOOC27C //SYSPRINT 3D SYSCUT=A
0000026C //SYSUT1 DO OSN = *&KAINE, DISP= «OIiP = (NE»,KE£P) •
0000031C II DCB=(RECFM=FB«LRECL=80.aLKSIZE=1600)
103
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APPENDIX D
METHOD FOR ESTIMATING EXHAUST GAS FLOW RATE
FROM FOSSIL-FUEL FIRED BOILERS
The exhaust gas, or flue gas, flow rate from boilers can be estimated by
calculating the theoretical flow rate. Calculation of the theoretical flow
rate requires assumption of various fuel and boiler values. The procedure
presented here requires that only the boiler size, in Btu/hr, or the maximum
fuel firing rate, and the fuel type be known. However, if additional data are
available, they can be used in place of assumed values as will be explained.
In general, the fuel firing rate is multiplied by the stoichiometric
(theoretical) air requirement. This theoretical amount of air is then
multiplied by an excess air factor that is determined based on the fuel type
and the boiler type. The resulting air flow is adjusted to reflect stack
temperature and this adjusted air flow is assumed representative of actual
conditions.
STEP 1. DETERMINE TYPE AND FIRING RATE OF FUEL
If the type of fuel is not known, the calculations can not be accurately
performed. The fuel firing rate may be known if the fuel type is known. If
the fuel firing rate is not known, it can be calculated from the boiler size
by dividing the boiler size by the heating value of the fuel type. If the
heating value is not known, the values in Table D-l can be used. If the type
of fuel can not be reasonably guessed when not known, or when neither the
boiler size nor the fuel rate are known, the calculation can not be performed.
STEP 2. DETERMINE STOICHIOMETRIC AIR FLOW
Multiply the fuel rate by the appropriate air rates from Table D-2 for
the fuel type in question and obtain the theoretical air flow.
STEP 3. ADJUST AIR FLOW FOR EXCESS AIR
For the fuel and furnace type in question, obtain a typical excess air
rate from Table D-3. Multiply the air flow from Step 2 by the excess air
factor (i.e., 20 percent excess air = excess air factor of 1.2).
104
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TABLE D-l. TYPICAL GRAVITY AND HEATING VALUE OF STANDARD
GRADES OF FUEL OILS*
Grade
no.
1
2
4
5L
5H
6
Gravity
API
38-45
30-38
20-28
17-22
14-18
8-15
Weight,
Ib/gallon
6.675-6.95
6.960-7.296
7.396-7.787
7.686-7.94
7.89 -8.08
8.053-8.488
Heating value
BTU/gallon
132,000-137,000
137,000-141,000
143,100-148,000
146,800-150,000
149,400-152,000
151,300-155,900
*Source: Lindeburg, Michael R., P.E.
Engineering Review Manual.
Mechanical
Professional
Engineering Registration Program, San
Carlos, CA 94070. Fifth Edition, I960.
TABLE D-2. APPROXIMATE STOICHIOMETRIC AIR REQUIREMENTS*
Solid fuels
Fuel oils
Gaseous fuels
Anthracite
Semi-bituminous
Bituminous
Lignite
Coke
No. 1
No. 2
No. 5
No. 6
Natural
Mixed
Manufactured
Propane
Butane
9.6 Ibs air/lb fuel
11.2
10.3
6.2
11.2
102.6 Ibs air/gallon fuel
105.5
112.0
-114.2
10.0 ft3 air/ft3 fuel
8.0
4.7
23.8
31.0
*Source: Lindeburg, Michael R., P.E. Mechanical Engineering
Review Manual. Professional Engineering Registration
Program, San Carlos, CA 94070. Fifth Edition, 1980.
105
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TABLE D-3. USUAL AMOUNT OF EXCESS AIR SUPPLIED TO FUEL EQUIPMENT*
Fuel
Type of furnace or burners
Excess air,
% by weight
Pulverized coal
Crushed coal
Coal
Fuel oil
Acid sludge
Natural, coke-
oven and
refinery gas
Blast furnace gas
Completely water-cooled furnace for 15-20
slag-tap or dry-ash-removal
Partially water-cooled furnace for 15-20
dry-ash removal
Cyclone furnace—pressure or suction 10-15
Stoker-fired, forced-draft, chain grate 15-50
Stoker-fired, forced-draft, underfeed 20-50
Stoker-fired, natural-draft 50-65
Oil burners, register-type 5-10
Multiple burners and flat-flame 10-20
Cone and flat-type burners, steam 10-15
Register-type 5-10
Multifuel burners 7-12
Dutch-oven (10-23% through grates) 20-25
and Hofft-type
*Source: Lindeburg, Michael R., P.E. Mechanical Engineering Review
Manual. Professional Engineering Registration Program,
San Carlos, CA 94070. Fifth Edition, 1980.
106
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STEP 4. CONVERT AIR FLOW RATE TO UNITS OF FT3/HR (solid and liquid fuel
only)
The calculations in Steps 2 and 3 yield an air flow rate at 70°F and 1
atm. p'ressure in units of Ibs/hr. There are 13.35 ft3 of air/lb of air at
70°F and 1 atra. Therefore, multiply the air flow from Step 3 by 13.35.
STEP 5. ADJUST STANDARD AIR FLOW FOR STACK TEMPERATURE
For this step it is necessary to know the temperature of the gases in the
boiler stack. If this is not known, a temperature between 300°F and 400°F can
be reasonably assumed. Calculate the ratio:
absolute stack temperature _ 460 + stack temperature
absolute standard temperature 460 + 70
and multiply the air flow from Step 4 by the value of this ratio to obtain the
estimated exhaust gas rate.
Standardized Formulae
The overall calculation described by the above steps can be represented
by a formula for each of the fuel types as follows:
Coal:
tons 2000 Ibs 13.35 ft3 460 +
fuel Ibs fuel air (excess air air stk. temp. _ ft air , .*
hr X ton fuel X Ib fuel X factor) X Ib air X 460 + 70 hr ^
Oil:
gallons Ibs 13.35-ft 460 +
fuel air (excess air air stk. temp. ft air ( _.
hr gallon factor) x Ib air x 460 + 70 hr ^ '
fuel
Gas:
33 46° + 3
ft fuel ft, air (excess air stk. temp. ft air , ~.
hr X ftJ fuel X factor) X 460 + 70 hr ^D"JJ
The information available in NEDS did not allow a precise estimate of
excess air. Therefore, after scrutiny of Table D-3, GCA was able to
reasonably assume the following:
107
-------
Assumed Excess air
Fuel type excess air factor
Coal 40% 1.40
Oil 15% 1.15
Gas 10% 1.10
Then, by substituting the assumed excess air factors into the appropriate
equations, converting hours to minutes, and combining constants, a set of
standardized formulae were obtained. These formula could be used to calculate
a "default" stack flow rate for those cases when the fuel type, boiler size or
fuel rate, and stack temperature were known. If the stack temperature was not
known, a value of 350°F was assumed.
The development of the standardized formula for anthracite coal-fired
boilers is shown below. All the standardized formulae developed and used to
calculate "default" air flows are presented in Table D-4.
Standardized formula for anthracite coal-fired boilers:
From Table D-2: 9.6 Ibs air/lb fuel
excess air factor: 1.40
substituting into equation D-l:
tons 2000 9.6 Ibs 1^.35 460 + stk. 3
fuel Ibs air 1.4 ft air temp., °F 1 hr _ ft air
hr ton X Ib fuel * * Ib air X 460 + 70°F X 60 min = min
(2000X9^)11.^(13^5) (46Q + stk temp< OF) tons fuel _ ft3 air
(530) (60) A """ ou*- 1-cmi" "' * hr
3
(11.285) x (460 + stack temp., °F) x (tons coal/hr) = ft .air
min
108
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TABLE D-4. DEFAULT EXHAUST FLOW CALCULATIONS*
Coal (assumes 40% excess air)
Anthracite:
Semi-bituminous & coke:
Bituminous:
Lignite:
(11.285)(460 + stack temp.
(13.165)(460 + stack temp.
(12.107X460 + stack temp.
(7. 288) (460 + stack temp.
"FKtons coal/nr)
°F)(tons coal/hr)
°F)(tons coal/hr)
°F)(tons coal/hr)
Fuel Oil (assumes 15% excess air)
#2 oil:
#4 oil:
#6 oil:
#5 oil:
(5.093 x 10~2) (460
(5.250 x 10~2) (460
stack temp.
+ stack temp.
(5.513 x 10~2)(460 + stack temp.
'F) (gallons oil/hr)
'F)(gallons oil/hr)
'F) (gallons oil/hr)
(5.407 x 10"2)(460 + stack temp. °F)(gallons oil/hr)
Natural Gas (assumes 10% excess air)
(3.459 x 10~4)(460 + stack temp. °F)(ft3 gas/hr)
*Source: GCA Calculations, 1981.
109
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TECHNICAL REPORT DATA
(Please read Instructions on the reverse before completing)
1. REPORT NO.
EPA-450/4-82-013d
2.
3. RECIPIENT'S ACCESSION NO.
4. TITLE AND SUBTITLE
Northeast Corridor Regional Modeling Project Annual
Emission Inventory Compilation and Formatting
Volume IV: Maine Emission Inventory
5. REPORT DATE
September 1982
6. PERFORMING ORGANIZATION CODE
7. AUTHOR(S)
Frederick M. Sellars, Michael J. Geraghty, Andrea M.
Kiddie, Barbara J. Bosy, Stephen V. Capone, LisaA. Bac:
8. PERFORMING ORGANIZATION REPORT NO.
GCA-TR-82-17-G(4)
9. PERFORMING ORGANIZATION NAME AND ADDRESS
GCA/Technology Division
213 Burlington Road
Bedford, Massachusetts 01730
10. PROGRAM ELEMENT NO.
11. CONTRACT/GRANT NO.
68-02-3510, Work
Assignment No. 5
12. SPONSORING AGENCY NAME AND ADDRESS
U.S. Environmental Protection Agency, Air Management
Technology Branch, Monitoring and Data Analysis
Division, Office of Air Quality Planning and Standards.
Research Triangle Park. North Carolina 27711
13. TYPE OF REPORT AND PERIOD COVERED
Final
14. SPONSORING AGENCY CODE
15. SUPPLEMENTARY NOTES
EPA Project Officers: James H. Southerland and Thomas F. Lahre
16. ABSTRACT
This report discusses the development of the Northeast Corridor Regional
Modeling Project (NECRMP) annual regional emission inventory. The inventory
reflects 1979/1980 data and focuses on point, area and mobile source emissions of
Volatile Organic Compounds (VOC) and Nitrogen Oxides (NOX), although particulate,
sulfur oxides and carbon monoxide emissions were also compiled for point sources.
The study area includes the entire northeast quadrant of the United States from
longitude 69° to 82° West, and latitude 38° to 45° North. This Volume discusses
the emission inventory for Maine.
17.
KEY WORDS AND DOCUMENT ANALYSIS
DESCRIPTORS
b.lDENTIFIERS/OPEN ENDED TERMS
c. COS AT I Field/Group
Emission Inventory
Inventory
Source Inventory
Point Sources
Area Sources
Ozone
Nitrogen Oxides
Volatile Organic Compounds
18. DISTRIBUTION STATEMENT
19. SECURITY CLASS (ThisReport)
Unclassified
21. NO. OF PAGES
114
20. SECURITY CLASS (This page)
Unclassified
22. PRICE
EPA Form 2220-1 (Rev. 4-77)
PREVIOUS EDITION IS OBSOLETE
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