EPA430-R-92-004
THE ADJUNCT DATA FILE
TECHNICAL SUPPORT DOCUMENT
Prepared for:
U.S. Environmental Protection Agency
Office of Atmospheric and indoor Air Programs
Washington, DC 20460
Prepared by:
Susan S. Rothschild
E.H. Pechan & Associates, Inc.
May 1992
Printed on Recycled Paper
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NOTICE '
This document has been reviewed by the Acid Rain Division, Office of Atmospheric and
Indoor Air Programs, U.S. Environmental Protection Agency, and approved for
distribution.
This document is available to the public through the Acid Rain Division, Office of
Atmospheric and Indoor Air Programs, U.S. Environmental Protection Agency.
11
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CONTENTS
Notices ii
Tables iv
Abbreviations and Symbols v
1. Introduction 1
2. Description of Data Elements 3
References 11
Appendix A: dBASE III Plus ADF File Structure A-l
111
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TABLES
Number Page
1 ADF Variable List ... 10
IV
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ABBREVIATIONS AND SYMBOLS
\DF - Adjunct Data File
bbl -Barrel
Btu - British thermal unit
CAA - Clean Air Act
CFR - Code of Federal Regulations
DOE - Department of Energy
EIA Energy Information Administration
EPA ~ U.S. Environmental Protection Agency
GWh - Gigawatt hour
kW - Kilowatt
kWh - Kilowatt hour
Ibs - Pounds
MMBtu - Million Btu
MW - Megawatt
NADB - National Allowance Data Base
NERC North American Electric Reliability Council
NSPS - New Source Performance Standards
PC Personal (micro)computer
Pechan - E.H. Pechan & Associates, Inc.
ppm Parts per million
QF Qualifying facilities
RNSPS Revised New Source Performance Standards
SAS Statistical Analysis System
SDF - Supplemental Data File
SIP - State Implementation Plan
SO2 - Sulfur dioxide
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.VI
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SECTION 1
INTRODUCTION
Section 402 of the Clean Air Act (CAA) defines a utility unit as a "fossil-fuel
combustion device." Although most of the utility units are associated with traditional
electric utilities (and are therefore included in the National Allowance Data Base (NADB)
Version 2.1), there are several that are associated with nontraditional utilities.
The Department of Energy's (DOE) Energy Information Administration (EIA) has
identified several possible utility units that are not included in the NADB. These units
were identified from Form EIA-867 (EIA, 1990), which includes units not operated by
traditional electric utilities.
Utility units from nontraditional utilities that filed Form EIA-867 are included in this
data base. These are generating turbines (generators) that are owned by a nontraditional
utility that potentially sell electricity to an electric utility and are greater than 25 MW.
Specifically, the following unit categories are included in the Adjunct Data File (ADF):
Existing units (on-line prior to November 15,1990), new units (on-line
after November 15,1990), and planned fossil-fuel steam units (not on-
line as of December 31,1991).
New and planned simple combustion units (including gas turbines
and internal combustion units).
New and planned cogenerators that are greater than 25 MW and can
potentially sell generation to a utility.
Represented in this data base are 793 generating unit records from 475 plants. Not
all ADF utility units are necessarily affected, but they are potentially affected. There are
38 fields (variables, or data elements). The data are sorted by State name, plant name,
boiler ID, and generator ID, and are assigned a unique sequence number beginning with
3,837, the first number after the last NADB Version 2.1 sequence number.
The ADF is available in dBASE in Plus PC format, as well as on the IBM mainframe
in Statistical Analysis System (SAS) format.
The data from Form EIA-867 are confidential. EPA is publishing the ADF for public
comment and review. It will be announced in a Spring 1992 Federal Register notice.
Once the rules are finalized, EPA will allocate allowances using the available data in the
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ADF based on the determinations of applicability. If sufficient data are unavailable for a
unit, no allowances will be allocated.
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SECTION 2
OF DATA ELEMENTS
The ADF contains 38 data elements, 9 of which have values that were extracted from
the 1990 Form EIA-867 (EIA, 1990). They have been grouped into five categories. The
first category - identification or fixed variables - includes variables numbered 1 through
11. The second category contains elements numbered 12 and 13, which relate to the
calculation of the 1985 actual S02 emission rate, and the third category includes data
elements numbered 14 through 18, which are associated with the determination of the
1985 allowable S02 emission rate. Elements numbered 19 through 34 fall into the fourth
category as EIA-supplied data. The fifth and last category includes the variables
numbered 35 through 38, which are each calculated from other elements in the data base.
Table 1 lists and summarizes these variables. The file structure of the PC version is
found in Appendix A.
Descriptions of each of the data elements appear below, although due to Form EIA-
867 confidentiality restrictions, only eight data elements (SEQNUM, STATNAM, PNAME,
GENID, UTILNAME, UCODE, EPARGN, and ORISPL) have values. Further informa-
tion may be found in the National Allowance Data Base Version 2.1 Technical Support
Document.
IDENTIFICATION OR FIXED VARIABLES
1. Sequence Number (SEQNUM) -
This field contains the record number, beginning with 3837 (the first integer after
the last SEQNUM for the NADB Version 2.1), which is assigned after the data
file has been sorted by State name, plant name, boiler ID, and generator ID.
2. State Name (STATNAM) -
This field contains the name of the State where the plant is located.
3. Plant Name (PNAME) -
The name associated with each plant (facility), as reported on Form EIA-867, is
contained in this field.
4. Boiler Identification Code (BLRID) -
This code identifies the boiler. Since none of the units have a known assigned
boiler ID code, a default value of two asterisks followed by the GENID is used.
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5. Generator Identification Code (GENID) -
This code identifies the generator or turbine. The source of the generator ID code
is Form EIA-867.
6. Nontraditlonal Utility Name (UTILNAME) -
There is a utility name for every utility. The nontraditional utility name is
determined from Form EIA-867.
7. Nontraditional Utility Code (UCODE) -
Each nontraditional utility has a unique utility code, originating from Form EIA-
867, that is associated with UTILNAME.
8. EPA Region (EPARGN) -
This field contains the number of the EPA region in which the facility is located.
9. County Name (CNTYNAME) -
The field contains the county name.
10. Plant Code (ORISPL) -
This plant code is a unique plant identification code, assigned by Form EIA-867.
Note that ORISPL in the ADF has 5 digits, while ORISPL in the NADB has 4
digits.
11. Phase 1 Allowances (PHASE1AL) -
This field contains the Phase 1 allowances, in tons, that appear in Table A of the
CAA. Note that these values are not necessarily the final Phase 1 allocations.
1985 ACTUAL SO2 EMISSION RATE-RELATED VARIABLES
12. 1985 Boiler Total Heat Input (TOTHT) ~
Total heat input, in 1012 Btu, is the sum for 1985 of the products of the amount of
each fuel consumed and the associated heat content.
13. 1985 Boiler SO2 Emissions (SO2) -
This field contains the 1985 S02 emissions, in tons.
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1085 ALLOWABLE SO2 EMISSION RATE (LIMIT)-RELATED VARIABLES
14. Boiler SO2 Regulatory Category C9O2CATEG) -
The regulatory category determines the type of emission regulation the .unit must
meet. The plant may be regulated under one of the following:
The State Implementation Plan (SIP), meaning that State or local
regulations are binding (=1);
The New Source Performance Standards (NSPS), 40 Code of Federal
Regulations (CFR) Part 60, subpart D (=2);
The revised NSPS (RNSPS), 40 CFR Part 60, subpart Da (=3);
The NSPS, 40 CFR Part 60, subpart GG (=4);
The SIP for the existing gas turbine, combined cycle, with auxiliary
firing (=6); or
The NSPS, 40 CFR Part 60, subpart GG for the existing gas turbine,
combined cycle, with auxiliary firing (=9).
15. Boiler SO2 Scrubber Flag (SCRUBBER) -
This field indicates whether the boiler was scrubbed (=1) or unscrubbed (=0) in
1985. Units that showed a zero percent S02 removal efficiency were assumed to
be unscrubbed.
16. 1985 Boiler SO2 Emission Limit (FELIM85) -
This field is the federally enforceable S02 emission limit (rounded to four decimal
places) that applied to each boiler in 1985; it has been converted to pounds of SO2
per million Btu of heat input (Ibs/MMBtu). For units with more than one limit,
the most stringent federally enforceable limit is used. For newer units subject to
NSPS, and those that came on-line after 1985, the federally permitted limit is
used. For units with no federally enforceable limit, a code of 99.9 is used.
17. 1985 SO2 Emission Limit Annualization Factor (ANNFACT) -
This field is the annualization factor that, when multiplied by the SO2 emissions
limit (FELIM85), produces the annualized SO2 emission limit (ANNLJM85).
18. 1985 SO2 Emission Limit Averaging Period (AVGPD) -
This field contains 1 of 18 codes indicating the averaging period or time over
which the emission limit is applied.
EIA-SUPPLIED VARIABLES
19. 1989 Generator Nameplate Capacity (NAMEPCAP) -
This field contains the 1989 nameplate capacity of the generator, in MW and
rounded to two decimal places.
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20. 1989 Generator Summer Net Dependable Capability (SUMNDCAP) -
This field contains the 1989 summer net dependable capability of the generator,
in MW and rounded to two decimal places. If a value is not available, the default
value is NAMEPCAP.
21. Generator Month On-line (GENMNONL) -
This data value is the month portion of the generator startup date. For existing
units, this is the first electricity date. For units that have been repowered, it is
the repowered generator startup date. For planned units, it is the projected first
electricity date.
22. Generator Year On-line (GENYRONL) -
This data value is the year portion of the generator on-line date. See
GENMNONL for further details.
23. Boiler Month On-line (BLRMNONL) -
The boiler on-line month is the month portion of the boiler on-line date.
For units from plants of at least 100 MW and with a generator first electricity on-
line date between 1984 and 1989, the boiler on-line date is the generator first
positive generation date.
For units with a generator first electricity on-line date prior to 1984 or from
plants with less than 100 MW, the boiler on-line date is the generator first
electricity date.
For units with future on-line dates of 1990 and beyond, the boiler on-line date is
the projected generator first electricity date.
There are, however, a few exceptions.
24. Boiler Year On-line (BLRYRONL) -
The boiler on-line year is the year portion of the boiler on-line date. See
BLRMNONL for further details.
25. 1985-1987 Boiler-generator Average Total Heat Input, "Baseline"
(BASE8587) -
The average total heat input (also called "baseline"), in 1012 Btu, is the arithmetic
mean of the calculated heat inputs for all 1985 through 1987 reported fuels.
If there was no fuel consumption for any of the three years, the baseline value is
0. Note that outage hours do not affect the numerical value contained in this
field.
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26. Consecutive Planned and Forced Outage Hours (OUTAGEHR) -
This field represents the number of continuous hours (with a 2,920-hour
minimum) a unit was out of service between 1985 and 1987 due to a planned or
forced outage. . ...
The North American Electric Reliability Council (NERC) defines a planned
outage as "the removal of a unit from service to perform work on specific
components that is scheduled well in advance and has a predetermined duration
(e.g., annual overhaul, inspections, testing)." It defines a forced outage as "an
unplanned component failure (immediate, delayed, postponed, startup failure) or
other condition that requires the unit be removed from service immediately or
before the next weekend" (NERC.1990).
If there were individual outages each totaling less than four months (2,920 hours)
during 1985-1987, the value is 0.
27. Primary Fuel Indicator (PRIMFUEL) -
This field, for those units with fuel use, has a value of 1 if the coal heat input is
greater than 50 percent of the total heat input for the years 1985 through 1987,
and a value of 2 otherwise (for oil/gas units).
28. 1980-1989 Gas Share (GAS8089) -
This value, calculated from 1980 through 1989 data for oil/gas units on-line
during the period from 1985 to 1987, is the percentage of gas consumed by each
boiler during this time period. The equation used is:
GAS8089=100*(1980-1989gas heat input)/(1980-1989 total heat input).
The value is 0 for coal units (those with a greater than 50 percent share) on-line
during the period from 1985 to 1987.
29. 1989 Generator Heat Rate (HEATRATE) -
The generator heat rate value, in Btu/kWh, is the net full load heat rate reported
for each generator.
30. 1985 Generator Generation (GENER) -
This field contains the generator generation for 1985, in GWh.
31. Total Capacity of the Fossil-steam Units of the Operating Utility
(UCAPFSST) -
This field is the sum, in MW, of the capacity of all the fossil-fuel steam units
operated by the operating utility of the particular unit in 1989. In a few cases,
this value is 0 because all of the utility's units retired before 1989 or had not
come on-line by 1989. In addition, if the capacity was less than 500 kW, this
field value was set to 0.
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32. Maximum of the Average Heat Inputs for Any Combination of Three
Consecutive Years from 1980-1989 (MXBS8089) -
This heat input data element (also called "maximum heat baseline"), in 1012 Btu,
is the maximum of the average heat inputs for every combination of three
consecutive years reported between 1980 and 1989. It is calculated similarly to .
BASE8587, but only for units subject to §405(0 of the CAA; the value is 0
otherwise.
33. Representative Year SO2 Emission Rate (RY.ER) -
The representative year S02 emission rate, in Ibs/MMBtu and rounded to four
decimal places, is nonzero only for those cases in which there is a positive
baseline (either BASE8587 or MXBS8089) value, but no 1985 emission rate.
This field is assigned the 1985 (or 1986 or 1987) S02 emission rate.
If a unit has a positive baseline value, a S02RTE value of 0, EIA emission rates
that are calculated to be 0, and is more than 90 percent gas for either the 1980 to
1989 (GAS8089>90) or 1985 time period, then this field is assigned a default
value of .0006, based on the AP-42 factor for natural gas. A utility may have
requested, during the comment period, use of an alternate year's rate.
34. Municipally Operated Flag (FLAGMUNI) -
If an operating utility is municipally owned, this field has a value of 1, and 0
otherwise.
CALCULATED VARIABLES
35. 1985 Boiler SO2 Emission Rate (SO2RTE) -
The actual SO2 emission rate, in Ibs/MMBtu and rounded to four decimal places,
is calculated from the boiler S02 emissions (tons) in 1985 and the boiler total
heat input of fuels burned (1012 Btu) in 1985. The equation used is:
SO2RTE=(2*SO2)/(1000*TOTHT).
36. 1985 Annualized Boiler SO2 Emission Limit (ANNLIM85) -
The "allowable 1985 S02 emission rate," in Ibs/MMBtu and rounded to four
decimal places, is defined in the CAA as an annual equivalent 802 emission limit.
ANNLIM85 is calculated using the equation:
ANNLIM85=ANNFACT*FELIM85.
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37. Generator Heat Input at 60 Percent Capacity (HT60) -
This field, in 1012 Btu, is calculated using the formula as shown, where 5,256 is a
conversion factor (60 percent of 8,760 brs/yr):
HT60~(HEATRATE*SUMNDCAP*5256)/1CP.
The net summer capability is used because the nameplate capacity for many
units is not a good measure of the maximum MW a generator can produce. Most
planners use a measure of dependable capacity such as net dependable summer
capability*
38. Boiler-generator Share of Generator Heat Input at 60 Percent Capacity
(HT60SHR)-
This field, in 1012 Btu, is calculated from HT60 for multi-header units. For each
generator with multiple boilers, based on BASE8587, HT60 is apportioned among
the boilers. If the BASE8587 value is 0, HT60 is then shared equally among the
boilers. If there is a single boiler associated with a generator, HT60SHR is equal
toHT60.
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Table 1
ADF Variable List
Field
Number
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
Variable
Name
SEQNUM
STATNAM
PNAME
BLRID
GENID
UTILNAME
UCODE
EPARGN
CNTYNAME
ORISPL
PHASE1AL
TOTHT
SO2
SO2CATEG
SCRUBBER
FELIM85
ANNFACT
AVGPD
NAMEPCAP
SUMNDCAP
GENMNONL
GENYRONL
BLRMNONL
BLRYRONL
BASE8587
OUTAGEHR
PRIMFUEL
GAS8089
HEATRATE
GENER
UCAPFSST
MXBS8089
RY ER
FLAGMUNI
SO2RTE
ANNLIM85
HT60
HT60SHR
Description
Sequence number
State name
Plant name
Boiler identification code
Generator identification code
Nontraditional utility name
Nontraditional utility code
EPA region
County name
DOE ORIS plant code
Phase 1 allowances (tons) from Table A of the CAA
1985 boiler total heat input (fo12 Btu)
1985 boiler SO2 emissions (tons)
Boiler SO2 regulatory category (1=SIP, 2=NSPS D, 3«NSPS Da,
4=NSPS GG, 6-SIP for existing gas turbine, combined cycle,
with auxiliary firing, 9=NSPS GG for existing gas turbine,
combined cycle, with auxiliary firing)
Boiler SO2 scrubber flag (1 =yes, 0=no)
1985 boiler S02 emission limit (Ibs/MMBtu)
1985 SO2 emission limit annualization factor
1985 SO2 emission limit averaging period
1989 generator nameplate capacity (MW)
1989 generator summer net dependable capability (MW)
Generator month on-line (first electricity)
Generator year on-line (first electricity)
Boiler month on-line
Boiler year on-line
1985-1987 boiler-generator average total heat input, "baseline"
(1012 Btu)
Consecutive planned and forced outage time during 1985-1987
> = 2,920 hours (hours) from GADS
Primary fuel indicator based on greatest fuel heat share during
1 985-1 987 (1 =coal > 50%, 2=oil/gas)
1980-1 989 gas share (%)
1989 generator full load heat rate (Btu/kWh)
1985 generator generation (GWh)
Total capacity of the fossil-steam units of the operating utility (MW)
Maximum of the average heat inputs for any combination of three
consecutive years from 1980-1989 for selected units (1012 Btu)
Representative year SO2 emission rate (Ibs/MMBtu)
Municipally operated flag (1 -yes, 0=no)
1985 boiler SO2 emission rate (Ibs/MMBtu)
1985 annualized boiler SO2 emission limit (Ibs/MMBtii)
Generator heat input at 60 percent capacity (1012 Btu) .
Boiler-generator share of generator heat input at 60 percent
capacity (1012 Btu)
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EIA, 1990: Energy Information Administration, "Annual Nonutility Power Producers
Report," Form EIA-867,1990.
NERC,,1990: North American Electric Reliability Council, Generating Availability Data
System, "Generating Availability Report: 1985-1989," August 1990.
Pechan, 1992: E.H. Pechan & Associates, Inc., "The National Allowance Data Base
Version 2.1: Technical Support Document," Contract No. 68-D9-0168, prepared for
EPA's Office of Atmospheric and Indoor Air Programs, May 1992.
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APPENDIX A
DBASE III PLUS ADF FILE STRUCTURE
(File: ADF.DBF)
Field Name
Type
Width
Description
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
SEQNUM
STATNAM
PNAME
BLRID
GENIO
UTILNAME-
UCODE
EPARGN
CNTYNAME
ORISPL
PHASE1AL
TOTHT
S02
SO2CATEG
SCRUBBER
FELIM85
ANNFACT
AVGPD
NAMEPCAP
SUMNDCAP
GENMNONL
GENYRONL
BLRMNONL
BLRYRONL
BASE8587
OUTAGEHR
PRIMFUEL
GAS8089
HEATRATE
GENER
UCAPFSST
MXBS8089
RY ER
FLAGMUNI
S02RTE
ANNLIM85
HT60
HT60SHR
Num
Char
Char
Char
Char
Char
Num
Num
Char
Num
Num
Num
Num
Num
Num
Num
Num
Num
Num
Num
Num
Num
Num
Num
Num
Num
Num
Num
Num
Num
Num
Num
Num
Num
Num
Num
Num
Num
4
20
20
6
4
30
5
2
20
5
9
11,6
10,2
2
1
8,4
4.2
2
7,2
7,2
2
4
2
4
11,6
6
1
7,3
8,2
8,2
8,2
11,6
8.4
1
8,4
8,4
11.6
11.6
Sequence number
State name
Plant name
Boiler ID
Generator ID
Nontraditional utility name
Nontraditional utility code
EPA region
County name
Plant code
Phase 1 allowances (tons) from Table A of the CAA
1985 boiler total heat input (1012 Btu) from NURF
1985 boiler S02 emissions (tons) from NURF
Boiler S02 regulatory category (0-no information, 1-SIP,
2-NSPS D, 3-NSPS Da, 4-NSPS GG, 6- SIP for existing ga
turbine, combined cycle, with auxiliary firing, 9-NSPS GG for
existing gas turbine, combined cycle, with auxiliary firing)
Boiler S02 scrubber flag (1-yes, 2-no, 9-no information)
1985 boiler SO2 emission limit (Ibs/MMBtu)
1985 SO2 emission limit annualization factor
1985 S02 emission limit averaging period (see
Technical Support Document)
1989 generator nameplate capacity (MW)
1989 generator summer net dependable capability (MW)
Generator month on-line (first electricity)
Generator year on-line (first electricity)
Boiler month on-line
Boiler year on-line
1985-1987 boiler-generator average total heat input,
baseline" (1012 Btu) from Form 767
Consecutive planned and forced outage tinrva during
1985-1987 > -2,920 hours (hours) from GADS
Primary fuel indicator based on greatest fuel
heat share during 1985-1987 (1 -coal>50%, 2-oil/gas)
1980-1 989 gas share (%)
1989 generator full load heat rate (Btu/kWh)
1985 generator-generation (GWh)
Total capacity of the fossil-steam units operated
by the operating utility (MW)
Maximum of the average heat inputs for any
combination of three consecutive years from
1980-1989 for selected units (10" Btu)
Representative year S02 emission rate (Ibs/iVIMBtu)
Municipally operated flag (1-yes, 0-no)
1985 boiler SO2 emission rate (Ibs/MMBtu)
1985 annualized boiler SO2 emission limit (Ibs/MMBtu)
Generator heat input at 60 percent capacity (1012 Btu)
Boiler-generator share of generator heat input at
60 percent capacity (1012 Btu)
A-l
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