REVISED EDR VERSION 2.2
REPORTING INSTRUCTIONS
Clean Air Markets Division
U.S. EPA
Washington, DC 20014
December 2005
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EDR v2.2 Instructions
December 2005
EDR VERSION 2.2
REPORTING INSTRUCTIONS
Table of Contents
Page
I. INTRODUCTION 1
II. GENERAL INSTRUCTIONS 2
A. EDR Record Structures 2
B. Quarterly Emissions File Organization and Ordering 4
(1) File Content 4
(2) Record Order 4
(3) Stack or Pipe Record Orders 5
(4) Record Order for Quality Assurance Data 5
C. General EDR Instructions 7
(1) Definition of Reporting Period 7
(2) Identification Numbers 7
(a) Facility/ORISPL Number 7
(b) Unit IDs 7
(c) Stack and Pipe IDs 8
(3) Data Entry and Editing of Quarterly Reports 10
(a) Emissions Data From CEMS 10
(b) Reference Method Backup Data 11
(c) Calibration and Linearity Data 11
(d) RATA Data 12
(e) Stack or Fuel Flow-to-load Ratio Test Data 12
(f) Appendix D Data 12
(g) Other Quality Assurance Data 13
(h) Calculated Emissions Values (e.g.. NOx Emission Rate in RT 320 or
Total S02 Quarterly Emissions in RT 301), Except For Units Using
Low Mass Emissions (LME) Methodology Under §75.19 13
(i) Missing Data 13
(j) Other Operating Data 14
(k) Data for Low Mass Emissions Units Under §75.19 14
(4) Use of Blank Spaces 14
(5) Reporting of Dates and Times 14
(6) Reporting in Standard Time 14
(7) Computational Requirements and Rounding 14
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EDR v2.2 Instructions
Table of Contents (cont.)
Page
(a) Computing Hourly Emissions Values 14
(b) Rounding Conventions for Reported Data 15
(c) Use of Reported Data for Emissions and QA Test Calculations 15
(d) QA Test Calculations 15
(8) Requirements for Component and System IDs 15
(9) Reporting Data Outside the Reporting Period 16
(10) Information on Non-operating Hours 16
(11) Blank Emissions or Other Values 16
(12) Missing Data and Percent Monitor Data Availability 16
(13) Data Reporting Requirements for Uncertified Units 17
(14) Data Reporting Requirements for Non-operating Quarters 18
III. RECORD TYPE INSTRUCTIONS 19
A. Facility Records 19
(1) RT 100: Facility Identification 19
(2) RT 101: Record Types Submitted (Optional) 19
(3) RT 102: Facility Location and Identification Information 24
B. Hourly Emissions and Quality Assurance Records and Emissions Summary
Records (RTs 200+ through 300+) 25
(1) RT 200: S02 Concentration Data (ARP) 25
(2) RT201: NOx Concentration Data 29
(3) RT 202: C02 Concentration Data (ARP) 36
(4) RT 210: C02 Diluent Concentration Data 39
(5) RT211: 02 Diluent Concentration Data 42
(6) RT 212: Moisture Data 49
(7) RT 220: Volumetric Flow Data 51
(8) RT 230: Daily Calibration Test Data and Results 53
(9) RT231: Flow Daily Interference Check Results 55
(10) RTs 260 Through 262: Reference Method Backup Quality Assurance Data .... 55
(11) RT 300: Unit Operating Parameters 56
(12) RT301: Quarterly Cumulative Emissions Data (ARP) 61
(13) RT 302: Oil Fuel Flow 65
(14) RT 303: Gas Fuel Flow 72
(15) RT 305: Quarterly Heat Input From Long Term Fuel Flow
Measurements for Qualifying Low Mass Emissions Units 75
(16) RT 307: Cumulative NOx Mass Emissions Data (ARP Low Mass
Emissions Units or Subpart H Units Only) 80
(17) RT310: S02 Mass Emissions Data (ARP) 84
(19) RT 314: S02 Mass Emissions Alternative Estimation Parameters for
Gas (ARP) 87
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EDR v2.2 Instructions
December 2005
Table of Contents (cont.)
Page
(20) RT 320: NOx Emission Rate Data 88
(21) RT 321: NOx Emission Rate Alternative Estimation Parameters for
Oil [Replaced] 92
(22) RT 322: NOx Emission Rate Alternative Estimation Parameters for
Natural Gas [Replaced] 92
(23) RT 323: NOx Emission Rate Alternative Estimation Parameters for
Oil and Gas 92
(24) RT 324: NOx Emission Rate Estimation Based on Appendix E 93
(25) RT 325: NOx Emission Rate Estimation Based on Appendix E for
Multiple Fuel Hours 96
(26) RT 328: NOx Mass Emissions (Subpart H) 96
(27) RT 330: C02 Mass Emissions Data (ARP) 98
(28) RT 331: C02 Mass Emissions Estimation Parameters (ARP) 99
(29) RT 360: Hourly Emissions Data for Qualifying Low Mass Emissions
(LME) Units (LME Only) 100
C. Monitoring Plan Records 102
(1) RT 500: Unit Definition Table [Retired] 103
(2) RT 501: Stack/Pipe Header Definitions Table [Retired] 103
(3) RT 502: Unit Definition Table [Retired] 103
(4) RT 503: Stack/Pipe Header Definition Table 103
(5) RT 504: Unit Information 106
(6) RT 505: Program Indicator for Report 108
(7) RT 506: EIA Cross Reference Information 110
(8) RT 507: Capacity Factor or Fuel Usage Data to Qualify as a Peaking
Unit or Acid Rain Program Gas-fired Unit 114
(a) Qualifying Using Historical and/or Projected Data 114
(b) Qualifying as "Gas-fired" Using Alternative Method 115
(9) RT 508: Subpart H Reporting Schedule (Subpart H) 117
(10) RT 510: Monitoring Systems/Analytical Components Table 119
(a) Defining a Monitoring System 119
(b) Types of Systems 120
(c) Additional Information for OILM, OILV, and GAS Systems 122
(d) Rotation of Fuel Flowmeters for Quality Assurance Purposes 123
(e) LME Units Using Long-term Fuel Flow at a Common Pipe 124
(f) Changing System Definitions and Recertification Events 124
(11) RT 520: Formula Table 130
(a) Required Formulas 131
(b) Referencing Other Formulas 132
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EDR v2.2 Instructions
Table of Contents (cont.)
Page
(c) F-factors and F-factor Formulas 132
(12) RT 530: Span Table 153
(13) RT 531: Maximums, Minimums, Defaults, and Constants 160
(14) RT 532: Rectangular Duct WAF Data 170
(15) RT 535: Unit and Stack Operating Load Data 172
(16) RT 536: Range of Operation and Normal Operating Load 173
(17) RT 540: Fuel Flowmeter Data 177
(18) RT 550: Reasons for Monitoring System Downtime or
Missing Parameter (Optional) 179
(19) RT 555: Monitoring System Recertification Events (OTC NBP) 181
(20) RT 556: Monitoring System Recertification, Maintenance, or
Other Events 181
(21) RT 560: Appendix E NOx Correlation Curve Segments 190
(22) RT 585: Monitoring Methodology Information 192
(23) RT 586: Control Equipment Information 200
(24) RT 587: Unit Fuel Type 202
D. Quality Assurance and Certification Data Reporting 204
(1) RT 600: 7-day Calibration Error Test Data and Results 205
(2) RTs 601 and 602: Linearity Check Data and Results 207
(3) RT 603: Flow Leak Check Results 211
(4) RT 605: Reference Data for Flow-to-load Ratio or
Gross Heat Rate Evaluation 212
(5) RT 606: Quarterly Flow-to-load Ratio or Gross Heat Rate Check 214
(6) RTs 610 and 611: Relative Accuracy Test Audit (RATA) and
Bias Test Data and Results 218
(7) RTs 614, 615, 616, and 617: Reference Method Supporting Data for Flow
RATA Tests 225
(8) RT 620: Cycle Time/Response Time Data and Results [Replaced] 234
(9) RT 621: Cycle Time Test Data and Results 234
(10) RT 623: Qualifying Test for Off-line Calibration Error Tests 236
(11) RT 624: Other QA Activities 237
(12) RT 627: Fuel Flowmeter Accuracy Test 238
(13) RT 628: Accuracy Test for Orifice, Nozzle, or Venturi Type
Fuel Flowmeters 240
(14) RT 629: Baseline Data for Fuel Flow-to-load Ratio or Gross Heat
Rate Check for Fuel Flowmeters 242
(15) RT 630: Quarterly Fuel Flow-to-load Test for Fuel Flowmeters 245
(16) RTs 630 and 631: Alternative Monitoring System Approval Petition
Results and Statistics [Renumbered] 248
(17) RTs 640 and 641: Alternative Monitoring System Approval
Petition Data, Results, and Statistics 248
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EDR v2.2 Instructions
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Table of Contents (cont.)
Page
(18) RT 645: Qualifying Data for Low Mass Emissions Units
Excepted Methodology 248
(19) RT 650: NOx Emission Rate Correlation Test Data 250
(20) RT 651: NOx Emission Rate Correlation Results 253
(21) RT 652: Heat Input from Oil Combusted During Test 254
(22) RT 653: Heat Input From Gas Combusted During Test 256
(23) RT 660: Requirements and Results for Unit Group Testing
(LME Units Only) 257
(24) RT 695: Single-load or Single-level Flow RATA Claim 258
(25) RT 696: Fuel Flowmeter Accuracy Test Extension 260
(26) RT 697: RATA Deadline Extension or Exemption 262
(27) RT 698: Quarterly QA Test Exemption Claim 266
(28) RT 699: QA Test Extension Claim Based on Grace Period 268
E. Electronic Compliance Certification Records 271
(1) RT 900: Part 75 Certification Statement and Designated
Representative Signature (ARP) 272
(2) RT 901: Part 72 Certification Statement (ARP) 272
(3) RT 910: Cover Letter Text, File-specific (Optional) 273
(4) RT 920: Cover Letter Text, Not File-specific (Optional) 273
(5) RT 940: Subpart H Certification Statement and Authorized
Account Representative Signature 273
(6) RT941: Subpart H General Certification Statement 274
(7) RT 999: Contact Person Record (Optional) 274
Appendix A
I. INTRODUCTION A-l
II. BASIC ELEMENTS OF AN EDR SUBMITTAL A-l
A. Monitoring Plans A-l
B. Certification or Recertification Application A-2
C. Quarterly Emissions Report A-3
D. Required Records for All Reports Based on Operational Configuration A-4
III. SUPPLEMENTARY TABLES A-5
A. Determining Applicable Program Requirements A-5
B. Determining the Available Monitoring Methodologies A-5
C. Interpreting Tables A-3 Through A-13 A-7
D. Reporting Data for an S02 CEMS A-7
E. Reporting Data for a NOx Emission Rate System A-9
F. Reporting Data from a NOx Concentration Monitoring System A-11
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EDR v2.2 Instructions
Table of Contents (cont.)
Page
G. Reporting Data for a C02 CEMS A-12
H. Reporting Data for a Stack Flow Monitoring System A-14
I. Reporting Data for a Diluent Monitor Used for Heat Input Rate Only A-16
J. Reporting Moisture Data A-17
(1) Reporting for Wet/Dry 02 CEMS A-18
(2) Reporting for Continuous Moisture Sensors A-19
(3) Reporting for Use of Default % Moisture A-20
(4) Reporting for Use of Temperature and a Look-up Table A-20
K. Reporting for Opacity Monitoring A-21
L. Summary of Hourly Emissions and QA Reporting for CEMS A-21
M. Reporting for Appendix D A-23
N. Reporting for Appendix E A-24
O. Reporting for Appendix G A-26
P. Other Records for Special Circumstances A-26
IV. REQUIRED REPORTING FOR LOW MASS EMISSIONS (LME) UNITS A-26
V. REPORTING FOR PREDICTIVE EMISSION MONITORING SYSTEMS (PEMS) A-29
A. Introduction A-29
B. Interpreting Table A-15 A-29
C. Supplementary EDR Reporting Instructions for PEMS A-33
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EDR v2.2 Instructions
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EDR VERSION 2.2
REPORTING INSTRUCTIONS
List of Tables
Page
Table 1: REPORTING REQUIREMENTS FOR OPERATING UNCERTIFIED UNITS 17
Table 2: REPORTING REQUIREMENTS FOR NON-OPERATING QUARTERS 18
Table 3: SUMMARY OF RT 201 REPORTING REQUIREMENTS 32
Table 4: SUMMARY OF RT 202 REPORTING REQUIREMENTS (ARP) 37
Table 5: SUMMARY OF RT 210 REPORTING REQUIREMENTS 41
Table 6: SUMMARY OF RT 211 REPORTING REQUIREMENTS 46
Table 7: SUMMARY OF RT 307 REPORTING REQUIREMENTS 80
Table 8: EDR RECORD TYPES USED FOR NOx MASS CALCULATIONS
(BASED ON RT 328 NOx METHODOLOGY FIELD) 98
Table 9: EXAMPLE DATA FOR QUALIFICATION BASED ON
HISTORICAL AND PROJECTED DATA 115
Table 10: EXAMPLE OF GAS-FIRED QUALIFICATION BASED ON
UNIT OPERATING DAT A 116
Table 11: F-FACTOR REFERENCE TABLE 135
Table 12: S02 EMISSION RATE FORMULA REFERENCES 136
Table 13: S02 EMISSION FORMULAS 136
Table 14: NOx EMISSION RATE FORMULA REFERENCE TABLE 137
Table 15: NOx EMIS SION RATE FORMULAS (LB/MMBTU) 139
Table 16: MOISTURE FORMULAS* 140
Table 17: C02 FORMULA REFERENCE TABLE 140
Table 18: C02 MASS EMISSION RATE FORMULAS 141
Table 19: HEAT INPUT FORMULA REFERENCE TABLE 143
Table 20: HEAT INPUT FORMULAS 144
Table 21: APPORTIONMENT AND SUMMATION FORMULAS 145
Table 22: NOx MASS EMISSIONS FORMULAS (POUNDS) 147
Table 23: MISCELLANEOUS FORMULA CODES 147
Table 24: STANDARD UNITS OF MEASUREMENT 148
Table 25: RT 520 REPRESENTATIONS FOR ELECTRONIC REPORTING 149
Table 26: CRITERIA FOR MPC/MEC/MPF DETERMINATIONS 156
Table 27: FUEL-SPECIFIC MINIMUM DEFAULT MOISTURE VALUES FOR S02,
NOx OR HEAT INPUT RATE CALCULATIONS 164
Table 28: FUEL-SPECIFIC MAXIMUM DEFAULT MOISTURE VALUES
FOR NOx EMISSION RATE CALCULATIONS 164
Table 29: NOx EMISSION FACTORS (LB/MMBTU)
FOR LOW MASS EMISSIONS UNITS 165
Table 30: S02 EMISSION FACTORS (LB/MMBTU)
FOR LOW MASS EMISSIONS UNITS 165
Table 31: C02 EMISSION FACTORS (TON/MMBTU)
FOR LOW MASS EMISSIONS UNITS 165
Table 32: UNITS OF MEASURE CODES BY PARAMETER 166
Table 33: ACID RAIN PROGRAM METHODOLOGIES AND PARAMETERS 196
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EDR v2.2 Instructions
List of Tables (cont.)
Page
Table 34: ACID RAIN PROGRAM LOW MASS EMISSIONS (LME)
METHODOLOGIES AND PARAMETERS 198
Table 35: NON-ACID RAIN SUBPART H METHODOLOGIES AND PARAMETERS 199
Table 36: NON-ACID RAIN SUBPART H LOW MASS EMISSIONS (LME)
METHODOLOGIES AND PARAMETERS 200
Table 37: SUMMARY OF EDR REPORTING REQUIREMENTS FOR
RECORD TYPES 614, 615, and 616 226
Table 37A: FLOW RATA SUPPORT RECORDS
(Rectangular Stacks or Ducts, with Wall Effects Adjustment) 227
Table A: BASIC MONITORING PLAN RECORD TYPES A-l
Table B: CERTIFICATION AND RECERTIFICATION BASIC RECORD TYPES A-2
Table C: QUARTERLY EMISSIONS REPORT RECORD TYPES A-3
Table D: RECORD TYPES REQUIRED FOR SPECIFIC
OPERATIONAL CONFIGURATIONS A-4
Table A-1: REQUIRED POLLUTANT AND PARAMETER INFORMATION BY PROGRAM . A-5
Table A-2: ALLOWABLE MONITORING METHODOLOGIES A-6
Table A-3: RECORD TYPES FOR S02 CEMS METHODOLOGY A-8
Table A-4a: RECORD TYPES FOR NOx-DILUENT CEMS A-9
Table A-4b: RECORD TYPES FOR NOx CONCENTRATION CEMS A-11
Table A-5: RECORD TYPES FOR C02 CEMS A-13
Table A-6a: RECORD TYPES FOR FLOW MONITORING SYSTEMS A-14
Table A-6b: RECORD TYPES FOR DILUENT MONITORS USED FOR
HEAT INPUT RATE ONLY A-16
Table A-7a: RECORD TYPES FOR WET/DRY 02 CEMS A-18
Table A-7b: RECORD TYPES FOR CONTINUOUS MOISTURE SENSOR A-19
Table A-7c: RECORD TYPES FOR DEFAULT % MOISTURE A-20
Table A-7d: RECORD TYPES FOR REPORTING % MOISTURE
FOR SATURATED GAS STREAMS A-20
Table A-8: RECORD TYPES FOR OPACITY MONITORS A-21
Table A-9: COMPARISON OF CEMS REPORTING A-22
Table A-10: RECORD TYPES FOR APPENDIX D A-23
Table A-l 1: RECORD TYPES FOR APPENDIX E A-25
Table A-12: RECORD TYPES FOR APPENDIX G A-26
Table A-13: RECORD TYPES FOR SPECIAL SITUATIONS A-26
Table A-14: RECORD TYPES FOR LOW MASS EMISSIONS UNITS A-27
Table A-15: EDR RECORD TYPES FOR UNITS WITH PEMS A-30
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EDR v2.2 Instructions December 2005
EDR VERSION 2.2
REPORTING INSTRUCTIONS
List of Illustrations
Page
Illustration 1: EXAMPLE RECORD STRUCTURE FOR RECORD TYPE 320 3
Illustration 2: EXAMPLE DATA FOR RECORD TYPE 320 4
Illustration 3: EXAMPLE SUMMARY OF QUARTERLY REPORT CONTENT
FOR TWO ACID RAIN CEMS UNITS EMITTING THROUGH COMMON STACK 6
Illustration 4: EXAMPLE NOx CORRELATION CURVE SEGMENTS 191
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EDR v2.2 Instructions
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EDR VERSION 2.2
REPORTING INSTRUCTIONS
I INTRODUCTION
The purpose of these instructions is to provide the necessary information for owners and
operators to meet reporting requirements for the Acid Rain Program (ARP) and for the NOx Budget
Trading Program, established under the 1998 NOx SIP Call (see: 40 CFR Part 96). Non-load based
units, units that report emission data from an approved predictive emission reporting system (PEMS), and
units that use certain compliance options provided by the June 12, 2002 revisions to Part 75 must use
these instructions for all EDR submissions including: 1) monitoring plans, 2) certification applications,
and 3) quarterly reports. A separate companion document, "Electronic Data Reporting—Acid Rain
Program/Subpart H — Version 2.2" (EDR v2.2), provides information on the electronic data reporting
file formats and record structures and should be consulted in conjunction with instructions for specific
record types. In this document, the acronym "ARP" is used to identify requirements for Acid Rain units
and the term "Subpart H" is used for units affected by State or federal regulations implementing NOx
mass emission monitoring consistent with 40 CFR Part 75, Subpart H.
These instructions explain the specific reporting requirements set forth in the applicable
regulations. Owners or operators of units subject to the Acid Rain Program and/or NOx Budget
Programs should use these instructions in conjunction with 40 CFR Part 75.
Policy on Ongoing Use of EDR v2.1
If your unit produces electrical or steam load and if: (a) you do not report emission data from a
PEMS; or (b) you do not elect to use any of the v2.2-specific reporting or missing data options allowed
in the June 12, 2002 revisions to Part 75; or (c) if your unit is not affected by any other rule change
supported only by EDR v2.2, then you may continue to report emissions data, monitoring plans and
certification test data in EDR v2.1 formats. EPA has provided separate guidance for when the use of
EDR v2.2 is required for each category of rule changes (see "Implementation Guidelines for the June 12,
2002 Revisions to Part 75," available on EPA's Clean Air Markets Division (CAMD) website, at
http ://www. epa. gov/ airmarkets/edr21 /index.html).
Organization of the Instructions
Section II provides general information on EDR v2.2. This general information is relevant to all
quarterly reports submitted using EDR v2.2 format, regardless of the program for which the data are
being reported or applicable reporting requirements.
Section III provides specific information on each record type in numerical record type order.
Record types or fields within record types that are applicable to one or more specific programs are clearly
indicated.
Appendix A is a guideline for determining which record types to include in an EDR submission.
Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions
II GENERAL INSTRUCTIONS
A. EDR Record Structures
The EDR v2.2 companion document provides the record structures which define the order,
length, and placement of information within the quarterly report or "file." All quarterly report files must
be in ASCII text format. The EDR provides the Record Type, Program, Type Code, Start Column, Data
Element Description, Units, Range, Length, Fortran (FTN) Format, and location on the hard copy form
for each data element in the electronic report. A detailed explanation of the information follows:
Record Type describes the type of information contained in the record, as required by the
appropriate section of the rule.
Program identifies the applicable reporting requirements (ARP and/or Subpart H) to which the
record applies.
Type Code is the three digit code for identifying the Record Type.
Start Column indicates the column in which the data element begins.
Field Notes provides specific information such as whether the Record Type is optional or should
only be used for certain types of units.
Units indicates the unit of measure in which the value is reported (e.g.. ppm for NOx
concentration data). Where applicable, the units column specifies how to format the data (e.g..
YYMMDD or YYYYMMDD).
Range provides information, where applicable, on the acceptable lower and upper values or
acceptable codes for the data element.
Length indicates the number of columns designated for the data element.
Format specifies the type of data and Fortran (FTN) format that should be used for the data
element. There are three data types: "I" for integer, "A" for alphanumeric, and "F" for fixed
decimal point. A format of "13" indicates that the data will be an integer of up to three digits. A
data element with an "I" format should never contain a decimal point, and all data elements
requiring an "I" format must be right-justified. Right-justification ensures that leading zeros are
not necessary; instead, these spaces should be left blank. "A3" indicates an alphanumeric data
element containing up to three characters, which may be either alphabetic or numeric and is left-
justified. "F5.1" indicates a numeric field, five columns wide, with one numeral to the right of the
decimal point. A decimal point (.) must be included in all data elements requiring an "F" format
(fixed decimal point format). In addition, all data elements requiring an "F" format must be
decimally-justified. In other words, the decimal point must be placed to allow the correct number
of columns to the right of the decimal point. Decimal-justification ensures that leading zeros are
not necessary; instead, these spaces should be left blank.
Total Record Length indicates the total number of assigned spaces (columns) for all required
data elements in a specific record type (e.g.. for NOx emission rate from CEMS, each record will
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EDR v2.2 Instructions
December 2005
appear as a single line, 54 columns in length). See Illustration 1 below for an example record
structure.
Each record (line) must begin with the three digit "Record Type Code," followed by the
associated data elements for the record type. The Record Type Code is a number that EPA has
assigned to label a category of information to be reported. The Record Structure for each record
type provides the location of each data element within the record. The example in Illustration 1
shows the record structure for RT 320, "NOx Emission Rate Data."
Illustration 1
EXAMPLE RECORD STRUCTURE FOR RECORD TYPE 320
I M l DAT
A
RECORD
ty pi:
TYPE
CODE
START
COL
DATA ELEMENT
DESCRIPTION
II III)
NOTES
I NHS
RANCE
I.ENCTII
EORM
AT
(FTN)
NOx EMISSIONS DATA
NO,
Emission
Rate Data
320
1
4
10
Record type code
Unit/Stack ID
Monitoring system ID
3
6
3
13
A6
A3
13
Date
YYMMD
D
6
16
19
Hour
HH
00-23
2
12
21
Percent monitor data availability
for NOx emission rate
calculations
%
0.0-100.0
5
F5.1
26
F-factor converting NO,
concentrations to emission rates
10
F10.1
36
Average NOx emission rate for
the hour
lb/mmBtu
6
F6.3
42
Adjusted average NOx emission
rate for the hour
lb/mmBtu
6
F6.3
48
Load range or operational bin
number
01-10
2
12
50
Formula ID from monitoring
plan for hourly NOx emission
rate
3
A3
53
Method of determination code5
01-12,
14,21, 22,
23,25,
54,55
2
12
Total Record Length
54
Illustration 2, below, presents an example line of hourly NOx emission rate data (RT 320). The
top line of numbers indicates the starting column position for each data element. The second line of
numbers represents one hourly record of NOx emission rate data as the data would appear in an electronic
file.
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December 2005
EDR v2.2 Instructions
Illustration 2
EXAMPLE DATA FOR RECORD TYPE 320
COLUMN POSITION
10 13
19 21
2 6
36
42
48 50 53
320**1
A1099050100 98.5
1800 0.331 0.33107N0101
Type
Code
Unit/Stack ID
Date
Hour
Percent
Availibility
NOx Emission
Rate
for Hour
F-factor
Load
Range
Form ula
ID
M onitoring
System ID
Adjusted NOx
Emission Rate
for Hour Method of
Determ ination
Code
B. Quarterly Emissions File Organization and Ordering
(1) File Content
For quarterly report data submitted in EDR format, individual units associated with single stacks
must be submitted in separate files, (e.g.. for Plant A, one file would be submitted for Unit 1 and a
separate file would be submitted for Unit 2). However, if units exhaust through a common stack and
emissions are monitored at the common stack (or fuel flow is metered at a common pipe), the data for the
units must be included in one file with all the data relevant to the common stack (or common pipe). For
all complex configurations (for example, three units which each exhaust through two or more common
stacks) submit all unit and stack information in a single quarterly report. In no situation is it acceptable to
submit two separate files containing operating and heat input data for the same unit in the same quarter.
Appendix A of these instructions specifies which record types must be reported in each of the
three basic types of EDR submittals (i.e.. monitoring plan submittals, certification or recertification
applications, and quarterly emissions reports). Illustration 3 below shows an example file summary for a
quarterly emissions report.
(2) Record Order
RT 100 must appear first in any electronic submission including quarterly emissions reports,
certification application data, and electronic monitoring plan files. Following RT 100, report RTs 101
(optional) and RT 102 for the facility. Following these records, order all records in the quarterly report
file first by unit/stack/pipe ID, second by record type code, third by date and time, and fourth by
component/system ID.
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(3) Stack or Pipe Record Orders
Stack and pipe IDs are the first IDs within the quarterly report file. Stack and pipe IDs must be in
alphanumeric order. The unit IDs must follow the stack and pipe IDs and also need to be in alphanumeric
order. For stacks and pipes, this means that CS or CP comes before MS or MP in the file. For units, 1A
comes before IB and 1 comes before 2.
(4) Record Order for Quality Assurance Data
Submit all daily quality assurance data (for example, RTs 230 and 231) in record type order with
the unit or stack emissions data. Order these records by date and time, then by component and system
ID. For records that may have more than one component/system record for the same unit and hour (for
example, daily calibration error data in RT 230), the records should be in alphanumeric order by
component/system ID. If there is more than one daily calibration record for the hour for a
component/system, order these records by the time the daily calibration was completed. This record
order is required; do not use alternative record orders.
For ongoing quality assurance data (RTs 600+) submit all records for a unit, stack or pipe with
the unit, stack or pipe emissions data in record type order. Within each record type, order the records
using either the standard record order (unit, record type, date, time, component/system, span) or using
the record order allowed for certification disks (unit, record type, component/system, span, date, time).
Clean Air Markets Division, U.S. EPA
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Illustration 3
EXAMPLE SUMMARY OF QUARTERLY REPORT CONTENT FOR TWO ACID RAIN
CEMS UNITS EMITTING THROUGH COMMON STACK
FACILITY INFORMATION
Type 100 Record
(Facility and report data)
Type 102 Record
(Facility information)
COMMON STACK FOR UNITS 1 & 2
Type 200 Records
(SO2 concentration data: by date and hour)
Type 201 Records
(NOx concentration data: by date and hour)
Type 202 Records
(C02 concentration data: by date and hour)
Type 210 Records
(Diluent data: by date and hour)
Type 220 Records
(Volumetric flow data: by date and hour)
Type 230 Records
(Daily calibration test data: by date and hour)
Type 231 Records
(Flow interference data: by date and hour)
Type 300 Records
(Stack operating parameters: by date and hour)
Type 301 Record
(Quarterly and cumulative emission data)
Type 310 Records
(SO2 mass emissions data: by date and hour)
Type 320 Records
(NOx emission rate data: by date and hour)
Type 330 Records
(C02 mass emissions data: by date and hour)
Type 503 Records
(For Unit 1 (Common stack definition table))
(For Unit 2 (Common stack definition table))
Type 510 Records
(Monitoring systems/analytical components table)
Type 520 Records
(Formula table)
Type 530 Records
(Span table)
Type 535 Records
(Stack operating load data)
Type 536 Record
(Range of Operation, normal load, and load usage)
Type 556 Records
(Monitoring system recertification events)
Type 601 Records
(Quarterly linearity test data)
Type 602 Records
(Quarterly linearity check results)
Type 603 Records
(Flow quarterly leak check results)
Type 605 Records
(Reference data for flow-to-load ratio or GHR evaluation)
Type 606 Records
(Quarterly flow-to-load or GHR check)
Type 610 Records
(RATA and bias test data)
Type 611 Records
(RATA and bias test results)
Type 623 Records
(On-line/Off-line calibration demonstration)
Type 699 Record
(QA test extension claim based on grace period)
UNIT 1 (MONITORED AT COMMON STACK)
Type 300 Records
(Unit operating parameters: by date and hour)
Type 301 Record
(Quarterly and cumulative emission data)
Type 504 Record
(Unit information)
Type 505 Record
(Unit/program information)
Type 585 Records
(Monitoring methodology information)
Type 586 Record
(Control equipment information)
Type 587 Record
(Unit fuel type)
UNIT 2 (MONITORED AT COMMON STACK)
Type 300 Records
(Unit operating parameters: by date and hour)
Type 301 Record
(Quarterly and cumulative emission data)
Type 504 Record
(Unit definition table)
Type 505 Record
(Unit/program information)
Type 585 Records
(Monitoring methodology information)
Type 586 Record
(Control equipment information)
Type 587 Record
(Unit fuel type)
CERTIFICATIONS
Type 900 Records
(Certification electronic signature)
Type 901 Records
(Certification statement)
Type 999 Record
(Contact person information)
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C. General EDR Instructions
(1) Definition of Reporting Period
Throughout these instructions, the terms "quarterly report" and "quarterly emissions file" are used
to describe the required data submittals. In other places, the term "reporting period" is used. The
relationship between the quarterly report and the reporting period is as follows:
• For sources that are required to report emissions data on a year-round basis, there are four
reporting periods in each calendar year, corresponding to the four quarters of the year. A
quarterly report submittal is required for each of these reporting periods.
• For sources that report data only during the ozone season, there are only two reporting periods in
each calendar year (i.e.. the second quarter (May and June only) and the third quarter). Quarterly
report submittals are required only for these two reporting periods.
(2) Identification Numbers
To ensure accurate processing by the Emissions Tracking System (ETS), the system that
processes the quarterly report files, each record in the quarterly report must contain consistent and
accurate ID numbers.
(a) Facility/ORISPL Number
Utility units and other units that generate energy for sale must use the plant code (otherwise
known as an ORISPL code) which is an integer data element assigned by the Department of Energy
(DOE) to identify the facility or plant. You can also obtain the plant/facility code from the Energy
Information Administration, Department of Energy (DOE) from Form EIA-860, "Annual Electric
Generation Report," or from Form EIA-867, "Annual Nonutility Power Producer Report."
If you do not have an ORISPL code for a plant/facility, contact EPA's Clean Air Markets Division
to determine what code you should use.
The ORISPL code is six digits in length. For purposes of reporting in the EDR, the ORISPL
code is right-justified. Note that unlike other integer ("I" format) data elements, the ORISPL code is
padded with leading zeroes. For example, ORISPL code 786 would appear in RT 100 as 000786.
(b) Unit IDs
Each unit at a facility must have a unique unit ID. The unit ID is an alphanumeric data element
that is from one to six characters in length.
The unit ID must be included in the quarterly report exactly as it appears in the unit ID column in
the National Allowance Database (NADB) (for Acid Rain units) or in the applicable federal or State NOx
mass allowance allocation list or data file (for Subpart H units). Include leading zeros or asterisks (*)
exactly as they appear in these files, except as noted below.
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If a unit is not listed in NADB or the allowance allocation list, or if the ID on the allowance list
differs from the ID commonly used by the company, you may submit a unit ID of your choice in the
CAMD Business System (CBS). CBS is a web-based application that enables authorized users to submit
data to CAMD on-line though the Clean Air Markets web site. You may also submit a unit ID of your
choice in the Certificate of Representation (for Acid Rain units) or the Account Certificate of
Representation form (for Subpart H units). In general, the unit ID should conform to the nomenclature
used by plant personnel and/or agency personnel to identify a unit. It should also be consistent with the
unit ID used on all other program submissions including submissions related to allowances or authorized
representatives. For example, use Unit ID "1" for Boiler #1 and "CT1" for combustion turbine #1.
In all cases, use the same unit ID provided in the CAMD Business System or the Certificate of
Representation or Account Certificate of Representation form when submitting the monitoring plan and
the quarterly report file.
When used to identify data in a quarterly report file, the unit ID must be left-justified (i.e.. there
must not be any leading blank spaces and no spaces in the unit ID), using blanks on the right if necessary
to fill the remaining spaces.
For example,
Unit ID "2" would be formatted as:
2BBBBB (for illustration = blank space)
(Note: Do not report unit "2" as unit "02", "002", or "000002". These are considered to be
different, unique IDs.)
Unit ID "003 A" would be formatted:
003 ABB (for illustration "B" = blank space)
(c) Stack and Pipe IDs
For monitored common or multiple stack (or pipe) configurations, each stack/pipe ID used for
data reporting must correspond to a stack or pipe ID identified in the monitoring plan for the facility.
When you assign a stack or pipe ID to a common or multiple stack or pipe, you must use one of the
following prefixes to define the type of stack or pipe header:
CS — For monitored common stacks (stacks serving more than one unit).
MS — For multiple stacks (i.e.. two or more monitored stacks uniquely associated with a
single unit).
Except as noted below, whenever a unit exhausts through more than one stack, if all stacks
are uniquely associated with the unit, they must be identified as multiple stacks. Also, if any
of the monitored stacks serves one or more other units, the stack must be identified as a
common stack. For example, if a scrubbed unit (Unit 1) emits to a monitored common stack
(CS012) which it shares with Unit 2 for most operating hours, but discharges through a
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dedicated, monitored unit-only stack during scrubber bypass conditions, you must identify the
bypass stack with a "MS" prefix (e.g.. "MSI").
The multiple stack designation must also be used for a unit when multiple ducts (breechings)
are individually monitored in lieu of monitoring at the stack. Each duct must be assigned an
"MS" prefix.
(Note the following exceptions to the use of multiple stack ("MS") prefixes:
• For a unit that has add-on S02 or NOx emission controls and which: (a) has
both a main stack and a bypass stack; and (b) uses CEMS to monitor at the
main stack; and (c) does not have monitors on the bypass stack; and (d) reports
the maximum potential concentration or emission rate during bypass hours,
you should report all data at the unit level instead of using "MS" prefixes.
• If, for a particular unit, flow rate monitors are installed on multiple breechings,
you may report the flow rate data at the unit level in lieu of using "MS"
prefixes, provided that you: (a) define the duct-mounted flow monitors as
components of a single flow monitoring system; (b) include a flow rate
summation formula in RT 520; and (c) collect reference method data in the
breechings simultaneously during all required flow RAT As, to ensure
representativeness.
• For a combustion turbine that: (a) uses the provisions of Appendix D to Part
75; and (b) has a main stack and a bypass stack; and (c) has a NOx monitor on
the main stack, but not on the bypass stack; and (d) reports the maximum
potential NOx emission rate during bypass hours, you should report all
emissions and heat input data at the unit level instead of using "MS" prefixes.
• For a combined-cycle combustion turbine (CT) that: (a) uses the provisions of
Appendix D to Part 75 for unit heat input; and (b) has a main stack and bypass
stack configuration; and (c) has NOx-diluent monitoring systems on both the
main and bypass stacks, Question 17.7 in the Part 75 Policy Manual
encourages you, for simplicity, to report all of your data at the unit level1,
defining two primary NOx monitoring systems in RT 510.
• For additional guidance on "MS" prefix exceptions, see Part 75 Policy Manual
Questions 17.6 and 17.7.
1 Note: For the combined-cycle CT described in the fourth bulleted item above, if you
anticipate that the CT will operate for a significant percentage of the total unit operating
hours in the simple-cycle mode, discharging through the bypass stack, it may be more
advantageous to report the emissions data using a multiple-stack configuration. One distinct
advantage of using multiple stack reporting for this type of unit is that it allows you to
reckon "QA operating quarters" and grace periods in terms of stack operating hours, rather
than unit operating hours. This makes it easier to complete the required QA tests of the NOx
monitoring systems in a timely manner.
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CP — For common pipes (oil or gas fuel supplies serving more than one unit), including
pipes and oil tanks serving a group of low mass emissions (LME) units.
MP — Use this prefix only for an Appendix E combined cycle unit comprised of a combustion
turbine and duct burner, if fuel flow rate is separately metered and reported at the
turbine and duct burner locations.
The pipe or stack ID is an alphanumeric ID of up to six characters; the four characters to the right
of the required prefix may be either numbers or letters. EPA recommends the use of commonly used
stack identifiers (i.e.. CS1 for common stack 1). Once you have assigned a stack ID, it should not be
changed.
As an alphanumeric field, the stack or pipe ID should always be left-justified for EDR reporting
purposes. See the examples for unit IDs provided above.
(3) Data Entry and Editing of Quarterly Reports
This section clarifies which data must be automatically recorded and reported by the DAHS and
which data may be manually edited or entered (or recorded in a computer system outside of the DAHS
and merged in the final quarterly report file). If data needs to be manually entered or edited in a quarterly
report for a situation that is not addressed below, contact EPA's Clean Air Markets Division. EPA will
determine whether the request is allowable under Part 75. If the situation is allowable under Part 75,
EPA still may require documentation indicating the use of manually entered or edited data. If the
situation is not allowable under Part 75, you may petition EPA under § 75.66 for authorization to
manually enter or edit data submitted in the quarterly report.
(a) Emissions Data From CEMS
1. Data Recorded Automatically
Except as noted below, all emissions values recorded from a CEMS must be automatically
recorded by the DAHS.
2. Data Entered or Edited Manually
In some cases, you may determine, using sound engineering judgment, that a measured emissions
value (or values) or other parameter is clearly in error and should be invalidated. When this situation
occurs, determine whether correction of all the measured value(s) believed to be in error results in a
significant change in the reported S02, NOx, or C02 emissions or heat input. Follow the guidance in
EPA's "Quarterly Report Review Process for Determining Final Annual Emissions Data" to make this
determination. If the effect of replacing the erroneous values is not significant, you may make the
replacements and do not have to notify EPA. However, if replacement of the erroneous data values has a
significant effect, contact EPA's Clean Air Markets Division. If the Agency agrees that the data are
clearly in error, document the error (in RTs 910 or 920 or as part of the quarterly report submittal letter)
and replace the erroneous data with quality-assured measured data from a certified backup monitoring
system, a substitute value according to missing data procedures, or reference method backup data. If you
replace measured data with substitute data, the replacement data should be automatically calculated by a
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certified component of the DAHS. If you replace measured data with data from a certified backup
monitoring system, the replacement data should be automatically recorded by the DAHS.
During startup and shutdown or when the efficiency of an emission control device approaches
100%, emissions may be very low and a CEM may occasionally record negative emissions values. It is
never acceptable to report negative emission values in your quarterly data file. For negative emissions or
moisture values, EPA will allow either automatic replacement by the DAHS or manual replacement of the
negative value. In most cases, it is acceptable to replace the negative emissions value with zero. When
you replace a negative value with zero, report an MODC of "21" for the hour in RT 200, 201, 212, or
320. MODC "21" may either be automatically replaced by the DAHS or manually entered. However, if
negative or zero C02 concentrations are obtained during startup or shutdown, you should replace these
readings with the diluent cap value of 5.0% C02 (for boilers) or 1.0% C02 (for combustion turbines), in
order to avoid receiving error messages in your electronic feedback report. Reported C02 concentrations
of zero can result in heat input rates of zero being reported for periods of unit operation. This will
generate an error message in the feedback report. You must also use the diluent cap values in the missing
data lookback period. It is not necessary to contact EPA when negative emissions values are replaced in
the above manner. [Note: A CEMS may also record negative values during daily calibrations or QA
tests (when a zero-level gas or signal is used); negative readings during these tests are valid and should
not be replaced.]
As required under § 75.1 l(e)(3)(iii), if you use an S02 CEMS to account for S02 emissions
during hours in which very low sulfur fuel (as defined in § 72.2) is combusted, for any bias-adjusted
hourly average S02 concentration of less than 2.0 ppm (including negative values) recorded by the
CEMS, adjust the value to a default value of 2.0 ppm. For this replacement, EPA allows either automatic
replacement by the DAHS or manual replacement of the value with 2.0 ppm. It is not necessary to
contact EPA in these cases.
If you need to manually enter or edit monitored emissions data in any other way, your designated
representative or your AAR must petition EPA under § 75.66.
If you use a like-kind replacement analyzer for a component of a primary monitoring system on a
temporary basis, EPA allows manual editing of the component ID and MODC for all hours in which data
are recorded by the like-kind replacement (which should not exceed 720 hours annually).
(b) Reference Method Backup Data
You may also manually enter reference method backup data. To the extent feasible, it may also
be automatically collected and/or processed in another computer/data logger and merged with the final
quarterly report file. This component does not have to be identified as part of the monitoring system.
(c) Calibration and Linearity Data
1. Data Recorded Automatically
All calibration and linearity test data recorded from a CEMS must be automatically recorded by
the DAHS. Calibration and linearity test results must be calculated by the DAHS. It is permissible for a
separate DAHS component to do these calculations, if this DAHS component is identified as part of the
monitoring system in the monitoring plan.
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2. Data Entered or Edited Manually
If you need to manually enter or edit calibration or linearity data, petition EPA.
(d) RATA Data
1. Data Recorded Automatically
Minute by minute emissions or flow values from the CEMS being tested must be automatically
recorded by the DAHS or data logger that is a component of the system. However, you may export this
data to an external data system or spreadsheet to perform the actual RATA calculations. It is not
necessary for the external software package to be part of the monitoring system.
2. Data Entered or Edited Manually
Reference method data may be recorded by and entered into the DAHS manually. It may also be
entered into a separate computer system that calculates the RATA results and exports the data into EDR
format. This separate computer system does not have to be identified as part of the monitoring system.
You may manually enter calculated RATA results into the DAHS.
(e) Stack or Fuel Flow-to-load Ratio Test Data
Results of stack or fuel flow-to-load ratio tests may be generated in a separate computer and
merged with the quarterly report file. This computer does not have to be a certified DAHS component of
the monitoring system.
(f) Appendix D Data
1. Data Recorded Automatically
Except as noted below, all fuel flow values recorded from a fuel flow meter must be automatically
recorded by the DAHS.
Except as noted below, hourly fuel sampling data recorded by a gas chromatograph or online
calorimeter must be automatically recorded by the DAHS.
2. Data Entered or Edited Manually
You may determine, using sound engineering judgment, that a measured fuel flow value or gas
chromatograph value (or values) or other parameter is clearly in error and should be invalidated. When
this situation occurs, determine whether correction of the measured value(s) believed to be in error
results in a "significant" change in the reported S02, NOx, or C02 emissions or heat input. Follow the
guidance in EPA's "Quarterly Report Review Process for Determining Final Annual Emissions Data" to
make this determination. If replacement of the erroneous data values has a significant effect, contact
EPA. If the Agency agrees that the data are clearly in error, document the error (in the RTs 910 or 920
or as part of the quarterly report submittal letter) and replace the erroneous data with quality-assured
data from a backup monitoring system or with a substitute value according to missing data procedures. If
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you replace measured data with missing data, the replacement data should be automatically calculated by
a certified DAHS component. If you replace measured data with data from a certified backup monitoring
system, the replacement data must be automatically recorded by the DAHS.
Except when a gas chromatograph is used to obtain hourly fuel sampling values, you may
manually enter fuel sampling data.
You may enter other quality assurance data (e.g.. orifice inspections, transducer/transmitter
accuracy test results) manually.
(g) Other Quality Assurance Data
1. Data Recorded Automatically
All results of daily interference checks must be automatically recorded by the DAHS.
2. Data Entered or Edited Manually
Information from other quality assurance tests that cannot be recorded automatically (e.g.. leak
checks) may be manually entered into the DAHS. The separate computer does not have to be a certified
DAHS component of the monitoring system.
(h) Calculated Emissions Values (e.g.. NOx Emission Rate in RT 320 or
Total S02 Quarterly Emissions in RT 301), Except For Units Using Low
Mass Emissions (LME) Methodology Under § 75.19
1. Data Recorded Automatically
Except as noted below, all calculated emissions values must be automatically calculated, recorded,
and reported in EDR format by the DAHS.
2. Data Entered or Edited Manually
If short term (not more than one calendar quarter) problems prevent automatic calculation by the
DAHS or recording by the DAHS of calculated emissions values, contact EPA and if the Agency agrees,
enter these values manually into the quarterly report (either by manually entering the values or by merging
a file containing the calculated values with the quarterly report file). Document the problem and indicate
which values were manually calculated and/or entered (in RTs 910 or 920 or as part of the quarterly
report submittal letter).
If you need to manually edit or enter calculated emissions values for a period longer than one
quarter, petition EPA under § 75.66.
(i) Missing Data
All substitute data values derived from the Part 75 (or other allowable) missing data routines must
be automatically calculated and recorded by the DAHS.
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(j) Other Operating Data
EPA recommends, but does not require, that other operating data (e.g.. unit load, unit operating
time) be automatically recorded by the DAHS. If these data are automatically recorded in another
computer system, this system does not have to be identified as a DAHS component of the monitoring
system.
(k) Data for Low Mass Emissions Units Under § 75.19
Most required data may be entered manually. However, when a unit uses a certified fuel flow
meter and Appendix D procedures to determine hourly fuel flow and heat input, the data from the fuel
flowmeter must be recorded automatically. For long term fuel flow, the DAHS should be capable of
recording unit output and apportioning the quarterly/ozone season heat input determined from the long
term fuel flow measurements. Long term fuel flow measurements may be entered manually.
(4) Use of Blank Spaces
Within one record, where some but not all data are reported, unused columns should be left blank.
For example, in RT 300 (Unit Operating Parameters) the field beginning in column 28 is steam load
which may be reported in lieu of gross unit load. If you are using this option, you should submit RT 300
with six blank columns for gross unit load in column 22. Furthermore, use blanks when a data element
does not entirely fill its allocated space. As specified above, alphanumeric fields ("A" format) should be
left-justified, using blanks if necessary for the last few spaces, while integer fields ("I" format) should be
right-justified, using blanks if necessary for the first few spaces. Fixed decimal point fields ("F" format)
must be decimally-justified. For example, in RT 610, beginning in column 34, a value of 436.2 ppm
recorded by the CEM would be reported with six leading blanks and two trailing blanks as follows in the
"F13.3" format: "¦¦¦¦¦¦436.2H" (for illustration B=blank space).
(5) Reporting of Dates and Times
Report time data according to the 24 hour clock: HHMM where HH is a two digit hour (00 - 23)
and MM is a two digit minute (00 - 59). Format dates from left to right: YYMMDD, where YY
represents the last two digits in the calendar year, MM is a two digit month (01 - 12), and DD is a two
digit day (01-31). In certain record types the date format is YYYYMMDD, where YYYY is a four-
digit year (e.g.. 2000).
(6) Reporting in Standard Time
Report all data in standard time. Each hour reported in the file represents a clock hour, not an
operating hour.
(7) Computational Requirements and Rounding
(a) Computing Hourly Emissions Values
When computing monitor readings for a specific hour (for example, NOx concentration for the
hour), use all the decimal digits which the DAHS computer normally employs for floating point
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calculations. Double-precision numbers (8 to 16 digits) may be used for these calculations and should be
employed when needed to compute the recorded emissions value.
(b) Rounding Conventions for Reported Data
When it is necessary to round a value to report it using the number of required decimal places, use
the standard arithmetic rounding convention where numbers 5 through 9 round to the next highest
number in the previous decimal position to the left. Some fields in the EDR were designed to be generic
and support reporting data for multiple purposes (e.g.. certain fields in RT 610 for reporting RATA
results). It is therefore not always appropriate to report values to the number of decimal places in the
EDR format. The precision of each measured parameter should be the same as the precision of the
hourly record for the parameter. For instance, for an S02, C02, or 02 RATA, report the CEM and
reference method values in columns 34 through 59 of RT 610 to the nearest 0.1 ppm or 0.1% C02 or 02
(as applicable); zeros may be used as place holders to the right of the last digit in each measurement, but
are not considered to be significant figures. For a NOx RATA, report the NOx emission rates to three
decimal places. For a flow RATA, the last significant digit in the reported flow rate values is in the
thousands place; fill in zeros in the hundreds, tens, and unit columns (e.g.. round 15,922,855 scfh to
15,923,000 scfh).
(c) Use of Reported Data for Emissions and QA Test Calculations
For quantities calculated from the reported CEM data (such as heat input rate or NOx emission
rate) or for calculation of cumulative emissions (such as quarterly NOx mass emissions), perform the
calculations or summations using values rounded to the number of decimals defined in the EDR. For
example, when you calculate NOx emission rate, use the values (rounded to one decimal place) of NOx
concentration and diluent gas concentration reported in RTs 201 and 210 or 211 to perform the
calculation. Do not use the values stored in the computer that may include 8 or 16 places to the right of
the decimal. Then, report the NOx emission rate in RT 320, rounded to the nearest 0.001 lb/mmBtu, as
required by Part 75.
(d) QA Test Calculations
Whenever you perform QA test calculations that involve a number of steps in sequence (e.g..
linearity error or percent relative accuracy calculations), begin the calculation sequence with the raw data
values reported in the EDR (i.e.. begin with flow rates that are rounded to the nearest 1000 scfh, gas
concentrations that are rounded to the nearest 0.1 ppm, etc.). However, once you have begun the
calculation sequence, do not round off any of the intermediate values (such as the mean difference,
confidence coefficient, (R - A), etc). Rather, retain the full decimal display of the computer in the
intermediate values until the final result is obtained and then and round off the final result. Similarly, do
not use rounded intermediate values of statistical terms such as the standard deviation, mean difference,
and confidence coefficient when you perform a bias test of a CEMS or determine a bias adjustment factor
(BAF). For a more detailed discussion, see Question 8.36 in the Part 75 Policy Manual.
(8) Requirements for Component and System IDs
You must report a system and component ID (as defined in RT 510) for a certified monitoring
system for all measured emission values. Exceptions to this requirement for specific record types and
configurations are discussed in Section III.
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(9) Reporting Data Outside the Reporting Period
Do not submit any hourly emissions data in the quarterly report file representing emissions values
recorded for any time period outside of the applicable quarter and year. In some limited cases, it is
permissible to submit quality assurance data for tests that were performed partially or entirely in a
different quarter. See Section III.D for more information.
(10) Information on Non-operating Hours
In general, operating time should always be indicated in RT 300. For each hour that the unit,
stack, or pipe did not operate, report a value of 0.00 in the field for unit operating time in RT 300. There
is one exception to this rule: for units that qualify as low mass emissions units under § 75.19, report unit
operating time (including non-operating hours) in RT 360 instead of RT 300.
(11) Blank Emissions or Other Values
For each operating hour report a non-blank emissions value and an appropriate method of
determination code.
(12) Missing Data and Percent Monitor Data Availability
The Part 75 standard missing data procedures in 40 CFR § 75.33 are based on percent monitor
data availability (PMA), which is calculated on a rolling annual basis (based on the previous 8,760 unit
operating hours). For infrequently-operated units that have fewer than 8,760 unit operating hours in the
past three years, PMA is calculated using all data from the past three years (26,280 clock hours). Percent
monitor data availability is calculated on a parameter basis (e.g.. S02 concentration, NOx emission rate,
stack flow rate, etc.), not on an individual analyzer or monitoring system basis (see 40 CFR § 75.32).
Reporting of PMA begins after the initial missing data procedures of § 75.31 have been applied for a
period of 720 (for 02, C02, and %H20) or 2,160 (for NOx or flow rate) quality-assured monitor
operating hours.
Percent monitor data availability is used to determine the appropriate substitute data values for
missing data periods. Although you may record the PMA for each hour of a missing data period, only the
PMA value at the end of the missing data period (i.e.. for the first hour in which quality-assured data are
available following the missing data period) is used to determine the substitute data values.
For a quarter in which a missing data period extends past the end of the quarter, the missing data
period is assumed to terminate with the end of the quarter. Use the PMA at the end of the quarter to
determine the correct substitute data values. For the next quarter, assume that a new missing data period
starts at the beginning of the quarter. Use the PMA at the end of this new missing data period to
determine the correct substitute data values.
Quality-assured monitor operating hours can occur only during unit operating (or partial
operating) hours. When the unit is not operating, monitor operating hours are not counted in the missing
data procedures. For example, if the monitoring system is down first for three hours with the unit still
operating, then for four more hours while the unit is down, and then the unit resumes operating while the
monitoring system is down for an additional three hours, the total missing data gap is six hours, even
though the monitoring system was down for a total of ten hours. If the missing data gap continues past
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the time when the unit restarts, hours on both sides of the unit down time are part of one single missing
data period.
When emissions are measured during a partial unit operating hour, the recorded values for that
hour are included in missing data substitution algorithms (including the availability calculation) as if the
hour were a full quality-assured monitor operating hour. The partial operating hour will also be treated
as a full hour in load ranges, in the missing data algorithm of the average of the hour before and hour
after, in the calculation of hours to determine a QA operating quarter, and in the reporting of quarterly,
ozone season, and year-to-date operating hours for RTs 301 and 307.
(13) Data Reporting Requirements for Uncertified Units
For new (non-deferred) units, submit quarterly reports beginning with the earlier of: (1) the
quarter in which the monitoring systems for the unit are provisionally certified; or (2) the quarter in which
the unit's compliance deadline occurs and emissions reporting from the unit is required. Existing
"deferred" units that are shut down at the time of the applicable compliance deadline (i.e.. on the program
participation date) must begin quarterly reporting on the date and hour that the unit recommences
commercial operation. Quarterly reports submitted before certification testing is completed and after the
compliance or program participation date must contain the following record types:
Table 1
REPORTING REQUIREMENTS FOR OPERATING UNCERTIFIED UNITS
R'I's
Acid Kitin lYognim
Suhpsirl II
100
Required
Required
101
Optional
Optional
102
Required
Required
Applicable Hourly RTs 200+ and 300+
(using appropriate maximum potential
values)
Required
Required
301
Required
Not applicable
307
Not applicable
Required
5XX*
Required
Required
900-901
Optional**
Not applicable
910
Optional
Optional
920
Optional
Optional
940-941
Not applicable
Optional**
999
Optional
Optional
* See Tables C, D, and A-l through A-13 in Appendix A for the applicable 500-level records.
** EPA recommends that certification statements be submitted electronically, rather than in hardcopy.
Clean Air Markets Division, U.S. EPA
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December 2005
EDR v2.2 Instructions
(14) Data Reporting Requirements for Non-operating Quarters
If you have been operating and reporting for a unit and your unit does not operate for a quarter
(and you do not notify EPA that the unit has permanently retired), you must still submit a quarterly report
for the non-operating quarter.
The quarterly report for a non-operating quarter must contain the following record types:
Table 2
REPORTING REQUIREMENTS FOR NON-OPERATING QUARTERS
RIs
Acid Uiiin IYo<>r;im
Suhpiirl II
100
Required
Required
102
Required
Required
301
Required
Not applicable
307
Required for LME only
Required
5XX*
Required
Required
900-901
Optional**
Not applicable
910
Optional
Optional
920
Optional
Optional
940-941
Not applicable
Optional**
999
Optional
Optional
* See Tables C, D, and A-l through A-13 in Appendix A for the applicable 500-level records.
** EPA recommends that certification statements be submitted electronically rather than in hardcopy.
No other record types should be submitted for a unit in a quarter in which the unit does not
operate.
If you elect to claim a deadline extension or exemption for a QA test (e.g.. RT 698 or 699) for a
non-operating quarter (or quarters), report this claim in the appropriate record type in the quarterly
report for the first operating quarter following the quarter(s) of non-operation.
Record Type Instructions for Non-operating Quarters
RT 301. The quarterly emissions and operations information in columns 16 through 25, 36
through 48, 62 through 71, 82 through 91, and 114 through 117 should contain zeros, not
blanks. If the unit operated for any other quarter in the calendar year for which the quarterly
report is being submitted, the cumulative emissions and operations information in columns 26
through 35, 49 through 61, 72 through 81, 92 through 101, and 118 through 121 must
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Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: RT 101
December 2005
contain the sum (or average, for NOx emission rate) of those emissions and operations values
from all prior quarters in the calendar year.
RT 307. The reporting period emissions and operations information in columns 18 through
27, 38 through 47, and 58 through 61 should contain zeros, not blanks. If the unit operated
for any other quarter in the calendar year for which the quarterly report is being submitted, the
cumulative emissions and operations information in columns 28 through 37, 48 through 57,
and 62 through 90 must contain the sum of those emissions and operations values from all
prior quarters in the calendar year.
Ill RECORD TYPE INSTRUCTIONS
A. Facility Records
(1) RT 100: Facility Identification
Report only one RT 100 in each quarterly report file. This record must be the first record in all
EDR submissions. This record identifies the facility represented by the data in the file.
Field Descriptions and Instructions
Facility/ORISPL Number (4). Report the ORISPL code or facility ID for the facility. The
number should be right-justified and padded to the left with leading zeros. The ORISPL code
is the same as the Department of Energy (DOE) plant or facility code. Obtain the
plant/facility code from the Energy Information Administration, Department of Energy (DOE)
Form EIA-860, "Annual Electric Generations Report" or Form EIA-867, "Annual Nonutility
Power Producer Report." If you do not have an ORISPL code for a plant/facility, contact
EPA's Clean Air Markets Division to determine what code to use.
Calendar Quarter Data Contained in Report (10). Report the calendar quarter
represented by the data (1, 2, 3, or 4). When submitting the initial monitoring plan for a new
or newly-affected unit, report the (projected) quarter of the first electronic quarterly report for
the unit.
Calendar Year Data Contained in Report (11). For a quarterly report submission, report
the calendar year represented by the data. When submitting the initial monitoring plan for a
new or newly-affected unit, report the (projected) calendar year of the first electronic
quarterly report for the unit.
EDR Version (15). Report the EDR version number used for the report as "V" followed by
the version number, Le^, enter "V2.2".
(2) RT 101: Record Types Submitted (Optional)
RTs 101 are optional records that indicate the record types included in the file for each unit,
stack, or pipe. RT 101 provides information to EPA on the content of each quarterly report file. RTs
101 do not merely summarize the record types in the file; instead, they are designed to identify for each
Clean Air Markets Division, U.S. EPA
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December 2005
EDR v2.2 Instructions: RT 101
unit, the stack or pipe IDs, record type, and number of records submitted for each pollutant. RT 101
provides a map to identify all stacks or pipes which are associated with a given unit for which data are
reported.
The first RT 101 reported should be the second record in the quarterly report file, immediately
following RT 100. For all units and stacks, list the RTs 101 in order by unit, stack ID, and parameter. If
there are no common or multiple stacks associated with the unit, leave the stack ID blank. Please note
that the order of RTs 101 is not the order in which these records appear in the quarterly report file.
There are seventeen types of records that may be associated with a unit or stack, as listed below.
Following this list are four examples of RTs 101 for reporting specific stack and unit configurations.
RT 101 Parameters Reported for All Units
This is a coal-fired unit with a single stack and the following monitoring approach: S02 CEM,
NOx(C02) CEM, and C02 CEM. This file includes data for fourth quarter 1994 (which has 2,208 hours
in all). The unit operated for all hours during the quarter and there were no periods of missing data.
C02CONC
C02MASS
DILUENT
FLOWRTE
GASRATE
HEATINP
LOWMASS
MOISTUR
NOXCONC
NOXMASS
NOXRATE
OILRATE
OPERATN
OSNSUMM
QTRSUMM
S02CONC
S02MASS
C02 Concentration Records (ARP)
C02 Mass Emissions Records (ARP)
Diluent Records
Flow Rate Records
Gas Fuel Flow Records
Heat Input Rate Records (Subpart H)
Hourly Low Mass Emission Records
Hourly Moisture Records
NOx Concentration Records
NOx Mass Emission (Subpart H)
NOx Emission Rate Records
Oil Fuel Flow Records
Operating Records
Ozone Season Summary (Subpart H)
Quarterly/Annual Cumulative Totals (ARP)
S02 Concentration Records (ARP)
S02 Mass Emissions Records (ARP)
EXAMPLE #1: SINGLE ACID RAIN COAL-FIRED UNIT
UNIT ID: 1
Page 20
Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: RT 101
December 2005
Record
Type
I nil II)
Stsick/Pipe
ID
P:ir:imcler
Record Type
I sod
# of Records
101
1
C02CONC
202
2208
1
C02MASS
330
2208
1
DILUENT
210
2208
1
FLOWRTE
220
2208
1
NOXCONC
201
2208
1
NOXRATE
320
2208
1
OPERATN
300
2208
1
QTRSUMM
301
1
1
S02CONC
200
2208
1
S02MASS
310
2208
EXAMPLE #2: SINGLE ACID RAIN OIL-FIRED UNIT USING
APPENDIX D AND APPENDIX G
UNHID: 3
This is a single oil-fired unit with one stack and the following monitoring approach: ADC
(Appendix D) for S02, N0X(C02) CEM, and FSA (Appendix G) for C02. This file contains data for
second quarter 1994 (which has 2,184 hours in all). The unit operated for all hours during the quarter.
The NOx monitor was out-of-control for 240 hours during the quarter and there are no backup systems.
Record
Type
I nil II)
Stsick/Pipe
ID
Piirnmeler
Record Type
I sed
# of Records
101
3
C02MASS
331
91
3
DILUENT
210
1944
3
NOXCONC
201
1944
3
NOXRATE
320
2184
3
OILRATE
302
2184
3
OPERATN
300
2184
3
QTRSUMM
301
1
3
S02MASS
313
2184
Clean Air Markets Division, U.S. EPA
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December 2005
EDR v2.2 Instructions: RT 101
EXAMPLE #3: ACID RAIN COAL-FIRED UNIT WITH MULTIPLE STACKS
UNHID: 4
STACK IDs: MS4A, MS4B
This is a coal-fired Acid Rain unit with two stacks. For each stack the utility uses the following
monitoring approach: S02 CEM, N0X(C02) CEM, and C02 CEM. Because the emissions are not
thoroughly mixed, the source must monitor NOx in both stacks and use flow to calculate a unit-level NOx
emissions rate. This file includes data for first quarter 1994 (which has 2,160 hours in all). Unit 4 was
shut down for maintenance for 720 hours during the quarter. There were no periods of missing data.
Record
Type
I nil II)
Stuck/Pipe
10
P;ir:imctcr
Record Type
I sod
# of Records
101
4
OPERATN
300
2160
4
QTRSUMM
301
1
4
MS4A
C02CONC
202
1440
4
MS4A
C02MASS
330
1440
4
MS4A
DILUENT
210
1440
4
MS4A
FLOWRTE
220
1440
4
MS4A
NOXCONC
201
1440
4
MS4A
NOXRATE
320
1440
4
MS4A
OPERATN
300
2160
4
MS4A
QTRSUMM
301
1
4
MS4A
S02CONC
200
1440
4
MS4A
S02MASS
310
1440
4
MS4B
C02CONC
202
1440
4
MS4B
C02MASS
330
1440
4
MS4B
DILUENT
210
1440
4
MS4B
FLOWRTE
220
1440
4
MS4B
NOXCONC
201
1440
4
MS4B
NOXRATE
320
1440
4
MS4B
OPERATN
300
2160
4
MS4B
QTRSUMM
301
1
4
MS4B
S02CONC
200
1440
4
MS4B
S02MASS
310
1440
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Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: RT 101
December 2005
EXAMPLE #4: TWO ACID RAIN UNITS IN A COMMON STACK
UNHID: 1,2
STACK ID: CS0001
Units 1 and 2 are monitored for S02 and NOx at CS0001 with the following monitoring approach:
S02 CEM and N0X(02) CEM. The C02 monitoring approach for each unit is FSA (Appendix G). This
file contains data for third quarter 1994 (which has 2,208 hours in all). Unit 2 only operated for 30 days
during the quarter.
Record
Type
I nil II)
Slsick/Pipc
ID
Piiriimclcr
Record Type
I sed
#of
Records
101
CS0001
OPERATN
300
2208
CS0001
QTRSUMM
301
1
1
C02MASS
331
92
1
OPERATN
300
2208
1
QTRSUMM
301
1
1
CS0001
DILUENT
211
2208
1
CS0001
FLOWRTE
220
2208
1
CS0001
NOXCONC
201
2208
1
CS0001
NOXRATE
320
2208
1
CS0001
S02C0NC
200
2208
1
CS0001
S02MASS
310
2208
2
C02MASS
331
30
2
OPERATN
300
2208
2
QTRSUMM
301
1
2
CS0001
DILUENT
211
2208
2
CS0001
FLOWRTE
220
2208
2
CS0001
NOXCONC
201
2208
2
CS0001
NOXRATE
320
2208
2
CS0001
S02C0NC
200
2208
2
CS0001
S02MASS
310
2208
Clean Air Markets Division, U.S. EPA
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December 2005
EDR v2.2 Instructions: RT 102
(3) RT 102: Facility Location and Identification Information
Include only one RT 102 in each quarterly report file, certification, or monitoring plan file. This
record contains information that identifies the facility and its location.
Field Descriptions and Instructions
Plant Name (4). Report the name of the facility, as it appears in the National Allowance
Database (NADB) (for Acid Rain units) or a similar inventory. If a non-Acid Rain Subpart H
unit is located at the same facility as an Acid Rain unit, use the facility name as it appears in
the NADB. The facility name must be the same for units that are affected by both the Acid
Rain Program and Subpart H.
(Reserved) (24). This field, formerly used for the FINDS ID, is reserved. Leave this field
blank.
EPA AIRS Facility System (AFS) ID (36). Report the ten digit AIRS AFS ID for your
facility. The first two digits of this ID are the State code, the next three are the FIPS county
code, and the last five are the CDS plant ID. Contact your EPA Regional Office if you do not
know this identifier. If your EPA Regional Office cannot provide this ID, leave the field
blank. This is not the four digit NEDS ID.
State Facility ID (46). Provide the State ID required by the applicable State regulatory
agency. Each State will provide specific instructions about the content of this field or about
locating the ID. This is not required for units subject only to the Acid Rain Program.
Source Category/Type (61). Describe the facility type. If applicable, use the following
uppercase descriptions:
AUTOMOTIVE STAMPINGS
BULK INDUSTRIAL CHEM
CEMENT MANUFACTURING
COGENERATION
ELECTRIC UTILITY
INDUSTRIAL BOILER
INDUSTRIAL TURBINE
INSTITUTIONAL
IRON & STEEL
MUNICIPAL WASTE COMB
PETROLEUM REFINERY
PULP & PAPER MILL
SMALL POWER PRODUCER
THEME PARK
If a unit does not fit one of these categories, contact EPA to agree on an appropriate
description. Do not leave this field blank.
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Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: RT 200
December 2005
Primary SIC Code (81). Report the primary Standard Industrial Classification code for the
plant (for example, 4911 for electric utilities).
You can get your SIC code from EPA's Monitoring Data Checking (MDC) software. If
MDC does not contain the correct code for your plant, contact EPA.
State Postal Abbreviation (85). Report the two-character postal abbreviation for the State
in which the facility is located. Do not leave this field blank.
County Code (FIPS) (87). Report the three-digit federal county code for the county in
which the facility is located. Do not leave this field blank.
[Reserved] (90). This field is reserved. Leave this field blank.
Latitude and Longitude (91, 97). Report the coordinates representing the facility location.
Latitude/longitude coordinates must be in accordance with Federal Interagency Coordinating
Committee for Digital Cartography (FICCDC) recommendations.
The format for representing this information is:
DDMMSS (latitude)
DDDMMSS (longitude)
Where:
DD represents degrees of latitude; a two-digit decimal number ranging from 00 through
90.
DDD represents degrees of longitude; a three-digit decimal number ranging from 000
through 180.
MM represent minutes of latitude or longitude; a two-digit decimal number ranging from
00 through 60.
SS represents seconds of latitude or longitude.
All latitudes are assumed to be north of the equator and longitudes are assumed to be west of
the prime meridian. Do not leave these fields blank.
B. Hourly Emissions and Quality Assurance Records and Emissions Summary Records
(RTs 200+ through 300+)
(1) RT 200: S02 Concentration Data (ARP)
If you use continuous emissions monitoring (CEM) to determine S02 mass emissions under the
Acid Rain Program, report S02 concentration in RT 200 for each hour or partial hour of unit operation,
with one exception: Do not report RT 200 for hours in which only gaseous fuel is combusted, if you
Clean Air Markets Division, U.S. EPA
Page 25
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December 2005
EDR v2.2 Instructions: RT 200
account for S02 mass emissions during those hours using the provisions of § 75.11(e)(1) or (e)(2), in lieu
of operating and recording data from the S02 monitoring system.
Field Descriptions and Instructions
Component and Monitoring System ID (10, 13). For each hour of quality-assured
data, identify the monitoring system and component used during the hour. If you have
missing data, leave these fields blank. Note that hours in which the flue gases are
discharged through an unmonitored bypass stack are considered to be missing data hours.
Report the monitoring system and component IDs of the monitoring system in use at the
time of any of the following occurrences: (1) when you report the 2.0 ppm default value
for an hour during which very low sulfur fuel (as defined in § 72.2) is combusted and the
bias-adjusted hourly average S02 concentration is below 2.0 ppm; or (2) when you use a
default high range value of 200% of the MPC in the calculation of the hourly average S02
concentration; or (3) when a full-scale exceedance of the high range occurs and you use a
value of 200% of the range in the calculation of the hourly average S02 concentration. In
these cases, the hours are treated as quality-assured monitor operating hours. They are
included in missing data lookback and are counted as available hours for percent monitor
data availability calculations.
If a like-kind replacement non-redundant backup analyzer is used during a period of
maintenance or repair of the primary analyzer (see § 75.20(d)), report the primary
monitoring system ID; however, for the like-kind replacement analyzer component, assign
a unique component ID number (beginning with the prefix "LK" as defined in RT
510—e.g.. "LK1"). The like-kind replacement analyzer component ID may be manually
entered.
For units with add-on S02 emission controls, if you report data from a certified inlet
monitor, report the system and component ID for the monitor. You may report from an
inlet monitor in lieu of reporting the MPC:
• During hours in which the flue gases are routed through an unmonitored bypass stack
(§ 75.16(c)(3)); or
• During hours when the outlet S02 monitor is unavailable and proper operation of the
add-on controls is not verified (§ 75.34 (a)(1)).
Percent Monitor Data Availability for S02 (24). Report the percent monitor data
availability for each hour unless data are substituted using Part 75 missing data
procedures. It is optional to report percent monitor availability during hours in which
missing data are substituted.
For units with add-on S02 emission controls:
(1) If you report the MPC for hours in which the flue gases are routed through an
unmonitored bypass stack, or when the outlet S02 monitor is unavailable and proper
operation of the emission controls is not verified, do not include these hours in the
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Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: RT 200
December 2005
calculation of percent monitor data availability. Treat these hours as missing data
hours; or
(2) If you report data from a certified inlet monitor during hours in which the flue gases
are routed through an unmonitored bypass stack, or when the outlet S02 monitor is
unavailable and proper operation of the emission controls is not verified, include these
hours in the missing data lookbacks and treat them as available hours in the PMA
calculations.
Average S02 Concentration for the Hour (29). Report the unadjusted, quality-assured
S02 concentration for the hour, expressed in parts per million, rounded to one decimal
place. Leave this field blank for hours in which you use substitute data.
Leave this field blank for hours in which the flue gases are routed through an unmonitored
bypass stack, or when the outlet S02 monitor is unavailable and proper operation of the
emission controls is not verified, if you report the MPC for those hours. However, if you
report data from a certified inlet monitor during those hours, report the unadjusted S02
concentration recorded by the monitor.
Do not leave this field blank for hours in which: (1) very low sulfur fuel is combusted and
you report a 2.0 ppm default value in column 35; or (2) you use the default high range
value of 200% of the MPC in the calculation of the hourly S02 concentration; or (3) a full-
scale exceedance occurs and you use 200% of the range in the calculation of the hourly
S02 concentration. All of the hours described in (1) - (3), above, are treated as quality-
assured monitor operating hours.
Average S02 Concentration for the Hour Adjusted for Bias (35). For each hour in
which you obtain quality-assured values, apply the appropriate bias adjustment factor
(BAF) to the rounded average S02 concentration for the hour and report the adjusted S02
concentration for the hour in ppm, also rounded to one decimal place.
(Note that for an initial certification, analyzer replacement, or complete monitoring
system replacement (as indicated by reporting an RT 556 with an Event Code of
100, 101, 120 or 125), if you are using conditional data validation, the BAF is
uncertain during the conditional data period. Therefore, apply a BAF of 1.000
from the beginning of the conditional data validation period to the completion hour
of the certification or recertification RATA.)
For each hour in which you use missing data procedures, report the substitute data value.
For each hour in which the flue gases are routed through an unmonitored bypass stack, or
when the outlet S02 monitor is unavailable and proper operation of the emission controls
is not verified, you may either report the MPC in this field or, if data are available from a
certified inlet monitor, report the bias-adjusted S02 concentration measured by the
monitor.
Clean Air Markets Division, U.S. EPA
Page 27
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December 2005
EDR v2.2 Instructions: RT 200
For each hour in which only very low sulfur fuel (as defined in § 72.2) is combusted,
report the bias-adjusted hourly average S02 concentration unless it is less than 2.0 ppm,
in which case, report 2.0 ppm.
For each hour in which a default high range value is used in the calculation of the hourly
average S02 concentration, report the bias-adjusted hourly average in this field unless
application of the BAF causes the hourly average to exceed 200% of the MPC, in which
case, report 200% of the MPC.
When a full-scale exceedance of the high range occurs and 200% of the range is used in
the calculation of the hourly average S02 concentration, report the bias-adjusted hourly
average in this field unless application of the BAF causes the hourly average to exceed
200% of the range, in which case, report 200% of the range.
See Questions 10.27 through 10.29 in the Part 75 Policy Manual for a further discussion
of overscaling and use of the default high range value.
Method of Determination Code (41). Report one of the following method of
determination codes (MODC) to identify the type of monitoring system or value used to
measure and report S02 concentration for the hour. Manual entry of MODCs "16", "17",
and "21" is permitted.
01 Primary Monitoring System
02 Redundant Backup or Regular Non-redundant Backup Monitoring System
03 Approved Subpart E Alternative Monitoring System
04 Reference Method Backup System (Method 6A)
05 Preapproved Parametric Monitoring Method Data for Controlled Units
06 Average Hour Before/Hour After
07 Average Hourly Concentration, Initial Missing Data
08 90th Percentile Value in Lookback Period
09 95th Percentile Value in Lookback Period
10 Maximum Hourly S02 Concentration Value in Lookback Period
12 Maximum Potential Concentration of S02 (see Section 2.1 of Appendix A
to Part 75)
16 S02 Concentration Value of 2.0 ppm During Hours When Very Low
Sulfur Fuel is Combusted. These hours are included in missing data
lookback and are treated as available hours for percent availability
calculation.
17 Like-kind Replacement Analyzer
19 200% of MPC; Default High Range Value Used in the Calculation of the
Hourly Average S02 Concentration. These hours are included in missing
data lookback and are treated as available hours for percent availability
calculations.
20 200% of the Full-scale Range Used in the Calculation of the Hourly
Average S02 Concentration (full-scale exceedance of high range). These
hours are included in missing data lookback and are treated as available
hours for percent availability calculations.
21 Negative Hourly Average S02 Concentration Replaced With Zero
Page 28 Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: RT 201
December 2005
23
22
55
54
S02 concentration from a certified monitor at the control device inlet, when
exhaust gases are routed through an unmonitored bypass stack, or when
the outlet S02 monitor is unavailable and proper operation of the emission
controls is not verified. These hours are included in missing data lookback
and are treated as available hours for percent availability calculations.
Maximum Potential Concentration of S02, When Flue Gases are Routed
Through an Unmonitored Bypass Stack. These hours are considered to be
missing data hours.
Other Quality-assured Methodologies Approved Through Petition by EPA.
These hours are included in missing data lookback and are treated as
unavailable hours for percent availability calculations.
Other Substitute Data Approved Through Petition by EPA. These hours
are not included in missing data lookback and are treated as unavailable
hours for percent availability calculations.
EPA has reserved codes 01 through 55. Codes 56 through 99 may be used by vendors
and companies for other purposes but must not be reported in a quarterly report.
(Note: When very low sulfur fuel is combusted, if a negative S02 concentration is
replaced (in column 29) with a value of zero ppm and the 2.0 ppm default S02
concentration is reported in column 35, report the MODC of "16", rather than
"21" for that hour.)
(2) RT201: NOx Concentration Data
Reporting Requirements for NOx Emission Rate Only
If you use a NOx-diluent monitoring system to determine and report the NOx emission rate in RT
320, then report RT 201 for each unit or stack operating hour in which a quality-assured NOx
concentration is available and a quality-assured diluent gas (C02 or 02) concentration is available. Report
RT 201 using the NOx diluent monitoring system ID using columns 1 through 31 only. If NOx
concentration is missing for an hour, or if the diluent concentration is missing for the hour, report the
appropriate substitute data value for NOx emission rate in RT 320 and do not report RT 201. Note that
for units with add-on NOx emission controls, hours in which the flue gases are discharged through an
unmonitored bypass stack are considered to be missing data hours. However, when the outlet NOx
monitor is unavailable and proper operation of the emission controls is not verified, § 75.34 (a)(1) allows
you to report data for from a certified NOx monitor at the control device inlet. If you choose this option,
these hours are treated as "available " hours, for the purposes of the missing data lookbacks and PMA
calculations (see instructions below for columns 10, 13, 24, 30 and 32).
Reporting Requirements for NOx Mass Calculations
For units subject to Subpart H, you may use either NOx emission rate times heat input rate or NOx
concentration times stack flow as the primary methodology for calculating hourly NOx mass emissions. If
you use NOx emission rate times heat input rate as the primary methodology, you may elect to use NOx
concentration times stack flow as a secondary (backup) methodology for any hour in which NOx
concentration is available and the diluent concentration is unavailable. The following general rules apply
to reporting in RT 201 for each of these options:
Clean Air Markets Division, U.S. EPA
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December 2005
EDR v2.2 Instructions: RT 201
(a) If NOx emission rate times heat input rate is the primary methodology for determining NOx
mass emissions:
Follow the instructions above under "Reporting Requirements for NOx Emission Rate
Only."
(b) If NOx concentration times stack flow is the primary methodology for determining NOx mass
emissions:
For hours (or partial hours) in which you use quality-assured data from a certified NOx
concentration system and flow monitoring system to calculate hourly NOx mass emissions
under Subpart H, report NOx concentration in RT 201. Report RT 201 using the NOx
concentration (NOXC) monitoring System ID and report data in columns 1 through 42. Do
not leave columns 32 and 38 blank. If NOx concentration is missing, report substitute data
in RT 201 using the applicable missing data procedures. Note that hours in which the flue
gases are discharged through an unmonitored bypass stack are considered to be missing data
hours. For units with add-on NOx emission controls, if you report data from a certified NOx
monitor at the control device inlet when the outlet NOx monitor is unavailable and proper
operation of the emission controls is not verified, treat these hours as "available" hours, for
the purposes of the missing data lookbacks and PMA calculations for the NOXC monitoring
system.
If you are required to report both the hourly NOx emission rate and the hourly NOx mass
emissions and if you elect to use NOx concentration times flow rate as the method of
determining NOx mass, you must report two RTs 201 for every hour in which quality-
assured data are obtained, (i.e.. one RT 201 under the NOx-diluent monitoring system ID
and one under the NOx concentration monitoring system ID). Then, when NOx
concentration is missing for the hour: (1) do not report RT 201 under the NOx-diluent
monitoring system ID and perform missing data substitution for NOx emission rate in RT
320; and (2) report RT 201 under the NOx concentration monitoring system ID and perform
missing data substitution for NOx concentration in RT 201.
(c) If NOx concentration times flow is a secondary methodology for NOx mass emissions:
For hours (or partial hours) in which the diluent monitor of your NOx-diluent system is
unavailable and you use a certified NOx concentration system and flow monitoring system as
a secondary (back up) methodology for calculating hourly NOx mass emissions under
Subpart H, report NOx concentration in RT 201. Report RT 201 using the NOx
concentration monitoring system ID and report data in columns 1 through 37. In column 32
report the bias-adjusted NOx concentration.
If the NOx and diluent concentration are both missing for the hour, do not use this
secondary methodology (NOx concentration times stack flow). Instead, use your primary
methodology (NOx emission rate times heat input rate) to calculate hourly NOx mass
emissions using a substitute NOx emission rate. Also, if you use the diluent concentration
from RT 210 or RT 211 to calculate heat input rate, use the appropriate substitute data
value for diluent gas concentration in the heat input rate equation.
Page 30
Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: RT 201
December 2005
For Acid Rain units which are also Subpart H units, RT 320 must be reported for every
operating hour, including hours in which the secondary NOx mass methodology is used. For
these units, perform missing data substitution in RT 320 and report RT 320 for each hour in
which you use the secondary NOx mass methodology.
For a summary of these requirements, see Table 3 below.
Reporting of High Range and Full Scale Exceedance Defaults
Treat any hour(s) in which a default high range value (200% of MPC) or a full scale exceedance
value (200% of range) is used in the calculation of the hourly average NOx concentration as follows:
(a) For NO., concentration monitoring systems: Treat these hours as quality-assured monitor
operating hours and include them in missing data lookback and as available hours for
percent monitor data availability calculations.
(b) For NO..-diluent monitoring systems:
1. If a quality-assured diluent value is available for the hour, treat the hour as quality-
assured data and use the appropriate NOx concentration value in conjunction with the
quality-assured average diluent gas concentration for the hour to calculate and report
NOx emission rate in RT 320.
2. If a quality-assured diluent gas concentration is not available for the hour, then consider
the NOx emission rate data for the hour to be missing and do not report RT 201 or RT
210 (or 211) for the hour. Instead, report the maximum potential NOx emission rate
(MER) as a substitute data value in RT 320 using an MODC of 25.
Clean Air Markets Division, U.S. EPA
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December 2005
EDR v2.2 Instructions: RT 201
Table 3
SUMMARY OF RT 201 REPORTING REQUIREMENTS
I so of \()s Aiiiilvzcr
Monitoring System
II) I sell
Report C olumns
Missing l):il;i
Instructions
For NOx emission rate
NOx-diluent monitoring
system ID
Columns 1
through 31
in RT 201
Perform NOx missing data substitution in
RT 320 (if NOx or diluent concentration
is unavailable). Do not report RT 201 for
the hour.
For NOx mass calculation using
NOx concentration times stack
flow as the primary method
NOx concentration
monitoring system ID
Columns 1
through 42
in RT 201
Perform missing data substitution for NOx
concentration in RT 201. Report RT 201
for the hour.
Subpart H-affected units: for NOx
mass calculation using NOx
emission rate times heat input
rate as the primary method and
NOx concentration times stack
flow rate as the secondary
(backup) method
NOx-diluent monitoring
system ID for hours that
primary method is used
Columns 1
through 31 in RT
201 for hours that
primary method is
used
(1) If NOx concentration is missing, use
the primary NOx mass
methodology.* Perform NOx
missing data substitution in RT 320.
Do not report RT 201.
(2) If a quality-assured NOx
concentration is available but diluent
concentration is missing, then either:
(a) Use the primary NOx mass
methodology and perform NOx
missing data substitution in
RT 320. Do not report RT 201;
NOx concentration
monitoring system ID
for hours that secondary
method is used
Columns 1
through 37 in RT
201 for hours that
secondary method
is used
or
(b) Use the secondary NOx
methodology. Report RT 201
under the NOx concentration
system ID, but do not report RT
320 unless the unit is also Acid
Rain-affected. If so, perform
NOx missing data substitution in
RT 320, report RT 320, and
suppress reporting of the RT 201
under the NOx diluent system
ID.
* The secondary (backup) method may only be used when a quality-assured NOx concentration is available.
Field Descriptions and Instructions
Component and Monitoring System ID (10, 13). For each hour of quality-assured
data, identify the monitoring system and component used during the hour.
If the NOx data from RT 201 are used to determine the hourly NOx emission rate, report
the monitoring system and component IDs for the NOx component of the NOx emission
rate monitoring system.
If the NOx concentration in RT 201 is used with the stack flow rate from RT 220 to
calculate NOx mass emissions, report the NOx concentration monitoring system ID and the
NOx component ID, as defined in the monitoring plan.
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EDR v2.2 Instructions: RT 201
December 2005
If you are using a NOx concentration monitoring system and have missing data, leave these
fields blank.
When reporting a default high range value of 200% of the MPC or when reporting a value
of 200% of the range during a full-scale exceedance of the high range, report the system
ID and the NOx component ID of the monitoring system in use at the time of the
occurrence of the full-scale exceedance.
If a like-kind replacement non-redundant backup analyzer is used during a period of
maintenance or repair of the primary analyzer (see § 75.20(d)), report the primary
monitoring system ID and assign and report a unique component ID (beginning with the
prefix "LK" as defined in RT 510 — e.g.. "LK1") for the like-kind replacement analyzer.
The like-kind replacement analyzer component ID may be manually entered.
For units with add-on NOx emission controls, if you report data from a certified inlet
monitor during hours in which the outlet NOx monitor is unavailable and proper operation
of the emission controls is not verified, report the system ID and component ID for the
inlet monitor.
Average NOx Concentration for the Hour (24). For both NOx concentration
monitoring systems and NOx-diluent monitoring systems, report the unadjusted, quality-
assured NOx concentration for the hour, expressed in parts per million, rounded to one
decimal place. For NOx concentration monitoring systems, leave this field blank for hours
in which you use substitute data for NOx concentration.
Do not leave this field blank for hours in which: (1) you use a default high range value of
200% of the MPC in the calculation of the hourly NOx concentration; or (2) a full-scale
exceedance occurs and you use 200% of the range in the calculation of the hourly NOx
concentration. All of the hours described in (1) and (2), above are treated as quality-
assured monitor operating hours. See Questions 10.27 through 10.29 in the Part 75
Policy Manual for further discussion of overscaling and use of the default high range.
For units with add-on NOx emission controls, if you report data from a certified control
device inlet monitor during hours in which the outlet NOx monitor is unavailable and
proper operation of the emission controls is not verified, report the average, unadjusted
NOx concentration recorded by the inlet monitor.
Method of Determination Code (30). Report one of the following method of
determination codes (MODC) to identify the type of monitoring system or missing data
procedures used to determine NOx concentration for the hour. Manual entry of MODCs
"17" and "21" is permitted.
All Systems
01 Primary Monitoring System
02 Redundant Backup or Regular Non-redundant Backup Monitoring System
03 Approved Subpart E Alternative Monitoring System
04 Reference Method Backup System (Method 7E)
Clean Air Markets Division, U.S. EPA
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December 2005
EDR v2.2 Instructions: RT 201
17 Like-kind Replacement Analyzer
19 200% of MPC; Default High Range Value Used in the Calculation of the
Hourly Average NOx Concentration. (These hourly concentrations or the
NOx emission rates calculated for these hours are included in missing data
lookback and are treated as available hours for percent availability
calculations for RT 201 or RT 320 as appropriate.)
20 200% of Full-scale Range Used in the Calculation of the Hourly Average
NOx Concentration. (These hourly concentrations or the NOx emission
rates calculated for these hours are included in missing data lookback and
are treated as available hours for percent availability calculations for RT
201 or RT 320 as appropriate.)
21 Negative Hourly Average NOx Concentration Replaced With Zero
22 NOx concentration from a certified monitoring system at the control device
inlet, when the outlet NOx monitor is unavailable and proper operation of
the emission controls is not verified. Include these hours in the missing
data lookbacks and treat them as available hours in the PMA calculations.
54 Other Quality-assured Methodologies Approved through Petition by EPA
(if data are submitted for the Acid Rain Program) or by EPA and the State
(if submitted solely for purposes of Subpart H). These hours are included
in missing data lookback and are treated as unavailable hours for percent
availability calculations.
Additional Codes for NO.. Concentration Monitoring Systems
06 Average Hour Before/Hour After
07 Average Hourly Concentration, Initial Missing Data
08 90th Percentile Value in Load Range Lookback Period
09 95th Percentile Value in Load Range Lookback Period
10 Part 75 Maximum Hourly Concentration Value in Load Range for
Lookback Period
11 Part 75 Average Hourly Concentration in Load Range
12 Part 75 Unit or Stack Maximum Potential Concentration (MPC)
23 Maximum Potential Concentration of NOx, When Flue Gases are Routed
Through an Unmonitored Bypass Stack. These hours are considered to be
missing data hours.
55 Other Substitute Data Approved through Petition by EPA (if data are
submitted for the Acid Rain Program) or by EPA and the State (if
submitted solely for purposes of Subpart H). These hours are not included
in missing data lookback and are treated as unavailable hours for percent
availability calculations.
EPA has reserved codes 01 through 55. Codes 56 through 99 may be used by vendors
and companies for other purposes but must not be reported in a quarterly report. MODCs
of 30, 31, 35, and 36 were defined in EDR v2.0 for OTC NBP units only and are not
allowed for Acid Rain or Subpart H reporting.
Page 34
Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: RT 201
December 2005
Adjusted Average NOx Concentration for the Hour (32).
Report data in this field only if you use NOx concentration times stack flow rate to
determine NOx mass emissions. Otherwise, leave it blank.
For each hour in which you obtain a quality-assured value and use NOx concentration
times stack flow as the methodology for NOx mass emissions calculations, apply the
appropriate adjustment factor (1.000 or system BAF) to the rounded average NOx
concentration for the hour. Report the adjusted average NOx concentration for the hour in
ppm, rounded to one decimal place.
(Note that for an initial certification, analyzer replacement, or complete monitoring
system replacement (as indicated by reporting an RT 556 with an Event Code of
100, 101, 120 or 125), if you are using conditional data validation, the BAF is
uncertain during the conditional data period. Therefore, apply a BAF of 1.000
from the beginning of the conditional data validation period to the completion hour
of the certification or recertification RATA.)
For each hour in which NOx concentration is missing, report the substitute NOx
concentration value.
For each hour in which a default high range value is used in the calculation of the hourly
average NOx concentration, report the bias-adjusted hourly average in this field unless it
exceeds 200% of the MPC, in which case, report 200% of the MPC.
When a full-scale exceedance of the high range occurs and 200% of the range is used in
the calculation of the hourly average NOx concentration, report the bias-adjusted hourly
average in this field unless it exceeds 200% of the range, in which case, report 200% of
the range.
For units with add-on NOx emission controls, if you report data from a certified NOx
monitor at the control device inlet during hours in which the outlet NOx monitor is
unavailable and proper operation of the emission controls is not verified, report the
average, bias-adjusted NOx concentration recorded by the monitor. Include these hours in
the missing data lookbacks and treat them as available hours in the PMA calculations.
Percent Monitor Data Availability for NOx Concentration (38). Report data in this
field only if you use NOx concentration times stack flow as the primary methodology for
NOx mass calculations for all hours. Report the percent monitor data availability for each
hour unless the hourly NOx concentration is unavailable and the Part 75 missing data
procedures are used. It is optional to report percent monitor data availability for hours in
which missing data are substituted.
Leave this field blank if you use NOx concentration times stack flow as a secondary
(backup) methodology.
Clean Air Markets Division, U.S. EPA
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December 2005
EDR v2.2 Instructions: RT 202
(3) RT 202: C02 Concentration Data (ARP)
Report RT 202 only if you use continuous emissions monitoring to determine C02 mass emissions
under the Acid Rain Program. If you use an 02 concentration monitor and Equation F-14a or F-14b to
determine C02 concentration for each hour, report both RT 211 and 202 for the hour (see the
instructions for RT 211). For non-Acid Rain Subpart H units, report the C02 diluent concentration
values used to calculate NOx emission rates and heat input rates in RT 210, not in RT 202.
(a) If you use a C02 monitor only to determine C02 mass emissions (and not for heat input rate
or NOx emission rate determination):
Report RT 202, under the C02 monitoring system ID, for each hour or partial hour of unit
operation. When the hourly C02 concentration is missing, or for hours in which the flue
gases are discharged through an unmonitored bypass stack, use the missing data routines in
§ 75.35 to provide substitute data values.
(b) If you use the same C02 monitor to account for C02 mass emissions and hourly heat input
rate (but not for NOx emission rate):
Report RT 202 under the C02 monitoring system ID and use the C02 data from RT 202 to
calculate the hourly C02 mass emissions and heat input rates. When the hourly C02
concentration is missing, or for hours in which the flue gases are discharged through an
unmonitored bypass stack, use the missing data procedures in §§ 75.35 and 75.36 to provide
substitute data values.
(c) If you use the same C02 monitor to account for C02 mass emissions and NOx emission rate
(but not heat input rate):
Report RT 202 under the C02 monitoring system ID and report RT 210 under the NOx-
diluent monitoring system ID. If the hourly C02 concentration is missing, or for hours in
which the flue gases are discharged through an unmonitored bypass stack, calculate and
report a substitute C02 concentration in RT 202, using the Part 75 missing data procedures
in § 75.35. Do not report RT 210 for the hour if: (1) a quality-assured C02 concentration is
not available; or (2) a quality-assured NOx concentration is not available; or (3) both (1) and
(2). Instead, report a substitute data value for NOx emission rate in RT 320.
(d) If you use the same C02 monitor to account for C02 mass emissions, heat input rate, and
NOx emission rate:
Report RT 202 under the C02 monitoring system ID and report RT 210 under the NOx-
diluent monitoring system ID. If the hourly C02 concentration is missing, or for hours in
which the flue gases are discharged through an unmonitored bypass stack, calculate and
report a substitute C02 concentration in RT 202, using the Part 75 missing data procedures
in §§ 75.35 and 75.36. Use the substitute data value in the heat input rate equation. Do not
report RT 210 for the hour if: (1) a quality-assured C02 concentration is not available; or (2)
a quality-assured NOx concentration is not available; or (3) both (1) and (2). Instead, report
a substitute data value for NOx emission rate in RT 320.
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Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: RT 202
December 2005
For a summary of these requirements, see Table 4 below.
Table 4
SUMMARY OF RT 202 REPORTING REQUIREMENTS (ARP)
I so of CO, Aiiiilv/or
Monitoring System
II) I soil
Report C olumns
Missing Instructions
For C02 mass emission
rate only
C02 monitoring system ID
Columns 1 through 36 in
RT 202
Perform C02 missing data
substitution in RT 202.
For heat input rate (HI)
and C02 mass emission
rate
C02 monitoring system ID for
both C02 mass and HI
Columns 1 through 36 in
RT 202
Perform C02 missing data
substitution in RT 202. Use
the substitute data value to
calculate heat input rate.
For C02 mass emission
rate and NOx emission rate
C02 monitoring system ID for
C02 mass (RT 202)
Columns 1 through 36 in
RT 202
Perform C02 missing data
substitution in RT 202.
NOx-diluent monitoring system
ID for NOx emission rate (RT
210)
Columns 1 through 30 in
RT 210
Perform NOx missing data
substitution in RT 320 for the
hour. Do not report RT 210.
For C02 mass emission
rate, NOx emission rate
and heat input rate
C02 monitoring system ID for
both C02 mass and HI (RT
202)
Columns 1 through 36 in
RT 202
Perform C02 missing data
substitution in RT 202. Use
the substitute data value to
calculate heat input rate.
NOx-diluent monitoring system
ID for NOx emission rate (RT
210)
Columns 1 through 30 in
RT 210
Perform NOx missing data
substitution in RT 320 for the
hour. Do not report RT 210.
Field Descriptions and Instructions
Component and Monitoring System ID (10, 13). For each hour of quality-assured
data, report the identification numbers of the monitoring system and component used
during the hour. For missing data hours, leave these fields blank.
If a full-scale exceedance value of 200% of the range is used in the calculation of the
hourly average C02 concentration, report the monitoring system and component IDs of
the monitoring system in use at the time of the occurrence. Treat such hours as though
they are quality-assured monitor operating hours; include them in missing data lookback
and count them as available hours for percent monitor data availability calculations.
If a like-kind replacement non-redundant backup analyzer is used during periods of
maintenance and repair of the primary analyzer (see § 75.20(d)), report the primary
monitoring system ID number and assign and report a unique component ID number
(beginning with the prefix "LK" as defined in RT 510, e.g.. "LK1") for the like-kind
replacement analyzer. The like-kind replacement analyzer component ID may be manually
entered.
Clean Air Markets Division, U.S. EPA
Page 37
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December 2005
EDR v2.2 Instructions: RT 202
Average C02 Concentration for the Hour (24). Report the quality-assured C02
concentration for the hour, expressed in percent C02 (%C02), rounded to one decimal
place. During hours in which you use substitute data, or for hours in which the flue gases
are discharged through an unmonitored bypass stack, report the substituted value obtained
from the C02 missing data procedures under §§75.35 or 75.36 (as applicable).
For each hour in which a diluent cap value is used to calculate C02 mass emissions or heat
input rate, report the actual quality-assured C02 concentration and appropriate MODC
(01 through 04). For each such hour, report the appropriate flag(s) in RT 300, column 56
and/or RT 330, column 43 if the diluent cap is being used to calculate heat input rate and
C02 mass emission rate. If you use Equation F-14B to determine C02 concentration from
02 concentration you must use the modified Equation F-14D to calculate %C02 from
%02 during hours in which you use the diluent cap (see Table 18 under RT 520). You
must also use the diluent cap value in the missing data lookback.
Method of Determination Code (30). Report one of the following method of
determination codes (MODC) to identify the type of monitoring system or missing data
procedure used to determine C02 concentration for the hour. Note that MODC 14 is no
longer valid for this record type. Manual entry of MODC "17" is permitted.
01 Primary Monitoring System
02 Redundant Backup Monitoring or Regular Non-redundant Backup System
03 Approved Subpart E Alternative Monitoring System
04 Reference Method Backup System (Method 3 A)
06 Average Hour Before/Hour After
07 Average Hourly Concentration, Initial Missing Data
08 90th Percentile Value in Lookback Period
09 95th Percentile Value in Lookback Period
10 Maximum Hourly C02 Concentration Value in Lookback Period
12 Maximum Potential Concentration of C02 (see Section 2.1.3.1 of
Appendix A to Part 75)
17 Like-kind Replacement Analyzer
20 200% of Full-scale Range Used in Hourly Average Percent C02
Calculation (full-scale exceedance of high range). These hours are included
in missing data lookback and are treated as available hours for percent
availability calculations.
54 Other Quality-assured Methodologies Approved Through Petition by EPA.
These hours are included in missing data lookback and are treated as
unavailable hours for percent availability calculations.
55 Other Substitute Data Approved Through Petition by EPA. These hours
are not included in missing data lookback and are treated as unavailable
hours for percent availability calculations.
EPA has reserved codes 01 through 55. Codes 56 through 99 may be used by vendors
and companies for other purposes but must not be reported in a quarterly report.
Percent Monitor Data Availability for C02 Concentration (32). Report the percent
monitor data availability for each hour unless missing data are substituted using Part 75
Page 38
Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: RT 210
December 2005
missing data procedures. It is optional to report percent monitor availability during hours
in which missing data are substituted.
(4) RT 210: C02 Diluent Concentration Data
Report RT 210 for each operating hour (or partial operating hour) to support NOx emission rate,
and/or heat input rate determination as follows:
(a) If the C02 concentration from RT 210 is used only to determine the hourly NOx emission
rate and not to determine hourly heat input rate:
Report RT 210 (under the NOx-diluent system monitoring ID) for each hour in which a
quality-assured C02 concentration is used with a quality-assured NOx concentration value to
calculate the NOx emission rate (reported in RT 320).
Do not report RT 210 for the hour if: (1) a quality-assured C02 concentration is not
available; or (2) a quality-assured NOx concentration is not available; or (3) both (1) and (2)
apply. Instead, report a substitute data value for NOx emission rate in RT 320. Note that
hours in which the flue gases are discharged through an unmonitored bypass stack are
considered to be missing data hours. (For these hours, do not report RT 210. In RT 320,
report the NOx MER and MODC 23.)
When a default high range value (200% of MPC) or a full-scale exceedance value (200% of
the range) is used in the calculation of the hourly average NOx concentration, the NOx
concentration is considered to be both quality-assured and available. Therefore, if a quality-
assured C02 concentration is available for that hour, report RT 210 and calculate the NOx
emission rate in the usual manner. However, if a quality-assured C02 concentration is not
available for that hour, the NOx emission rate data for the hour are considered missing. In
that case, do not report RT 210 for the hour and report the maximum potential NOx
emission rate (MER) as a substitute data value in RT 320, using an MODC of 25.
(b) For an Acid Rain unit using a C02 analyzer to determine C02 mass emissions, NOx emission
rate, and heat input rate:
Report RT 210 under the NOx-diluent monitoring system ID and follow the instructions in
(a) above. In this case, the C02 value used for heat input rate purposes and for C02 mass
emissions is reported (and substituted if necessary) in RT 202 (using the C02 monitoring
system ID) and not in RT 210.
(c) If the C02 concentration from RT 210 is used to determine the hourly NOx emission rate
and the hourly heat input rate:
Report RT 210 for every unit or stack operating hour or partial operating hour (under the
NOx-diluent monitoring system ID), including hours in which substitute data are reported in
RT 320 for NOx emission rate.
If the hourly C02 concentration is missing, or for hours in which the flue gases are
discharged through an unmonitored bypass stack: (1) calculate a substitute C02
Clean Air Markets Division, U.S. EPA
Page 39
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December 2005
EDR v2.2 Instructions: RT 210
concentration, using the Part 75 missing data procedures in § 75.36; (2) report the substitute
data value in RT 210; (3) use the substitute data value to calculate the heat input rate; and
(4) perform missing data substitution for RT 320 for the hour for NOx emission rate (for
unmonitored bypass stack hours, report NOx MER and MODC 23).
(d) If the C02 concentration from RT 210 is to be used only for heat input rate determination
(and not to determine NOx emission rate):
Define a C02 monitoring system in the monitoring plan. Then, report RT 210 (under the
C02 monitoring system ID) for every unit or stack operating hour.
When C02 concentration for the hour is missing, use the missing data procedures in § 75.36
to calculate an appropriate substitute C02 concentration. Report the value and use it for the
hourly heat input rate determination.
For a summary of these requirements, see Table 5 below.
Field Descriptions and Instructions
Component and Monitoring System ID (10, 13). If the C02 data from RT 210 are used
only to determine the hourly NOx emission rate or are used to determine both NOx
emission rate and hourly heat input rate, report the monitoring system and component IDs
for the C02 component of the NOx-diluent monitoring system.
If the C02 data from RT 210 are used only to determine heat input rate, report the
monitoring system and component IDs for the C02 component of the C02 monitoring
system certified for heat input rate purposes. If C02 concentration is missing for the hour
and this value is needed to determine hourly heat input rate, use missing data substitution
for the hour and leave the monitoring system and component ID blank. Note that hours in
which the flue gases are discharged through an unmonitored bypass stack are considered
to be missing data hours.
If a like-kind replacement non-redundant backup analyzer is used, during periods of
maintenance and repair of the primary analyzer (see § 75.20(d)), report the primary
monitoring system ID; for the like-kind replacement analyzer assign and report a unique
three-character component ID (beginning with the prefix "LK" as defined in RT 510, e.g..
"LK1"). The component ID of the like-kind analyzer may be manually entered.
Average C02 Concentration for the Hour (24). Report the C02 concentration for the
hour, expressed as percent (%C02), rounded to one decimal place. For each hour in
which you use the diluent cap value to calculate NOx emission rate, heat input rate, or C02
mass emissions, report the actual quality-assured C02 concentration in RT 210 and
appropriate MODC (01 through 04). There is one exception to this — if the actual
measured hourly average C02 concentration is negative or zero and you use the diluent
cap, report the cap value in RT 210 (see section II. C. (3). (a).2 of these Instructions).
For each hour in which the diluent cap is used for NOx emission rate, report an MODC of
14 in RT 320, column 53. If the diluent cap is used to calculate heat input rate and C02
Page 40
Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: RT 210
December 2005
mass emission rate, report the appropriate flag(s) in RT 300, column 56 and/or RT 330,
column 43. The use of the diluent cap is optional for any type of unit, but if you use it to
calculate C02 mass emission rate you must also use it to calculate the heat input rate.
If you use the C02 diluent monitor only for heat input rate determination, but not to
determine C02 mass emissions (i.e.. for the third or fourth case in Table 5, below), then,
for any hour in which the flue gases are routed through an unmonitored bypass stack,
report the substitute C02 concentration calculated using the missing data procedures in
§ 75.36. If you use the C02 monitor to determine C02 mass emissions as well as heat
input rate (i.e.. the second case in Table 5), perform the missing data substitution in RT
202.
Table 5
SUMMARY OF RT 210 REPORTING REQUIREMENTS
I so of CO, Diluent
Aiiiilv/or
Monitoring System
II) I soil
Report Columns
Missing Instructions
For NOx emission rate only
NOx-diluent system
monitoring ID
Columns 1 through 30 in
RT 210
Perform NOx missing data
substitution in RT 320 for the
hour. Do not report RT 210.
For NOx emission rate, heat
input rate and C02 mass
emissions (Acid Rain only)
NOx-diluent monitoring
system ID for NOx emission
rate (RT 210)
Columns 1 through 30 in
RT 210
Perform NOx missing data
substitution in RT 320 for the
hour. Do not report RT 210.
C02 monitoring system ID
for HI and C02 mass (RT
202)
Columns 1 through 36 in
RT 202
Perform C02 missing data
substitution in RT 202. Use
the substitute data value in the
heat input rate equation.
For NOx emission rate and
heat input rate
NOx-diluent system
monitoring ID
Columns 1 through 35 in
RT 210
Perform C02 missing data
substitution in RT 210. Use
the substitute data value in the
heat input rate equation.
Also perform NOx missing
data substitution in RT 320 for
the hour for NOx emission rate.
For heat input rate only
C02 monitoring system ID
Columns 1 through 35 in
RT 210
Perform C02 missing data
substitution in RT 210 for the
hour. Use the substitute data
value in the heat input rate
equation.
Method of Determination Code (29). This field is required for all hours in which RT
210 is reported. Do not leave this field blank. Report one of the following method of
determination codes (MODC) to identify the type of monitoring system or missing data
procedure used to determine C02 concentration for the hour. Manual entry of MODC
Clean Air Markets Division, U.S. EPA
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December 2005
EDR v2.2 Instructions: RT 211
"17" is permitted. Codes 06 through 12 apply only when a C02 monitor is used for heat
input rate determinations. Codes 06 through 12 do not apply when the necessary C02
data for heat input rate determinations are obtained from RT 202.
All Systems
01 Primary Monitoring System
02 Redundant Backup or Regular Non-redundant Backup Monitoring System
03 Approved Part 75 Alternative Monitoring System
04 Reference Method Backup System (Method 3 A)
Additional C(X Codes for Heat Input Rate Determinations
06 Average Hour Before/Hour After
07 Average Hourly Concentration, Initial Missing Data
08 90th Percentile Value in Lookback Period
09 95th Percentile Value in Lookback Period
10 Maximum Hourly C02 Concentration in Lookback Period
12 Maximum Potential Concentration (Section 2.1.3.1 of Appendix A to
Part 75)
17 Like-kind Replacement Analyzer
20 200% of Full-scale Range Used in the Calculation of the Hourly Average
C02 Concentration. These hours are included in missing data lookback and
are treated as available hours for percent availability calculations..
54 Other Quality-assured Methodologies Approved Through Petition by EPA
and the State (if submitted solely for purposes of Subpart H). These hours
are included in missing data lookback and are treated as unavailable hours
for percent availability calculations.
55 Other Substitute Data Approved Through Petition by EPA and the State (if
submitted solely for purposes of Subpart H). These hours are not included
in missing data lookback and are treated as unavailable hours for percent
availability calculations.
EPA has reserved codes 01 through 55. Codes for 56 through 99 may be used by vendors
and companies for other purposes but must not be reported in a quarterly report. An
MODC of 30 was defined in EDR v2.0 for OTC NBP units only and is not allowed for
Acid Rain or Subpart H reporting.
Percent Monitor Availability for C02 Concentration (31). Report percent monitor
data availability in RT 210 only when the C02 data in RT 210 are used for determining
heat input rate (i.e.. for the third or fourth case in Table 5, above). It is optional to report
percent monitor availability during hours in which missing data are substituted.
(5) RT 211: 02 Diluent Concentration Data
For each hour in which you obtain a quality-assured 02 concentration and use this value to
determine the hourly NOx emission rate, heat input rate, C02 concentration, or percent moisture, report
the 02 concentration in RT 211.
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Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: RT 211
December 2005
(a) If the 02 concentration from RT 211 is used only to determine the hourly NOx emission rate:
Report RT 211 (under the NOx-diluent monitoring system ID) for each hour in which a
quality-assured 02 concentration is obtained and is used with a quality-assured NOx
concentration to calculate a quality-assured NOx emission rate (reported in RT 320).
Do not report RT 211 for the hour if: (1) a quality-assured 02 concentration is not available;
or (2) a quality-assured NOx concentration is not available; or (3) both (1) and (2) apply.
Instead, report a substitute data value for NOx emission rate in RT 320. Note that hours in
which the flue gases are discharged through an unmonitored bypass stack are considered to
be missing data hours. (For these hours, do not report RT 211. In RT 320, report the NOx
MER and MODC 23 .)
When a default high range value (200% of MPC) or a full-scale exceedance value (200% of
the range) is used in the calculation of the hourly average NOx concentration, the NOx
concentration is considered to be both quality-assured and available. Therefore, if a quality-
assured 02 concentration is available for the hour, calculate and report the NOx emission rate
in the usual manner. However, if a quality-assured 02 concentration is not available for the
hour, the NOx emission rate data for the hour are considered to be missing. In that case, do
not report RT 211 for the hour and report the maximum potential NOx emission rate (MER)
as a substitute data value in RT 320, using an MODC of 25.
(b) If the 02 concentration from RT 211 is used to determine both the hourly NOx emission rate
and the hourly heat input rate:
Report RT 211 for every unit or stack operating hour or partial operating hour (under the
NOx-diluent monitoring system ID).
If the hourly 02 concentration is missing or for hours in which the flue gases are discharged
through an unmonitored bypass stack, calculate a substitute 02 concentration, using the Part
75 missing data procedures in § 75.36. Report the substitute data value in RT 211 and use it
for the hourly heat input rate determination. Also perform missing data substitution for NOx
emission rate in RT 320 (for unmonitored bypass stack hours, report NOx MER and MODC
23). Hours in which the flue gases are discharged through an unmonitored bypass stack are
considered to be missing data hours.
(c) If the 02 concentration from RT 211 is used only to determine the hourly heat input rate:
Define an 02 monitoring system in the monitoring plan. Report RT 211 (under the 02
monitoring system ID) for every unit or stack operating hour.
When 02 concentration for the hour is missing or for hours in which the flue gases are
discharged through an unmonitored bypass stack, use the missing data procedures in § 75.36
to calculate an appropriate substitute 02 concentration in RT 211 for the hourly heat input
rate determination. Hours in which the flue gases are discharged through an unmonitored
bypass stack are considered to be missing data hours.
Clean Air Markets Division, U.S. EPA
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December 2005
EDR v2.2 Instructions: RT 211
(d) If you use wet and dry 02 analyzers only to determine the hourly percent moisture:
Report two RTs 211 for each hour under the moisture monitoring system ID. Report one
RT 211 with a "W" in column 31 and report the other RT 211 with a "D" in column 31, as
appropriate.
If either 02 value is missing or for hours in which the flue gases are discharged through an
unmonitored bypass stack, perform missing moisture data substitution in RT 212, in
accordance with § 75.37.
(e) If the 02 concentrations from RTs 211 are used to determine both hourly percent moisture
and hourly heat input rate (but not NOx emission rate):
Report one RT 211 under the 02 monitoring system ID and report a second RT 211 under
the moisture monitoring system ID. Report one RT 211 with a "W" and the other with a "D"
in column 31, as appropriate.
If either 02 value is missing or for hours in which the flue gases are discharged through an
unmonitored bypass stack, perform missing moisture data substitution in RT 212, in
accordance with § 75.37. Do not report RT 211 for the hour under the moisture monitoring
system ID.
When the 02 concentration used for heat input rate determination is missing or for hours in
which the flue gases are discharged through an unmonitored bypass stack, use the missing
data procedures in § 75.36 to calculate an appropriate substitute 02 concentration in RT 211
for the hourly heat input rate determination.
(f) If you define a moisture system comprised of wet and dry 02 analyzers and one of the 02
analyzers is also part of a NOx-diluent system:
Report one RT 211 under the NOx-diluent monitoring system ID and report a second RT 211
under the moisture monitoring system ID. Report one RT 211 with a "W" and the other with
a "D" in column 31, as appropriate.
For hours in which the flue gases are discharged through an unmonitored bypass stack,
perform the missing data substitution for percent moisture in RT 212 using the procedures in
§ 75.37 and report NOx MER and MODC 23 in RT 320.
If the 02 concentration needed for the NOx emission rate determination is missing for the
hour, then: (1) perform missing data substitution in RT 320 for NOx emission rate; (2) do
not report any RTs 211 for the hour; and (3) perform missing data substitution for percent
moisture in RT 212 using the procedures in § 75.37.
If the 02 concentration needed only for moisture determination is missing for the hour but the
other 02 concentration is available, perform missing data substitution for percent moisture in
RT 212. Do not report RT 211 for the hour under the moisture monitoring system ID.
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Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: RT 211
December 2005
(g) If the 02 concentration from RT 211 is used to calculate C02 concentration using Equations
F-14A or F-14B and this C02 value is used to determine hourly C02 mass emissions:
(1) If the 02 analyzer is used to determine C02 concentration but not for NOx emission
rate, define a C02 monitoring system in the monitoring plan. Report RT 211 (under the
C02 monitoring system ID) for each hour in which a quality-assured 02 concentration
is obtained. If a quality-assured 02 concentration is not available or for hours in which
the flue gases are discharged through an unmonitored bypass stack, then: (a) perform
missing C02 data substitution in RT 202, according to § 75.35, and (b) do not report
RT 211 for that hour unless the 02 data are needed for heat input rate determination, in
which case, also perform missing 02 data substitution in RT 211, according to the
procedures in § 75.36.
(2) If the 02 analyzer is also part of a NOx-diluent system and you use the same 02 hourly
value for both NOx emission rate and C02 concentration, report RT 211 under the
NOx-diluent system ID. Calculate and report in RT 202 the C02 concentration (under
the C02 monitoring system ID) based on the 02 value reported in RT 211. If a quality-
assured 02 concentration is not available for the hour or for hours in which the flue
gases are discharged through an unmonitored bypass stack, then: (a) perform missing
C02 data substitution in RT 202, according to § 75.35; (b) perform missing data
substitution in RT 320 for NOx emission rate (but for unmonitored bypass stack hours,
report NOx MER and MODC 23); and (c) do not report RT 211 for that hour unless 02
data are needed for heat input rate determination, in which case also perform missing
02 data substitution in RT 211, according to the procedures in § 75.36.
For a summary of these requirements, see Table 6 below.
Field Descriptions and Instructions
Component and Monitoring System ID (10, 13). If the 02 data in a particular RT 211
are used to determine: (1) hourly NOx emission rate only; or (2) both hourly NOx
emission rate and heat input rate; or (3) both hourly NOx emission rate and moisture; or
(4) both hourly NOx emission rate and C02 concentration, report the monitoring system
and component IDs for the 02 component of the NOx emission rate monitoring system.
If the 02 data in a particular RT 211 are only used for heat input rate determination, define
an 02 monitoring system in your monitoring plan. Report the monitoring system ID and
the 02 component ID as defined in the 02 system.
If the 02 data in a particular RT 211 are only used for purposes of determining C02
concentration, define a C02 monitoring system in your monitoring plan. Report the
monitoring system ID and the 02 component ID as defined in the C02 system.
Clean Air Markets Division, U.S. EPA
Page 45
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December 2005
EDR v2.2 Instructions: RT 211
Table 6
SUMMARY OF RT 211 REPORTING REQUIREMENTS
I so of ()> Diluent
Aiiiilv/er
Monitoring System
II) I sod
Report C olumns
Missing
Instructions
For NOx emission rate
only
NOx-diluent monitoring
system ID
Columns 1 through 30
in RT 211
Perform NOx missing data substitution
in RT 320 for the hour.
Do not report RT 211.
For NOx emission rate
and heat input rate
NOx-diluent monitoring
system ID
Columns 1 through 36
in RT 211
Perform 02 missing data substitution in
RT 211 for the hour. Use the substitute
data value in the heat input rate
equation.
Also perform NOx missing data
substitution in RT 320 for the hour.
For heat input rate only
02 monitoring system
ID
Columns 1 through 36
in RT 211
Perform 02 missing data substitution in
RT 211 for the hour. Use the substitute
data value in the heat input rate
equation.
For moisture only
Moisture monitoring
system ID
Columns 1 through 31
in RT 211
Perform moisture missing data
substitution in RT 212 for the hour if
either 02 concentration is missing.
Do not report any RTs 211 for the hour.
For heat input rate and
moisture (but not NOx
emission rate)
02 monitoring system
ID for one 02 reading
Columns 1 through 36
in RT 211
Perform 02 missing data substitution in
RT 211 for the hour. Use the substitute
data value in the heat input rate
equation.
Moisture monitoring
system ID for other 02
reading
Columns 1 through 31
in RT 211
Perform moisture missing data
substitution in RT 212 for the hour if
either 02 concentration is missing.
Do not report this RT 211.
For NOx emission rate
and moisture
NOx-diluent monitoring
system ID for one 02
reading (wet or dry)
Columns 1 through 31
in RT 211
Perform NOx missing data substitution
in RT 320 for the hour.
Perform moisture missing data
substitution in RT 212 for the hour if
this 02 concentration is missing.
Do not report any RTs 211 for the hour.
For NOx emission rate
and moisture (cont.)
Moisture monitoring
system ID for other 02
reading (wet or dry)
Columns 1 through 31
in RT 211
Perform moisture missing data
substitution in RT 212 for the hour if
this 02 concentration is missing.
Do not report this RT 211 for the hour.
(cont.)
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Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: RT 211
December 2005
Table 6
SUMMARY OF RT 211 REPORTING REQUIREMENTS (cont.)
I so of ()> Diluent
Aiiiilv/er
Monitoring System
II) I sod
Report C olumns
Missing
Instructions
lor deleniiiiiing CO
concentration and
possibly heat input
rate, but not NOx
emission rate
CO nioiiiumiig s\ sleni
ID in RT 211 for
measured 02 value
Columns 1 lliiough 31
in RT 211
Do no I ivpoi'l RT 211 if U is missing
for the hour unless 02 is needed for heat
input rate determination.
C02 monitoring system
ID in RT 202 for
calculated C02 value
Columns 1 through 36
in RT 202
Perform C02 missing data substitution
in RT 202 for the hour.
For C02 concentration
and NOx emission rate,
and possibly for heat
input rate
NOx-diluent monitoring
system ID in RT 211 for
measured 02 value
Columns 1 through 31
in RT 211
Perform NOx missing data substitution
in RT 320 for the hour.
Do not report RT 211 if 02 is missing
for the hour unless 02 is needed for heat
input rate determination.
C02 monitoring system
ID in RT 202 for
calculated C02 value
Columns 1 through 36
in RT 202
Perform C02 missing data substitution
in RT 202 for the hour.
If the 02 data in a particular RT 211 are only used for purposes of determining moisture,
report the monitoring system ID and the appropriate 02 component ID as defined in the
moisture monitoring system.
If 02 concentration is missing for the hour and missing data are substituted for heat input
rate purposes, leave the monitoring system and component ID blank. This includes hours
in which the flue gases are discharged through an unmonitored bypass stack.
If a like-kind replacement non-redundant backup analyzer is used, during periods of
maintenance and repair of the primary analyzer (see § 75.20(d)), report the primary
monitoring system ID and assign and report the like-kind replacement analyzer a unique
component ID (beginning with the prefix "LK" as defined in RT 510, e.g.. "LK1"). The
component ID of the like-kind analyzer may be manually entered.
Average 02 Concentration for the Hour (24). Report 02 concentration for the hour,
expressed in %02, rounded to one decimal place. For each hour in which you use the
diluent cap value to calculate NOx emission rate, C02 mass emission rate, or heat input
rate, report the actual quality-assured 02 concentration in RT 211 and appropriate MODC
(01 through 04). For each such hour, report an MODC of 14 in RT 320, column 53, to
indicate that the diluent cap is being used for NOx emission rate. Also, if applicable,
report the appropriate flag(s) in RT 300, column 56 and/or RT 330, column 43 if the
diluent cap is used to calculate heat input rate and C02 mass emission rate. The use of the
diluent cap is optional for any type of unit, but if you use it to calculate C02 mass emission
rate you must also use it to calculate heat input rate.
Clean Air Markets Division, U.S. EPA
Page 47
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December 2005
EDR v2.2 Instructions: RT 211
If you use the data in RT 211 for heat input rate determination, report the appropriate
substitute data value in this field when a quality-assured 02 concentration for the hour is
unavailable or for hours in which the flue gases are discharged through an unmonitored
bypass stack.
Method of Determination Code (29). This field is required for all hours in which RT
211 is reported. Do not leave this field blank. Report one of the following method of
determination codes (MODC) to identify the type of monitoring system or missing data
procedure used to report 02 concentration for the hour. Manual entry of MODC "17" is
permitted. Codes 06 through 12 apply only when a separately certified 02 monitoring
system is defined in the monitoring plan and is used exclusively for heat input rate
determinations in accordance with Equation F-17 orF-18in Appendix F to Part 75.
All Systems
01 Primary Monitoring System
02 Redundant Backup or Regular Non-redundant Backup Monitoring System
03 Subpart E Alternative Monitoring System
04 Reference Method Backup System (Method 3 A)
Additional Codes for Heat Input Rate
06 Average Hour Before/Hour After
07 Average Hourly Concentration, Initial Missing Data
08 10th Percentile Value in Lookback Period
09 5th Percentile Value in Lookback Period
10 Minimum Hourly 02 Concentration in Lookback Period
12 Minimum Potential Concentration (Section 2.1.3.2 of Appendix A to
Part 75)
17 Like-kind Replacement Analyzer
20 200% of Full-scale Range Used in the Calculation of the Hourly Average
02 Concentration. These hours are included in missing data lookback and
are treated as available hours for percent availability calculations
54 Other Quality-assured Methodologies Approved Through Petition by EPA
(if data are submitted for the Acid Rain Program) or by EPA and the State
(if submitted solely for purposes of Subpart H). These hours are included
in missing data lookback and are treated as unavailable hours for percent
availability calculations.
55 Other Substitute Data Approved Through Petition by EPA (if data are
submitted for the Acid Rain Program) or by EPA and the State (if
submitted solely for purposes of Subpart H). These hours are not included
in missing data lookback and are treated as unavailable hours for percent
availability calculations.
EPA has reserved codes 01 through 55. Codes for 56 through 99 may be used by vendors
and companies for other purposes but must not be reported in a quarterly report. An
MODC of 30 was defined in EDR v2.0 for OTC NBP units only and is not allowed for
Acid Rain or Subpart H reporting.
Page 48
Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: RT 212
December 2005
Moisture Basis of Measurement (31). If you use reported 02 values to determine hourly
moisture, report one of the following uppercase codes to indicate the moisture basis of the
02 reading.
D
W
Dry
Wet
Percent Monitor Availability for 02 Concentration (32). Reporting of percent monitor
data availability in RT 211 is only required when the C02 data in RT 211 are used for
determining heat input rate. It is optional to report percent monitor availability during
hours in which missing data are substituted.
(6) RT 212: Moisture Data
For any unit or stack that requires hourly moisture measurements to determine emissions or heat
input rate, report the moisture value in RT 212 for each operating hour or partial operating hour.
Moisture is updated hourly from moisture sensors, wet and dry-basis 02 analyzers, or, for saturated gas
streams, from a temperature sensor and look-up table. Do not report moisture values in RT 220.
(a) If you use a fuel-specific default moisture value, as allowed under §75.11 or §75.12 (for
coal and wood burning units only), see the instructions for RT 531 and use this constant in
the calculation. Represent the constant as a variable in the formula text of RT 520. Do not
report RT 212 on an hourly basis.
(b) If you use a moisture value from a look-up table based on the stack temperature and the
presence of saturated conditions, report this value on an hourly basis in RT 212.
(c) When moisture is determined using wet and dry-basis 02 analyzers, the percent monitor data
availability for moisture is tracked in RT 212 on a system basis, and the percent availability of
the individual 02 monitors is not tracked. This is analogous to the reporting and availability
requirements for NOx-diluent monitoring systems (see the instructions for RT 320).
The Part 75 missing data procedures for moisture are found in § 75.37. These procedures are
modeled after the standard missing data procedures for S02. In most instances, the moisture missing data
algorithm is the inverse of the S02 algorithm (i.e.. the lower moisture values are more conservative and
therefore an inverted moisture missing data algorithm must be applied (using 10th percentile values
instead of 90th percentile values, minimum values instead of maximum values, etc)). However, when
Equations 19-3, 19-4, or 19-8 from Method 19 of 40 CFR Part 60 are used to determine NOx emission
rate, a higher moisture value is more conservative and therefore the standard S02 missing data algorithm
must be applied.
Field Descriptions and Instructions
Component ID (10). Leave the component ID blank if: (1) the reported moisture value
is a substitute data value or (2) if the reported moisture value is calculated from the
readings of two or more components in the system. Otherwise report the component ID.
Hours in which the flue gases are discharged through an unmonitored bypass stack are
considered to be missing data hours.
Clean Air Markets Division, U.S. EPA
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December 2005
EDR v2.2 Instructions: RT 212
Monitoring System ID (13). If the reported moisture value is a substitute data value,
leave the monitoring system ID blank; otherwise report the monitoring system ID.
Average Moisture Content of Flue Gases for the Hour (24). Report moisture for the
hour, expressed in %H20, rounded to one decimal place. Report the appropriate
substitute data value for hours in which a quality-assured moisture percentage is
unavailable or for hours in which the flue gases are discharged through an unmonitored
bypass stack.
Formula ID (29). If hourly moisture is calculated from wet and dry oxygen readings,
report the formula ID from RT 520 that represents this calculation. If moisture is
provided by a continuous moisture sensor or by a temperature sensor and a look-up table,
leave this field blank.
Method of Determination Code (32). Report one of the following method of
determination codes (MODC) to identify the type of monitoring system or missing data
procedure used to determine hourly moisture. Manual entry of MODC "21" is permitted.
01 Primary Monitoring System
02 Redundant Backup or Regular Non-redundant Backup Monitoring System
03 Part 75 Alternative Monitoring System
04 Reference Method Backup System
06 Average Hour Before/Hour After
07 Average Hourly Moisture Percentage, Initial Missing Data
08 90th or 10th Percentile Value in Lookback Period
09 95th or 5th Percentile Value in Lookback Period
10 Maximum or Minimum Hourly Moisture Percentage in Lookback Period
12 Maximum or Minimum Potential Moisture Percentage (Section 2.1.5 or
2.1.6 of Appendix A to Part 75)
21 Measured Negative Moisture Percentage Replaced with Zero
54 Other Quality-assured Methodologies Approved Through Petition by EPA
(if data are submitted for the Acid Rain Program) or by EPA and the State
(if submitted solely for the purposes of Subpart H). These hours are
included in missing data lookback and are treated as unavailable hours for
percent availability calculations.
55 Other Substitute Data Approved Through Petition by EPA (if data are
submitted for the Acid Rain Program) or by EPA and the State (if
submitted solely for the purposes of Subpart H). These hours are not
included in missing data lookback and are treated as unavailable hours for
percent availability calculations.
EPA has reserved codes 01 through 55. Codes 56 through 99 may be used by vendors
and companies for other purposes but must not be reported in a quarterly report. MODCs
of 30 and 31 were defined in EDR v2.0 for OTC NBP units only and are not allowed for
Acid Rain or Subpart H reporting.
Percent Monitor Data Availability for Moisture (34). When you use the standard
moisture missing data procedures in § 75.37, which are based on percent availability,
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Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: RT 220
December 2005
calculate and report the annual moisture percent data availability for each hour unless
missing data are substituted. It is optional to report percent monitor availability during
hours in which missing data are substituted.
(7) RT 220: Volumetric Flow Data
If you use stack flow monitoring to determine hourly heat input rate or S02, C02, or NOx mass
emissions, report RT 220 for each operating hour or partial operating hour.
Field Descriptions and Instructions
Component ID (10). If you determine hourly stack flow rate by averaging (or
subtracting) the readings from two flow components which are identified as components
of the same monitoring system, leave this field blank. If the hourly flow rate is a substitute
data value, leave this field blank. This includes hours in which the flue gases are
discharged through an unmonitored bypass stack.
Monitoring System ID (13). If the hourly flow rate is a substitute data value, leave this
field blank. This includes hours in which the flue gases are discharged through an
unmonitored bypass stack. If a full-scale exceedance occurs and you use a value of 200%
of the range in the calculation of the hourly average flow rate, report the monitoring
system and component IDs of the monitoring system which is in use at the time of the
occurrence. Treat such hours as though they are quality-assured monitor operating hours;
include them in missing data lookback and count them as available hours for percent
monitor data availability calculations.
Percent Monitor Data Availability for Volumetric Flow (24). Report the percent
monitor data availability for each hour unless missing data are substituted. It is optional to
report percent monitor data availability for hours in which missing data are substituted.
Average Volumetric Flow Rate for the Hour (29). For each operating hour (or partial
operating hour) in which a quality-assured flow rate was measured (MODC 01 through 04
and 54), report the unadjusted flow rate in units of scfh (wet basis). Report flow rate to
the nearest 1000 scfh. For missing data hours, leave this field blank (this includes hours in
which the flue gases are discharged through an unmonitored bypass stack).
If a start-up or shut-down hour results in a stack flow rate that is too low to be registered
by the stack flow monitor, you may report a default minimum stack flow rate of 1,000
scfh. In column 56, report MODC 55 for the hour. Manual entry of this MODC is
permitted.
Average Volumetric Flow Rate for the Hour Adjusted for Bias (39). For hours in
which quality-assured data are obtained, apply the appropriate bias adjustment factor
(1.000 or BAF) to the rounded quality-assured value and report the adjusted stack flow
for the hour, also rounded to the nearest 1000 scfh. For each hour in which missing data
procedures are used to report data, report the substitute data value. When the flue gases
are discharged through an unmonitored bypass stack, report the maximum potential flow
rate in this field. Do not leave this field blank.
Clean Air Markets Division, U.S. EPA
Page 51
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December 2005
EDR v2.2 Instructions: RT 220
(Note that for an initial certification, analyzer replacement, or monitoring system
replacement (as indicated by reporting an RT 556 with an Event Code of 300 or
305), if you are using conditional data validation, the BAF is uncertain during the
conditional data period. Therefore, apply a BAF of 1.000 from the beginning of
the conditional data validation period to the completion hour of the certification or
recertification RATA.)
Average Moisture Content of Flue Gases for the Hour [Reserved] (49). This field has
been replaced by RT 212, column 24. Leave this field blank.
Load Range or Operational Bin Number (54). Report the appropriate load range
("load bin number") for each operating hour for units that produce electrical output
(megawatts) or steam load (klb/hr). See the RT 300, column 34 instructions for a further
discussion of load bin numbers.
For non load-based units (e.g.. cement kilns, refinery process heaters, etc.), report the
operational bin number, if operational bins are used—otherwise, leave this field blank. If
the operational bin number is indeterminable for a particular operating hour, report "00".
Allowable load bin numbers: 01-20
Allowable operational bin numbers: 00-10
Method of Determination Code (56). Report one of the following method of
determination codes (MODC) to identify the flow monitoring system or missing data
procedure used to report hourly stack flow:
01 Primary Monitoring System
02 Redundant Backup or Non-redundant Backup Monitoring System
03 Part 75 Alternative Monitoring System
04 Reference Method Backup System (Method 2)
05 Part 75 Approved Parametric Method
06 Average Hour Before/Hour After
07 Average Hourly Flow Rate, Initial Missing Data
08 90th Percentile Value in Load Range in Lookback Period
09 95th Percentile Value in Load Range in Lookback Period
10 Maximum Flow Rate in Load Range in Lookback Period
11 Average Flow Rate in Load Range in Lookback Period
12 Unit or Stack Maximum Potential Flow Rate (MPF)
20 200% of the Full-scale Range Used in the Calculation of the Hourly
Average Flow Rate (full scale exceedance of high range). These hours are
included in missing data lookback and are treated as available hours for
percent availability calculations.
54 Other Quality-assured Methodologies Approved Through Petition by EPA
(if data are submitted for the Acid Rain Program) or by EPA and the State
(if submitted solely for the purposes of Subpart H). These hours are
included in missing data lookback and are treated as unavailable hours for
percent availability calculations.
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55 Other Substitute Data Approved Through Petition by EPA (if data are
submitted for the Acid Rain Program) or by EPA and the State (if
submitted solely for the purposes of Subpart H). These hours are not
included in missing data lookback and are treated as unavailable hours for
percent availability calculations.
EPA has reserved codes 01 through 55. Codes 56 through 99 may be used by vendors
and companies for other purposes but must not be reported in a quarterly report. MODCs
of 30 and 31 were defined in EDR v2.0 for OTC NBP units only and are not allowed for
Acid Rain or Subpart H reporting.
(8) RT 230: Daily Calibration Test Data and Results
Report all daily calibrations performed on S02, NOx, C02, 02, or flow components to quality
assure measured data, as required in the applicable regulation. Report the results of all failed, passing,
and incomplete calibrations that affect data validation in component, system, and chronological order.
For redundant backup monitors, the results of daily calibration error tests need not be reported except on
days when you use the monitors to report emission data. Do not report the results of off-line calibrations
performed during periods of non-operation of the unit or stack unless the unit has passed the off-line
calibration demonstration and is using off-line calibrations to validate data.
During maintenance procedures, you do not have to report the results of calibration gas injections
used during those procedures if the results of the calibration gas injection do not indicate that the control
status of the monitor has changed. For instance, if a monitoring system is already out-of-control and
calibration gases are injected as part of the maintenance procedures, you do not have to report the results
of these injections. Only the results of the post-maintenance calibration error test which is used to
validate the subsequent emissions data must be reported. Similarly, if as part of a maintenance procedure
on one monitor, calibration gases must be injected into other monitors, you do not have to report the
results of these injections as long as they are within the calibration error specification. If the results of
these injections indicate that any monitoring system is out-of-control, you must report these injections
and consider them to be a failed calibration error test.
If a component is part of two systems (for example, a C02 analyzer used both as a primary C02
monitor and as a diluent monitor in a NOx-diluent monitoring system) report the calibration twice, once
for each system using the appropriate system IDs. For example, for a diluent monitor used as part of a
C02 monitoring system and a NOx-diluent system, report C02 daily calibrations twice. Report one RT
230, using the C02 monitoring system ID and the diluent component ID and the other RT 230 using the
NOx-diluent monitoring system ID and the diluent component ID.
For moisture monitoring systems consisting of wet and dry-basis 02 monitors, report two
calibrations only if the wet and dry readings are obtained from two different analyzers. Report only the
dry-basis 02 calibration when a single analyzer is used for both wet and dry oxygen.
For an 02 monitor which is used to determine C02 mass emissions in accordance with § 75.13(c),
report the daily calibration of the 02 monitor under the C02 monitoring system ID. If the 02 monitor is
also part of a NOx-diluent monitoring system, report the 02 monitor calibration a second time, under the
NOx-diluent system ID.
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For flow monitoring systems comprised of two flow components, perform and report a daily
calibration for each flow component in the system.
For dual range monitors, perform and report daily calibrations for the instrument range(s) used
during the day.
Conduct the daily calibration according to the requirements of 40 CFR Part 75, Appendices A and
B. Daily calibrations validate the acceptability of emissions data from each monitoring component. The
validation rules and criteria used for Subpart H are the same as those used in the Acid Rain Program.
Field Descriptions and Instructions
Component and Monitoring System ID (10, 13). For calibration of a like-kind
replacement analyzer, report the special "LK" component ID and the primary monitoring
system ID (see RT 510 instructions). Manual entry of the "LK" component ID is
permitted.
Instrument Span (24). Report the span value used to determine the appropriate
calibration gas or reference signal used for the check. The span value must be the same as
the span value defined for the unit or stack and scale in RT 530, column 36.
Reference Value (37). Report the calibration gas or reference signal value used in this
injection.
Measured Value (50). Report the value measured by the instrument in response to the
reference following the gas injection or reference signal.
Results (Calibration Error or |R - A|) (63). Report the results of the calibration error
test, as required by Part 75. For S02, NOx, and flow monitors, express the results either
as a percentage of the span value or (for low-emitters of S02 or NOx or for low-span
differential pressure-type flow monitors) as the absolute value of the difference between
the reference and measured values, (i.e.. |R - A|). If the calculated calibration error meets
the standard specification, report the result as a percentage of the span even though the
result would also pass the alternative specification. Only when the result does not pass the
standard specification, but meets the alternative specification, should you report the
absolute value of the difference. Note that in the June, 2002 revisions to Part 75, the
alternate calibration error specification |R - A| was lowered to 5.0 ppm for S02 and NOx
monitors with span values of 50 ppm or less. For span values between 50 ppm and 200
ppm, the alternate calibration error specification remains at 10.0 ppm.
For C02 and 02 monitors, the results are always determined using |R - A| and are
expressed in terms of absolute percent C02 or 02. Use this method for all diluent gas
monitors used for C02 reporting and/or NOx reporting.
For low-span DP-type flow monitors using the alternate calibration error specification:
(1) report "0.0" in this field if the value of |R - A| is < 0.02 inches of water; or (2) report
"0.1" in this field if the value of |R - A| is > 0.02 , but <0.10 inches of water; or (3) if the
value of |R - A| is > 0.10 inches of water, report the result to the nearest 0.1 in. H20.
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Alternative Performance Specification (APS) Flag (68). Report whether the test result
was determined using the normal specification (APS Flag equals "0" (zero)) or low emitter
specification (APS Flag equals "1") allowed under Part 75.
Appendix A to Part 75 specifies that the calibration error of an 02 or C02 monitor is
always expressed in %02 or %C02, rather than as a percentage of span. This is
considered to be the normal calibration error specification and must have a "0" flag in RTs
230 and 600. The alternative specification flag in these record types applies only to S02
and NOx pollutant concentration monitors at facilities that are low-emitters of those
pollutants and to low-span differential pressure flow monitors.
Calibration Gas or Reference Signal Level (71). Indicate whether the gas injection or
reference signal is zero (Z) or high (H) by reporting the appropriate code. You may
perform and report mid-level (M) gas injections in lieu of the high level injections,
provided that the mid-level (M) gas is more representative of the actual stack emissions.
Span Scale (72). Report whether the component or the range of the instrument tested is
high (H) or low (L) scale. If the unit or stack only requires monitors that measure at a
single instrument range, enter "H" or leave this field blank.
(9) RT 231: Flow Daily Interference Check Results
Perform and report a daily interference check according to Part 75 requirements for all flow
monitors, including ultrasonic monitors, that are used for measuring and recording volumetric stack flow.
(10) RTs 260 Through 262: Reference Method Backup Quality Assurance Data
For more information on the reporting of quality assurance information for each reference method
run used to provide data as a backup monitoring methodology, consult the reference methods in
Appendix A to 40 CFR Part 60 and the separate guidance provided by the Clean Air Markets Division in
the Reference Methods as Backup Monitors Section of the Part 75 Policy Manual.
Whenever you use a reference method backup monitoring system to report pollutant or diluent
concentration data (S02, NOx, C02, or 02), submit RT 260 for each hour of data reported and submit the
associated quality assurance information in RT 261 for each run. In other words, submit one RT 260 for
each hour of data reported in RTs 202, 210, or 211 from a reference method backup system. The
corresponding RT 260 must have the same component/system ID, date and hour, and emissions value as
its companion record. You must report RT 261 for each reference method component/system for each
run. Because the run length may be up to eight hours, you may report one RT 261 for up to eight RTs
260 associated with the run.
If you use Reference Method 2 (or one of its allowable alternatives in Appendix A to 40 CFR Part
60) as a backup reference method to measure stack flow, submit one RT 262 for each hour of data
reported in RT 220 using Reference Method 2. Each reference method run represents one clock hour,
and therefore for reporting purposes, each run is regarded as beginning on minute 00 and ending on
minute 59. The total flow rate in scfh in RT 262 should be the same as the flow rate reported for the
same hour in RT 220.
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Selected Field Descriptions and Instructions for RT 262
Average Square Root of AP (26). Report this value only when Method 2 or 2G is used.
Otherwise leave this field blank.
Pitot Tube or Probe Coefficient (70). For Method 2 or 2G, report the pitot tube
coefficient, Cp. For Method 2F, report the velocity calibration coefficient, F2. If more
than one probe is used for the velocity traverses, leave this field blank.
Date of Latest Pitot Tube or Probe Calibration (75). If more than one probe is used
for the velocity traverses, leave this field blank.
Total Volumetric Flow Rate (87). Using the reported average velocity and the stack
cross-sectional area, calculate and report the stack gas total volumetric flow rate, at
standard conditions, wet basis.
Average Axial Velocity (97). Report the average velocity for the run, at stack
conditions, on a wet basis. If Reference Method 2F, 2G, or 2H is used, the average
velocity for each traverse shall be the average of the individual velocities at the traverse
points, corrected for pitch angle, yaw angle, and wall effects (as applicable).
Reference Method Probe Type (105). Select from among the following the type of
reference method probe used for the velocity traverses:
AS
Type S (automated)
DA
3-D Pitot (without thermocouple)
DAT
3-D Pitot (with thermocouple)
P
Prandtl
S
Type S (manual)
SPH
Spherical
(11) RT 300:
Unit Operating Parameters
Report RT 300 for every clock hour of every unit operating quarter, as follows: (a) for each
affected unit, irrespective of the location(s) at which the emissions are measured; and (b) for each
common stack (or pipe) or multiple stack (or pipe) location at which emissions are measured. Note: For
common stacks, a unit operating quarter is a calendar quarter in which any of the units serving the
common stack operates.
For example, if common stack CS1 serves Units 1 and 2 and emissions are monitored at the
common stack, report RT 300 for the common stack and also report RTs 300 for each unit. As a second
example, if Unit 1 discharges through two stacks, MSI and MS2, and emissions are monitored at each
stack, report separate RTs 300 for each stack and also report RT 300 for Unit 1.
If a common stack serves Units 1, 2, and 3, but Unit 1 did not operate during the quarter, report
RTs 300 for every clock hour in the quarter for Unit 1 with 0.00 as the operating time in column 18 and
leave the remaining columns blank. The RTs 300 for Units 2 and 3 will contain the appropriate operating
data.
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Exception
For units using the low mass emissions methodology in § 75.19, report RT 360 for each hour
(including non-operating hours) and do not report RT 300.
Field Descriptions and Instructions
Unit Operating Time (18). Report the fraction of the clock hour during which the unit
combusted any fuel (or the fraction of the clock hour during which the stack or pipe was
used). You may use any equal increments from hundredths (0.01 hr.) to quarters (0.25
hr.) of an hour.
For single unit-single stack configurations, report a unit operating time of "0.00" in RT
300 for any clock hour in which the unit does not combust fuel.
For common stack and multiple stack configurations, report an operating time of 0.00 in
RT 300 for any clock hour in which none of the units that exhaust through a particular
stack are operating or for any clock hour in which the dampers are closed so that flue gas
is unable to pass through the stack.
If you elect to use a multiple-stack configuration to report NOx emissions data from a
combined-cycle combustion turbine that: (a) uses Appendix D to measure the unit-level
heat input; and (b) has a NOx-diluent monitoring system installed on each stack (i.e.. on
the main stack and the bypass stack), report the stack operating times as follows:
• For any hour in which all of the exhaust gases flow through one stack or the other, the
operating time for the stack that is in use will be equal to the unit operating time for
that hour, and the operating time for the other stack will be 0.00; and
• For a transition hour, in which gases flow through both stacks during the entire hour
or any part of the hour:
— Report that fraction of the hour (if any) in which gases flow only through the main
stack as the "main stack operating time;" and
— Report the remainder of the hour, in which gases either flow through both stacks
simultaneously or flow only through the bypass stack, as the "bypass stack
operating time."
Gross Unit Load and Steam Load During Unit Operation (22, 28). Report hourly
load information as either steam load or unit load. Leave the other load field blank. The
units for average hourly gross unit load are megawatts and the units for steam load are
1000 lbs/hr. Note that these values are rates and must be multiplied by operating time to
yield the output for an hour. Do not correct steam load for standard temperature and
pressure; use steam load at measured temperature and pressure (see Part 75, Appendix C,
Section 2.2.1).
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If you convert auxiliary heat input to megawatts equivalent (e.g.. for a heat recovery
steam generator with a duct burner) and add that value to megawatts for a gas turbine,
you should report the unit electric load and leave the steam load field blank.
For monitored common stacks, report the sum of the hourly unit loads, for all units that
exhaust through the stack.
For all multiple-stack configurations, for each unit operating hour in which gases flow
through a particular stack or duct, report the unit load in both the stack-level and unit-
level 300 records for that hour.
Leave these fields blank (do not report zeros) for any clock hour in which the unit does
not operate. Also leave these fields blank for units that do not produce electrical or steam
load (e.g.. cement kilns, refinery process heaters, etc.).
Load Range or Operational Bin Number (34).
Report an operating load range (load bin number) for each operating hour (see Appendix
C to Part 75) for units that produce electrical or steam load. For units that do not
produce electrical or steam load (e.g.. cement kilns, refinery process heaters, etc.), report
the operational bin number, if operational bins are used for missing data purposes. If the
operational bin number is indeterminable, report "00".
For a monitored common stack, the load bins are defined at the common stack, on the
basis of combined unit load, and load-based missing data routines are applied at the
common stack. Therefore, for each unit operating hour, report the common stack load bin
number in both the common stack and unit-level 300 records.
For a multiple-stack configuration in which gases normally flow through both stacks or
ducts simultaneously (e.g.. a twin-stack or split-breeching configuration), the load bins are
set up on the basis of unit load. Therefore, for each unit operating hour, report the unit
load bin number in both the unit-level and stack-level 300 records.
For load-based units, leave this field blank (do not report zeros) for any clock hour in
which the unit does not operate or gases do not flow through the stack (as applicable).
Also leave this field blank for non load-based units that do not use operational bins for
missing data purposes.
Hourly Heat Input Rate During Unit Operation for All Fuels (36). Report this value
in mmBtu per hour (mmBtu/hr). If you use CEMS to determine hourly heat input rate,
calculate the hourly rate using the diluent gas concentration, bias-adjusted hourly stack
flow rate, percent moisture (if appropriate), and F-factor.
If you measure and report heat input rate at a common stack or pipe, also apportion and
report heat input rate at the unit level. This apportionment should be based on either
megawatts, steam load, or fuel flow rate, using Equation F-21A , F-21B, or F-21D in
Appendix F to Part 75, as applicable. These formulas use time-weighted hourly load to
apportion the heat input rate measured at a common stack to the individual units.
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For each hour, the sum of the individual heat inputs in mmBtu (i.e.. the sum of the
individual unit heat input rates, each multiplied by the corresponding unit operating time)
must equal the total common stack heat input in mmBtu (i.e.. the common stack heat input
rate multiplied by the common stack operating time).
For a unit with a multiple stack configuration, having installed flow rate and diluent
monitors on each stack, calculate the hourly heat input rate for the unit using Equation F-
21C in Appendix F to Part 75. Also use Equation F-21C for multiple pipe configurations
(see section II.C (2)(c), above).
For each hour, the total unit heat input in mmBtu (i.e.. the unit heat input rate multiplied
by the unit operating time) must equal the sum of the individual stack (or pipe) heat inputs
in mmBtu (i.e.. the sum of the individual stack (or pipe) heat input rates, each multiplied
by the corresponding stack (or pipe) operating time).
For Appendix D units combusting multiple fuels, report the hourly heat input rate
calculated from all fuels in RT 300.
For non-Acid Rain Subpart H units that use NOx concentration times stack flow as the
primary methodology to calculate NOx mass emissions, report the hourly heat input rate
unless you are specifically exempted (e.g.. by a State SIP) from reporting it for allocation
purposes. However, you must report unit operating time and load (except for non load-
based units) for each hour in RT 300, even if you are not required to report hourly heat
input.
Leave these fields blank (do not report zeros) for any clock hour in which the unit does
not operate or gases do not flow through the stack (as applicable).
If you elect to use a multiple-stack configuration to report NOx emissions data from a
combined-cycle combustion turbine that: (a) uses Appendix D to measure the unit-level
heat input; and (b) has a NOx-diluent monitoring system installed on both the main and
bypass stacks, report the heat input rate only in the unit-level 300 record. Leave this field
blank in the stack-level 300 records.
Heat Input Formula ID (43). Report the formula ID (from RT 520) representing the
equation used to calculate heat input rate for the hour.
Leave these fields blank (do not report zeros) for any clock hour in which the unit does
not operate.
F-factor for Heat Input Calculation (46). If you use CEMS or another F-factor based
methodology to determine hourly heat input rate, report the F-factor used for each hour or
partial hour of operation. Otherwise, leave this field blank.
Leave these fields blank (do not report zeros) for any clock hour in which the unit does
not operate.
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Use of Diluent Cap for Heat Input Calculation for This Hour (56). If you elect to
substitute a maximum or minimum diluent cap value to calculate heat input rate for hours
in which the quality-assured diluent gas concentration is below or above the specified cap,
indicate the use of the diluent cap value by reporting "Y". A diluent cap value can only be
used for measured (quality assured) operating hours. Leave this field blank for all hours in
which the diluent cap is not used for heat input rate calculations. If you normally use
Equation F-17 to determine heat input rate, you must use modified Equation F-17D to
calculate heat input rate during hours in which you use the diluent cap to calculate heat
input rate (see Table 20 under RT 520).
Leave these fields blank (do not report zeros) for any clock hour in which the unit does
not operate.
Total Heat Input for the Hour (Optional) (57). Report the total heat input for the hour
(mmBtu) by multiplying the heat input rate by the operating time. This field is optional.
Leave these fields blank (do not report zeros) for any clock hour in which the unit does
not operate.
Type of Fuel Combusted (64). Report data in this field only if: (1) you have elected to
use the fuel-specific CEMS missing data option under § 75.33; or (2) you have a an
exhaust configuration consisting of a monitored main stack and an unmonitored bypass
stack, and you opt to report the fuel-specific MPC or MER value during bypass hours (see
§§ 75.16, 75.17 and 75.72). Select one of the following fuel type codes:
MIX
Use this code for any hour in which fuels are co-fired
BFG
Blast Furnace Gas
BUT
Butane (if measured as a gas)
C
Coal
CDG
Coal Derived Gas
COG
Coke Oven Gas
CRF
Coal Refuse (culm or gob)
DGG
Digester Gas
DSL
Diesel Oil
LFG
Landfill Gas
LPG
Liquified Petroleum Gas (as defined in § 72.2)
NNG
Natural Gas
OGS
Other Gas
OIL
Residual Oil
OOL
Other Oil
OSF
Other Solid Fuel
PDG
Producer Gas
PNG
Pipeline Natural Gas (as defined in § 72.2)
PRG
Process Gas
PRP
Propane (if measured as a gas)
PRS
Process Sludge
PTC
Petroleum Coke
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WL
R
RFG
SRG
TDF
W
Refuse
Refinery Gas
Unrefined Sour Gas
Tire-derived Fuel
Wood
Waste Liquid
(12) RT 301: Quarterly Cumulative Emissions Data (ARP)
Do not report RT 301 for non-Acid Rain Subpart H units.
For Acid Rain units, report quarterly and cumulative annual S02 mass emissions, C02 mass
emissions, heat input (in mmBtu), and operating hours in RT 301. In addition, report the quarterly and
year-to-date average NOx emission rate. Report this information for each location (unit, stack, or pipe) at
which emissions are measured.
For common stack, multiple stack, and complex stack configurations, report RT 301 for each
monitored stack. Also report RT 301 for each affected unit, irrespective of the location(s) at which
emissions are measured.
Common Stacks or Pipes. For a simple common stack or pipe (emissions from two or more
units accounted for at one stack or pipe location), a RT 301 must be submitted for the common stack or
pipe and an additional RT 301 must be submitted for each unit associated with the common stack or pipe.
The quarterly and cumulative heat input values for the stack or pipe (in mmBtu) must equal the sum of
the heat inputs for the units associated with the stack or pipe. Report only heat input and operating hour
information in the RTs 301 for the individual units. Do not apportion S02 mass emissions, C02 mass
emissions, or average NOx emission rates to the individual units.
For example, if CS1 is a monitored common stack for Units 1 and 2, report three RTs 301: one
for Stack CS1, one for Unit 1, and one for Unit 2. In RT 301 for CS1, report the quarterly and year-to-
date cumulative heat inputs, S02 mass emissions, C02 mass emissions, and average NOx emission rates,
as measured at the common stack, and report the operating hour information for the common stack. In
the RTs 301 for Units 1 and 2, report only the quarterly and year-to-date cumulative apportioned heat
input in mmBtu (as derived from the heat input rates and operating times in the RTs 300) and operating
hours. Do not report unit-level C02 mass emissions, S02 mass emissions, or NOx emission rates in the
RTs 301 for Units 1 and 2.
Multiple Stacks or Pipes. For some units, there are multiple stacks or ducts (with installed
CEMS) leading from the unit. Included among these are combined-cycle combustion turbines that have a
main stack-bypass stack configuration, where the NOx emission rate is monitored at both stacks.
Additionally, a combined cycle Appendix E combustion turbine with a duct burner may have multiple fuel
pipes (with installed fuel flowmeters). For these configurations, submit one RT 301 for each multiple
stack, duct, or pipe and a separate RT 301 for the unit. For each multiple stack, duct, or pipe, report the
quarterly and cumulative S02 or C02 mass emissions, the quarterly and year-to-date arithmetic average
NOx emission rates, and the quarterly and cumulative heat input and operating hours. Report only the
quarterly and cumulative heat input, operating hour information, and weighted average NOx emission
rates in the unit-level RT 301 (see the instructions below for calculation of quarterly and cumulative
weighted average NOx emission rates.) Do not report quarterly and cumulative S02 or C02 mass
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emissions at the unit level. The reported quarterly or cumulative heat input value for the unit must equal
the sum of the corresponding heat input values reported for the individual stacks, ducts, or pipes.
For example, if MSI A and MS1B are monitored multiple stacks for Unit 1, report three RTs
301: one for MS1A, one for MS1B, and one for Unit 1. In the RTs 301 for MS1A and MS1B, report
the quarterly and year-to-date cumulative heat input, S02 emissions, C02 emissions, and average NOx
emission rates, as measured by the CEMS at each stack, and report the operating hour information. In
the RT 301 for Unit 1, report only the quarterly and year-to-date cumulative apportioned heat input in
mmBtu (as derived from the heat input rates and operating times in the RTs 300), the weighted average
NOx emission rate, and operating hour information. Do not report unit-level C02 mass emissions or S02
mass emissions in the RT 301 for Unit 1.
Note that for certain multiple-stack configurations, data may be reported at the unit level, in lieu
of using multiple stack ("MS") prefixes. See section II.C.(2)(b) of these Instructions for further
guidance.
Complex Stack Configurations. A complex stack configuration exists where a unit's emissions
are measured at more than one stack location and where at least one of these stack locations is a common
stack shared with one or more other units.
For the purposes of quarterly and cumulative heat input accounting, the sum of the heat inputs for
all units associated with all stacks in a complex configuration must equal the sum of the stack heat inputs
for all of the stacks. For example, if emissions from scrubbed Units 1, 2, and 3 are measured at CS1
during normal unit operation and are measured at CS2 during scrubber bypass hours, the sum of the heat
inputs for Units 1, 2, and 3 must equal the sum of the heat inputs for CS1 and CS2.
Data for all units and stacks involved in a complex configuration must be reported in a single
quarterly report file. In this quarterly report file, report only one RT 301 for each individual unit,
regardless of the number of stacks to which the unit discharges its emissions.
Low Mass Emissions Units. For Acid Rain Program units using the low mass emissions
excepted methodology under § 75.19, report the quarterly and cumulative S02 mass emissions, C02 mass
emissions, heat input, average NOx emission rate, and operating hours for each unit in RT 301.
If a group of LME units is served by a common fuel pipe (or supply tank) and the long-term fuel
flow option is used to quantify heat input, also submit a RT 301 for the common pipe (or tank). Report
data only in the quarterly and cumulative heat input fields, leaving all of the emissions fields and operating
hours fields blank. If more than one common pipe (or tank) serves the same group of LME units, report
the quarterly and cumulative heat input for each pipe (or tank) in a separate RT 301.
(Note: RT 301 does not contain fields for reporting quarterly and cumulative NOx mass emissions.
Therefore, for the purpose of documenting compliance with the LME emission thresholds for
NOx, you must report the appropriate quarterly, ozone season (if applicable), and cumulative tons
of NOx emissions from each Acid Rain Program LME unit in RT 307.)
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Field Descriptions and Instructions. Report data in the RT 301 fields as described below,
except where the RT 301 introductory text above instructs you to leave a field blank for a
particular parameter, monitoring methodology or configuration.
Date of Report Generation (10). Report the calendar date on which the quarterly report
was created.
Quarterly and Cumulative Annual S02 Tons Emitted (16, 26). For data from an S02
CEMS, convert each of the S02 pounds per hour values reported in RT 310 to S02 mass
in pounds by multiplying it by the corresponding unit operating time from column 18 of
RT 300. For Appendix D data, convert each S02 pounds per hour value reported in RTs
313 and 314 to S02 mass in pounds by multiplying it by the corresponding fuel usage time
from column 52 of RT 302 or RT 303 (as applicable). Sum the hourly S02 mass values
for the quarter. Divide this sum by 2,000 to convert to tons and round to one decimal
place.
For Acid Rain low mass emissions units, sum the hourly S02 mass emissions (lbs) reported
in column 44 of RT 360, divide by 2,000, and round to one decimal place.
In Quarter 1, the quarterly total S02 tons reported in column 16 must be the same as the
cumulative annual tons reported in column 26. In subsequent quarters, add the total S02
tons emitted in the current quarter to the cumulative annual S02 tons reported in column
26 of the previous quarter's report to obtain the new value of the cumulative annual S02
tons emitted.
Quarterly and Cumulative Average NOx Emission Rate (36, 49). For NOx-diluent
monitoring system data or for Appendix E data, report the quarterly and cumulative (year-
to-date) average NOx emission rates in RT 301. The quarterly value in column 36 is a
straight arithmetic average of the NOx emission rates for all unit operating hours in the
quarter, as reported in RT 320 (for CEMS) or, for Appendix E, in RTs 323, 324 (single
fuel hours only), or 325 (as appropriate). The cumulative value in column 49 is a straight
arithmetic average of the hourly NOx emission rates for all unit operating hours in the
calendar year to-date (see Equation F-10 in Appendix F to Part 75).
If the recorded NOx emission rate is zero, include these hours in your average only if the
operating time for the hour (as reported in RT 300) is greater than zero. Do not weight
the quarterly or cumulative average NOx emission rate for partial operating hours (i.e..
count all hourly NOx emission rates equally, irrespective of the unit operating time).
Report both the quarterly and cumulative average NOx emission rates for the unit or stack
to three decimal places.
For simple multiple stack or multiple duct configurations in which NOx emissions and heat
input are monitored separately with CEMS in each of the stacks or ducts, you must
calculate and report the quarterly and cumulative arithmetic average NOx emission rate in
RT 301 for each stack or duct, and you must also calculate and report a quarterly and
cumulative heat input-weighted NOx emission rate in RT 301 for the unit. Determine the
heat input-weighted averages for the unit as follows. First, use the reported hourly data
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(i.e.. stack level NOx emission and heat input rates) and the following formula to calculate
a heat input-weighted unit NOx emission rate for each stack operating hour in the quarter:
In the formula above, the term "Heat Input" for multiple stack A or B is the product of the
hourly heat input rate for the stack (as reported in RT 300, column 36) and the
corresponding operating time for the stack (as reported in RT 300, column 18). Note that
these weighted hourly NOx emission rates are recorded and stored, but are not reported in
The quarterly heat input-weighted average NOx emission rate for the unit is then
determined by taking the sum of all of the stored hourly heat input-weighted NOx emission
rates for the quarter and dividing this sum by the total number of unit operating hours in
the quarter. In determining the number of unit operating hours in the quarter, each partial
operating hour is counted as a full hour of unit operation. The cumulative heat input-
weighted average NOx emission rate for the unit is determined in the same way as the
quarterly average for the unit, except that the terms "for the quarter" and "in the quarter"
are replaced, respectively, with the terms, "for the year, to date" and "in the year, to date."
When a multiple-stack configuration is selected for a combined-cycle combustion turbine
(CT) that: (a) uses the provisions of Appendix D to Part 75 for unit heat input; and (b)
has a main stack and bypass stack configuration; and (c) has NOx -diluent monitoring
systems on both the main and bypass stacks, the mathematics are slightly different. In this
case, for any unit operating hour in which gases flow through both stacks for any part of
the hour, a time-weighted, rather than a heat-input-weighed unit-level NOx emission rate is
calculated, using an equation similar to the one above, except that the terms "(Heat
Input)A" and "(Heat Input)B" are replaced with tA and tB, respectively, where tA and tB are
the main stack operating time and bypass stack operating time, respectively (see the RT
300, column 18 instructions). The time-weighted hourly average NOx emission rates are
then used to determine the quarterly and cumulative NOx emission rates for the unit.
For Acid Rain Program low mass emissions (LME) units, determine the quarterly average
NOx emission rate for each unit as follows. Sum all of the hourly NOx mass values from
column 50 of RT 360 to get the total NOx mass for the quarter. Then, sum the hourly
heat input values in column 34 of RT 360 to obtain the total heat input for the quarter.
Divide the total NOx mass for the quarter by the total quarterly heat input, to determine
the quarterly NOx emission rate in lb/mmBtu. Calculate the cumulative (year-to-date) NOx
emission rate by separately summing the RT 360 hourly NOx mass and heat input values
over all operating hours in all quarters, and then dividing the NOx mass sum by the heat
input sum.
Quarterly and Cumulative Annual C02 Tons Emitted (62, 72). For hourly C02 data
reported from a CEMS or determined using Equation G-4 of Appendix G, convert each of
the C02 tons per hour values reported in RT 330 to C02 mass in tons by multiplying it by
Hourly Unit NOx Emission Rate (lb / mmBtu)
(NOx Rate}A(HeatInput}A + (NOx Rate} b(H eat Input} b
(Heat Input} + (Heat Input}
the EDR.
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the corresponding unit operating time from column 18 of RT 300. Sum the hourly C02
tons values for the quarter and round the result to one decimal place. For Appendix G
data determined from Equation G-l, sum the C02 daily tons reported in RT 331 for the
quarter. Round and report the sum to one decimal place.
For Acid Rain low mass emissions units, sum the C02 mass emissions reported in RT 360
and round to one decimal place.
In Quarter 1, the quarterly total C02 tons reported in column 62 must be the same as the
cumulative annual tons reported in column 72. In subsequent quarters, add the total tons
of C02 emitted in the current quarter to the cumulative annual C02 tons reported in
column 72 of the previous quarter's report to obtain the new value of the cumulative
annual C02 tons emitted.
Quarterly and Cumulative Annual Total Heat Input (82, 92). For each unit, stack or
pipe, determine the quarterly heat input in mmBtu as follows. Calculate the heat input for
each hour in the quarter, by multiplying the hourly heat input rate (reported in RT 300,
column 36) by the corresponding operating time (reported in RT 300, column 18). Then,
sum all calculated hourly heat input for the quarter. Round and report this sum to one
decimal place.
Except for low mass emissions (LME) units, this is the correct method to use for all units,
stacks, and pipes, including units that are associated with a common stack or pipe.
For low mass emissions units, sum the hourly heat inputs reported in RT 360 and round to
one decimal place. If a common fuel pipe (or supply tank) serves a group of LME units
and the long-term fuel flow option is used to quantify heat input, report the cumulative
heat input for the group of units in a RT 301, under the common pipe (or tank) ID. If
more than one common pipe (or tank) serves the same group of LME units, report a
separate RT 301 for each pipe (or tank).
In Quarter 1, the quarterly heat input in mmBtu reported in column 82 must be the same
as the cumulative annual heat input reported in column 92. In subsequent quarters, add
the total heat input in the current quarter to the cumulative annual heat input reported in
column 92 of the previous quarter's report to obtain the new value of the cumulative
annual heat input.
Quarterly and Cumulative Annual Unit/Stack/Pipe Operating Hours (114, 118). In
column 114, report the number of hours in which the unit, stack or pipe operated during
the quarter. Count each hour of partial operation as a single hour. For CEMS units, this
value indicates whether the calendar quarter is a "QA operating quarter" (i.e.. a calendar
quarter with >168 unit or stack operating hours). In column 118 report the cumulative
number of unit, stack, or pipe operating hours in the year-to-date.
(13) RT 302: Oil Fuel Flow
Report RT 302 for each hour in which oil is combusted and you use an oil flowmeter to determine
heat input rate or S02 or C02 mass emissions in accordance with Appendix D. Also report RT 302 for
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any hour in which oil is combusted as a startup fuel and fuel flow is estimated through tank
measurements.
For low mass emissions units that use a certified Appendix D fuel flowmeter for long term fuel
flow purposes, do not report RT 302. See the instructions for RT 360 and RT 305.
If you combust different types of oil in the same hour (which must be measured by separately
defined fuel flowmeter monitoring systems), report a RT 302 for each type of fuel combusted, using the
monitoring system ID associated with the appropriate flowmeter monitoring system and identifying the
type of oil in column 56.
It is not necessary to report RT 302 for other hours in which the unit operated, if, during these
hours, only fuels other than oil were burned.
For Acid Rain units, report a companion RT 313 for each RT 302. Do not report a companion
RT 313 for non-Acid Rain Subpart H units.
The oil flow rate is the net fuel flow rate to the unit(s). For example, it may represent the
difference between the values measured for the main supply and recirculating oil lines or it may represent
the sum of oil flow for two fuel flowmeters measuring the same type of oil to the unit.
If you measure fuel flow at a common pipe location, report RT 302 using the common pipe ID for
each hour in which fuel is combusted by a unit served by the common pipe. Do not report RTs 302 for
the individual units on an hourly basis. Apportion the heat input rate calculated at the common pipe
location to each unit, using appropriate time-weighted apportionment formulas based on load (see
Appendix F and the RT 520 instructions). Report the apportioned hourly heat input rate values in
separate RTs 300 for the individual units. Use the hourly heat input rates and operating times from RT
300 to calculate the cumulative heat input values for each unit and report these values in unit-level RTs
301 and 307 (as applicable). If you use Equation F-21D to apportion the common pipe heat input to the
individual units, report RT 302 only for the common pipe — do not report any RTs 302 showing the oil
flow to the individual units.
If the fuel flow system measures mass flow rate of oil directly, leave blank columns 59 through 88
in RT 302.
Field Descriptions and Instructions
Monitoring System ID (10). For hours in which the oil flow system provides quality-
assured data, report the monitoring system ID for the OILM or OILV system.
For hours in which you report the source of the oil flow rate data (column 31 or 74) as
codes 4, 5, or 6 for "Emergency Fuels," "Ignitor Oil from Tank Measurements," or
"Uncertified OFFM to Measure Ignitor Oil," leave the monitoring system ID blank.
For hours in which you use substitute data for fuel flow rate, you may either report the
primary monitoring system ID or leave the monitoring system ID blank (subject to the
exception described below).
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For Acid Rain units, you must report the same fuel flow monitoring system ID in RT 313
as is reported in RT 302. For any hour in which you use substitute data, report either the
primary system ID in both the RT 302 and RT 313, or leave the system ID blank in both
RTs.
For hours in which two different fuels are combusted and two RTs 302 are reported for a
unit or common pipe, if the fuel flow rate data are missing for both fuels, you must report
a valid monitoring system ID (as reported in RT 510) in at least one of the 302 records.
Report this same monitoring system ID in the companion RT 313.
For Appendix E units, if you report NOx emission rate in RT 324 and report heat input
rate in RT 302, each RT 302/324 pair (for the same type of oil and the same fuel
flowmeter) must contain the same fuel flow monitoring system IDs in columns 10 of RT
302 and column 13 of RT 324.
Mass Flow Rate of Oil During Oil Combustion (21). This value is either measured
directly by a fuel flowmeter system or calculated from the volumetric flow rate measured
by a fuel flowmeter system. All values must be reported in lb/hr, rounded to one decimal
place. This value represents an hourly rate for the period in which fuel is combusted, not
total flow for the hour.
For Acid Rain units using Appendix D, you must report mass flow rate in order to
calculate S02 mass emissions. Where the density of the oil is determined by the applicable
ASTM procedures referenced in Part 75, use Equation D-3 to calculate the mass flow rate
of oil (in lb/hr).
OILrate Voil-rate * ^ oil
(Equation D-3)
Where:
OILrate = Mass rate of oil consumed per hr (lb/hr) (RT 302, column 21)
Voii-rate = Volume rate of oil consumed per hr, measured in scfh, gal/hr, barrels/hr, or
m3/hr (RT 302, column 59) (rounded to one decimal place)
Doil = Density of oil, measured in lb/scf, lb/gal, lb/barrel, or lb/m3 (RT 302, column
75)
However, for non-Acid Rain Subpart H units using Appendix D for heat input
determination, you may measure and report either mass flow rate or volumetric flow rate
of oil. If you use volumetric flow rate and GCV to determine hourly heat input rate, leave
this field blank.
Source of Data Code for Mass Oil Flow Rate (31). Report one of the following codes
to indicate the type of value reported for oil flow rate:
0 Measured Data (using a mass flowmeter)
1 Substitute Data Using Lookback Procedures
2 Mass Flowrate Derived From Volumetric Value
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3 Maximum Potential Fuel Flow Rate (simplified missing data procedure for peaking
units, only)
4 Emergency Fuel (maximum unit fuel flow rate)
5 Ignitor Oil From Tank Measurements
6 Uncertified OFFM to Measure Ignitor Oil
9 Default Minimum Fuel Flow Rate
Do not leave this field blank if fuel flow is reported in column 21.
Load Range or Operational Bin Number (32).
If you use the standard, load-based fuel flow missing data substitution procedures required
in Part 75, Appendix D, report an operating load range ("bin number") for each hour.
During hours when you report measured values, use the load ranges to define the values at
each load range for missing data purposes. During hours of fuel flow missing data use the
load ranges to calculate the appropriate substitute value.
Leave this field blank if you use the simplified missing data procedures for peaking units,
as described in section 2.4.2.1 of Appendix D.
For units that do not produce electrical or steam load (e.g.. cement kilns, refinery process
heaters, etc.), leave this field blank unless you use operational bins for fuel flowrate
missing data substitution (see Part 75, Appendix C, Section 3). In that case, report the
operational bin number. If the operational bin number is indeterminable for a particular
hour, report "00".
For common pipes, you may use load ranges of 01 through 10 or 01 through 20; for fuel
flow measured at single units, use load ranges of 01 through 10. For non load-based units
with approved petitions to use operational bins, the allowable operational bin numbers
range from 00 through 10.
Gross Calorific Value (GCV) of Oil (34). Report the heat content or gross calorific
value (GCV) of the oil from an appropriate sample to calculate heat input. If GCV is
missing, report a substitute value based on the Appendix D missing data procedures.
Report this value in units consistent with the units used to report the mass or volumetric
flow of oil as described below.
Reserved (44). This field was used only by OTC NOx Budget Program units, and has
been reserved.
Heat Input Rate from Oil During Oil Combustion (45). Calculate and report heat
input rate to the unit or common pipe by multiplying the heat content (GCV) of the fuel by
the hourly oil mass flow rate or the volumetric flow rate. Report this value in units of
mmBtu/hour rounded to one decimal place.
Fuel Usage Time (52). Report the fraction of the clock hour during which the unit
combusted oil. You may use any equal increments from hundredths (0.01 hr.) to quarters
(0.25 hr.) of an hour. Do not leave this field blank.
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For common pipes, report the cumulative portion of the hour during which oil was
combusted in any of the units served by the common pipe, not to exceed a fuel usage time
of 1.00. For example, if a common pipe serves Units 1 and 2 and both units operate for
the first 24 minutes (0.40 hr) of the hour and then are both shut down, the fuel usage time
is 0.40. If Unit 1 operates only for the first 24 minutes of the hour and Unit 2 operates
only for the last 24 minutes of the hour, the fuel usage time is 0.40 hr plus 0.40 hr, or
0.80. If Unit 1 operates for the first 40 minutes of the hour and Unit 2 operates for the
last 40 minutes of the hour, report a fuel usage time of 1.00, since for all minutes in the
hour, at least one of the units operated.
Type of Oil (56). Identify the type of oil combusted during the hour for the system
reported in column 10. You may either report the type of fuel using the General Fuel
Type codes below (which are consistent with the codes for oil in RT 587) or you may
report more specific information on the type of oil combusted using one of the Specific
Fuel Type codes below. Do not provide information on more specific types of oil if you
are uncertain about the fuel type for all or any hours in the quarter.
General Fuel Type Codes
DSL
OIL
OOL
Diesel Oil
Residual Oil
Other Oil
Specific Fuel Type Codes
1GT
2GT
3GT
4GT
WMO
G4L
G4H
G5L
G5H
G6
G1
G2
ATF
LPG
KER
ID
2D
4D
0GT
Grade 1 Light Distillate Used in Vaporizing Burners
Grade 2 Distillate Used in Atomizing Type Burners
Aviation Turbine Fuels Meeting ASTM D-1655-91b (Jet A and Jet A-l)
Liquefied Petroleum Gases Meeting ASTM D-1835-91 (propane, butane,
and propane-butane mixtures)
Kerosene Meeting ASTM D-3699-90 or Equivalent
Diesel Fuel Oil Meeting ASTM D975-91 Grade 1-D
Diesel Fuel Oil Meeting ASTM D975-91 Grade 2-D
Diesel Fuel Oil Meeting ASTM D975-91 Grade 4-D
Gas Turbine Fuel Oil Meeting ASTM D2880-90a Grade 0-GT
(naphtha, Jet B)
Gas Turbine Fuel Oil Meeting ASTM D2880-90a Grade 1-GT
Gas Turbine Fuel Oil Meeting ASTM D2880-90a Grade 2-GT
Gas Turbine Fuel Oil Meeting ASTM D2880-90a Grade 3-GT
Gas Turbine Fuel Oil Meeting ASTM D2880-90a Grade 4-GT
Waste Motor Oils
Grade 4 Light
Grade 4 Heavy
Grade 5 Light
Grade 5 Heavy
Grade 6, Also Known as Bunker C
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EDR v2.2 Instructions: RT 302
Volumetric Flow Rate of Oil During Oil Combustion (59). If the fuel flow system
measures the volumetric flow rate of oil, report the volumetric flow rate, as measured,
rounded to one decimal place. This value represents an hourly rate for periods in which
the fuel is combusted, not a total flow for the hour. If the hourly oil flow rate is so small
that it results in a heat input rate of 0.0 mmBtu/hr (rounded to the nearest tenth) when
Equation D-8 is used, you may report, as a default value, the minimum oil flow rate that
will give a heat input rate greater than zero.
For Acid Rain units you must report mass flow rate and you must also report volumetric
flow rate used to calculate the mass flow if you use a volumetric flowmeter. For both
Acid Rain Program units and non-Acid Rain, Subpart H units, if the fuel flow system
measures mass flow rate of oil directly, leave this field blank.
Units of Measure for Volumetric Oil Flow Rate (69). Report the units of measure used
to report volumetric flow rate using one of the following uppercase codes:
Volumetric Oil Flow Rate Units
BBLHR Barrels/Hour
GALHR Gallons/Hour
M3HR Cubic Meters/Hour
SCFH Standard Cubic Feet/Hour
If you calculate hourly heat input directly from volumetric flow for a non-Acid Rain
Subpart H unit, be sure that gross calorific value of the fuel reported in column 34 is
expressed in the corresponding units, as follows:
GCV Units
BTU/BBL Btu Per Barrel (Subpart H)
BTU/GAL Btu Per Gallon (Subpart H)
BTU/M3 Btu Per Cubic Meter (Subpart H)
BTU/SCF Btu Per Standard Cubic Foot (Subpart H)
Source of Data Code for Volumetric Oil Flow Rate (74). Report one of the following
codes to indicate the type of value reported for oil flow rate:
0 Measured Data
1 Substitute Data Using Lookback Procedures
3 Maximum Potential Fuel Flow Rate (simplified missing data procedure for peaking
units, only)
5 Ignitor Oil From Tank Measurements
6 Uncertified OFFM to Measure Ignitor Oil
9 Default minimum fuel flow rate
If you measure and report volumetric flow rate in column 59, do not leave this field blank.
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Density of Oil (75). If you measure volumetric flow rate of oil for an Acid Rain unit, you
must sample and report the density of oil used to calculate the mass flow rate of oil.
If you calculate hourly heat input rate using volumetric fuel flow rate and are not required
to report mass flow rate of oil, it is not necessary to sample and report density. Leave this
field blank.
Units of Measure for Density of Oil (83). If you sample and report density of the oil,
report the units of measure for density. The units must correspond to the units of measure
for oil flow rate reported at column 69 as follows:
Oil Flow Rate Units
Density of Oil Units
BBLHR
GALHR
M3HR
SCFH
LBBBL
LB GAL
LBM3
LBSCF
Pounds Per Barrel
Pounds Per Gallon
Pounds Per Cubic Meter
Pounds Per Standard Cubic Feet
If you report density of oil, do not leave this field blank.
Reserved (88). This field was for OTC NOx Budget Program units only, and has been
reserved.
Flag to Indicate Multiple or Single Fuel Types Combusted (89). Report for each hour
whether only a single type of fuel was burned or whether other types of fuel were burned
during the same hour. Report an "S" for hours during which only one type of fuel was
combusted. Report an "M" for hours during which multiple fuels were combusted.
Type of Oil Sampling and GCV/Density Value Used in Calculations (90, 92). Report
the type of oil sampling and value used with one of the following codes:
0 Actual Measured Value From Daily Manual Sample
1 Actual Measured Value From Flow Proportional/Weekly Composite Sample
2 Actual Measured Value From Oil Tank Sample
4 Highest Sampled Value in Previous Calendar Year From Oil Tank Sampling (or a
higher sampled value, superseding the assumed value)
5 Highest Sampled Value in Previous Calendar Year From As Delivered Sample (or
a higher sampled value, superseding the assumed value)
6 Maximum Value Allowed by Contract (or a higher oil tank sample value,
superseding the assumed value )
7 Maximum Value Allowed by Contract (only if higher than measured oil as
delivered sample)
8 Maximum potential value from Table D-6 for missing data or emergency fuel
10 Highest Value in Previous 30 Daily Samples
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EDR v2.2 Instructions: RT 303
(14) RT 303: Gas Fuel Flow
Report RT 303 for each hour in which gaseous fuel is combusted and you use a gas flowmeter to
determine heat input rate or S02 or C02 emissions in accordance with Appendix D.
For low mass emissions units that use a certified Appendix D fuel flowmeter for long term fuel
flow purposes, do not report RT 303. See the instructions for RT 360.
If more than one type of gas is combusted in the hour (which must be measured by separately
defined fuel flowmeter monitoring systems), report multiple RTs 303 for the hour (i.e.. one for each type
of fuel).
It is not necessary to report RT 303 for other hours in which the unit operated, if, during those
hours, only fuels other than gaseous fuels were burned.
For Acid Rain units, report a companion RT 314 for each RT 303. Do not report a companion
RT 314 for non-Acid Rain Subpart H units.
If you measure fuel flow at a common pipe location, report RT 303 using the common pipe ID for
each hour in which fuel is combusted by a unit served by the common pipe. Do not report RTs 303 for
the individual units on an hourly basis. Apportion the heat input rate calculated at the common pipe to
each unit, using appropriate time-weighted apportionment formulas based on load (see Appendix F and
the RT 520 instructions). Report the apportioned hourly heat input rate values in separate RTs 300 for
the individual units. Use the hourly heat input rates and operating times from columns 36 and 18 of RT
300 to calculate the cumulative heat input values for each unit and report these values in unit-level RTs
301 and 307 (as applicable). If you use Equation F-21D to apportion the common pipe heat input to the
individual units, report RT 303 only for the common pipe — do not report any RTs 303 showing the gas
flow to the individual units.
Field Descriptions and Instructions
Monitoring System ID (10). For hours in which the gas flow system provides quality-
assured data, report the monitoring system ID for the GAS system.
For hours in which you use substitute data, you may either report the primary monitoring
system ID or leave the monitoring system ID blank (subject to the exception described
below).
For Acid Rain units, you must report the same fuel flow monitoring system ID in RT 314
as is reported in RT 303. For hours in which you use substitute data, report either the
primary system ID in both the RT 303 and RT 314, or leave the system ID blank in both
RTs.
For hours in which two different fuels are combusted and two RTs 303 are reported for a
unit or common pipe, if the fuel flow rate data are missing for both fuels, you must report
a valid monitoring system ID (as reported in RT 510) in at least one of the 303 records.
Report this same monitoring system ID in the companion RT 314.
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For Appendix E units, if you report NOx emission rate in RT 324 and report heat input
rate in RT 303, each RT 303/324 pair (for the same type of gas and the same fuel
flowmeter) must contain the same fuel flow monitoring system IDs in columns 10 of RT
303 and column 13 of RT 324.
Flow Rate of Gas During Gas Combustion (21). For Appendix D gas systems, the flow
rate of gas is measured hourly by the fuel flowmeter system. The flow rate is the net fuel
flow rate to the unit(s). For example, it may represent the sum of the gas flow rates for
two fuel flowmeters measuring gas to the unit. All values must be reported in 100
standard cubic feet per hour (100 scfh) rounded to one decimal place. This value
represents an hourly rate for periods in which the fuel is combusted, not a total flow for
the hour. If the hourly gas flow rate is so small that it results in a heat input rate of 0.0
mmBtu/hr (rounded to the nearest tenth) when Equation D-6 is used, you may report, as a
default value, the minimum gas flow rate that will give a heat input rate greater than zero.
Source of Data Code for Gas Flow Rate (31). Report one of the following codes to
indicate the source of the value for gas flow rate:
0 Hourly Measurement
1 Substitute Data Using Lookback Procedures
2 Default Minimum Fuel Flow Rate
3 Maximum Potential Fuel Flow Rate (simplified missing data procedure for peaking
units, only)
4 Emergency Fuel (maximum unit fuel flow rate)
Do not leave this field blank.
Load Range or Operational Bin Number (32).
If you use the standard, load-based fuel flow missing data procedures of Part 75,
Appendix D, you must report an operating load range ("bin number") for each hour.
During hours when you report quality assured values, use the load ranges to define the
values at each load range for missing data purposes. During hours when you use the fuel
flow missing data procedure, use the load ranges to calculate the appropriate substitute
value.
Leave this field blank if you use the simplified missing data procedures for peaking units,
as described in section 2.4.2.1 of Appendix D.
For units that do not produce electrical or steam load (e.g.. cement kilns, refinery process
heaters, etc.), leave this field blank unless you have an approved petition to use
operational bins for fuel flowrate missing data substitution. In that case, report the
operational bin number. If the operational bin number is indeterminable for a particular
hour, report "00".
For common pipes, you may use load ranges of 01 through 10 or 01 through 20. For fuel
flowmeters serving a single unit, use load ranges of 01 through 10. For non load-based
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units with approved petitions to use operational bins, the allowable operational bin
numbers range from 00 through 10.
Gross Calorific Value (GCV) of Gas (34). Report the heat content or gross calorific
value of the gas from the appropriate sample to calculate heat input. Report this value in
units of Btu/100 scf.
[Reserved] (44). This field was for OTC NOx Budget Program units only, and has been
reserved.
Heat Input Rate from Gas During Gas Combustion (45). Calculate and report hourly
heat input rate to the unit or common pipe from gas by multiplying the heat content of the
gas sample by the hourly gas flow rate. Report this value in units of mmBtu/hour rounded
to one decimal place.
Fuel Usage Time (52). Report the fraction of the clock hour during which the unit
combusted gas. You may use any equal increments from hundredths (0.01 hr.) to quarters
(0.25 hr.) of an hour. For common pipes, report the cumulative portion of the hour during
which gas was combusted in any of the units served by the common pipe, not to exceed a
fuel usage time of 1.00 (see example under instructions for column 52 of RT 302).
Type of Gas (56). Identify the type of gas combusted during the hour for the system
reported in column 10. You may either report the type of fuel using the General Fuel
Type codes (which are consistent with the codes for gas in RT 587) or you may report
more specific information on the type of gas combusted using one of the Specific Fuel
Type codes listed below. Do not provide information on more specific types of gas if you
are uncertain about the fuel type for all or any hours in the quarter.
General Fuel Type Codes
LPG Liquefied Petroleum Gas (if measured as a gas)
NNG Natural Gas
OGS
PNG
PRG
Other Gas
Pipeline Natural Gas (as defined in § 72.2)
Process Gas
Specific Fuel Type Codes
BFG
BUT
CDG
COG
DGG
LFG
PDG
PRP
Blast Furnace Gas
Butane (if measured as a gas)
Coal Derived Gas
Coke Oven Gas
Digester Gas
Landfill Gas
Producer Gas
Propane (if measured as a gas)
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RFG
SRG
Refinery Gas
Unrefined Sour Gas
Flag to Indicate Multiple or Single Fuel Types Combusted (59). Report for each hour
whether only one type of fuel was burned or whether other types of fuel were burned
during the same hour. Report an "S" for hours during which only one type of fuel was
combusted. Report an "M" for hours during which multiple fuels were combusted.
Type of Gas Sampling and GCV Value Used in Calculations (60). Report the type of
gas sampling and value used with one of the following codes:
0 Actual Measured GCV From Most Recent Monthly Sampling
1 Highest of All Sampled Values in Previous Calendar Year (or a higher sampled
value, superseding the assumed value)
2 Maximum Value Allowed by Contract (or a higher sampled value, superseding the
assumed value)
4 Actual Measured GCV From Continuous (hourly) Sampling
5 Gas Fuel in Lots, as Delivered Sampling: Highest of All Sampled Values in
Previous Calendar Year (or a higher sampled value, superseding the assumed
value)
6 Gas Fuel in Lots, as Delivered Sampling: Maximum Value Allowed by Contract
(or a higher sampled value, superseding the assumed value)
7 Actual Measured GCV From Daily Sampling
8 Missing Data Based on Table D-6 Default
10 Actual GCV From Most Recent Shipment or Lot
(15) RT 305: Quarterly Heat Input From Long Term Fuel Flow Measurements for
Qualifying Low Mass Emissions Units
If you have a qualifying low mass emissions unit and use a long term fuel flow system to measure
oil or gas to calculate heat input for the unit, report one RT 305 for each long term oil (LTOL) system
and one RT 305 for each long term gas (LTGS) monitoring system used during the quarter or reporting
period.
For a group of LME units served by a common pipe (or supply tank), you must define a LTOL
or LTGS monitoring system in the monitoring plan (RT 510) for the pipe or tank. In both cases (i.e.. for
common pipe or tank), the pipe or tank ID number must begin with a "CP" prefix (e.g.. CP001). If two
or more common pipes or tanks of different fuel types supply the same group of LME units, you must
define a separate LTOL or LTGS system in RT 510 for each pipe or tank. If two or more pipes or tanks
supply the same type of fuel to a group of LME units, you may represent it as a single LTOL or LTGS
system in RT 510.
Field Descriptions and Instructions
Monitoring System ID (10). Report the monitoring system ID for the long term fuel
flow system, as defined in RT 510.
Clean Air Markets Division, U.S. EPA
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December 2005
EDR v2.2 Instructions: RT 305
Type of Fuel (13). Report the type of fuel combusted using the following uppercase
codes:
If more than one type of fuel is combusted, you must measure the fuel using separate fuel
flow systems and report more than one RT 305 for the reporting period.
Quarter or Reporting Period (16). Report the quarter or reporting period for which
measurements were taken using the following codes, as described below:
1, 2, 3, or 4 Entire quarter
2A April only
2S May and June only
LME Acid Rain Units. NOT Subject to Subpart H
If you use long term fuel flow to determine emissions, measure and report long term fuel
flow for each quarter and indicate the quarter for which data are reported using codes 1
through 4.
LME Units. Subject to Subpart H
If you are required to report on a year-round basis, measure and report long term fuel flow
for quarters 1, 3, and 4. Indicate the quarter for which data are reported using codes 1, 3,
or 4. If you report on an ozone season-only basis, measure and report long term fuel flow
for quarter 3, but not for quarters 1 and 4.
For quarter two, if you are required to report on a year-round basis, measure long term
fuel flow for the month of April (not in the ozone season) and report the result using the
code 2A. For both year-round reporters and ozone season-only reporters, measure long
BFG
BUT
CDG
COG
DGG
DSL
LFG
LPG
NNG
OGS
OIL
OOL
PDG
PNG
PRG
PRP
RFG
SRG
Blast Furnace Gas
Butane (if measured as a gas)
Coal Derived Gas
Coke Oven Gas
Digester Gas
Diesel Oil
Landfill Gas
Liquefied Petroleum Gas (if measured as a gas)
Natural Gas
Other Gas
Residual Oil
Other Oil
Producer Gas
Pipeline Natural Gas (as defined in § 72.2)
Process Gas
Propane (if measured as a gas)
Refinery Gas
Unrefined Sour Gas
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Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: RT 305
December 2005
term fuel flow for May and June (in the ozone season) and report the result using the code
2S.
Year (18). Report the calendar year for which measurements were taken and reported.
Quarterly or Reporting Period Fuel Flow (22). Report the total fuel flow recorded for
the quarter or reporting period. If you measure in units other than those listed in the
instructions for column 32 (Units of Measure for Fuel Flow), convert the reading to
allowable units by using conversion equations.
Instructions for Using Billing Records
• If you have daily billing records, then use the daily fuel usage to apportion the fuel
flow on a daily basis to hours within the ozone season or quarter beginning on the first
operating day of the ozone season or quarter and ending on the last operating day of
the ozone season or quarter.
Example 1. If a billing period starts on June 15 and ends on July 16 and the bill
includes daily usage, use the daily quantities to determine which fuel was combusted
during June (attributed to the second quarter) and which fuel was combusted during
July (attributed to the third quarter).
• If the bill does not specify daily fuel usage, apportion fuel based on unit output, as
reported in columns 22 or 28 of RT 360.
Example 2. If the billing period starts on June 15 and ends on July 16 and the bill only
has total fuel combusted during the period, apportion the fuel into June and July based
on the unit output for the billing period. Thus, if 75% of the unit output between June
15 and July 16 occurred during June, then apportion 75% of the total fuel into June
and 25% into July.
• It is the responsibility of the owner/operator to obtain all necessary billing records in
time to ensure timely quarterly report submissions.
Instructions for Using Tank Drop Measurements
• For year-round reporting, measure the tank volume (the beginning and ending long
term fuel flow (LTFF) measurement) within no more than 48 hours of the beginning or
end of a quarter.
Example 3. If you measure the level of oil in a tank on December 30 or 31 or on
January 1 or 2, use this measurement (compared to the baseline value at the beginning
of the quarter) to calculate the amount of fuel combusted during the quarter (even if
the measurement was taken in January). Use this measurement as the baseline for
determining the amount of fuel combusted during the next quarter. When
apportioning heat input based on unit output only, use output from the beginning and
end of the quarter, not the output corresponding to the beginning and end of the actual
measurement period.
Clean Air Markets Division, U.S. EPA
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December 2005
EDR v2.2 Instructions: RT 305
• Perform as many measurements as necessary to accurately determine fuel usage during
the measurement period. The Agency recommends performing measurements before
and after fuel is added to a tank unless you know the exact volume of fuel added to the
tank.
• If a unit operated for only a very short period or used only a very limited amount of
fuel during a quarter or reporting period so that a tank drop measurement will not
yield an accurate estimate of the fuel combusted during the quarter, use the unit's
maximum rated heat input for each hour of operation during that quarter.
Instructions for Using Certified Fuel Flowmeters
• When a certified Appendix D fuel flowmeter is used for long term fuel flow purposes,
you are required to record hourly fuel flow rates. You must also submit RT 540 (fuel
flowmeter data) and must submit the results of all periodic fuel flowmeter quality
assurance tests (RTs 624, 627, 628, 629, and 630, as applicable). However, reporting
of hourly fuel flow rate information is not required. Therefore, do not report RTs 302
and 303 for low mass emissions units.
• Use the recorded hourly fuel flow rates, fuel usage times (if available) and the density
of the fuel (if needed) to determine the total mass or volume (as applicable) of each
type of fuel combusted during the reporting period. Then, use Equation LM-2 or LM-
3 in § 75.19, as appropriate, to calculate the heat input from each type of fuel
combusted during the reporting period. Add together all of the reporting period heat
input values for all fuels, according to Equation LM-4. Then, apportion the total heat
input for the reporting period to each operating hour in the period, using Equations
LM-5 through LM-8A (as applicable) replacing the term "quarter" with the term
"reporting period."
• When calculating the total mass or volume of fuel combusted, if hourly fuel usage
times are not available, use a value of 1.00 for each operating hour in the reporting
period.
• If any fuel flowmeter data are missing for any hour(s) in the reporting period, you
must provide substitute data for those hours, using either: (1) the load-based missing
data procedures in Appendix D (if these procedures are programmed in the DAHS); or
(2) the maximum system fuel flow rate in column 20 of RT 540.
Units of Measure for Fuel Flow (32). Report the units of measure in which you are
reporting fuel flow using one of the following uppercase codes:
GAL Gallons
LB Pounds
SCF Standard Cubic Feet
Gross Calorific Value (37). Report the heat content or gross calorific value (GCV) of
the fuel from Table LM-5 of § 75.19 or the highest GCV recorded in the previous
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Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: RT 307
December 2005
calendar year from fuel sampling and analysis according to the procedures of Appendix D
to Part 75.
If you measure in units other than those listed in the instructions for column 47 (GCV
Units of Measure), convert to an allowable unit by using appropriate conversion
equations.
Gross Calorific Value Units of Measure (47). Report the units of measure for GCV
using one of the following uppercase codes:
BTU/GAL Btu Per Gallon
BTU/LB Btu Per Pound
BTU/SCF Btu Per Standard Cubic Feet
Total Heat Input (55). Calculate and report the total heat input measured by the long
term fuel flow system for the quarter or reporting period using the appropriate heat input
formula from § 75.19. If this system is the only long term fuel flow system used for the
unit or group of units, apportion this heat input to the unit operating hours in the quarter
(or reporting period) in RT 360, using the appropriate equation in § 75.19. If two or
more long term fuel flow systems are used during the quarter or reporting period, sum the
total heat input values from all systems before apportioning heat input to the unit
operating hours.
For a single Acid Rain Program LME unit which is not part of a group of LME units, the
total heat input values in RT 305, column 55 for all long term fuel flow systems used
during the quarter must equal the quarterly unit heat input value reported in column 82 of
RT 301.
For a group of Acid Rain Program LME units served by one or more common pipes or
tanks, you must report both RT 305 and RT 301 under each common pipe (or tank) ID
number. For each common pipe or tank ID, the total heat input reported in column 55 of
RT 305 must equal the quarterly heat input reported in column 82 of RT 301.
(16) RT307: Cumulative NOx Mass Emissions Data (ARP Low Mass Emissions
Units or Subpart H Units Only)
For each reporting period, submit RT 307 for each Subpart H stack, unit (including LME units),
and pipe ID included in the quarterly report.
For Acid Rain Subpart H units, report RTs 301 and 307.
For non-Acid Rain Subpart H units, report RTs 307 but do not report RT 301.
For Acid Rain Program low mass emissions (LME) units not subject to Subpart H, report S02
mass emissions, C02 mass emissions, heat input, average NOx emission rate and operating hours in RT
301. In RT 307, report only the information in columns 1 through 27 and the NOx mass emissions
information in columns 67 through 76, for the purpose of documenting compliance with the applicable
NOx emission threshold.
Clean Air Markets Division, U.S. EPA
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December 2005
EDR v2.2 Instructions: RT 307
For a summary of which fields to report based on program applicability and use of the low mass
emissions (LME) provisions, see Table 7 below. Note that for Acid Rain Program units, cumulative
annual heat input and operating hours are not reported in RT 307. Rather, these values are reported in
RT 301.
Table 7
SUMMARY OF RT 307 REPORTING REQUIREMENTS
Applicable
Pro<>riims
LME?
Report
RT
307?
RT 307 Fields l<> Report
NO, Tons
1 lent Input
Oper:itin»
1 lours
Anniiiil \'sillies
Rpt
Period
(IS)
OS
(28)
Rpt
Period
(38)
OS
(48)
Rpt
Period
(58)
OS
(62)
NOx
Ions
(67)
HI
(77)
Op
Hrs
(87)
ARP-only
No
N
N/A
ARP-only
Yes
Y
Y
N
N
N
N
N
Y
N
N
ARP + SUBH
No
Y
Y
Y
Y
Y
Y
Y
Y
N
N
ARP + SUBH
Yes
Y
Y
Y
Y
Y
Y
Y
Y
N
N
SUBH-only
No
Y
Y
Y
Y1
Y1
Y
Y
Y2
Y3
Y2
SUBH-only
Yes
Y
Y
Y
Y1
Y1
Y
Y
Y2
Y3
Y2
Y1 - Unless exempted by State SIP
Y2 - If reporting year-round
Y3 - If reporting year-round, unless exempted by State SIP
Common Stacks or Pipes. For a simple common stack or pipe (two or more units served by one
stack or pipe), the heat input for the stack or pipe must equal the sum of the heat inputs for the units
associated with the stack or pipe. This applies to reporting period heat input, cumulative ozone season
heat input, and (if applicable) cumulative annual heat input. Do not apportion NOx mass emissions to the
individual units. Submit a RT 307 for the common stack or pipe and submit an additional RT 307 for
each unit associated with the common stack or pipe.
Example # 1: If CS1 is a monitored common stack serving Units 1 and 2, report three RTs 307,
one for Stack CS1, one for Unit 1, and one for Unit 2. In RT 307 for CS1, report the heat input and NOx
mass, as measured at the common stack, and the operating hour information for the common stack. In
the RTs 307 for Units 1 and 2, report only the individual unit heat input in mmBtu (as derived from the
heat input rates and operating times in the unit-level RTs 300) and the operating hour information. Do
not report unit-level NOx mass emissions in the RTs 307 for Units 1 and 2. If you are affected by Subpart
H only and are not required to report heat input, follow these instructions but leave the heat input fields
blank.
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Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: RT 307
December 2005
Example #2: For a group of low mass emissions units (Units 1, 2 and 3) served by a common
pipe and using long term fuel flow to quantify heat input, report RTs 307 and 301 for the common pipe
and individual units, as follows:
• If the units are in the Acid Rain Program but are not Subpart H units, report only the quarterly
and cumulative annual NOx mass emissions in a separate RT 307 for each of the three units.
Do not report RT 307 for the common pipe. In a separate RT 301, report for each unit the
quarterly and cumulative S02 mass emissions, C02 mass emissions, heat input, average NOx
emission rate, and unit operating hours. Submit RT 301 for the common pipe, but report only
the quarterly and cumulative heat input — leave all of the emissions data fields and operating
hour fields blank.
• If Units 1, 2, and 3 are non-Acid Rain, Subpart H units, do not report any RTs 301. Instead,
report one RT 307 for each unit and one RT 307 for the common pipe. In each unit-level RT
307, report only the reporting period values and the appropriate cumulative values of NOx
mass emissions, heat input, and operating hours. In the RT 307 for the common pipe, report
only the reporting period values and the appropriate cumulative values of heat input. If data
are reported year-round, the "appropriate" cumulative values are the ozone season and annual
values. If data are reported on an ozone season-only basis, the appropriate cumulative values
are the ozone season values.
• If Units 1, 2, and 3 are affected units under both the Acid Rain Program and Subpart H,
report both RT 301 and RT 307 for each unit and for the common pipe. In each unit-level RT
307, report only the reporting period and cumulative ozone season values of NOx mass
emissions, heat input, and operating hours. In the RT 307 for the common pipe, report only
the appropriate reporting period and ozone season cumulative values of heat input. Report
the cumulative annual heat input and cumulative annual operating hours in the RT 301 for
each unit. In the RT 301 for the common pipe, report only the cumulative annual heat input.
Multiple Stacks or Pipes. For some units, there are multiple stacks or ducts (with installed
CEMS) leading from the unit. In other cases, there are multiple pipes (with installed fuel flowmeters)
associated with the unit (e.g.. a combined cycle turbine with duct burner using Appendix E). For these
configurations, each reported emission or heat input value for the unit must equal the sum of the
corresponding emission or heat input values reported for the individual stacks or pipes.
For example, if MSI A and MS IB are multiple stacks associated with Unit 1, report three RTs
307, one for Unit 1, one for Stack MSI A and one for Stack MS IB. RT 307 for Unit 1 would include the
sum of heat input, and the operating hour information for Unit 1. Do not report unit level NOx mass
emissions in RT 307 for Unit 1. RTs 307 for MS1A and MS1B would include the heat inputs, the NOx
mass emissions measured at the individual stack locations and the operating hour information for each
stack. If the unit is affected by Subpart H only and you are not required to report heat input for the unit,
follow these instructions but leave the heat input fields blank.
Complex Stacks. A complex stack situation exists where a unit's emissions are measured at more
than one stack location and where at least one of these stack locations is a common stack shared with one
or more other units. For the purposes of heat input accounting, the sum of the heat inputs for all units
associated with all stacks in a complex configuration must equal the sum of the stack heat inputs for all
the stacks. Do not apportion NOx mass emissions to the individual units in complex configurations.
Clean Air Markets Division, U.S. EPA
Page 81
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December 2005
EDR v2.2 Instructions: RT 307
For example, if emissions from Units 1, 2, and 3 are measured at CS1 and are also measured
during bypass hours at CS2, the sum of the heat inputs for Units 1, 2, and 3 must equal the sum of the
heat inputs for CS1 and CS2. The RTs 307 for CS1 and CS2 must contain the heat inputs and NOx mass
emissions measured at the stack locations and the operating hour information. RTs 307 for Units 1, 2,
and 3 must contain the apportioned heat inputs and the operating hour information; do not report NOx
mass emissions in the unit level RTs 307. If you are affected by Subpart H only and are not required to
report heat input, follow these instructions but leave the heat input fields blank.
Report data for all units and stacks involved in a complex configuration in a single quarterly
report file. In this quarterly report file, report only one RT 307 for each individual unit, regardless of the
number of stacks to which the unit discharges its emissions.
Field Descriptions and Instructions
Date of Report Generation (10). Report the calendar date on which the quarterly report
was created.
Reporting Period NOx Tons Emitted (18). Report the sum of the actual NOx mass
emissions for the reporting period (calendar quarter) using Equation F-27 in Appendix F
of Part 75. Use the values reported in RT 328 (for Subpart H) or RT 360 (for low mass
emissions units) in this equation. Round and report the sum to one decimal place.
Cumulative Ozone Season NOx Tons Emitted (28). Report the NOx mass emissions for
the ozone season through the end of the reporting quarter. For the first quarter report,
report zero or leave this field blank. For the second quarter report the total NOx mass
emissions for May and June. For the third quarter report, report the total NOx mass
emissions from May through September. For the fourth quarter, report again the total
NOx mass emissions from May through September. Round and report the sum to one
decimal place.
For Acid Rain Program low mass emissions units not subject to Subpart H, leave this field
blank.
Reporting Period Heat Input (38). For non-LME Subpart H units (whether Acid Rain
or non-Acid Rain affected) for each hour in the reporting period, calculate the hourly heat
input by multiplying the hourly heat input rate reported in column 36 of RT 300 for the
unit, stack, or pipe, by the corresponding operating time in column 18 of RT 300. Report
the sum of these calculated heat input values. Round and report the result to one decimal
place.
For low mass emissions units subject to Subpart H, report the sum of the actual heat input
values reported in RT 360 for the current reporting period (see also the instructions for
RT 305).
For Acid Rain low mass emissions units not subject to Subpart H, leave this field blank.
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Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: RT 307
December 2005
For non-Acid Rain Subpart H units that use NOx concentration times stack flow as the
primary methodology to calculate NOx mass emissions, you may leave this field blank,
unless reporting of heat input is required for allocation purposes.
Cumulative Ozone Season Heat Input (48). If required to do so by State or federal
regulations or by the State regulatory agency, calculate the cumulative heat input for the
ozone season. For each hour in the ozone period, calculate the hourly heat input by
multiplying the hourly heat input rate reported in column 36 of RT 300 for the unit, stack,
or pipe, by the corresponding operating time in column 18 of RT 300. Report the sum of
these calculated heat input values. Round and report the sum to one decimal place.
For low mass emissions units subject to Subpart H, report the sum of the actual heat input
values reported in RT 360 for the ozone period (see also the instructions for RT 305).
For Acid Rain low mass emissions units not subject to Subpart H, leave this field blank.
For the first quarter report, report zero or leave this field blank. For the second quarter
report, report the total heat input for May and June. For the third quarter report, report
the total heat input from May through September. For the fourth quarter, report again the
total heat input from May through September.
For non-Acid Rain Subpart H units that use NOx concentration times stack flow as the
primary methodology to calculate NOx mass emissions you may leave this field blank,
unless reporting of heat input is required for allocation purposes.
Total Reporting Period Operating Hours (58). Report the number of hours in which
the unit or stack operated during the reporting period. Count each partial hour as a whole
hour.
For Acid Rain low mass emissions units not subject to Subpart H, leave this field blank.
Cumulative Ozone Season Operating Hours (62). Report the cumulative number of
hours in which operation occurred during the ozone season through the end of the
reporting quarter. For the first quarter report, report zero or leave this field blank. For
the second quarter report, the sum will include the operating hours for May and June. For
the third quarter report, this will include the operating hours from May through
September. Count each partial hour as a whole hour. For the fourth quarter, report again
the cumulative ozone season operating hours from May through September.
For Acid Rain low mass emissions units not subject to Subpart H, leave this field blank.
Cumulative Annual NOx Tons Emitted (67). For each unit, stack, or pipe that reports
NOx mass emissions on a year-round basis, sum the annual NOx mass emissions reported
for the year. Round and report this sum to one decimal place. In Quarter 1, the reporting
period total NOx tons reported in column 18 must be the same as the cumulative annual
tons reported in column 67. In subsequent quarters, add the total NOx tons emitted in the
current quarter to the cumulative annual NOx tons reported in column 67 of the previous
Clean Air Markets Division, U.S. EPA
Page 83
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December 2005
EDR v2.2 Instructions: RT 310
quarter's report to obtain the new value of the cumulative annual NOx tons emitted.
Round and report to one decimal place.
If you report NOx mass emissions only during the ozone season, leave this field blank.
Cumulative Annual Total Heat Input (Non-Acid Rain Subpart H) (77). For non-
Acid Rain Subpart H units reporting on a year-round basis, report this field if your State
or EPA requires heat input data for allocation or other purposes. For each hour in the
year, calculate the hourly heat input by multiplying the hourly heat input rate reported in
column 36 of RT 300 for the unit, stack, or pipe by the corresponding operating time in
column 18 of RT 300. Report the sum of these calculated heat input values.
For Subpart H units reporting on an ozone season only basis, leave this field blank. For
non-Acid Rain Subpart H units that use NOx concentration times stack flow as the primary
methodology to calculate NOx mass emissions, leave this field blank, unless reporting of
heat input is required for allocation purposes.
Cumulative Annual Unit/Stack/Pipe Operating Hours (Non-Acid Rain Subpart H)
(87). For all non-Acid Rain Subpart H units, stacks, or pipes reporting operating data on
a year-round basis, sum the number of hours in which the unit, stack, or pipe operated
during the year-to-date. Count each hour of partial operation as a single hour. If you
report NOx mass emissions only during the ozone season, leave this field blank.
(17) RT 310: S02 Mass Emissions Data (ARP)
For each Acid Rain Program unit or stack with an S02 CEMS, report the calculated S02 emission
rate in RT 310, for each operating hour (or partial operating hour), with one exception: do not report
RT 310 for hours in which only gaseous fuel is combusted, if you account for S02 mass emissions during
those hours using the provisions of § 75.11(e)(2), in lieu of operating and recording data from the S02
monitoring system. If you calculate the hourly S02 mass emission rate from a quality-assured S02
concentration and a quality-assured stack flow rate (including hours in which data from a like-kind
replacement S02 analyzer are reported in RT 200), you must report data in all fields of RT 310, except
for column 35.
If you monitor S02 mass emission rate and report RT 310 at a common stack, do not apportion
the S02 mass emission rate measured at the common stack to the individual units (i.e.. do not report any
additional RTs 310 under the associated unit IDs).
If, for a particular unit, you monitor S02 mass emission rate at multiple stacks (or ducts), do not
report the combined S02 mass emission rate for the unit (i.e.. do not report any unit-level RTs 310).
Field Descriptions and Instructions
S02 Mass Emission Rate for the Hour (18). This value is derived using the quality-
assured, unadjusted stack flow reported in RT 220, column 29, and the quality-assured,
unadjusted S02 concentration reported in RT 200, column 29, in conjunction with the
appropriate equation in Appendix F to Part 75. Report this field in lb/hr. Round to one
decimal place.
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Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: RT 313
December 2005
Leave this field blank if substitute data value(s) are reported in either RT 200, column 35
(for S02 concentration) or in RT 220, column 39 (for flow rate), or both. During such
hours, the unadjusted S02 mass emission rate cannot be calculated because the unadjusted
S02 concentration in RT 200, column 29 or the unadjusted flow rate in RT 220, column
29 (or both) will be blank.
If you calculate the hourly S02 mass emission rate using Equation F-l or F-2 in Appendix
F to Part 75, leave this field blank if the unadjusted S02 concentration reported in RT 200,
column 29 is blank and if any of the following occurs for a particular hour: (1) a 2.0 ppm
default S02 concentration value is reported in RT 200, column 35 during combustion of a
very low-sulfur gaseous fuel; or (2) a default high range value of 200% of the MPC is
used in the calculation of the hourly average S02 concentration reported in RT 200,
column 35; or (3) a full-scale exceedance value of 200% of the range is used in the
calculation of the hourly average S02 concentration reported in RT 200, column 35.
Leave this field blank for any hour in which only natural gas is combusted and the hourly
S02 mass emission rate is calculated from a CEMS-derived heat input rate and a default
S02 emission rate, using Equation F-23 in Appendix F to Part 75 (see § 75.11(e)(1)).
Leave this field blank for hours in which you calculate S02 emission rate using data
provided by a reference method backup monitoring system, either for S02 concentration
or stack flow rate (or both).
S02 Mass Emission Rate During Unit Operation Based on Adjusted Values (25).
This value is normally derived using the bias-adjusted stack flow reported in RT 220,
column 39, and the bias-adjusted S02 concentration reported in RT 200, column 35, in
conjunction with the appropriate equation in Appendix F to Part 75. However, for an
hour in which only natural gas is combusted, the value may be calculated from a CEMS-
derived heat input rate and a default S02 emission rate using Equation F-23 (see
§ 75.11(e)(1)). Report data in this field in lb/hr. Round to one decimal place.
Formula ID From Monitoring Plan for Hourly S02 Emissions (32). Report the
formula ID from RT 520 that is used for the S02 hourly emissions rate calculation.
Total S02 Mass Emissions for the Hour (Optional) (35). If you choose to report this
field, report total S02 mass emissions in pounds, rounded to one decimal place.
(18) RT 313: S02 Mass Emissions Alternative Estimation Parameters for Oil
(ARP)
For Acid Rain units using Appendix D, for each hour in which any type of oil is burned, report RT
313 (and the corresponding RT 302 for that type of oil). Do not report this RT for non-Acid Rain
Subpart H units.
Clean Air Markets Division, U.S. EPA
Page 85
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January 2003
EDR v2.2 Instructions: RT 313
Field Descriptions and Instructions
Monitoring System ID (10). There is a one-to-one correspondence for each hourly fuel
flow rate record in RT 302 and the estimated S02 emissions associated with the fuel,
reported in RT 313. Report the same system ID in RTs 313 and 302 for each hour.
For hours in which the fuel flow rate is missing, either report the primary fuel flow system
ID in both RT 302 and 313 or leave the system ID blank in both RTs.
Sulfur Content of Oil Sample Used to Calculate S02 Mass Emission Rate (21).
Report the sulfur content of the oil sample. If percent sulfur is measured to the nearest
hundredth you may report the actual value using two decimal places.
Use Table D-4 in Appendix D to Part 75 to determine what value you should report in this
field.
Code for Method of Oil Sampling [Reserved] (26). This field has been replaced by the
field in column 44. Leave this field blank.
Missing Data Flag for Sulfur Content [Reserved] (29). This field has been replaced by
the field in column 44. Leave this field blank.
S02 Mass Emission Rate From Oil During Oil Combustion (30). Report the S02
mass emission rate in lb/hr calculated using Equation D-2 from Appendix D to Part 75,
rounded to one decimal place.
Total S02 Mass Emissions From Oil (Optional) (37). Report the total S02 mass
emissions (in lb) using the rounded S02 mass emission rate from oil reported in column 30
multiplied by the fuel usage time during the hour in RT 302 column 52, rounded to one
decimal place. This is an optional field.
Type of Sulfur Sampling and Value Used in Calculations (44). Report the derivation
of the sulfur content value using one of the following codes:
1 Actual Measured Value from Oil Composite Sample
2 Actual Measured Value from Oil Tank Sample
3 Highest Daily Sample in 30 Daily Samples
4 Highest Sampled Value in Previous Calendar Year from Oil Tank Sampling (or a
higher sampled value, superseding the assumed value)
5 Highest Sampled Value in Previous Calendar Year from As Delivered Sample (or a
higher sampled value, superseding the assumed value)
6 Maximum Value Allowed by Contract (or a higher tank sample value, superseding
the assumed value)
7 Maximum Value Allowed by Contract (or a higher sampled value, superseding the
assumed value)
8 Missing Data (Maximum Potential Value for missing data or emergency fuel from
Table D-6)
9 Actual Measured Value from a Daily Sample
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January 2003
(19) RT 314: S02 Mass Emissions Alternative Estimation Parameters for Gas
(ARP)
For Acid Rain units using Appendix D, for each hour in which any type of gas is burned, report
RT 314 (and the corresponding RT 303). Do not report this RT for non-Acid Rain Subpart H units.
Field Descriptions and Instructions
Monitoring System ID (10). There is a one-to-one correspondence for each hourly fuel
flow rate record in RT 303 and the estimated S02 mass emissions associated with the fuel
reported in RT 314. Report the same system ID as for the RT 303 on which the S02
calculation is based.
For hours in which fuel flow is missing, either report the primary fuel flow system ID in
both RT 303 and 314 or leave the system ID blank in both RTs.
Sulfur Content of Gas Sample Used to Calculate S02 Mass Emission Rate (21).
Report the sulfur content of the gaseous sample in grains/100 scf. Use Table D-5 in
Appendix D to determine the correct value. If you report using a default S02 emission
rate, leave this field blank. If the sulfur content for any sample(s) is 0.04 grains/100 scf or
less, contact EPA for further reporting guidance.
Missing Data Flag for Sulfur Content [Reserved] (29). This field has been replaced by
the field in column 52. Leave this field blank.
Default S02 Emission Rate (30). If pipeline natural gas is combusted, report the default
S02 emission rate for natural gas of 0.0006 lb/mmBtu for pipeline natural gas. If you
calculate a default emission rate using Equation D-lh, report the default rate in this
column.
S02 Mass Emission Rate From Gas During Gas Combustion (37). If you report a
default S02 emission rate in column 30, calculate and report the S02 mass emission rate
using the default S02 emission rate and the hourly heat input rate reported in RT 303
using Equation D-5 from Appendix D.
If you report the sulfur content of the gas in column 21 of this record, calculate and report
S02 mass emission rate by using the sulfur content reported in column 21 and the hourly
volumetric flow rate of gas flow reported in RT 303. Use Equation D-4 from
Appendix D.
Total S02 Mass Emissions From Gas (Optional) (45). Report the total S02 mass
emissions (lbs) using the S02 mass emission rate reported in column 37 multiplied by the
fuel usage time reported in RT 303, column 52. This is an optional field.
Type of Sulfur Sampling and Value Used in Calculations (52). Report the derivation
of the sulfur content value using one of the following codes:
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EDR v2.2 Instructions: RT 322
0 Actual Measured Hourly Average Sample from GCH
3 Highest Daily Sample in 30 Daily Samples
5 Highest Sampled Value in Previous Calendar Year from As Delivered Sample (or a
higher sampled value, superseding the assumed value)
7 Maximum Value Allowed by Contract (or a higher sampled value, superseding the
assumed value)
8 Maximum Potential Value from Table D-6 for missing data or emergency fuel
9 Actual Measured Value from Daily Sample
10 Actual Measured Value from Most Recent Shipment or Lot
If you report a default S02 emission rate in column 30, leave this field blank.
(20) RT 320: NOx Emission Rate Data
If you use a NOx-diluent system to measure NOx emission rate, report RT 320 for each hour (or
partial hour) in which the unit or stack operates. For hours in which the unit or stack did not operate, do
not report RT 320.
For Subpart H units that do not have a Part 75 requirement to report NOx emission rate, do not
report RT 320 for hours in which you report NOx mass emissions as NOx concentration times stack flow
rate.
If you monitor NOx emission rate and report RT 320 at a common stack, do not apportion the
NOx emission rate measured at the common stack to the individual units (i.e.. do not report any additional
RTs 320 under the associated unit IDs).
If, for a particular unit, you use CEMS to monitor both the NOx emission rate and the heat input
rate at multiple stacks (or ducts), for hours in which gases flow through both stacks or ducts, report the
hourly NOx emission rates measured at each stack (or duct) in separate, stack-level RTs 320. In addition,
use the equation in the RT 301 instructions (columns 36, 49) to calculate, hour-by-hour, the heat input-
weighted NOx emission rate for the unit. Store, but do not report these hourly unit-level weighted NOx
emission rates (i.e.. do not report any unit-level RTs 320). Rather, use them to calculate the quarterly
and cumulative NOx emission rates for the unit. Report these quarterly and cumulative values in the unit-
level RT 301 (see the RT 301 instructions for further details).
For a combined-cycle turbine that uses a multiple-stack configuration, report separate stack-level
RT 320 for each hour in which there is both main stack and bypass stack operating time (see RT 300,
column 18 instructions). Then, calculate a time-weighted unit-level NOx emission rate for each hour, as
described in the RT 301, column 36 instructions. Store, but do not report these time-weighted, hourly
unit-level emission rates. Rather, use them to calculate the quarterly and cumulative unit-level NOx
emission rates.
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December 2005
Field Descriptions and Instructions
Monitoring System ID (10). Report the monitoring system ID for the NOx-diluent
monitoring system that is providing quality-assured data for the hour.
For missing data hours, leave this field blank. This includes hours in which the flue gases
are discharged through an unmonitored bypass stack.
If either: (1) a default high range NOx concentration value of 200% of the MPC is
reported in RT 201 due to a full-scale exceedance of the low range; or (2) a value of
200% of the range is reported in RT 201 during a full-scale exceedance of the high range,
report the ID number of the NOx-diluent monitoring system which is in use at the time of
the full-scale exceedance.
Percent Monitor Data Availability for NOx Emission Rate Calculations (21). Report
the percent monitor data availability for all hours unless missing data are substituted. You
may report percent monitor data availability for hours in which missing data are
substituted, but this is optional.
F-factor Converting NOx Concentrations to Emission Rates (26). Report the F-factor
used to calculate NOx emission rate for the hour. For missing data hours, this field may be
blank. The instructions for RT 520 contain a table of the standard F-factors.
Average NOx Emission Rate for the Hour (36). Calculate and report to three decimal
places the NOx emission rate based on the measured data reported in RTs 201, 210 (or
211), and 212 (or 531), as applicable. For hours in which you use missing data
procedures leave this field blank, including hours in which the flue gases are discharged
through an unmonitored bypass stack.
If you use Equation 19-3 or 19-5 to determine NOx emission rate, you must use modified
Equation 19-3D or 19-5D (as applicable) instead of Equation 19-3 or 19-5, for hours in
which you use the diluent cap (see Table 14 in the RT 520 instructions).
Adjusted Average NOx Emission Rate for the Hour (42). For each hour in which you
report NOx emission rate in column 36, apply the appropriate adjustment factor (1.000 or
bias adjustment factor (BAF)) to the rounded average NOx emission rate and report the
adjusted NOx emission rate for the hour, rounded to three decimal places.
(Note that for an initial certification, analyzer replacement or complete monitoring
system replacement (as indicated by reporting an RT 556 with an Event Code of 100,
101, 120 or 125), if you are using conditional data validation, the BAF is uncertain
during the conditional data period. Therefore, apply a BAF of 1.000 from the
beginning of the conditional data validation period to the completion hour of the
certification or recertification RATA.)
For each hour in which you substitute and report missing data, report the appropriate
substitute data value , including hours in which the flue gases are discharged through an
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EDR v2.2 Instructions: RT 322
unmonitored bypass stack, and you report the maximum potential NOx emission rate
(MER).
For a combined-cycle CT using a multiple-stack configuration to report NOx emission
rate, use missing data substitution for any transition hour (i.e.. an hour during which gases
flow through both stacks), if either the main stack or bypass monitoring system is out of
service, and draw the appropriate substitute data value from the bypass stack data pool.
Do not leave this field blank.
If a full-scale exceedance of the low NOx range occurs and you use a default high range
value of 200% of the MPC in the calculation of the hourly average NOx concentration
reported in RT 201, or if a full-scale exceedance of the high NOx range occurs and you use
a value of 200% of the range in the calculation of the hourly average NOx concentration
reported in RT 201, use the reported NOx concentration in conjunction with the quality-
assured diluent concentration for the hour to calculate and report the NOx emission rate.
These hours are treated as quality-assured monitor operating hours; they are included in
missing data lookback and are treated as available hours for percent monitor data
availability calculations.
If a diluent concentration is unavailable during an hour in which a full scale exceedance of
the NOx analyzer occurs or an hour in which the default high range value is used, the NOx
emission rate for the hour is considered to be missing. In that case, do not report RT 201
for this hour and do not report RT 210 or 211 (unless the RT 210 or 211 is needed for
heat input rate determination), since the NOx emission rate cannot be calculated; instead,
report the maximum potential NOx emission rate (MER) in this field, and use an MODC of
25.
Load Range or Operational Bin Number (48). For a load-based unit, report the
appropriate load range ("load bin number") for each operating hour (see the RT 300,
column 34 instructions for a further discussion of load bin numbers).
For non load-based units (e.g.. cement kilns, refinery process heaters), if operational bins
are used for missing data purposes, report the operational bin number. If the operational
bin is indeterminable for a particular hour, report "00". If operational bins are not used,
leave this field blank.
Formula ID From Monitoring Plan for Hourly NOx Emission Rate (50). Report the
appropriate formula ID from RT 520 for the NOx emission rate calculation. If you report
an MODC of 14 (use of diluent cap) in column 53, you must report a formula ID for the
hour. For missing data hours you may leave this field blank or continue to report the
formula ID in use before the missing data period.
Method of Determination Code (53). Report one of the following method of
determination codes (MODC) to identify the monitoring system or missing data procedure
used to report hourly NOx emission rate. Report an MODC of 14 when the diluent cap
value for C02 or 02 is used in place of the measured value reported in RT 210 or 211.
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December 2005
Also, be sure that you register the diluent cap value for the unit in RT 531. A diluent cap
value can only be used for measured (quality assured) operating hours.
For full-scale exceedances of a NOx analyzer, EPA requires reporting of an MODC
reflecting the monitoring system in use during the exceedance or reporting of an MODC
of 25 if the diluent concentration normally reported in RT 210 or 211 is not quality-
assured. Therefore, during full-scale exceedances, when 200% of MPC or 200% of range
is reported for NOx concentration in RT 201 and is used in conjunction with a quality-
assured diluent gas concentration to calculate the NOx emission rate, report the MODC
code associated with the monitoring system that is in use at the time of the full-scale
exceedance (for example, report 01 if the primary NOx-diluent monitoring system is in
use). If a full-scale exceedance of the NOx analyzer occurs and no quality-assured diluent
gas concentration for the hour is available, report an MODC of 25 for that hour. Manual
entry of MODC "21" is permitted.
01 Primary Monitoring System
02 Redundant Backup or Regular Non-redundant Backup Monitoring System
03 Approved Part 75 Alternative Monitoring System
04 Reference Method Backup System
05 Part 75 Approved Parametric Method
06 Average Hour Before/Hour After
07 Average Hourly Rate, Initial Missing Data
08 90th Percentile Value in Load Range in Lookback Period
09 95th Percentile Value in Load Range in Lookback Period
10 Maximum Hourly Rate in Load Range in Lookback Period
11 Average Hourly Rate in Load Range in Lookback Period
12 Unit or Stack Maximum Emission Rate (MER)
14 Diluent Cap (If the cap is replacing a C02 measurement it should be 5.0% for
boilers and 1.0% for turbines; if it is replacing an 02 measurement it should be
14.0%) for boilers and 19.0% for turbines.)
21 Zero NOx Emission Rate, Calculated Using a Negative NOx Concentration
Replaced with Zero
22 NOx Emission Rate calculated from a certified NOx monitor at the control device
inlet, when the outlet NOx monitor is unavailable and proper operation of the
emission controls is not verified. These hours are included in missing data
lookback and are treated as available hours for percent availability calculations.
23 Maximum Potential NOx Emission Rate, When Flue Gases are Routed Through an
Unmonitored Bypass Stack. These hours are considered to be missing data hours.
25 Maximum Potential NOx Emission Rate (MER). Use only when a NOx
concentration full-scale exceedance occurs and the diluent monitor is unavailable.
54 Other Quality-assured Methodologies Approved Through Petition by EPA (if data
are submitted for the Acid Rain Program). These hours are included in missing
data lookback and are treated as unavailable hours for percent availability
calculations.
55 Other Substitute Data Approved Through Petition by EPA (if data are submitted
for the Acid Rain Program). These hours are not included in missing data
lookback and are treated as unavailable hours for percent availability calculations.
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EDR v2.2 Instructions: RT 323
EPA has reserved codes 01 through 55. Codes 56 through 99 may be used by vendors
and companies for other purposes; do not report these codes in a quarterly report.
MODCs of 30 and 31 were defined in EDR v2.0 for OTC NBP units only and are not
allowed for Acid Rain or Subpart H reporting.
(21) RT 321: NOx Emission Rate Alternative Estimation Parameters for Oil
[Replaced]
This record type was retired December 31, 1995. RT 323 replaced RT 321.
(22) RT 322: NOx Emission Rate Alternative Estimation Parameters for Natural
Gas [Replaced]
This record type was retired December 31, 1995. RT 324 replaced RT 322.
(23) RT 323: NOx Emission Rate Alternative Estimation Parameters for Oil and
Gas
Report RT 323 if your unit always uses a consistent mix of fuels and you performed Appendix E
testing on this unit for this mix of fuels. Report the average NOx emission rate for a unit in RT 323. If
you performed Appendix E testing separately for each fuel, report NOx emission rate in RTs 324 and 325.
Field Descriptions and Instructions
Monitoring System ID (10). Report the monitoring system ID for the NOx monitoring
system defined in RT 510 for Appendix E. This system should contain only a DAHS
component.
Parameters Status Flag (21). Report one of the following codes:
E Emergency Fuel
N Operating Parameter is Outside of Normal Limits
U Uncontrolled Hour
W Operation Above Highest Tested Heat Input Rate Point on the Curve
M Correlation Curve for the Fuel Mixture has Expired
X Operating Parameter Data Missing or Invalid
Y Designated Operational and Control Equipment Parameters Within Normal Limits
Z Operation Below Lowest Tested Heat Input Rate Point on the Curve
Use the applicable Appendix E missing data procedures for any hour in which an "N, "X",
or "W" is reported. Report the maximum potential NOx emission rate (for the highest-
emitting fuel in the mixture when reporting M) when a required Appendix E retest is not
completed by its due date. Also report the NOx MER for any hour in which "E" or "U" is
reported. For more information about these codes, see the instructions for RT 324 below.
Average NOx Emission Rate for the Hour (22). Identify the appropriate segment of the
heat input rate/NOx emission rate curve reported in RT 560. Determine the hourly NOx
emission rate for the unit using the appropriate curve segment. This includes hours in
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EDR v2.2 Instructions: RT 324
December 2005
which you report "N" in column 21 and apply the standard missing data procedure in
section 2.5.2 of Appendix E. Report this rate to three decimal places.
For hours in which you report "W", "U", "M" or "E" in column 21, report the appropriate
substitute NOx emission rate value in this field, to three decimal places (see Appendix E,
sections 2.5.2.1, 2.5.2.2, and 2.5.2.3 and the column 21 instructions).
Average NOx Emission Rate for the Hour (Oil) [Reserved] (28). This field is reserved.
Leave this field blank.
Average NOx Emission Rate for the Hour (Gas) [Reserved] (34). This field is
reserved. Leave this field blank.
Segment ID of Correlation Curve (40). Report the segment ID from RT 560 for the
correlation curve for a consistent mix of fuels used to determine the NOx emission rate for
the hour. Leave this field blank if you report "W", "U", "M", or "E" in column 21.
(24) RT 324: NOx Emission Rate Estimation Based on Appendix E
Submit RT 324 for each hour or partial hour of operation of each Appendix E unit. If more than
one type of fuel is combusted during an hour, submit one RT 324 for each type of fuel burned. When
more than one type of fuel is combusted during an hour, also submit RT 325 for that hour.
Field Descriptions and Instructions
NOx Monitoring System ID (10). Report the monitoring system ID for the NOx system
defined in RT 510 for Appendix E. This system should only contain a DAHS component.
If Appendix E curves have been derived separately for each fuel type, then, whenever the
fuels are co-fired, report a separate, unique NOx monitoring system ID number in each RT
324 for the hour. When emergency fuel is combusted, if you do not have a separate
correlation curve for the fuel, leave this field blank.
Fuel Flow Monitoring System ID (13). Identify the OILV, OILM, or GAS monitoring
system ID used to measure fuel flow for the hour. EPA uses this fuel measurement to
determine the heat input rate that is the basis for the heat input rate/NOx emission rate
correlation. If the fuel flow monitoring system was in missing data during the hour and
you left blank the monitoring system ID in RT 302 or RT 303, leave this field blank.
When emergency fuel is combusted, if you do not have a certified fuel flowmeter system
for the emergency fuel, also leave this field blank.
Parameters Status Flag (24). Report one of the following codes:
E
Emergency Fuel
N
Operating Parameter is Outside of Normal Limits
M
Correlation Curve for the Fuel Type has Expired
U
Uncontrolled Hour
W
Operation Above Highest Tested Heat Input Rate Point on the Curve
X
Operating Parameter Data Missing or Invalid
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EDR v2.2 Instructions: RT 324
Y Designated Operational and Control Equipment Parameters Within Normal Limits
Z Operation Below Lowest Tested Heat Input Rate Point on the Curve
When to Report "E"
Report an "E" for the parameter status flag if the unit burned an emergency fuel during the
hour, and you do not have a separate correlation curve for the emergency fuel. For these
hours, report the fuel-specific NOx MER in column 25.
When to Report "N"
Report an "N" for the parameter status flag if a unit operating parameter is outside of
normal limits. For example, report an "N" when excess 02 exceeds by more than 2.0% the
excess 02 value recorded at the same operating heat input rate during the last NOx
emission rate test.
Also, if one or more parameters is outside the normal limits for > 16 consecutive operating
hours, a re-test is required within 30 unit operating days or 180 calendar days (whichever
occurs first — see Appendix E, Section 2.3). Beginning with the 17th consecutive "out-of-
spec" operating hour and continuing until the re-test is completed, continue to report "N"
for each hour of combustion of the fuel(s) that triggered the need for the re-test.
Use missing data procedures from Appendix E for any hour in which an "N" is indicated.
These procedures require you to substitute the highest tested NOx emission rate on the
curve for the fuel.
Note: If fuel flow rate and gross calorific value data which are reported in RTs 302 or
303 are missing, use the missing data procedures in Appendix D, not Appendix E.
When to Report "M"
When 20 calendar quarters have elapsed since the quarter of the last Appendix E test for a
particular type of fuel, without a subsequent re-test being done, the correlation curve for
that fuel type has expired. From that point on (i.e.. starting with the first hour after the
end of the 20th quarter), the previous correlation curve is considered invalid and you must
report the fuel-specific maximum potential NOx emission rate (MER) for every hour in
which the fuel is combusted, until a successful re-test has been completed. Report a
parameter status flag of "M" for each such hour.
When to Report "U"
For units with add-on NOx controls only. Report a "U" for the parameter status flag if
any parameter used to verily proper operation of the emission controls is outside of
normal limits (or the control equipment is not functioning). For these hours, report the
fuel-specific NOx MER in column 25.
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December 2005
When to Report "W"
Report a "W" for the parameter status flag if the hourly heat input rate is higher than the
maximum heat input rate correlated on the curve. Use the missing data procedures in
section 2.5.2.1 of Appendix E when this occurs. During your next periodic or quality
assurance/quality control related testing, test under conditions more representative of your
maximum potential heat rate. If possible, use the new maximum heat input rate as the
highest heat input point during the next test.
When to Report "X"
For missing or invalid excess 02 or other operating parameter data, report a parameter
status flag value of "X" in column 24 and report the highest NOx emission rate on the
curve for the fuel. This indicates that the hour is not demonstrated to be within the
specified limits in Section 2.3 of Appendix E, but it also is not demonstrated to be outside
the specified limits. (Note that the use of the "X" flag is optional, you may choose instead
to treat these hours as out of spec.) Hours marked with a flag of "N" count towards the
16 consecutive unit operating hours before retesting is required, while hours marked with
a flag of "X" do not count for this purpose. In either case, the data count against the
availability of data where the unit operates within the parameters. If the data availability
falls below 90.0%, the Agency may require retesting.
When to Report "Z"
Report a "Z" in the parameter status flag if the hourly heat input rate is below the lowest
heat input rate. In this case it is not necessary to verify that the operational parameters are
within any specified limits. Report the same NOx emission rate recorded during testing at
the lowest heat input rate.
Average NOx Emission Rate for the Hour for Fuel Type (25). Using the appropriate
segment of the heat input rate/NOx emission rate curve, determine the hourly NOx
emission rate for the unit. This includes hours in which you report "N" in column 24 and
apply the standard missing data procedure in section 2.5.2 of Appendix E. Report this
rate in lb/mmBtu to three decimal places.
For hours in which you report "W", "U", "M", or "E" in column 24, report the appropriate
substitute NOx emission rate value in this field, to three decimal places (see Appendix E,
sections 2.5.2.1, 2.5.2.2, and 2.5.2.3).
NOx Mass Emission Rate for the Hour for Fuel Type (Subpart H) (31). Calculate and
report the hourly NOx mass emission rate associated with this type of fuel (based on the
type of fuel reported in the associated RT 302 or 303 for the hour). Round and report in
pounds per hour to two decimal places.
Segment ID of Correlation Curve (42). Report the segment ID from RT 560 for the
corresponding segment of the correlation curve used to determine NOx emission rate for
the hour. Leave this field blank if you report "W", "U", "M", or "E" in column 24.
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EDR v2.2 Instructions: RT 328
Flag to Indicate Multiple or Single Fuel Types Combusted (45). If you use Appendix
E to determine NOx emission rate, you must indicate for each hour whether more than one
type of fuel was burned during the hour. Report an "S" for hours during which the unit
combusted only one type of fuel. Report an "M" for hours during which the unit
combusted multiple fuels.
(25) RT 325: NOx Emission Rate Estimation Based on Appendix E for Multiple
Fuel Hours
Report RT 325 for every hour in which more than one type of fuel is combusted and for which
two or more RTs 324 were reported in the same hour for a unit or pipe.
Field Descriptions and Instructions
Average NOx Emission Rate for All Fuels During Multiple Fuel Hours (18). Using
Equation E-2 from Appendix E to Part 75, calculate and report the average NOx emission
rate for the unit for the hour. This average rate is derived from the NOx emission rates
reported in column 25 of the RTs 324, heat input rates reported in column 45 of the
corresponding RTs 302 and 303, and fuel usage times reported in column 52 of the
corresponding RTs 302 or 303 for each fuel. Report in lb/mmBtu, rounded to three
decimal places.
(26) RT 328: NOx Mass Emissions (Subpart H)
Except for low mass emissions (LME) units, submit RT 328 for each unit, stack or pipe at which
NOx mass emissions are measured or estimated, for every hour in the reporting period that the unit or
stack operates. However, if there are no hours of operation for a given unit or stack in a reporting
period, it is not necessary to report hourly RTs 328 for that unit or stack.
For LME units, use RT 360 to report hourly NOx mass emissions. Do not report RT 328.
If you monitor NOx mass emissions and report RT 328 at a common stack, do not apportion the
NOx mass emissions measured at the common stack to the individual units (i.e.. do not report any
additional RTs 328 under the associated unit IDs ).
If, for a particular unit, you monitor NOx mass emissions at multiple stacks (or ducts), do not
report the combined hourly NOx mass emissions for the unit (i.e.. do not report any unit-level RTs 328).
Do not report the quarterly and cumulative unit-level NOx mass emissions in RT 307 (see instructions for
RT 307).
Field Descriptions and Instructions
Unit Operating Time (18). Report the fraction of the clock hour during which the unit
combusted any fuel (or the fraction of the clock hour during which the stack or pipe was
used). You may use any equal increments from hundredths (0.01 hr.) to quarters (0.25
hr.) of an hour.
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NOx Mass Emission Rate During Unit Operation (Optional) (22). This is an optional
field. If you elect to use it, report the NOx mass emission rate in pounds per hour. Round
to one decimal place.
If it is not possible to determine a single NOx mass emission rate for the hour (for
example, if two fuels were combusted for different portions of the hour and you are using
Appendix E and NOv mass emissions for each fuel was reported in RT 324), leave this
field blank.
Total NOx Mass Emissions for the Hour (32). Report the total hourly NOx mass
emissions in pounds for the hour. Round to one decimal place. Do not leave this field
blank.
Formula ID from Monitoring Plan for Total NOx Mass (42). Report the formula ID
from RT 520 which is used to calculate total NOx mass emissions for this hour. Do not
leave this field blank.
NOx Methodology for the Hour (45). Report one of the following uppercase codes to
indicate the calculation methodology used to report NOx mass emissions during the hour:
AE-GAS
Appendix E Gas Curve
AE-MIX
Appendix E Mixed Fuels (consistent fuel combination)
AE-MUL
Appendix E Multiple Fuels (from single fuel curves)
AE-OIL
Appendix E Oil Curve
NOXM-AMS
NOx Concentration (Part 75, Subpart E, AMS) and Stack Flow
NOXM-CEMS
NOx Concentration and Stack Flow
NOXR-AMS
NOx Emission Rate AMS (Part 75, Subpart E, AMS)
NOXR-BYS
NOx Emission Rate Based on NOx MER for Unmonitored Bypass
Stack
NOXR-CEMS
NOx Emission Rate CEMS
NOXR-PEMS
NOx Emission Rate Predictive Emissions Monitoring System
Use Table 8 to determine which EDR record types are used to calculate NOx mass
emissions for each NOx methodology code.
Heat Input Rate Methodology for the Hour (55). Indicate the measurement
methodology used to determine the heat input rate that was used to calculate NOx mass
emissions for the hour. Report one of the following uppercase codes:
CEMS Diluent and Stack Flow CEMS
AMS Alternative Monitoring System Approved Under Part 75,
Subpart E
FF-GAS Appendix D Gas Flow
FF-MIX Appendix D Mixed Fuel
FF-OIL Appendix D Oil Flow
Clean Air Markets Division, U.S. EPA
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August 2002
EDR v2.2 Instructions: RT 330
Leave blank if heat input rate is not reported for the hour. Note that the code FF-MIX
should be used both for hours in which two or more different fuels are co-fired and hours
when two or more different fuels are combusted separately.
Table 8
EDR RECORD TYPES USED FOR NOx MASS CALCULATIONS
(BASED ON RT 328 NOx METHODOLOGY FIELD)
\()s Methodology
Code
Kxpecled \()s
Hourly Records
Kxpecled Ill/How
Hourly Records I sed
lor NO, Muss
C'iilcuhitions
Kxpecled Record
lor I nit ()pcr:ilin»
Time (I ()T)/Kuel
I s;i»e Time
Other/Comments
AE-GAS
RT 324, column 25
RT 300, column 36
RT 300, column 18
AE-MIX
RT 323, column 22
RT 300, column 36
RT 300, column 18
For Appendix E
testing of fuel
mixture only (one
curve)
AE-MUL
RT 324, column 25
RT 302, column 45
and
RT 303, column 45
RT 302, column 52
and
RT 303, column 52
AE-OIL
RT 324, column 25
RT 300, column 36
RT 300, column 18
NOXM-CEMS
RT 201, column 32
RT 212, column 24
or
RT 531, column 14 for
moisture content
RT 220, column 39
RT 300, column 18
Also need RT 520
formula
NOXR-BYS
RT 530, column 30 for
NOx MER
RT 300, column 36
RT 300, column 18
For unmonitored
bypass stacks only
NOXR-CEMS
RT 320, column 42
RT 300, column 36
RT 300, column 18
(27) RT 330: C02 Mass Emissions Data (ARP)
For any operating hour (or partial hour) for each unit, stack, or pipe at which emissions are
monitored or estimated on an hourly basis, report C02 mass emission rate in RT 330.
If you monitor C02 mass emission rate and report RT 330 at a common stack, do not apportion
the C02 mass emission rate measured at the common stack to the individual units (i.e.. do not report any
additional RTs 330 under the associated unit IDs).
If, for a particular unit, you monitor C02 mass emission rate at multiple stacks (or ducts), do not
report the combined C02 mass emission rate for the unit (i.e.. do not report any unit-level RTs 330).
Field Descriptions and Instructions
C02 Mass Emission Rate for the Hour (18). If you are using CEMS, this value is
derived using the bias adjusted stack flow reported in column 39 of RT 220, and the
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EDR v2.2 Instructions: RT 331
August 2002
unadjusted C02 concentration reported in RT 202, column 24, in conjunction with the
appropriate equation in Appendix F to Part 75.
For oil-fired or gas-fired units using Appendix G, this value is calculated using gas or oil
fuel flow and Equation G-4 from Appendix G to Part 75. During hours in which multiple
fuels are burned, calculate the C02 mass emissions (tons/hr) for each fuel separately using
Equation G-4 and then use Equation G-4A (see Table 18, in the RT 520 instructions) to
determine the combined C02 mass emission rate for the hour. Report the combined
hourly C02 mass emission rate (tons/hr) in RT 330.
Report this field in tons per hour, rounded to one decimal place.
Formula ID from Monitoring Plan for Hourly C02 Mass Emission Rate (28). Report
the formula ID from RT 520 that is used to calculate actual C02 mass emission rate for
this hour. Do not leave this field blank.
Method of Determination Code [Reserved] (31). This field has been reserved in EDR
v2.1 because of changes to the missing data procedures applicable to C02 concentration
reported in RT 202. Leave this field blank.
Total C02 Mass Emissions for the Hour (Optional) (33). This is an optional field. If
you elect to use it, report the total C02 mass emissions for the hour in tons. Round to one
decimal place.
Use of Diluent Cap Value for C02 Calculation for This Hour (CEMS only) (43). If
you elect to substitute a maximum or minimum diluent cap value for hours in which the
measured diluent is above or below the specified cap value, indicate the use of the diluent
cap by reporting "Y". Leave this field blank for all hours in which the diluent cap is not
used or is not relevant.
(28) RT331: C02 Mass Emissions Estimation Parameters (ARP)
If you estimate C02 mass emissions using Appendix G Fuel Sampling and Analysis (FSA) and
Equation G-l, you must report daily C02 mass emissions in RT 331 for the unit or pipe. This value is the
total mass emissions for the day, not a daily rate.
Field Descriptions and Instructions
Total Daily Combustion-Related C02 Mass Emissions Adjusted for C02 Retained in
Flyash (16). This field applies only to coal-fired units and is optional. If you adjust the
C02 mass emissions for carbon content of the flyash, report the adjusted value, in tons.
Round to one decimal place. If you elect not to make an adjustment for the carbon
content of the flyash, leave this field blank.
Total Daily Sorbent-Related C02 Mass Emissions (26). This field is only for units with
add-on S02 emission controls. Report data in this field in tons. Round to one decimal
place. If this field is not applicable, leave it blank.
Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: RT 360
Total Daily C02 Mass Emissions (36). Report the total C02 mass emissions for the day
in tons. Round to one decimal place.
(29) RT 360: Hourly Emissions Data for Qualifying Low Mass Emissions (LME)
Units (LME Only)
If you use the low mass emissions (LME) methodology under § 75.19, report RT 360 for every
hour for every unit operating quarter, in the same manner as RT 300 is reported for non-LME units. For
non-Acid Rain Subpart H units, your State regulation may allow you to qualify for reporting only during
the ozone season.
Field Descriptions and Instructions
Unit Operating Time (18). If you use maximum heat input for each hour, report the
fraction of the clock hour during which the unit combusted any fuel (or the fraction of the
clock hour during which the stack or pipe was used). You may use any equal increments
from hundredths (0.01 hr.) to quarters (0.25 hr.) of an hour.
If you use long term fuel flow to determine heat input, report "1.00" for each hour in
which operation occurred, whether the unit operated for a full or partial hour.
Report a unit operating time of "0.00" in RT 360 for any clock hour in which the unit did
not operate in a unit operating quarter.
Gross Unit Load During Unit Operation (22). This field is required for units that use
megawatts to apportion long term heat input to each operating hour. Report total unit
output for the hour in megawatts. If steam load is reported starting in column 28, do not
report gross unit load.
Steam Load (28). This field is required for units that use steam load to apportion long
term heat input to each operating hour. Report steam load in 1000 lb/hr. It is not
necessary to correct steam load for standard temperature and pressure; use steam load at
measured temperature and pressure (see Part 75, Appendix C, Section 2.2.1). If gross
unit load is reported in column 22, do not report steam load.
Total Hourly Heat Input (From All Fuels) (34). Report the total heat input for the
hour (mmBtu) from combustion of all fuels. This will either be the maximum hourly heat
input rate multiplied by operating time or will be an apportioned value determined from
long term fuel flow measurements and unit load.
Fuel Type (41). Identify the type of fuel combusted in the hour using one of the
following uppercase codes:
BFG Blast Furnace Gas
BUT Butane (if measured as a gas)
CDG Coal Derived Gas
COG Coke Oven Gas
DGG Digester Gas
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EDR v2.2 Instructions: RT 360
December 2005
DSL
LFG
LPG
NNG
OGS
OIL
OOL
PDG
PNG
PRG
PRP
RFG
SRG
Diesel Fuel
Landfill Gas
Liquefied Petroleum Gas (if measured as a gas)
Natural Gas
Other Gas
Residual Oil
Other Oil
Producer Gas
Pipeline Natural Gas (as defined in § 72.2)
Process Gas
Propane (if measured as a gas)
Refinery Gas
Unrefined Sour Gas
If multiple fuels are burned in the hour, report the fuel used to determine mass emissions
(i.e.. of all the fuels burned in that hour, report the fuel with the highest S02, C02, and/or
NOx emission factors in Tables LM-1, LM-2, and LM-3 of § 75.19). If records are
missing as to which fuel was burned in the hour, report the fuel with the highest S02, C02,
and/or NOx emission factors of all of the fuels capable of being burned in the unit.
S02 Mass Emissions (ARP) (44). Report the estimated pounds of S02 emitted during
that hour determined using the provisions of §§ 75.19 (c)(l)(i) and (c)(4)(i), unless you
have an approved petition to use a site-specific default S02 emission rate for fuel oil
combustion. In that case, use the approved S02 emission rate in the calculations, rather
than the generic default value from Table LM-1.
NOx Mass Emissions (50). Report the estimated pounds of NOx emitted during that hour
determined using the provisions of § 75.19(c)(4)(ii).
C02 Mass Emissions (ARP) (56). Report the estimated tons of C02 emitted during that
hour determined using the provisions of § 75.19 (c)(4)(iii) .
Control Status (65). For units that use a fuel and unit-specific default NOx emission rate
and have NOx controls, indicate the status of the NOx emissions controls at the unit for the
hour using the following uppercase codes:
C Controls Operating Properly
U Unit Controls Not Operating or Not Operating Properly
If the unit is uncontrolled, leave this field blank.
If the NOx controls either did not operate or did not operate properly during the hour, use
the rate for uncontrolled emissions for the hour as defined in Table 29 in RT 531 (which
corresponds to Table LM-2 in § 75.19) to calculate NOx mass emissions for the hour.
NOx Methodology for the Hour (66). Report one of the following uppercase codes to
indicate the measurement methodology used to report NOx mass emissions during the
hour:
Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: RT 360
NOXG
NOXU
Generic Default NOx Emission Rate, from Table LM-2
Fuel-and-Unit-specific NOx Emission Rate
Report "NOXG" if you use the generic default NOx emission rate from Table LM-2 as the
primary NOx methodology.
If, for an uncontrolled or a controlled unit, you use a fuel-and-unit-specific NOx emission
rate determined from emission testing as the primary NOx methodology (or, for units with
SCR or SNCR, if you use an emission rate of 0.15 lb/mmBtu):
• If the unit is uncontrolled, report "NOXU".
• For units with NOx emission controls (e.g.. water injection, SCR, SNCR, dry low-NOx
technology, etc.), report "NOXU" for any hour in which the control status reported in
column 65 is "C" and report "NOXG" for any hour in which the reported control
status is "U".
Heat Input Methodology for the Hour (76). Report one of the following uppercase
codes to indicate the measurement methodology used to determine the heat input value
used to calculate mass emissions during the hour:
LTFF Long Term Fuel Flow
MHHI Maximum Hourly Heat Input Capacity
Base Load or Peak Load Hour (86). For a combustion turbine that operates principally
at base load (or at a set point temperature) but is capable of operating at a higher peak
load (or higher internal operating temperature), indicate for each operating hour whether
operation was a base load (B) or peak load (P).
B Unit operated at base load or set point temperature
P Unit operated at peak load or higher internal operating temperature
For non-operating hours, leave this field blank.
C. Monitoring Plan Records
Submit a complete set of monitoring plan records as part of your initial monitoring plan
submission, with the certification application and in each quarterly report. These records will typically
remain the same from quarter to quarter. The following instructions describe each record type which
comprise the EDR portions of a monitoring plan.
To ensure the completeness and quality of monitoring plan data, EPA has developed and released
the Monitoring Data Checking Software (MDC) on the Acid Rain Home Page:
(URL:www.epa.gov/airmarkets/cems/mdc/htmY EPA strongly recommends that you use this software to
evaluate and correct any inconsistencies and omissions before submitting the monitoring plan data to
EPA. EPA also uses this software to analyze monitoring plan data and provide feedback to sources.
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Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: RT 503
December 2005
(1) RT 500: Unit Definition Table [Retired]
This record type was retired December 31, 1995. RT 502 replaced RT 500.
(2) RT 501: Stack/Pipe Header Definitions Table [Retired]
This record type was retired December 31, 1995. RT 503 replaced RT 501.
(3) RT 502: Unit Definition Table [Retired]
This record type has been retired and must not be submitted for a reporting period after March
31, 2000. RTs 504, 505, 585, 586 and 587 replaced RT 502.
(4) RT 503: Stack/Pipe Header Definition Table
This record type is only required if you measure emissions from (or fuel to) a unit in more than
one location or in a location shared by more than one unit. For a single unit exhausting to a single stack
(or receiving fuel from pipes) not shared with any other unit, use the unit ID to report all emissions data
and do not report this record type.
Type of Stacks and Pipes
Common Stacks. If a stack serves more than one unit and emissions are monitored at
that stack, you must define it as a "common stack" for reporting purposes. Assign a
common stack ID beginning with the prefix "CS" followed by up to four alphanumeric
characters and submit a RT 503 for each unit associated with the stack.
For example, if Units 1 and 2 share a common stack CS001, submit two RTs 503 in the
same file: one defining the relationship between stack CS001 and Unit 1, and the other
defining the relationship between stack CS001 and Unit 2. Note that except for the unit
ID, all values in all RTs 503 for the same common stack should be identical.
Common Pipes. If a fuel pipe serves more than one unit and fuel flow is monitored at
that common pipe header, you must define it as a "common pipe" for reporting purposes.
Assign a pipe ID beginning with the prefix "CP" followed by up to four additional
alphanumeric characters and submit a RT 503 for each unit served by the common pipe
header.
Multiple Ducts or Stacks. A multiple stack defines two or more ducts or stacks in which
CEMS are located for a single unit; it also defines any additional monitoring location(s)
for a single unit which is also monitored at a common stack or common pipe. If a unit has
a CEMS located in more than one duct or stack from the unit, assign a multiple stack ID
to each monitoring location. Assign a stack ID beginning with the prefix "MS" followed
by up to four alphanumeric characters. Submit RT 503 for each multiple stack associated
with a unit.
Clean Air Markets Division, U.S. EPA
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December 2005
EDR v2.2 Instructions: RT 503
For example, if Unit 3 has two ducts with installed CEMS, ducts MS3A and MS3B,
submit two RTs 503 in the same file: one defining the relationship between duct MS3A
and Unit 3, and the other defining the relationship between duct MS3B and Unit 3.
As a second example, if Unit 2 can either exhaust through a monitored common stack,
CS001, or through a monitored bypass stack, the bypass stack ID must begin with "MS"
(e.g.. MS2). Submit a RT 503 defining the relationship between Unit 2 and MS2 and a
separate RT 503 defining the relationship between Unit 2 and CS001.
Multiple Pipes. If you have a combined cycle peaking unit with a combustion turbine and
duct burner for which: (1) Appendices D and E are used; and (2) fuel flow is measured
separately for the turbine and duct burner, define multiple pipes for each fuel flowmeter
location. Assign a pipe ID beginning with the prefix "MP" followed by up to four
alphanumeric characters. Consult with the EPA Clean Air Markets Division or your State
agency prior to your initial monitoring plan submission if your facility has this
configuration.
Example RT 503 for Multiple and Common Stacks
Example #1: Common Stack Serving Two Units
Record Type (1)
Stsick/Pipe II) (4)
Stuck/Pipe l)cscriplion/\:inie (10)
I nil 11) lor Associated
I nil (30)
503
CS001
Common Stack 1 & 2
1
503
CS001
Common Stack 1 & 2
2
Example #2: Multiple Stacks for One Unit
Record Type (1)
Stsick/Pipe II) (4)
Sliick/Pipe Description/N:ime (10)
I nil 11) lor Associated
I nil (30)
503
MS1A
Unit 1 Stack A
1
503
MS IB
Unit 1 Stack B
1
Field Descriptions and Instructions
Stack/Pipe ID (4). The stack or pipe ID must begin with "CS", "CP", "MS", or "MP".
Always left-justify this field.
Stack/Pipe Description or Name (10). This is the unique name given to the stack or
Pipe-
Unit ID for Associated Unit (30). To identify units in the stack or pipe relationship, use
the unit ID in the program inventory, or as required in the National Allowance Database
(NADB) or other allowance tracking purposes. The unit ID should be consistent for all
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EDR v2.2 Instructions: RT 503
December 2005
submissions that are made to meet program requirements. This unit ID should be left-
justified beginning at column 30.
Submission Status [Reserved] (36). This field has been reserved. Leave this field blank.
Maximum Hourly Gross Load in Megawatts [Reserved] (37). This field has been
replaced by RT 535, column 12. Leave this field blank.
Maximum Hourly Gross Steam Load [Reserved] (43). This field has been replaced by
RT 535, column 12. Leave this field blank.
Activation Date (49). For a stack or pipe existing prior to the date that the unit became
subject to the applicable program, report either the date emissions first went through the
stack or the program effective date for data reporting. For a stack or pipe that becomes
operational after the program participation date (as defined in column 24 of RT 505),
report the actual date on which emissions first exit the stack or fuel is combusted at the
pipe or stack location from a "commercially operational unit."
Retirement Date (55). Report the actual date the stack or pipe was last used for
emissions measurement or estimation purposes. Do not report estimated dates in this
field. For active stacks or pipes, leave the retirement date blank.
Bypass Stack Flag (61). Report "B" for any stack that is a bypass stack; leave blank for
all non-bypass stacks. Leave this field blank for all pipes.
Air Quality Modeling Information (62 through 78)
(1) For a common stack (CS) configuration, (where emissions are monitored), report the
stack exit height, base elevation, and inside cross-sectional area (CSA) at the flue
exit. If the common stack has a stack flow monitoring system, also report the inside
cross-sectional area at the flow monitor location. Repeat the same information in
each RT 503 for the common stack.
(2) For multiple stack (MS) configurations:
(a) If the monitors are located on the stacks, report the height, elevation and CSA
information for each stack.
(b) If the monitors are located at breechings or ducts rather than on the stack, report
the stack exit height, base elevation and inside cross-sectional area information in
columns 62 through 74 for the exhaust stack, but in column 75, report the inside
CSA at the flow monitor location in the ductwork.
(3) For common pipe (CP) and multiple pipe (MP) configurations, leave columns 62
through 78 blank. Report the air quality modeling information for these units in RT
504, column 36 through 52.
Clean Air Markets Division, U.S. EPA
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December 2005
EDR v2.2 Instructions: RT 504
Stack Exit Height Above Ground Level (62). Report the height in feet of the stack exit
above ground level.
Ground Level Elevation Above Sea Level (66). Report the number of feet above sea
level at ground level.
Inside Cross-sectional Area at Flue Exit (71). Report the inside cross-sectional area (in
square feet) of the stack at the flue exit.
Inside Cross-sectional Area at Flow Monitor Location (75). For any stack or duct
with a stack flow monitor installed, report the inside cross-sectional area (in square feet)
of the stack or duct at the flow monitor location.
(5) RT 504: Unit Information
Provide one RT 504 for each unit in the file. Do not provide RT 504 with a stack or pipe ID; this
is a unit-specific record type.
Field Descriptions and Instructions
Unit Type (10). Identify the type of boiler or combustion unit using the following
uppercase codes:
Boilers
WBF
WBT
WVF
AF
BFB
C
CB
CFB
DB
DTF
DVF
OB
PFB
S
T
Arch-fired boiler
Bubbling fluidized bed boiler
Cyclone boiler
Cell burner boiler
Circulating fluidized bed boiler
Dry bottom wall-fired boiler
Dry bottom turbo-fired boiler
Dry bottom vertically-fired boiler
Other boiler
Pressurized fluidized bed boiler
Stoker
T angentially-fired
Wet bottom wall-fired boiler
Wet bottom turbo-fired boiler
Wet bottom vertically-fired boiler
Turbines
CC
CT
ICE
IGC
OT
Combined cycle combustion turbine
Simple cycle combustion turbine
Internal combustion engine
Integrated gasification combined cycle technology
Other turbine
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EDR v2.2 Instructions: RT 504
December 2005
Others
KLN
PRH
Cement kiln
Refinery process heater
If you have a unit type other than those shown above, contact EPA.
Maximum Hourly Heat Input Capacity (13). Report the design heat input capacity for
the unit or the highest hourly heat input rate observed in the past five years, whichever is
greater. If the unit has been derated, report the derated hourly heat input value. For
combined cycle units, the reported value should reflect the maximum heat input of the unit
and the supplemental duct burner, combined (unless in agreement with EPA you have
defined the duct burner as a separate unit). For units using the low mass emissions
methodology, enter the maximum rated hourly heat input as defined in § 72.2 or modified
according to § 75.19(c)(2)(i).
Date of First Commercial Operation (20). Report the date the unit first operated for
commercial purposes. If this date preceded the applicable program effective date, you
may provide an approximate date. For example, units listed in the National Allowance
Database (NADB) may use the year and month reported for the "boiler on line date" in
that database as the date of first commercial operation. If this is a new unit which began
operation after the initial program effective date, enter the actual date on which the unit
became operational. If the unit has not yet become commercially operational, leave the
date blank. Do not leave this field blank in any electronic certification application or
quarterly report submittal.
Unit Retirement Date (28). Report the date the unit permanently ceased operation and
retired. If the unit has not retired, leave this field blank.
Air Quality Modeling Information (36 through 52)
Report air quality modeling information in the record type for the following types of units:
• Units that monitor or estimate and report any emissions on a unit basis;
• Units that are part of a common pipe (CP) or multiple (MP) configuration and use
Appendix D estimation procedures for heat input, C02 or S02. For these units,
determine the stack height, elevation and inside cross- sectional area of the stack
through which emissions are discharged to the atmosphere. This can be a single unit
stack or stack serving more than one unit. If the unit emits through more than one
stack, report information for the stack typically associated with higher emissions for
the unit.
For units that measure and report all emissions at a common stack (CS) or multiple stack
(MS), leave columns 36 through 52 blank and provide air quality modeling information in
RT 503, columns 62 through 78.
Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: RT 505
Stack Exit Height Above Ground Level (36). Report the height in feet of the stack exit
above ground level.
Ground Level Elevation Above Sea Level (40). Report the number of feet above sea
level at ground level.
Inside Cross-sectional Area at Flue Exit (45). Report the inside cross-sectional area (in
square feet) of the stack at the flue exit.
Inside Cross-sectional Area at Flow Monitor Location (49). For any unit with a stack
flow monitor installed, report the inside cross-sectional area (in square feet) at the primary
flow monitor location.
Non Load-Based Unit Identifier (53). If the unit does not produce electrical or steam
load (e.g.. cement kilns, refinery process heaters, etc.), report "Y" in this field. For all
other units, leave this field blank.
(6) RT 505: Program Indicator for Report
Submit at least one RT 505 for each unit represented in the file. This record type identifies the
unit and the reporting requirements for which the file has been submitted. Do not submit RT 505 for
regulatory programs that apply to the unit but that are not relevant to the submission. If you submit data
from a unit to meet the requirements of more than one program, submit one RT 505 for each program.
For each unit order the records alphabetically by program code.
Field Descriptions and Instructions
Program/Reporting Requirements for Which EDR is Submitted (10). Report one
code in uppercase to indicate the program and reporting requirements applicable to the
unit. If more than one program code applies, report the second code in a second RT 505
for the unit. The applicable codes are:
ARP Acid Rain Program
OTC-SUBH Former OTC NOx Budget Program Unit, Now Using Reporting
Consistent with 40 CFR Part 75, Subpart H and EDR v2.2. (This
includes new units that never reported in EDR v2.0 but were
affected by the OTC program and were required to hold 2002
allowances.)
SUBH Unit in a NOx Trading Program Consistent with the Requirements
of 40 CFR Part 75, Subpart H
Acid Rain units subject to NOx mass emissions reporting should use either the code
"SUBH" or "OTC-SUBH" (for Acid Rain Units that were also in the OTC NOx Budget
Program) in a second RT 505.
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EDR v2.2 Instructions: RT 505
December 2005
Unit Classification (20). Report the classification of the unit for the program, using one
of the following codes:
Acid Rain Program Units
PI Phase I Unit (listed in 1990 CAA Amendments)
P2 Phase II Unit (including new units)
OP Opt-in Unit
RE Retired Unit
NA Non-affected Unit
Subpart H Units
B Budget Unit
NB Non-budget Unit: a unit that is not subject to the requirements of a NOx
mass trading program but for which monitoring plan information must be
submitted because the unit shares a common stack or pipe with a NOx
budget unit at which mass emissions are measured under a NOx trading
rule.
OP Opt-in Unit: a unit that you elect to include in a NOx trading program.
RE Retired Unit: a unit that has formally and permanently ceased operation
and is not subject to the emissions monitoring requirements.
Reporting Frequency (22). Report one of the following uppercase codes to indicate the
frequency reports are submitted for the unit:
OS Ozone Season Reporting (second and third quarters)
Q Quarterly Reporting (four quarters)
Program Participation Date (24). Report the date on which a unit is required to begin
monitoring and reporting emissions data under the applicable program.
For former OTC NOx Budget Program units using the "OTC-SUBH" code (see column 10
instructions, above), report the date on which you began to use Subpart H monitoring
methods and to report data consistent with EDR v2.1 or 2.2:
• For OTC sources that switched from EDR v2.0 to EDR v2.1 or 2.2 at the start of the
2002 ozone season, the appropriate date is either April 1, 2002 (if the source reports
data on a year-round basis) or May 1, 2002 (if the source reports data only during the
ozone season).
• For OTC sources that began using EDR v2.1 prior to the 2002 ozone season, the
appropriate date is the first day of the calendar quarter in which EDR v2.1 was first
used.
Clean Air Markets Division, U.S. EPA
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December 2005
EDR v2.2 Instructions: RT 506
For Subpart H units located in states where the SIP requires NOx mass and heat input
monitoring and reporting to begin on May 1, 2003, the program participation date is April
1, 2003 (for sources that submit EDR reports year-round), and May 1, 2003 (for sources
that report on an ozone season-only basis).
For Subpart H units located in states where the SIP requires NOx mass and heat input
monitoring and reporting to begin on May 1, 2004, but the source elects to begin
monitoring and reporting NOx mass and heat input data on May 1, 2003, the program
participation date is April 1, 2003 for sources that submit EDR reports year-round, and
May 1, 2003 for sources that report on an ozone season-only basis.
For Subpart H units located in state where the SIP required NOx mass and heat input
monitoring and reporting to begin May 1, 2004, the program participation date is April 1,
2004 for sources that submit EDR reports year-round, and May 1, 2004 for sources that
report on an ozone season-only basis.
State Regulation Code (Subpart H) (32). Report a code for the State regulation under
which the report is required. States will provide guidance on the appropriate codes for
each State and regulation. For Acid Rain units not subject to Subpart H reporting, leave
this field blank.
State or Local Regulatory Agency Code (Subpart H) (42). Report the four character
code or abbreviation for the State or local air pollution agency that has regulatory
responsibility for the unit and program. For Acid Rain units not subject to Subpart H
reporting, leave this field blank.
(7) RT 506: EIA Cross Reference Information
Use this record to provide information to EPA on the identifiers used to report data to the Energy
Information Administration (EIA) for affected units. This information allows EPA to use information
reported to EIA, in conjunction with emissions data reported to EPA, to improve air quality modeling
and air quality impact research tools. For each unit, report one or more RTs 506 to identify the EIA
boiler and flue exit ID reported in Form 767 for each emission monitoring location defined in the
monitoring plan. This record is also used to identify units for which Form 767 is not submitted. For new
units, submit RT 506 for the first year of operations indicating the EIA identifiers which will be used in
that year or indicating in column 30 that you will not report to EIA for this unit.
Field Descriptions and Instructions
Unit ID (4) For each unit for which emissions are monitored, submit at least one RT 506
to identify the EIA ID or to indicate that Form 767 has never been submitted (and is not
required).
Acid Rain or Subpart H Monitoring Location ID (10). Identify a monitoring location
for emissions reporting under the Acid Rain Program or Subpart H. For example, if you
monitor and report emissions at a common or multiple stack or pipe, the Acid Rain or
Subpart H monitoring location would be the stack or pipe ID. If you monitor and report
using a unit ID for all parameters, report only one RT 506 and use the unit ID as the "Acid
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EDR v2.2 Instructions: RT 506
December 2005
Rain Monitoring Location." If you monitor and report at multiple locations (for example
two multiple stacks) submit two RTs 506, one for each monitoring location. If you
monitor and report for one parameter at a common stack and another parameter using the
unit ID, report two RTs 506.
EIA Boiler ID (16). For each unit and monitoring location, identify the EIA Boiler ID
used to report information to EIA on Form 767, Schedule II (Plant Configuration), Line 1.
For most Acid Rain units, the EIA ID should be the same as the Acid Rain Program unit
ID, originally published by EPA in NADB. Leave this field blank if you report "N" in
column 30.
EIA Flue ID (21) For each unit and monitoring location, identify the EIA Flue ID used
to report information to EIA on Form 767, Schedule II (Plant Configuration), Line 7 and
Schedule VIII (Stack and Flue Information - Design Parameters), Line 1. If you list more
than one flue ID on Schedule II, report a RT 506 for each flue. Do not report multiple
flue IDs in this field. Leave this field blank if you report "N" in column 30.
EIA Reporting Year (26). Report the year for which this EIA identifier was first used.
For most units the EIA information will not change from year to year. Leave this field
blank if you report "N" in column 30. If the original year of reporting was prior to 1986,
you may report 1985 for the reporting year.
EIA Reporting Indicator (30). If you do not report to EIA on Form 767 for a unit,
indicate this by reporting a "N". Otherwise, leave this field blank.
[Reserved] (31). This field, previously used to report the facility ID, has been reserved.
EIA Facility Number (37). For each unit identify the EIA Facility ID. Leave this field
blank if you report "N" in column 30.
RT 506 Examples
(a) One Single Unit (11 Emitting through a Single Flue
RT
I nil II)
Acid Riiin or
Suhp;irl II
Monitoring
Location
EIA Boiler
ID
KIA l ine
ID
KIA Reporting
Yeiir
EIA
Reporting
liuliciitor
506
1
1
1
1
1996
506
2
2
N
Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: RT 506
(b) Two Single Units. Sharing Common Flue. But Measuring and Reporting
Emissions as Single Units
If emissions from Unit 1 and 2 are separately monitored under the Acid Rain Program as single
units but emit through a shared stack (not defined for Acid Rain reporting purposes):
RT
I nil II)
Acid Riiin or
Suhpiirl II
Monitoring
l.ociition
KIA Boiler
ID
KIA l ine
ID
KIA Reporting
Yenr
EIA
Reporting
Indiciilor
506
1
1
1
1
1996
506
2
2
2
1
1996
(c) Two Units. Sharing Common Stack
If measuring and reporting of emissions occurs at the shared common stack:
RT
I nit II)
Acid Riiin or
Suhpiirl II
Monitoring
l.ociition
KIA Boiler
ID
KIA Hue
ID
KIA Reporting
Yenr
EIA
Reporting
Indiciitor
506
1
CS1
1
1
1996
506
2
CS1
2
1
1996
(d)
One Unit Measures and Reports as Multiple Ducts, but Emits though a Single
Stack
RT
I nit II)
Acid Riiin or
Suhpiirl II
Monitoring
l.ociition
KIA lioiler
ID
KIA Hue
ID
KIA Reporting
Yenr
EIA
Reporting
Indiciitor
506
1
MS1A
1
1
1996
506
1
MS IB
1
1
1996
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EDR v2.2 Instructions: RT 506
December 2005
(e) One Unit Measures and Reports S(X at a Bypass Stack and Main Stack. But
Measures and Reports NO., at the Unit Level Using Appendix E
RT
I nil II)
Acid R.iin or
Subpart II
Monitoring
Location
KIA Boiler II)
KIA l ine
ID
KIA Reporting
Year
EIA
Reporting
Indicator
506
1
CSM001
1
1
1996
506
1
CSB001
1
2
1996
506
1
1
1
1
1996
506
1
1
1
2
1996
(f) Three Units in a Complex Configuration
Unit 1 emits through bypass stack CS001, Unit 3 emits through bypass stack CS002, Unit 2 emits
through either bypass stack CS001 or CS002. Each unit can emit through the any of three flues in the
main scrubber stack. Each flue is monitored separately and defined in the Part 75 monitoring plan as a
separate common stack (CSS1, CSS2, CSS3).
RT
I nit II)
Acid Ruin or
Suhpnrt II
Monitoring
Locution
EIA
lioiler II)
EIA
Hue II)
EIA
Reporting
Year
EIA
Reporting
Indiciilor
506
1
CS001
1
1
1996
506
1
CSS1
1
3
1996
506
1
CSS2
1
4
1996
506
1
CSS3
1
5
1996
506
2
CS001
2
1
1996
506
2
CS002
2
2
1996
506
2
CSS1
2
3
1996
506
2
CSS2
2
4
1996
506
2
CSS3
2
5
1996
506
3
CS002
3
2
1996
506
3
CSS1
3
3
1996
506
3
CSS2
3
4
1996
506
3
CSS3
3
5
1996
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EDR v2.2 Instructions: RT 507
(8) RT 507: Capacity Factor or Fuel Usage Data to Qualify as a Peaking Unit or
Acid Rain Program Gas-fired Unit
For any year or ozone season in which a unit qualifies as a peaking or gas-fired unit, submit RT
507 documenting the capacity or fuel usage of the unit during a three year period. "Peaking unit" is
defined in 40 CFR 72.2 for an annual basis and is described in 40 CFR 75.74(c)(l 1) for an ozone season
basis. "Gas-fired" is defined in 40 CFR 72.2. Do this for any regulatory purpose (i.e.. either for the
selection of monitoring methodology, exemption from multi-load testing, or frequency of on-going
QA/QC activities). Submit ozone season data in RT 507 for non-Acid Rain Subpart H units that qualify
as peaking units for any regulatory purpose.
If you qualify both as a peaking unit and as a gas-fired unit, submit two RTs 507 documenting
each qualification separately.
Include RT 507 in each quarterly report submission. In the first quarterly report submitted each
year (i.e.. in either the first calendar quarter report (for year-round reporters) or in the second calendar
quarter report (for sources that report data only in the ozone season), update the record to include
capacity factor or fuel usage data for the previous calendar year (or the previous ozone season).
If, after evaluating the capacity factor or fuel usage data for a particular reporting year, the unit
no longer qualifies as a peaking or gas-fired unit, submit RT 507 with the first quarterly report for the
following year or ozone season, to indicate that the peaking or gas-fired unit status has been lost.
You may initially qualify as a gas-fired or peaking unit by using historical data or projected data.
You may also use a combination of historical and projected data. However, to maintain peaking unit or
gas-fired unit status, you must report actual capacity factor or fuel usage data for each subsequent year.
Thus, if your basis for qualifying in the first reporting year is three years of projections, you may not
requalify in the second reporting year based solely on projections. The qualifying data for the second
reporting year must include the actual capacity factor or fuel usage data from the first reporting year.
A unit may also qualify as a gas-fired unit if the pattern of fuel usage changes, and if 720 hours of
unit operating data are provided to demonstrate this (see paragraph (3)(ii)(B) of the definition of "gas-
fired" in § 72.2). A statement from the designated representative is required in this case, projecting the
new fuel usage pattern to be permanent. If you initially qualify as a gas-fired unit using the 720 hour
demonstration, you must submit actual fuel usage data from that point on, in order to maintain gas-fired
unit status.
If a unit has previously qualified as a peaking or gas-fired unit but has lost that status and you
wish to re-establish peaking or gas-fired status, the unit may only requalify based on three years of actual
historical data. The use of projections is disallowed in such cases (see § 72.2, paragraph (4) of "gas-
fired" definition and paragraph (3) of the "peaking unit" definition).
(a) Qualifying Using Historical and/or Projected Data
Provide three years of historical percent capacity factor or fuel usage information using projected
data as provided for in the definitions of gas-fired and peaking unit in § 72.2. For a non-Acid Rain
Subpart H unit reporting on an ozone season basis, provide ozone season capacity factor information for
the period from May 1 through September 30 of each year. Year 1 should be the earliest year for which
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EDR v2.2 Instructions: RT 507
December 2005
data are reported (for example, if all historical data are being used, year 1 would be three years before the
current calendar year or, if all projected data were being used, year 1 would be the current calendar year).
Similarly, year 3 should be the last year for which data are reported (for example, if all historical data are
being used, year 3 would be one year before the current calendar year or if all projected data were being
used, year 3 would be two years after the current calendar year).
Calculate the three year average annual capacity factor or percentage of the annual heat input (HI)
from the combustion of gaseous fuel, by averaging the percent capacity factor (or percent of HI from
gaseous fuel) for the three years of data provided. For example, if a unit has operated for three years at
6.0%, 10.0% and 12.0% annual capacity factor, report these values to one decimal place in columns 19,
29 and 39, respectively. Report the average of these three values rounded to one decimal place (9.3%) in
column 44.
In column 51, report the appropriate code to indicate whether you are qualifying based on three
years of historical data, three years of projections, or a combination of historical data and projections (see
Table 9 below).
Table 9
EXAMPLE DATA FOR QUALIFICATION BASED ON
HISTORICAL AND PROJECTED DATA
Initial Qualifying
Methodology
Data Reported in RT 507
Current
Year
(col l»)
Yesir 1
(col 14)
Type
(col IS)
Year 2
(col 24)
Type
(col 28)
Year 3
(col 34)
Type
(col 38)
C ode
(col 51)
Actual Historical Data
2000
1997
A
1998
A
1999
A
3HD
2001
1998
A
1999
A
2000
A
3HD
2002
1999
A
2000
A
2001
A
3HD
Projected Data
2000
2000
P
2001
P
2002
P
3PR
2001
2000
A
2001
P
2002
P
1HD
2002
2000
A
2001
A
2002
P
2HD
2003
2000
A
2001
A
2002
A
3HD
Combination of Actual
Historical Data and
Projected Data
2001
2000
A
2001
P
2002
P
1HD
2002
2000
A
2001
A
2002
P
2HD
2003
2000
A
2001
A
2002
A
3HD
* A = Actual historical data; P = Projected data
(b) Qualifying as "Gas-fired" Using Alternative Method
In accordance with paragraph (3)(ii)(B) of the "gas-fired" definition in § 72.2, you may provide
720 hours of unit operating data to initially qualify as a gas-fired unit, if the designated representative
certifies that the pattern of fuel usage has permanently changed. A unit is classified as gas-fired as of the
Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: RT 507
date on which the results of the 720-hour demonstration are submitted to the Administrator (see
paragraph (3)(iii) of "gas-fired" definition). The 720 hour demonstration data qualifies a unit as gas-fired
from the date on which you submit the results of the demonstration until the end of that same calendar
year. For the next year, you must submit actual, historical fuel usage data from the previous year
(beginning with the date on which you first qualified as gas-fired) to verily that you met the fuel usage
requirements for the first reporting year. For example, if you qualify based on the 720 hour
demonstration as of June 30, 2000, then, in 2001, you must submit historical data for the time interval
from June 30, 2000 through December 31, 2000 (labeled as year 1). In 2002, you would submit
historical data for 2000 (labeled as year 1) and 2001 (labeled as year 2). In 2003, you would submit
historical data for 2000, 2001, and 2002, labeled as year 1, year 2, and year 3, respectively (see Table 10,
below).
In column 51 of RT 507, report the appropriate code to indicate the manner in which the unit
qualifies as gas-fired for the reporting year.
Table 10
EXAMPLE OF GAS-FIRED QUALIFICATION BASED ON
UNIT OPERATING DATA
Initial Qualifying
Methodology
Data Reported in RT 507
Current
Year
(col l»)
Yesir 1
(col 14)
Type
(col IS)
Year 2
(col 24)
Type
(col 28)
Year 3
(col 34)
Type
(col 38)
Code
(col 51)
Qualifying Based on
720 Hours of Unit
Operating Data
After the first year,
you must provide
available historical
data.
2000
2000
D"
2001
P
2002
P
720
2001
2000
A
2001
P
2002
P
1HD
2002
2000
A
2001
A
2002
P
2HD
2003
2000
A
2001
A
2002
A
3HD
** Initial qualification based on 720 hours of unit operating data
Field Descriptions and Instructions
Current Calendar Year or Ozone Season (10). Report the current year or ozone
season. This is the year or ozone season for which peaking unit capacity or fuel usage
data are provided to qualify for a regulatory exception from a requirement (or to indicate
that peaking unit or gas-fired unit status has been lost).
Ozone Season or Years 1 -3 (14, 24, 34). Report the calendar year or season
represented by Year 1, etc.
Ozone Season or Years 1-3 Type (18, 28, 38). Report "A" to indicate that the data for
the year or season are actual percent capacity or fuel usage; report "P" to indicate
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EDR v2.2 Instructions: RT 508
December 2005
projected capacity or fuel usage. Report "D" to indicate qualification as gas-fired based
on 720 hours of unit operating data.
Ozone Season or Years 1-3 Percent Capacity Factor for Peaking Units or Percent
Heat Input from Gaseous Fuel (19, 29, 39). Report historical and/or projected data for
percent capacity factor or for percent heat input from gaseous fuel, for three years or three
ozone seasons.
Three Ozone Season or Year Average Annual Capacity for Peaking Units or Percent
Heat Input From Gaseous Fuel (44). Report the average percent capacity factor or the
average percent of heat input from gaseous fuel for three years or ozone seasons.
Type of Qualification (49). Report "PK" to identify the data submitted as annual
peaking unit capacity factor. Report "SK" to identify the data submitted as ozone season
capacity factor. Report "GF" to identify the data submitted as percent of heat input from
gaseous fuel.
Method of Qualifying as a Peaking Unit or as a Gas-fired Unit Per § 72.2 (51). For
the current reporting year of ozone season, indicate the method used to verify that a unit
qualifies as a gas-fired unit or as a peaking unit as defined in § 72.2 using one of the
following uppercase codes:
3PR Three Years of Projected Capacity Factor or Fuel Usage Data
1HD One Year of Historical Data and Two Years of Projections
2HD Two Years of Historical Data and One Year of Projections
3HD Three Years of Historical Data
720 720 Hour Initial Demonstration (Gas-fired Unit Qualification Only)
PSL Peaking Unit Status Lost; Unit Exceeded a Required Capacity Factor
GSL Gas-fired Unit Status Lost; Unit Failed to Meet the Minimum Required
Percentage of Heat Input from Gaseous Fuel
(9) RT 508: Subpart H Reporting Schedule (Subpart H)
Submit one RT 508 for each unit, stack, and/or pipe in the file only when there is going to be a
change in reporting frequency for the unit, stack, and/or pipe.
For Subpart H units that are also subject to the Acid Rain Program or to a State program that
requires year-round reporting for your units, you must report year-round and may not use this record
type.
For units subject only to Subpart H for which you are not required to report on a year-round basis
under a State program, you may elect to submit reports either for the ozone season (second and third
quarters only) or year-round (all four quarters). See § 75.74 for more detailed information about your
reporting options and requirements (63 FR 57511-57512 and 64 FR 28627-28630).
Any change in reporting frequency takes effect at the beginning of the next calendar year. If you
are making the change from reporting in the ozone season to reporting year-round, you are not required
to submit a fourth quarter report in the calendar year you elect to make the change. Your next required
Clean Air Markets Division, U.S. EPA
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December 2005
EDR v2.2 Instructions: RT 508
submission would be the first quarter of the next calendar year. Conversely, if you are changing your
reporting frequency from year-round to ozone season, you are not required to report a first quarter report
in the calendar year following when you elect to make the change. Your next required submission would
be the second quarter, at the start of the ozone season for the next calendar year.
Regardless of which method you choose, the reporting frequency must be the same for any stack
or pipe and its associated units.
Instructions for Changing from Ozone Season Reporting to Year-round Reporting
• Report a RT 508 in your third quarter report.
• In column 10, enter the new reporting frequency as "Q" (quarterly). Do not change the
reporting frequency reported in RT 505 in the third quarter report. The reporting frequency
in RT 505 must be changed in the first report submitted under the new reporting frequency
(first quarter).
• In column 12, enter the beginning date of the new reporting frequency (i.e.. January first of
the next calendar year).
• Submit your next quarterly report for the first quarter of the next calendar year.
Instructions for Changing from Year-round Reporting to Ozone Season Reporting
• Report a RT 508 in your fourth quarter report.
• In column 10, enter the new reporting frequency as "OS" (ozone season). Do not change the
reporting frequency reported in RT 505 in the fourth quarter report. The reporting frequency
in RT 505 must be changed in the first report submitted under the new reporting frequency
(second quarter).
• In column 12, enter the beginning date of the new reporting frequency (i.e.. May first of the
next calendar year).
• Submit your next quarterly report for the second quarter (start of the ozone season) of the
next calendar year.
Field Descriptions and Instructions
New Reporting Frequency (10). Enter the new reporting frequency as quarterly ("Q")
(year-round) or ozone season ("OS"). Do not change the reporting frequency indicated in
RT 505, column 20 until you actually begin reporting using the new reporting schedule
indicated in RT 508, column 10. RT 505 indicates the reporting requirements under
which you are currently reporting.
Begin Date of New Reporting Frequency (12). Report the year, month, and day on
which reporting will conform to the requirements associated with the new reporting
schedule indicated in column 10. For any RT 508 you submit to change the reporting
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December 2005
frequency from ozone season to year-round, the begin date must be January 1 (whether or
not you operate or intend to operate your unit on that date). For any RT 508 you submit
to change the reporting frequency from year-round to ozone season, the begin date must
be May 1 (whether or not you operate or intend to operate your unit on that date).
End Date of Reporting Schedule [Reserved] (20). This field is reserved. Leave this
field blank.
Flag for Year-round Reporting Required by State [Reserved] (28). This field is
reserved. Leave this field blank.
The following are examples of how RT 508 should appear in your quarterly report to indicate a
change in reporting frequency.
Changing From Ozone Season-only Reporting to Year-round Reporting
RT
STACK/1 Ml/
imim: II)
ri:i>ortim;
l-'RKQl i:\CY
m-:<;i\
dati:
ri:si:rm:d
ri:si:rm:d
508
1
Q
20010101
[Blank]
[Blank]
For the change to be effective, you must submit RT 508 in the third quarter report. You cannot
change your reporting frequency from ozone season-only to year-round for the upcoming
calendar year after September 30.
Changing From Year-round Reporting to Ozone Season-only Reporting
RT
STACK/1 Ml/
imim: II)
ri:i»()rti\(;
l-'REQl i:\CY
m:(;i\
dati:
ri:si:rm:d
ri:si:rm:d
508
1
OS
20010501
[Blank]
[Blank]
For the change to be effective, you must submit RT 508 in the fourth quarter report. You cannot
change your reporting frequency from year-round to ozone season-only for the upcoming
calendar year after the submission deadline for the third quarter report.
(10) RT 510: Monitoring Systems/Analytical Components Table
(a) Defining a Monitoring System
For CEMS methodologies, a monitoring system is any combination of analytical components,
sensors, and data software components for which a relative accuracy is specified (e.g.. S02 monitoring
system, flow monitor, NOx-diluent monitoring system, NOx concentration system, C02 concentration
system, or moisture system). For monitoring methodologies based on fuel flow metering, a monitoring
system consists of the fuel flowmeter component(s) and the software component(s) needed to calculate
and report hourly fuel flow for a unit or common pipe for a particular fuel. A monitoring system for an
Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: RT 510
Appendix E NOx/heat input rate correlation curve consists of the software component used to estimate
NOx emissions.
For low mass emissions units do not define monitoring systems and do not report this record type
unless long term fuel flow monitoring systems are used to measure fuel flow and heat input.
Monitoring systems are comprised of the actual, physical components that are installed or will be
installed for a unit, pipe, or stack where the measurement equipment is installed.
• Parameter. Each monitoring system either directly measures a specific emissions parameter
(for example, NOx emission rate) or provides a parameter necessary for calculating emissions
(for example, pollutant concentration, stack flow, moisture, mass oil flow, or heat input rate).
• Hardware Components. Most monitoring systems include one or more monitoring or
measurement hardware components. Identify the primary analytical component(s) as part of
the monitoring system. For a dilution-extractive system, the dilution probe may be included.
• DAHS Components (Software and Hardware). Identify the software component(s) of the
Data Acquisition and Handling System (DAHS) for each monitoring system. Any software
program which calculates emissions or heat input rate, or implements missing data substitution
algorithms or quarterly reporting functions should be included as a DAHS software
component in all relevant monitoring systems. Identify the programmable logic controller
(PLC) or automated data logger (DL) as a system component if it performs any of those
functions.
For example, software or hardware components that perform the following functions do
not have to be identified as part of the DAHS:
— Calculation of RAT A results and generation of RT s 610 through 616
— Calculation of flow-to-load results (that are merged with the final quarterly report)
— Record operating parameters (that are merged with the final quarterly report)
— Generation of monitoring plan record types
While these components do not have to be identified in the monitoring plan, you must identify
them in either the data flow diagram under § 75.53 (c)(5)(iii) and/or the quality assurance plan
under Appendix B to Part 75.
(b) Types of Systems
The following types of systems may be defined and used:
• S02 Concentration System. This monitoring system is used in the Acid Rain Program to
measure S02 concentration. It is used in conjunction with a flow monitoring system to
determine hourly S02 mass emission rates in lb/hr. The system consists of an S02 pollutant
concentration monitor and a DAHS software component.
• Flow Monitoring System. This monitoring system is used to measure stack flow rate in
standard cubic feet per hour (scfh). The flow rate is used to calculate heat input rate and/or
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EDR v2.2 Instructions: RT 510
December 2005
S02, C02, and/or NOx mass emissions. At a minimum, the system is comprised of a flow
monitor and DAHS software. For flow monitors, identify a single component as
representative of the control unit of the monitor.
If the average of two or more flow monitors will be used to determine the hourly flow value,
identify each separate flow monitor as a component in the primary flow system. If each
monitor alone will be used as a redundant backup flow system, define each redundant backup
system containing the single flow monitor. For example, you may install flow monitors
Component A and Component B on a single stack. If the average value from Components A
and B will be reported as the hourly flow value, then the primary flow system ("P01") would
include both Component A and Component B along with the DAHS. You may also create a
redundant backup flow system ("B01") consisting of Component A and the DAHS and a
redundant backup system ("B02") consisting of Component B and the DAHS. Any redundant
backup monitoring system must meet the initial certification and ongoing quality assurance
requirements for a redundant backup monitoring system.
• NOx-diluent System. This monitoring system is used to determine NOx emission rate in
lb/mmBtu. It is comprised of a NOx concentration monitor, C02 or 02 diluent monitor, and
DAHS software.
• C02 or 02 System. A C02 monitoring system is used either: (1) to measure percent C02 for
determination of heat input and the calculation of C02 mass emissions (ARP units, only); or
(2) exclusively to determine hourly heat input rate (in conjunction with a flow monitoring
system). An 02 monitoring system is used exclusively for hourly heat input rate
determination.
A C02 or 02 system is comprised of a C02 or 02 analyzer and DAHS software. If you use
Equation 14A or 14B to convert a measured 02 value to C02 for purposes of determining
hourly C02 mass emissions for an Acid Rain unit, define a C02 monitoring system containing
an 02 component and DAHS software.
• Moisture System. This system is used to measure hourly percent moisture for the calculation
of hourly heat input rate, NOx emission rate, NOx mass emissions, C02 mass emissions, or S02
mass emissions, if an hourly moisture adjustment is required because component monitors use
different moisture bases. A moisture system may be comprised of a moisture sensor and
DAHS software or one or more dry and wet basis oxygen analyzers and DAHS software.
One of these oxygen analyzers may also be a component of the NOx-diluent system described
above. If you own or operate a unit with a wet scrubber you may also use a moisture system
comprised of a temperature sensor and a moisture look-up table. This type of system is
represented by a single DAHS software component (note that this is the same DAHS
component that is listed as a component of the other monitoring systems at the unit or stack).
• NOx Concentration System. This monitoring system is used to determine NOx
concentration, and is used in conjunction with a separately certified flow monitoring system to
calculate NOx mass emissions. It is comprised of a NOx concentration monitor and DAHS
software. This type of system is used for Subpart H units only.
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EDR v2.2 Instructions: RT 510
• NOx Emission Rate Predictive Emissions Monitoring System (PEMS). This type of
monitoring system must be approved by petition under under § 75.66 and Subpart E of Part
75. It is used to determine NOx emission rate for a gas-fired turbine or boiler and is
comprised only of a DAHS software component (or components).
• Opacity System. This monitoring system is used to determine the opacity of emissions. It is
comprised of a continuous opacity monitor (COM) and DAHS software.
• GAS System. This monitoring system measures gas flow rate in 100 standard cubic feet per
hour. Gas flow rate is used to calculate S02 and C02 mass emissions and/or heat input rate.
At a minimum, this system is comprised of a gas fuel flow meter and DAHS software.
• OILV System. This monitoring system measures hourly volumetric oil flow rate. Oil flow
rate is used to calculate S02 and C02 mass emissions and/or heat input rate. At a minimum, it
is comprised of an oil fuel flow meter and DAHS software.
• OILM System. This monitoring system measures hourly mass of oil combusted in pounds
per hour. Oil flow rate is used to calculate S02 or C02 mass emissions and/or heat input rate.
At a minimum, it is comprised of an oil fuel flow meter and DAHS software.
• Appendix E NOx System. This monitoring system is used to determine NOx emission rate in
lb/mmBtu based on a NOx/heat input rate correlation curve derived from emission testing.
The system is comprised of only a single DAHS software component (note that this is the
same DAHS component that is listed as a component of the other monitoring systems at the
unit or pipe). Appendix E systems are associated with a unit or multiple pipe, not with a
common stack. If separate NOx/heat input rate correlation curves are derived for oil and gas,
you must: (a) define a separate Appendix E monitoring system for each type of fuel, having a
unique system ID number; and (b) during co-fired hours, report a separate RT 324 under each
monitoring system ID.
• Long Term Gas System or Long Term Oil System (Low Mass Emissions Units Only).
These monitoring systems measure fuel flow during the ozone season on a long term (non-
hourly) basis. The systems are comprised of DAHS software and the Appendix D or billing
fuel flowmeters or other relevant components. These systems are used in conjunction with a
default or unit-specific, fuel-specific NOx emission rate for low mass emissions units.
• Part 75 Alternative Monitoring System (AMS). This monitoring system is used in lieu of
one of the monitoring systems described in Part 75. It is comprised of components defined in
a petition approved as meeting the requirements of Subpart E of Part 75. You must receive
approval from EPA before reporting with this kind of system.
(c) Additional Information for OILM, OILV, and GAS Systems
Each oil or gas system must include at least one fuel flowmeter hardware component (component
type GFFM, BGFF, OFFM, or BOFF). You may also include auxiliary components (for example
temperature and pressure sensors and transmitters), but the simplest possible representation of the fuel
flowmeter (i.e.. one component to represent each fuel flowmeter) is recommended. Each oil and gas
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system must also include a DAHS component to record and calculate fuel flow and heat input and to
perform missing data substitutions.
If different types of oil (or gas) are burned in one unit, you must define a separate oil (or gas)
system for each type of fuel combusted in the unit.
The oil (or gas) system for the unit or common pipe must include all fuel flowmeters that are
necessary to determine net fuel flow for one type of fuel. For example, if net oil flow is measured by
using one flowmeter for the main fuel line to the unit and subtracting the value measured by the
flowmeter on the return fuel line, the system must include both the main and return flowmeters as
separate components of the same system. If more than one pipe supplies the same type of fuel to a unit
and separate fuel flowmeters are installed on each of the pipes (e.g.. for a combined cycle turbine with a
duct burner), include all the flowmeters measuring that one fuel as separate components of the same
system, whenever possible.
Do not include components associated with oil or gas sampling methodologies, unless you are
using a gas chromatograph to determine the sulfur content or heat content of gas on an hourly basis. For
a gas chromatograph, include it as a component in each gas system for which it is providing hourly
readings.
(d) Rotation of Fuel Flowmeters for Quality Assurance Purposes
If you maintain a group of similar fuel flowmeters for a facility or utility and rotate installation at
different units to facilitate removal of meters for accuracy testing, include each of the rotated fuel
flowmeters as a separate component of the fuel flow system in RT 510 for each unit or pipe. Identify all
of the possible fuel flowmeters by manufacturer, model and serial number. At any given time, EPA will
assume that one (or more) of the fuel flowmeters listed in the plan is installed and operating at the unit or
pipe. If you install a different fuel flowmeter, update the monitoring plan to include the new component.
There is no limit on the number of fuel flowmeters that can be included in a system for a unit or pipe or
the number of units that can be part of a rotational schedule.
For example, at Unit 1, OILV system 100 might include eight fuel flowmeters, 001 through 008
each of which are turbine meters of the same make and model. However, each fuel flowmeter has a
unique serial number. At Unit 2, there is an OILV system 100 which includes the same list of eight fuel
flowmeters. For the first quarter of 1997, components 001 and 002 are installed at Unit 1 as the main
supply and return OFFMs; at Unit 2 components 003 and 004 are installed. In December 2000, the utility
removes components 001 and 002 from Unit 1 to perform laboratory accuracy tests and installs
components 005 and 006 in their place. Components 001 and 002 are tested and returned to the facility.
At Unit 2, components 003 and 004 are removed and replaced by components 001 and 002. This
approach allows the utility to remove the instruments and perform accuracy tests with minimal loss of
data and without making any changes to the monitoring plan for these units.
In the formulas reported in RT 520 to calculate heat input rate, S02, and C02 emissions, reference
the monitoring system ID and a fuel flowmeter component ID for any one of the component meters. It is
not necessary to change the formulas when the fuel flowmeter components are switched.
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(e) LME Units Using Long-term Fuel Flow at a Common Pipe
For a group of LME units served by a common pipe (or supply tank), you must define a LTOL or
LTGS monitoring system for the pipe or tank. In both cases (i.e.. for common pipe or tank), the pipe or
tank ID number must begin with a "CP" prefix (e.g.. CP001). If two or more common pipes or tanks of
different fuel types supply the same group of LME units, you must define a separate LTOL or LTGS
system in RT 510 for each pipe or tank. If two or more pipes or tanks supply the same type of fuel to a
group of LME units, you may represent it as a single LTOL or LTGS system.
(f) Changing System Definitions and Recertification Events
If you must make changes to key data fields and/or add, change, or delete key components of a
system after that system has been provisionally certified and used to report emissions, recertification
testing may be required. If it is necessary to make such changes and you are unsure of what testing or
other requirements may be associated with that change, consult with EPA or the applicable State agency.
Field Descriptions and Instructions
Component ID (10). Assign unique three character alphanumeric IDs to each component
at a stack, pipe, or unit. Do not repeat a component ID for different components at the
same unit, pipe, or stack, even if they are associated with different monitoring systems. If
a component is part of two or more systems for the same stack, pipe, or unit, list the
component in each system using the same unique component ID you have assigned to it.
For example, an 02 monitor could be listed as a component in the NOx emissions rate
system and as a component in a moisture system. Each time it is listed, the 02 monitor
would have the same component ID. Do not reuse a component ID at a particular stack,
pipe, or unit when the component is retired or no longer in use at that stack, pipe, or unit.
If you have DAHS software that is installed on one computer that processes data from
multiple hardware components, assign that DAHS installation a single component ID and
include it as a component of each monitoring system with which it is associated. If you
have the same type of software installed on separate computers or processors, assign a
unique component identification number (and serial number (optional)) to each
installation.
If a dual range analyzer is used for both high and low scale measurements, either: (1)
define the high scale and low scale as separate components in the system and submit two
component records with different component IDs (and the same system ID); or (2) use a
single component ID to represent both scales and use a component type code of "S02A",
"NOXA", "C02A", "02WA", or "02DA" for dual range analyzers or auto-ranging
analyzers.
If a like-kind replacement analyzer is used as part of the primary monitoring system, use
"LK" as the first two characters of the three character component ID, followed by either a
number or letter (for example, LK1, LK2, LKA, LKB, etc.).
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Monitoring System ID (13). Assign unique three character alphanumeric IDs to each
monitoring system at a stack, pipe, or unit. Do not repeat a system ID for a given stack,
pipe, or unit. However, the same system numbering scheme may be used for different
units, stacks, or pipes at the same facility.
Status (16). Report "A" when adding a new entry, "C" when correcting a previous entry,
"D" when deleting a previous entry, or "U" when resubmitting an unchanged entry. For
the initial submission, this column will include "A" for all entries.
If you are deleting an entire system, submit all complete RTs 510 for the system with a
"D" in the status field. Also include the date on which the system ID was last used to
report data in column 108. See directions for column 108 below.
If you are deleting a single component and replacing it with a different component, report
a "D" in the status field for the component no longer in use. Submit a second RT 510 for
the new component being added to the system. The replacement component record
should contain an "A" as the status. Use a different component ID. Report RT 556 to
indicate the quality-assured status of data from the system because of this change, per RT
556 instructions and Part 75 requirements.
Note: Do not delete a system or component in the middle of a calendar quarter if the
system of component is used to report data in that quarter. Rather, use status code "C",
as explained in detail, below.
A status of "A", "C", and/or "D" should only be reported for the quarter in which the
change occurred. When "A" or "C" is reported for any 510 records in the current
quarter, the status for these records in the next quarter's report should be changed to "U",
provided that the information stays the same. For example, if an S02 system was added in
the first quarter, the status reported for each component of the system is "A". The status
for each component of the same system must be changed to "U" for the second quarter.
Note that there is one exception to this, Le^, when status code "C" is used to "close out" a
monitoring system. This occurs when a system is used to report data for part of a
calendar quarter and then is permanently taken out of service at a later date within the
quarter. In this case, you should report a status code of "C" for the system and indicate in
column 108 the last date that the system was used to report data. Then, in the next
quarterly report, use status code "D" to delete the monitoring system. When a "D" status
is reported for any 510 records in the current quarter, do not report these records in any
subsequent quarterly report submittal.
System Parameter Monitored (17). Report one of the following uppercase codes to
indicate the pollutant or parameter measured by the system. This code should be identical
for each component associated with a unique system ID. For example, for a NOx-diluent
system, containing NOx concentration, C02, and DAHS components, all three components
must be identified with a system parameter monitored of "NOX".
C02 C02 Concentration System (ARP)
FLOW Stack Flow System
GAS Gas Fuel Flow System
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H20
Moisture System
LTGS
Long Term Gas Fuel Flow System (LME)
LTOL
Long Term Oil Fuel Flow System (LME)
NOX
NOx Emission Rate System
NOXC
NOx Concentration System (Subpart H)
02
02 Concentration System
OILV
Volumetric Oil Fuel Flow System
OILM
Mass of Oil Fuel Flow System
OP
Opacity System (ARP)
S02
S02 Concentration System (ARP)
Primary/Backup Designation (21). Report one of the following uppercase codes for all
component records for the monitoring system.
B Non-redundant Backup. A non-redundant backup system (B) is a "cold"
backup or portable monitoring system, having its own probe, sample
interface and analytical components.
DB Data Backup. A data backup system is comprised of the analytical
components contained in the primary monitoring system (or in a redundant
backup system), but includes a backup DAHS component.
P Primary
PE Predictive Emission Monitoring System (PEMS). Use this code only for
approved PEMS systems.
RB Redundant Backup. A redundant backup (RB) monitoring system is
operated and maintained by meeting all the program QA/QC requirements.
RM Reference Method Backup. A reference method (RM) monitoring system
is a monitoring system which is operated as a reference method pursuant to
the requirements of Appendix A to Part 60.
CI Certified Monitoring System at the Inlet to an Emission Control Device.
Use code "CI" only for units with add-on S02 or NOx emission controls. Specifically, the
use of a "CI" monitoring system is limited to the following circumstances:
• If the unit has an exhaust configuration consisting of a monitored main stack and an
unmonitored bypass stack, and you elect to report S02 data from a certified
monitoring system located at the control device inlet (in lieu of reporting maximum
potential concentration) during hours in which the flue gases are routed through the
bypass stack; or
• If the outlet S02 or NOx monitor is unavailable and proper operation of the add-on
emission controls is not verified, and you elect to report data from a certified S02 or
NOx monitor at the control device inlet in lieu of reporting MPC or MER values.
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However, note that for the purposes of reporting NOx emission rate, this option may
only be used if the inlet NOx monitor is paired with a diluent monitor and represented
as a NOx -diluent monitoring system in RT 510. The existing diluent monitor on the
stack may be used for this purpose, or a second diluent monitor may be installed at the
control device inlet.
Except for fuel flow monitoring systems or systems containing like-kind replacement
components, a system should not contain any components that are not used when the
system is being used to monitor and report data. For example, do not include backup
DAHS software as an additional DAHS component of a primary system. If you have
defined primary S02 system 101, consisting of a S02 concentration monitor (component
ID S01) and a DAHS software installation (component ID D01), and you also have a
second installation of that DAHS software, you should define a Data Backup (DB) S02
system 102 consisting of the same S02 concentration monitor (component S01) and the
second DAHS installation, defined as component D02.
Component Type Code (23). This field indicates the function of the particular
component, not the value reported by the system as a whole. For example, each system
will have at least one DAHS component, and a NOx-diluent system will include a diluent
component that is either type "C02" or "C02A", type "02D", "02DA", "02W", or
"02WA". Report one of the following uppercase codes for component type:
For CEMS Systems
Note that "02" is no longer a valid component type code.
C02 C02 Concentration
C02A Auto-ranging or Dual Range C02 Analyzer
C02H High Scale C02 Concentration
C02L Low Scale C02 Concentration
FLOW Stack Flow Analyzer
H20 Percent Moisture (Continuous Moisture Sensor, only)
NOX NOx Concentration (Single Scale or Range)
NOXA Auto-ranging or Dual Range NOx Analyzer
NOXH High Scale NOx Concentration
NOXL Low Scale NOx Concentration
02D 02 Concentration-Dry Measurement
02DA Auto-ranging or Dual Range 02 Analyzer - Dry Measurement
02DH High Scale 02 Concentration - Dry Measurement
02DL Low Scale 02 Concentration - Dry Measurement
02W 02 Concentration - Wet Measurement
02WA Auto-ranging or Dual Range 02 Analyzer - Wet Measurement
02WD 02 Concentration - Wet and Dry Measurement (Single Analyzer)
02WH High Scale 02 Concentration - Wet Measurement
02WL Low Scale 02 Concentration - Wet Measurement
OP Opacity Measurement
PRB Probe
S02 S02 Concentration (Single Scale or Range)
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S02A Auto-ranging or Dual Range S02 Analyzer
S02H High Scale S02 Concentration
S02L Low Scale S02 Concentration
If you use a default high range value for S02 or NOx, the correct component type for the
low scale is S02L orNOXL.
For OILV, OILM, or LTOL Systems
BOFF Billing Oil Fuel Flowmeter
DP Differential Pressure Transmitter/Transducer
OFFM Oil Fuel Flowmeter
PRES Pressure Transmitter/Transducer
TEMP Temperature Transmitter/Transducer
TANK Oil Supply Tank
For low mass emissions (LME) units using the long term fuel flow option to quantify unit
heat input, report "TANK" if you use oil tank drop measurements, report "BOFF" if you
rely on fuel usage records, and report "OFFM" if you use a certified Appendix D fuel
flowmeter.
For GAS or LTGS Systems
BGFF Billing Gas Fuel Flowmeter
CALR Calorimeter
DP Differential Pressure Transmitter/Transducer
FLC Flow Computer
GCH Gas Chromatograph
GFFM Gas Fuel Flowmeter
PRES Pressure Transmitter/Transducer
TEMP Temperature Transmitter/Transducer
For LME units using the long term fuel flow option to quantify unit heat input, report
"BGFF" if you rely on fuel usage records, and report "GFFM" if you use a certified
Appendix D fuel flowmeter.
For All Types of Systems
DAHS Data Acquisition and Handling System
DL Data Logger or Recorder
PLC Programmable Logic Controller
Sample Acquisition Method (27). Report the appropriate concentration/diluent codes,
operational principle (volumetric flow codes), or type of fuel flowmeter (fuel flowmeter
type codes). If a sample acquisition method is not applicable to the component type (e.g..
for a DAHS component), leave this field blank. For LME units using long-term fuel flow,
leave this field blank unless you use a certified fuel flowmeter to quantify heat input.
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If you enter the letter "O" (Other) to identify the method or principle, submit a brief
description of the method in RTs 910. Clearly identify the information with the system ID
(column 13) and component ID (column 10).
Report one of the following uppercase codes:
For CEMS
DIL Dilution
DIN Dilution In-stack
DOU Dilution Out-of-stack
EXT Dry Extractive
IS In Situ
ISP Point/Path in Situ
ISC Cross Stack in Situ
O Other
WXT Wet Extractive (includes 02WD components)
For Volumetric Stack Flow CEMS
DP Differential Pressure
O Other
T Thermal
U Ultrasonic
For Fuel Flowmeter Types
COR Coriolis
DP Differential Pressure (e.g.. Annubar)
NOZ Nozzle
O Other
ORF Orifice
PDP Positive Displacement
T Thermal Mass Flowmeter
TUR Turbine
U Ultrasonic
VEN Venturi
VTX Vortex
Manufacturer (30). Report the name or commonly used acronym for the manufacturer
or developer of the component. This field is limited to 20 characters. Do not use this
field to identify the unit or location of the component.
If you have developed software in-house, use an abbreviation that clearly identifies the
utility or operating company responsible for the software development. Use the same
abbreviation or name for all units and sources using the software.
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For LME units using long-term fuel flow, leave this field blank unless you use a certified
fuel flowmeter to quantify heat input.
Model/Version (55). Report the model of any hardware component or the version
number of a software component. This field is limited to 15 characters.
For LME units using long-term fuel flow, leave this field blank unless you use a certified
fuel flowmeter to quantify heat input.
Serial Number (70). Report the serial number for each component. For hardware or
analytical components the serial number should be unique and should allow identification
of the instrument or device in the field. Serial numbers are optional for DAHS software
components and billing fuel flowmeters. If you choose to assign one, it must be unique to
the software installation. This field is limited to 20 characters.
For flow monitors, provide a single component serial number that represents the control
unit of the monitor.
For LME units using long-term fuel flow, leave this field blank unless you use a certified
fuel flowmeter to quantify heat input.
Provisional Certification Date [Reserved] (90). This field has been reserved. Leave
this field blank.
Provisional Certification Time [Reserved] (96). This field has been reserved. Leave
this field blank.
First Date System Reported Data (100). Report the date on which data of any kind
(i.e.. certification test data or emissions data) were first reported under the monitoring
system ID. This date must be the same for all RTs 510 associated with the monitoring
system.
For example, if you did initial certification testing of System 100 in June, 2001, the date in
this field should be the start of the earliest test conducted, e.g.. 6/3/2001. Even if you
later recertify the system, as long as you keep System ID 100, the First Date System
Reported Data should be kept as 6/3/2001. Also note that this date must be the same for
all components of the system.
Last Date System Reported Data (108). If you retire or permanently deactivate a
system, report the date the system ID was last used. This date must be the same for all
RTs 510 associated with the monitoring system. Do not submit emissions data using this
system ID after this date. For active systems, leave this field blank.
(11) RT 520: Formula Table
In RT 520, provide the formulas that will be used to calculate required data from primary
monitoring systems defined in RT 510. It is not necessary to define formulas referencing backup
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monitoring systems if the backup monitoring systems measure on the same monitor basis for the same
parameter and therefore would use the same formulas as the primary system.
RT 520 formulas are used for three primary purposes:
• To verily that the formulas selected are appropriate to the monitoring approach and reflect a
thorough understanding of emissions calculations and the use of appropriate variables;
• To provide the basis for formula verification to ensure that the DAHS software calculates
emissions and selected values accurately; and
• To verily hourly calculations in quarterly reports. To facilitate the use of formulas in ETS, it
is necessary for companies to provide formulas in clear, simple and consistent formats.
(a) Required Formulas
Depending on the monitoring methodologies and component types in use, include in your
monitoring plan one or more of the following formulas in the Tables in Section (c), below.
• For CEMS Based Methodologies
— S02 mass emission rate (ARP)
— NOx emission rate
— NOx mass emissions (Subpart H)
— C02 concentration (ARP, if using 02 monitor)
— C02 mass emission rate (ARP)
— Heat input rate
— F-factor proration calculation for mixed fuels (if elected)
— Flow-weighted or heat input-weighted NOx emission rate formulas for multiple stacks
using two primary NOx systems
— Moisture formulas for moisture systems using 02 wet and dry readings
— Flow formulas for all flow systems containing two flow monitors
• For Fuel Flow Based Methodologies
— S02 mass emission rate (ARP)
— C02 mass emission rate (ARP)
— Heat input rate
— Mass of oil formulas for OILV measurements (ARP)
— Net fuel flow formulas for systems with more than one flowmeter
— F-factor proration calculation for mixed fuels (if elected)
Do not provide formulas representing the default heat input rate or default NOx emission rate for
a unit or stack. Do not include quarterly, seasonal or cumulative summation formulas. Formulas are not
required for low mass emissions units.
Do not report formulas representing Appendix E NOx correlation curve segments in RT 520.
Report the segments in RTs 560.
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(b) Referencing Other Formulas
In certain circumstances a value that is used in one formula is actually derived from another
formula. The use of pro-rated F-factors (described below) is an example. This value should be
represented in the formula by the ID number of the formula from which it is derived. Any intermediate-
level formula that is referred to in another formula must also be included in RTs 520.
Whenever you create a formula based on an equation defined in 40 CFR Part 75, Appendices D
through G, or 40 CFR Part 60, Appendix A, Method 19, replace each variable in the equation with a
reference to a single constant, primary component/system ID, or with a formula ID (unless it represents a
value obtained from an independent source, such as through fuel sampling and analysis). If you need to
represent a single variable as a mathematical expression, create a separate formula for that expression,
and then refer to that expression in the original formula by this second formula's ID.
Example 1: If you determine flow by using two flow monitors to calculate an average flow
value, you should create a separate formula to calculate the average flow value, and then refer to
this formula ID in the emissions formulas that require a flow value.
Example 2: If you determine fuel flow by using two flowmeters, one that measures the flow of
fuel from the fuel source and one that measures the return flow, create a separate formula that
calculates the flow of the fuel consumed (by subtracting the return flow from the source flow).
Refer to this formula ID in the formulas for heat input rate.
Example 3: If you need to measure moisture but do not use a moisture sensor to determine this
value directly, you will have to calculate moisture. In this case, create a separate formula for
calculating moisture, and then refer to this formula ID in the emissions formulas that require the
moisture value.
(c) F-factors and F-factor Formulas
Heat input rate, NOx emission rate, and S02 emission rate formulas based on CEMS require the
inclusion of a specific F-factor based on the fuel being combusted. Unless you provide and use an F-
factor proration formula, provide fuel and F-factor specific formulas for each fuel that will be combusted
at the affected unit or stack. If a combination of fuels may be combusted within any given hourly period,
two options for calculating emissions are available: (1) use the highest F-factor, or (2) use a pro-rated
F-factor. Calculate pro-rated F-factors using the appropriate formulas in 40 CFR Part 75, Appendix F.
If a pro-rated F-factor formula is used, include it in RTs 520.
See Table 11 below for a summary of the standard F-factors.
Field Descriptions and Instructions
Submission Status (10). Report "A" for a new formula, "U" for an unchanged formula,
"C" for a corrected formula, or "D" for an inactive or deleted formula.
A status of "A", "C", and/or "D" should only be reported for the quarter in which the
change occurred. When "A" or "C" is reported for any 520 records in the current quarter,
the status for these records in the next quarter's report should be changed to "U",
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provided that the information stays the same. For example, if an S02 formula was added
in the first quarter, the status reported for the formula is "A". The status for the same
formula must be changed to "U" for the second quarter. When a "D" status is reported for
any 520 records in the current quarter, it is not necessary to report these records in any
subsequent quarterly report submittal.
Formula ID (11). Assign a unique three character formula ID for each formula defined at
a unit, stack, or pipe. If a facility includes a common stack, pipe header, or multiple stack,
assign unique formula IDs across all related units and stacks.
Do not reuse formula IDs if you have changed component types (e.g.. from dry extractive
to wet dilution systems) and have therefore changed the type of formula in use. EPA
relies on the accuracy of the formula code to verily hourly emissions calculations.
Parameter Monitored (14). Report the parameter representing the pollutant or
parameter calculated by the formula. Use the following uppercase codes:
C02
C02 Concentration or Mass Emission Rate (ARP)
FC
Carbon Based F-factor
FD
Dry F-factor
FGAS
Net Gas Flow Rate to Unit/Pipe
FLOW
Net Stack Gas Volumetric Flow Rate
FOIL
Net Oil Flow Rate to Unit/Pipe
FW
Wet F-factor
H20
Percent Moisture
HI
Heat Input Rate
NOX
NOx Emission Rate
NOXM
NOx Mass Emissions
OILM
Mass of Oil
S02
S02 Mass Emissions or Mass Emission Rate (ARP)
S02R
S02 Emission Rate when equation D-lh is used (ARP)
Formula Code (18). Report the formula code of the formula that appears in Tables 11
through 23 and in 40 CFR Part 75, Appendices D through G (or, if appropriate, in 40
CFR Part 60, Appendix A, Method 19) that is applicable to the parameter and the types of
monitoring components. Tables 12 through 23 provide summaries of the primary
formulas used to calculate S02, C02, and NOx emissions, moisture and heat input rate
using CEMS, and fuel flowmeter methodologies. Table 24 gives the standard units of
measure for the various parameters in the formulas. For moisture monitoring systems
comprised of wet and dry oxygen analyzers, see Table 16, Equations M-l and M-1K. For
net fuel flow and average stack flow formulas, see Table 23. For sources with a wet/dry
02 monitor, distinguish the wet and dry values by annotating the formula. All formula
codes must be entered exactly as they are presented in Tables 12 through 23. This
includes the use of dashes and capital letters.
For example, report "F-l" (from Table 13) if you are using the equation for converting
measurements of S02 concentration and flow rate on a wet basis to S02 in lb/hr. Report
"F-5" (from Table 15) if you are using the equation from Method 19, Appendix A, 40
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CFR Part 60 for converting measurements of NOx concentration and 02 diluent on a dry
basis to NOx emission rate in lb/mmBtu. In the second example, formula code "19-1"
could have been used instead of "F-5", since Equation 19-1 in Method 19 is identical to
Equation F-5 in Appendix F to Part 75.
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Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: RT 520
December 2005
Table 11
F-FACTOR REFERENCE TABLE
l"-l';iclor is the nilio ol'(lie «:is xolunic of nil (lie products of combustion (less wilier) to the licnt content ol'llic fuel.
l\.-l';iclor is the rsilio ol'llic «:is \olunic ol'llic CO, ycncnilcd lo the lic.it content of the fuel (see Purl 75, Appendix
I-, Section 3.3).
Option 1: l-'ucl-liiised C'onstiints
l-uci
I'-I'iictor
(dscT/ninilJUi)
r.-liictor (scf
C'(),/ninilitu)
r„-l':iclor
(wsiT/m in IJlu)
Coal
Anthracite
10100
1970
10540
Bituminous (or Sub-bituminous)
9780
1800
10640
Lignite
9860
1910
11950
Gas
Natural Gas
8710
1040
10610
Propane
8710
1190
10200
Butane
8710
1250
10390
Oil
Oil
9190
1420
10320
Waste
Municipal Solid Waste
9570
1820
...
Wood
Bark
9600
1920
...
Wood Residue
9240
1830
...
F-7A
p _ 3.64(%ff) + 1.53(%C) +0.57(%S) + 0.14(%A/) - 0.46(%0) „ 1()6
GCV
F = Dry-basis F-factor (dscf/mmBtu)
Fc = Carbon-based F-factor (scf
C02/mmBtu)
Fw = Wet-basis F-factor (wscf/mmBtu)
%H,%N,= Content of element, percent by
%S, %C, weight, as determined on the same
%0,%H20 basis as the gross calorific value by
ultimate analysis of the fuel
combusted using ASTM D3176-89
for solid fuels, ASTM D1945-91 or
ASTM D1946-90 for gaseous fuels,
as applicable
GCV = Gross calorific value (Btu/lb) of fuel
combusted determined by ASTM
D2015-91 for solid and liquid fuels
or ASTM D1826-88 for gaseous
fuels, as applicable
GCVW = Calorific value (Btu/lb) of fuel
combusted, wet basis
F-7B
F _ 321 x 103 x (%Q
GCV
19-14
5.57(%H) + 1.53(%C) +0.57(%S) + 0.14(%iV) - 0.46(%0) + 0.21(%H2O)
= * 10
F-8*
F = E ^ ^
i* 1
F = Dry-basis F-factor (dscf/mmBtu)
Fc = Carbon-based F-factor (scf
C02/mmBtu)
n = Number of fuels being combusted
F«(Fc)i = Applicable F or Fc factor for each
fuel type
Xj = Fraction of total heat input derived
from each type of fossil fuel
Fo = E WcX
i=\
* This formula should be used for affected units that combust combinations of fossil fuels or fossil fuels and wood residue. For
affected units that combust a combination of fossil and non-fossil fuels, the selected F-factor must receive State or EPA
approval.
Clean Air Markets Division, U.S. EPA
Page 135
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December 2005
EDR v2.2 Instructions: RT 520
Table 12
S02 EMISSION RATE FORMULA REFERENCES
Monitoring Methodology
CEMS
Oil Fuel
Flowmeter
Gas Fuel
Flowmeter
Other Gas
Gas Fuel
Flowmeter
PNG
Gas Fuel
Flowmeter
Natural Gas
Moisture IJnsis
(RT 510. Stiirt C olumn 27)
WET
DRY
Appropriate 1 lourlv
loillllllitS
(I'iirt 75, Appendices l)«SI-")
F-l
F-2
D-2
D-4
D-5
D-1H
* IS, IS/P, IS/C, D/IN, D/OUT, DIL, WXT - wet; EXT - dry. Exceptions are possible. Check with vendor if uncertain.
Table 13
S02 EMISSION FORMULAS
C ode
loriiiuln
Where:
F-l
Eh=KxChx Qh
Eh = Hourly S02 mass emission rate (lb/hr)
K = 1.660 x 10"7 for S02 ((lb/scf)/ppm)
Chp = Hourly average S02 concentration (ppm (dry))
Ch = Hourly average S02 concentration (ppm (stack
moisture basis))
Qh and = Hourly average volumetric flow rate (scfh
Qhs (stack moisture basis)
%H20 = Hourly average stack moisture content (%by
volume)
F-2
100-%HiO
E. - K X C. X Q x 2
h hp z-'hs 1QQ
D-lh
ER - 2 0 x 10s x S""al
7000 GCV
ER = Default S02 emission rate for natural gas (or
"other" gaseous fuel) combustion (lb/mmBtu)
Stotai = Total sulfur content of gaseous fuel (grains/100 scf)
GCV = Gross calorific value of the gas (Btu/100 scf)
2.0 = Ratio of lb S02/lb S
7000 = Conversion of grains/100 scf to lb/100 scf
106 = Conversion of Btu to mmBtu
D-2
%S'
S02rate_otl = 2.0 x OILrate x
S02rate_oll = Hourly mass emission rate of S02 emitted from
combustion of oil (lb/hr)
OILrate = Mass rate of oil consumed per hour during
combustion (lb/hr)
%S0ll = Percent sulfur by weight measured in oil sample
2.0 = Ratio of lb S02 to lb S
D-3
OILmte = V0U-rate x ^oll
OILrate = Mass rate of oil consumed per hr (lb/hr)
V01i-rate = Volume rate of oil consumed per hr, measured
(scf/hr, gal/hr, barrels/hr, or m3/hr)
D0ll = Density of oil, measured (lb/scf, lb/gal, lb/barrel, or
lb/m3)
(cont.)
Page 136
Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: RT 520
December 2005
Table 13
S02 EMISSION FORMULAS (cont.)
Code
l-'onnula
Where:
D-5
S02rate = ER x HIrate
S02rate = Hourly mass emission rate of S02 from combustion
of gaseous fuel (lb/hr)
ER = S02 emission rate from Appendix D, Section
2.3.1.1 or Appendix D, Section 2.3.2.1.1 to Part 75
(lb/mmBtu)
HIrate = Hourly heat input rate of a gaseous fuel, calculated
using procedures in Appendix D, Section 3.4.1 to
Part 75 (mmBtu/hr)
F-23
Eh = ER x HI
Eh = Hourly S02 mass emission rate (lb/hr)
ER = Applicable S02 default emission rate from
Appendix D, Section 2.3.1.1, or Appendix D,
Section 2.3.2.1.1 to Part 75 (lb/mmBtu)
HI = Hourly heat input rate, determined using a certified
flow monitor and diluent monitor, according to
Appendix F, Section 5.2 (mmBtu/hr)
D-12
MS02.hr= £ S02rate_iti
all-fuels
MS02-hr = Total mass of S02 emissions from all fuels
combusted during the hour (lb)
S02rate.i = S02 mass emission rate for each type of gas or oil
fuel combusted during the hour (lb/hr)
tj = Time each gas or oil fuel was combusted for the
hour (fraction of an hour)
Table 14
NOx EMISSION RATE FORMULA REFERENCE TABLE
Monitoring System Type
NO, Kmission Ksite (('()> Diluent)
\Os l~mission R:ite ((): Diluent)
Moisture liiisis
NO,
DRY
DRY
WET
WET
DRY
DRY
WET
WET
co2
DRY
WET
DRY
WET
o2
DRY
WET
DRY
WET
Appropriate 1 lourly
loillllllitS
19-6
19-9
19-8
19-7
19-1
19-5 or
19-5D
19-4
19-2, 19-3, or
19-3D
* IS, IS/P, IS/C, D/IN, D/OUT, DIL, WXT - wet; EXT - dry. Exceptions are possible. Check with vendor if uncertain.
Use of the Diluent Cap With Equations 19-3, 19-5, F-14B, and F-17
When using the diluent cap with Equations 19-3, 19-5, F-14B, and F-17 it is possible to
have unrepresentative or negative results if the percent moisture is high. To avoid this
problem, the Agency has developed special variations of these equations for use with the
diluent cap. For any hour in which the diluent cap is used in place of Equations 19-3, 19-
5, F-14B, and F-17, use the variations of these equations with the diluent cap in the
following manner:
• If you use Equation 19-3 for NOx emission rate, use Equation 19-3D for any hour in
which you use the diluent cap.
Clean Air Markets Division, U.S. EPA
Page 137
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December 2005
EDR v2.2 Instructions: RT 520
• If you use Equation 19-5 for NOx emission rate, use Equation 19-5D for any hour in
which you use the diluent cap.
• If you use Equation F-14B to determine percent C02 from percent 02, use Equation F-
14D for any hour in which you use the diluent cap.
• If you use Equation F-17 for heat input, use Equation F-17D for any hour in which
you use the diluent cap.
Include these formulas in RT 520 of your monitoring plan and report the formula ID in the
appropriate hourly record type whenever the diluent cap is used.
Page 138
Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: RT 520
December 2005
Table 15
NOx EMISSION RATE FORMULAS (LB/MMBTU)
Code
loiimilit
Where:
19-1
(F-5)
19-2
19-351
19-3D*
19-4*
19-5*
19-5D
19-6
19-7
(F-6)
19-8*
19-9*
E = K x Cd x Fd x
20.9
20.9-%0,
20.9
E = K x C x F x
" w 20.9 (l-BJ-%02
E = K x C x- F. x
w a
20.9
100-%H,0
20.9 x
-%0,
100
2»
E = K x C x F. x
20.9
20.9 x
100-%ff20
100
-%0, x
100-%ff20
100
E = K x
(Cw ><
20.9
(100-%/f20)-100 (20.9-%02^
£¦ =
20.9 x K x Cdx Fd
O
0s"
1
O
O
20.9 -
%0, *¦
o
o
E = K x Cd x Fd x
20.9
20.9 - %a
E = K x Cj x Fx
a c
100
%ca
E = K x Cw x Fc x
100
%ca
E = K x
(C x F)
^ W C'
100
(100 - %H20)+\00 %co2
E = K x Cd x
100-%h2o
100
X F X
100
%ca
Formulas should be multiplied by the
conversion factor "K" (if Cd or Cw is in
ppm).
FROM TO MULTIPLY BY "K"
ppm NOx lb/scf K = 1.194 X 10"7
E = Emission rate (lb/mmBtu)
Cd = Pollutant concentration (ppm, dry
basis)
(= Pollutant concentration (ppm, wet
basis)
Fd = Dry-basis F-factor (dscf/mmBtu)
Fc = Carbon-based F-factor (scf
C02/mmBtu)
Fw = Wet-basis F-factor (wscf/mmBtu)
BW(I = Moisture fraction of ambient air
(default value 0.027)
%H20 = Moisture content of effluent gas
O,
O,
o2„
co2„
CO,
= Oxygen diluent concentration
(percent of effluent gas, dry basis)
= Oxygen diluent concentration
(percent of effluent gas, wet basis)
= Default diluent cap 02 value
(14.0% for boilers, 19.0% for
combustion turbines)
= Carbon dioxide diluent
concentration (percent of effluent
gas, dry basis)
= Carbon dioxide diluent
concentration (percent of effluent
gas, wet basis)
Note that [(100 - % H2O/100] may also represented as (1 - Bws), where Bws is the proportion by volume of
water vapor in the stack gas stream.
Clean Air Markets Division, U.S. EPA
Page 139
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December 2005
EDR v2.2 Instructions: RT 520
Table 16
MOISTURE FORMULAS*
( Olio
loillllllit
Where:
M-l
%H20 ~ ^°ld °1"> x 100
%H20 = Percent Moisture
02d = Oxygen diluent concentration (percent of effluent
gas, dry basis)
02w = Oxygen diluent concentration (percent of effluent
gas, wet basis)
M-1K
(o2d - o2w)
%H20 - x 100, as adjusted1
^2 d
* Please contact the EPA Clean Air Markets Division for the assigned code for other moisture formulas.
1 Using a K-factor or other mathematical algorithm, per Appendix A, Section 6.5.7(a).
Table 17
C02 FORMULA REFERENCE TABLE
Monitoring Method
C02 Concentration
(02 CEMS)
C02 Mass
Emissions
(Fuel Sampling)
C02 Mass
Emissions
(Gas-fired Units)
co2
Concentration
(CO, CEMS)
Moisture linsis"
(RT 510. Sliirt Column 27)
WET
DRY
WET
DRY
Appropriate loi inuhts
(I'iirl 75, Appendices I", (J)
F-14B or F-
14D&
F-ll
F-14A&
F-2
G-l, 2, 3 or 5
(App. G, 2.1, 3.1)
G-4, G-4A
F-ll
F-2
* IS, IS/P, IS/C, D/IN, D/OUT, DIL, WXT - wet; EXT - dry. Exceptions are possible. Check with vendor if uncertain.
Page 140
Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: RT 520
December 2005
Table 18
C02 MASS EMISSION RATE FORMULAS
Code
loillllllit
Where:
F-2
100- %H?0
Eh = KxChpxQhsx io()
Eh = Hourly C02 mass emissions (tons/hr)
K = 5.7 x 10"7 for C02 ((tons/scf)/%C02)
Chp = Hourly average, C02 concentration (% C02,
dry basis)
Qhs = Hourly average volumetric flow rate (scfh, wet
basis)
%H20 = Hourly average stack moisture content (% by
volume)
F-ll
Eh = KxChxQh
Eh = Hourly C02 mass emission rate (tons/hr)
K = 5.7xl0"7 for C02 ((tons/scf)/%C02)
Ch = Hourly average C02 concentration (%C02, wet
basis)
Qh = Hourly average volumetric flow rate (scfh, wet
basis)
F-14A
F 20.9 - 02d
CO,, = 100 X — X —
2d F 20.9
C02d = Hourly average C02 concentration (percent by
volume, dry basis)
F = Dry-basis F-factor (dscf/mmBtu)
Fc = Carbon-based F-factor (scf C02/mmBtu)
20.9 = Percentage of 02 in ambient air
02d = Hourly average 02 concentration (percent by
volume, dry basis)
F-14B
100 F \ ("100 -%H.O\ 1
CO, = x—x 20.9 —\-0.w
2w 20.9 F _ v 100 J 2IF
C02w = Hourly average C02 concentration (percent by
volume, wet basis)
F = Dry-basis F-factor (dscf/mmBtu)
Fc = Carbon-based F-factor (scf C02/mmBtu)
20.9 = Percentage of 02 in ambient air
02W = Hourly average 02 concentration (percent by
volume, wet basis)
%H20 = Moisture content of gas in the stack (%)
F-14D
100 F (100-%H2)\ j \
c°2w ~ 2Q 9 * F 4 10Q J x (20.9 - 02_d¥)
C02w = Hourly average C02 concentration (percent by
volume, wet basis)
F = Dry-basis F-factor (dscf/mmBtu)
Fc = Carbon-based F-factor (scf C02/mmBtu)
20.9 = Percentage of 02 in ambient air
02_def = Default diluent cap 02 value (14.0% for
boilers, 19.0% for combustion turbines)
%H20 = Moisture content of gas in the stack (%)
G-l
(.MWC + MW0i) x Wc
W -
c°2 2000 MWC
Wco2 = C02 emitted from combustion (tons/day)
MWC = Molecular weight of carbon (12.0)
MWq2 = Molecular weight of oxygen (32.0)
Wc = Carbon burned (lb/day) determined using fuel
sampling and analysis and fuel feed rates*
(cont.)
Clean Air Markets Division, U.S. EPA
Page 141
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December 2005
EDR v2.2 Instructions: RT 520
Table 18
C02 MASS EMISSION RATE FORMULAS (cont.)
Code
loillllllit
Where:
G-2
M/ MWcol (A%) fC%)
NC°2 - Wcm MWC * I looj * I looj * COAL
Wnc02 = Net C02 mass emissions discharged to the
atmosphere (tons/day)
WC02 = Daily C02 mass emissions calculated by
Equation G-l (tons/day)
MWC02 = Molecular weight of carbon dioxide (44.0)
MWC = Molecular weight of carbon (12.0)
A% = Ash content of the coal sample (percent by
weight)
C% = Carbon content of ash (percent by weight)
Wcoal = Feed rate of coal from company records
(tons/day)
G-3
WNC02 = -99 X WC02
Wnc02 = Net C02 mass emissions from the combustion
of coal discharged to the atmosphere
(tons/day)
.99 = Average fraction of coal converted into C02
upon combustion
WC02 = Daily C02 mass emissions from the
combustion of coal calculated by Equation
G-l (tons/day)
G-4
F x Hx Uf x MWrn
Tjr J 2
c°2 ~ 2000
Wco2 = C02 emitted from combustion (tons/hr)
Fc = Carbon-based F-factor, 1,040 scf/mmBtu for
natural gas; 1,420 scf/mmBtu for crude,
residual, or distillate oil and calculated
according to the procedures in Section 3.3.5
of Appendix F to Part 75 for other gaseous
fuels
H = Hourly heat input rate (mmBtu/hr)
Uf = 1/385 scf C02/lb-mole at 14.7 psi and 68 °F
MWCq2 = Molecular weight of carbon dioxide (44.0)
G-4A
r~<^)ry all—fuels
Unit
'¦unit
C02umt = Unit C02 mass emission rate (tons/hr)
C02rild = C02 mass emission rate calculated using
Equation G-4 for a single fuel (tons/hr)
tfcel = Fuel usage time
tunit = Unit operating time
G-5
MWco
SEco = WCaCO x F x 2-
C°2 CaC°3 " MWCaCOi
SECq2 = C02 emitted from sorbent (tons/day)
WCaco3 = Calcium carbonate used (tons/day)
Fu = 1.00, the calcium to sulfur stoichiometric
ratio
MWCq2 = Molecular weight of carbon dioxide (44)
MWCaCo3= Molecular weight of calcium carbonate (100)
(cont.)
Page 142
Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: RT 520
December 2005
Table 18
C02 MASS EMISSION RATE FORMULAS (cont.)
Code
lorimilit
Where:
G-6
_ , Wso2 MWC02
c°2 " 2000 MWS02
SECq2 = C02 emitted from sorbent (tons/day)
MWCq2 = Molecular weight of carbon dioxide (44)
MWs02 = Molecular weight of sulfur dioxide (64)
WSq2 = Sulfur dioxide removed (lb/day) based on
applicable procedures, methods, and
equations in § 75.15
Fu = 1.00, the calcium to sulfur stoichiometric
ratio
* Collect at least one fuel sample during each week that the unit combusts coal, one sample per each shipment or delivery
for oil and diesel fuel, and one fuel sample for each delivery for gaseous fuels in lots, for each daily or hourly gas sample
for gaseous fuel that is required to be sampled daily or hourly for gross calorific value under Section 2.3.4.1 or 2.3.4.2 of
Appendix D to Part 75. Collect coal samples from a location in the fuel handling system that provides a sample
representative of the fuel bunkered or consumed during the week. Determine the carbon content of each fuel sampling
using one of the following methods: ASTM D3178-89 or ASTM D5373-93 for coal; ASTM D5291 "Standard Test
Methods for Instrumental Determination of Carbon, Hydrogen, and Nitrogen in Petroleum Products and Lubricants,"
ultimate analysis of oil, or computations based upon ASTM D3238-90 and either ASTM D2502-87 or ASTM D2503-82
(Reapproved 1987) for oil; and computations based on ASTM D1945-91 or ASTM D1946-90 for gas. Use daily fuel
feed rates from company records for all fuels and the carbon content of the most recent fuel sample under this section to
determine tons of carbon per day from combustion of each fuel. (All ASTM methods are incorporated by reference
under § 75.6.) Where more than one fuel is combusted during a calendar day, calculate total tons of carbon for the day
from all fuels.
Table 19
HEAT INPUT FORMULA REFERENCE TABLE
Monitor Type
How Monitor (Wet) and Diluent
CEIVI
Fuel Flow and Fuel Sampling
Combusting Oil
Combusting Gas
Moisture
li:isis"
co2
WET
DRY
MASS
VOL
o2
WET
DRY
Appropriate l-'oriiiuhis
(I'sirl 75, Appendices 1) ȣ
1 )
F-15
F-16
F-17 or
F-17D
F-18
D-8
(F-19)
D- and D-
X (l-l'J)
D-6
(F-20)
* IS, IS/P, IS/C, D/IN, D/OUT, DIL, WXT - wet; EXT - dry. Exceptions are possible. Check with vendor if uncertain.
Clean Air Markets Division, U.S. EPA
Page 143
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December 2005
EDR v2.2 Instructions: RT 520
Table 20
HEAT INPUT FORMULAS
C oilo
lorniuhi
Where:
D-15
HIhr = £ HIrate_fi
all-fuels
HI,,, = Total heat input from all fuels
combusted during the hour (mmBtu)
Hlrate-b = Heat input rate from all fuels
combusted during the hour
(mmBtu/hr)
HIrate-i = Heat input rate for each type of gas or
oil combusted during the hour
(mmBtu/hr)
tj = Time each gas or oil fuel was
combusted for the hour (fuel usage
time) (fraction of an hour)
tu = Operating time of the unit
D-15A
£ HIrate-fi
jjj all-fuels
rate-hr .
lu
F-15
1 %co,„
HI ~ Qw x x
w F 100
c
HI = Hourly heat input rate (mmBtu/hr)
Qw, Qh = Hourly average volumetric flow rate
(scfh, wet basis)
Fc = Carbon-based F-factor (scf/mmBtu)
F = Dry basis F-factor (dscf/mmBtu)
%C02w = Hourly concentration of C02 (percent
C02, wet basis)
%C02d = Hourly concentration of C02 (percent
C02, dry basis)
%02w = Hourly concentration of 02 (percent
02, wet basis)
%02d = Hourly concentration of 02 (percent
02, dry basis)
%H20 = Hourly average moisture of gas in the
stack (%)
02def = Default diluent cap 02 value (percent
02, wet basis) (14.0% for boilers,
19.0% for combustion turbines)
F-16
hi = eA ><
100-%H20
100F
c
%coJ
100 J
F-17
1 [(20.9/100)(100-VaH O)-%OJ
HI = Q„, x — x = —
w F 20.9
F-17D
X
-lb,
X
&
Oi
II
' 100-%h2c
100
))
- (20.9-%0. )
4ief
/
>0.9
F-18
(ioo-%/y,0)
HI - -
100F
;20.9-%om)1
20.9 J
D-8"
(F-19V)
GCV.,
HIrate-ml = OILmte x —fl
HIrate-oii, = Hourly heat input rate from combustion
of oil (mmBtu/hr)
OILrate, = Rate of oil consumed (lb/hr for Eq. D-8
or gal/hr for Eq. F-19V)
GCV0ll, = Gross calorific value of oil (Btu/lb for
Eq. D-8 or Btu/gal for Eq. F-19V)
106 = Conversion of Btu to mmBtu
(cont.)
Page 144
Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: RT 520
December 2005
Table 20
HEAT INPUT FORMULAS (cont.)
C oilo
lorniuhi
Where:
F-19
GCVn
HI ~ M x
° 106
HI0 = Hourly heat input rate from
combustion of oil (mmBtu/hr)
M0, = Mass rate of oil consumed per
hour (lb/hr)
GCV0, = Gross calorific value of oil
(Btu/lb)
106 = Conversion of Btu to mmBtu
D-6
GAS' x GCVm.
TTJ - r<2te
rate-gas
HIrate-gas, = Hourly heat input rate from combustion
HIg of gaseous fuel (mmBtu/hr)
GASrate, = Average volumetric flow rate of fuel
Qg (100 scfh)
GCVgas = Gross calorific value of gaseous fuel
GCVg (Btu/100 scf)*
106 = Conversion of Btu to mmBtu
F-20
m _ iQg * GCVg)
g 106
For non-Acid Rain Subpart H units, if you have a volumetric oil flowmeter, you may use Equation D-8 on a
volumetric basis, rather than a mass basis. If you use this option, represent the Equation as F-19V in your
monitoring plan.
Table 21
APPORTIONMENT AND SUMMATION FORMULAS
C "ode
loiinuht
Where:
F-21A
J3
II
to*"*
f \
tcs
MWt tt
HI = Heat input rate for a unit (mmBtu/hr)
HICS = Heat input rate at the common stack or
pipe (mmBtu/hr)
MWj = Gross electrical output (MWe)
tj = Operating time at a particular unit
tcs = Operating time at common stack or pipe
n = Total number of units using the common
stack or pipe
i = Designation of a particular unit
i=\
F-21B
= HIcs
\
*cs
' SFt tt '
HI = Heat input rate for a unit (mmBtu/hr)
HICS = Heat input rate at the common stack or
pipe (mmBtu/hr)
n = Number of stacks or pipes
SF = Gross steam load (flow) (lb/hr)
tj = Operating time at a particular unit
tcs = Operating time at common stack or pipe
n = Total number of units using the common
stack or pipe
i = Designation of a particular unit
fj
isFiti
_ i=\
(cont.)
Clean Air Markets Division, U.S. EPA
Page 145
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December 2005
EDR v2.2 Instructions: RT 520
Table 21
APPORTIONMENT AND SUMMATION FORMULAS (cont.)
C oilo
loiinuht
Where:
F-21C
imsts
HiUnit = —f
lUnit
HIUmt = Heat input rate for a unit (mmBtu/hr)
HIS = Heat input rate for each stack or duct
(mmBtu/hr)
tumt = Operating time for the unit
ts = Operating time for a particular stack or
duct
s = Designation of a particular stack or
duct
n = Total number stacks, ducts
F-21D
ii
tcj
FFi tt
t,FFi t,
i=l
HI = Heat input rate for a unit (mmBtu/hr)
HICP = Heat input rate at the common pipe
(mmBtu/hr)
FFj = Fuel flow rate to a particular unit
(appropriate units)
tj = Operating time at a particular unit (hr)
tCP = Operating time at common pipe (hr)
n = Total number of units using the common
pipe
i = Designation of a particular unit
F-25
s-3
to
•Ma
II
J3
HIU = Hourly average heat input rate for a unit
(mmBtu/hr)
HICS = Hourly average heat input rate at the
common stack (mmBtu/hr)
p = Number of units
tu = Operating time at a particular unit
tcs = Operating time at common stack
u = Designation of a particular unit
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Table 22
NOx MASS EMISSIONS FORMULAS (POUNDS)
Code
loillllllit
Where:
N-l
(F-26)*
Mnoh = K y Ch„y Qhy th
MN0Xh = Hourly NOx mass emissions (lbs)
K = 1.194 x 10"7 for NOx ((lb/scf)/ppm)
Chd = Hourly average, NOx concentration (ppm (dry))
Chw - Hourly average, NOx concentration, stack
moisture basis (ppm (wet))
Qh = Hourly average volumetric flow rate (scfh)
%H20 = Hourly average stack moisture content (% by
volume)
M-:°xh = NOx mass emissions from fuel 1 (lbs)
N-2
(F-26)*
(100-%H^O)
~ K x C, x Q,x 2 x t
NOx,t hd zZh JQQ h
N-3
M NOxh NOxfmIl NOx fuell
MNoXfi,pl9 = NOx mass emissions from fuel 2 (lbs)
HIh = Hourly average heat input rate (mmBtu/hr)
th = Unit/stack operating time (hour or fraction of an
hour)
E(NOx)h = Hourly average NOx emission rate (lb/mmBtu)
F-24
^NOxk = NOx)h * HIh x th
* Equations N-l and N-2 are equivalent to Equation F-26 in Appendix F to Part 75 (see Appendix F, Sections 8.2
and8.3). The right-hand side of Equation F-26 is Eh x th, where Eh is the hourly NOx mass emission rate, in lb/hr and th
is the unit or stack operating time, in hours. For purposes of program implementation, use codes N-l and N-2 in RT
520, rather than F-26. The use of separate equation codes (i.e.. N-l and N-2) for wet and dry-basis NOx measurements
is preferable to using a single code (F-26), which does not indicate the moisture basis of the NOx readings.
Table 23
MISCELLANEOUS FORMULA CODES
C ode
Piirnmeler
Description
N-GAS
FGAS
Net Gas fuel flow rate (100 scfh)
N-OIL
FOIL
Net Oil fuel flow rate (scf/hr, gal/hr, barrels/hr, or m3/hr)
X-FL
FLOW
Average hourly stack flow rate (scfh). (To calculate the average of two or more
primary flow monitors, for example, two ultrasonic monitors in an X-pattern.)
SS-1A
S02
Total hourly S02 mass emissions from the affected unit(s) in a subtractive stack
configuration (lb)
SS-1B
S02
Hourly S02 mass emissions from a particular affected unit in a subtractive stack
configuration (lb)
SS-2A
NOXM
Total hourly NOx mass emissions from the affected unit(s) in a subtractive stack
configuration (lb)
SS-2B
NOXM
Hourly NOx mass emissions from a particular affected unit in a subtractive stack
configuration (lb)
SS-2C
NOXM
Hourly NOx mass emissions from a particular affected unit in a subtractive stack
configuration (lb)
(cont.)
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Table 23
MISCELLANEOUS FORMULA CODES (cont.)
C oilo
Piinimelor
Description
SS-3A
HI
Total hourly heat input for the affected unit(s) in a subtractive stack configuration
(mmBtu)
SS-3B
HI
Hourly heat input rate for a particular affected unit in a subtractive stack
configuration (mmBtu/hr)
NS-1
NOX
Hourly NOx apportionment for NOx affected units in a subtractive stack configuration
(lb/mmBtu)
NS-2
NOX
Hourly NOx apportionment for NOx affected units using simple NOx apportionment
(lb/mmBtu)
Table 24
STANDARD UNITS OF MEASUREMENT
Piimmoler
I nits
C02 and 02 (as reported in RTs 210 and 211)
percent C02 or 02
Stack Flow Rate (as reported in RT 220)
scfh
Gas Flow Rate (as reported in RT 303)
100 scf/hr
Moisture (as reported in RT 212)
percent H20
Mass Oil Flow Rate (as reported in RT 302)
lb/hr
NOx Concentration (as reported in RT 201)
ppm
S02 Concentration (as reported in RT 200)
ppm
Volumetric Oil Flow Rate (as reported in RT 302)
scfh, gal/hr, m3/hr, barrels/hr
Formula Text (23). Report in this 200 character field a representation of the formula, replacing
its variables with the appropriate references to monitoring system IDs, component IDs, other
formulas, and constants. Enter the formula in the order of calculation and with the constants as
they appear in the tables above and operators as they appear in Table 25. If necessary, use
parentheses; do not use brackets.
• Component/System References. Refer to systems as "S#(001-002)" where 001-002 is the
component ID-system ID from RT 510, columns 10 and 13. This symbol represents the
measurement value in the appropriate standard units of measurement for the parameter
already adjusted for bias (if appropriate), temperature, and pressure. The following table lists
the standard units of measurement assumed to be represented by each type of system.
• Formula References. Refer to other formulas as "F#(001)M where 001 is the Formula ID for
another formula in RTs 520.
• Constants. You must also include any constants, such as unit conversion factors, fuel
factors, etc., that are required for the calculation. Do not perform any intermediate
calculations on the constants; your formula should have the same format as the equation in 40
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CFR Part 60 or Part 75 upon which it is based. Represent each constant as it is represented in
Part 75 or Method 19. If your DAHS software uses other equivalent constants or performs
the calculations in an order different from the regulations, demonstrate that these calculations
are equivalent to those in RTs 520 as part of the formula verification required for certification.
Table 25
RT 520 REPRESENTATIONS FOR ELECTRONIC REPORTING
Operation or \ ;iri;ihle
Recommended
Representation
Kxiimple
Addition
+
MW_1 + MW_2
Subtraction
-
100 - S#(001-001)
Multiplication
*
S#(001-001) * S#(002-001)
Division
/
100/S#(001-001)
Exponential power
**
1.66 * 10 ** -7
Subscript
Underscore
MW, = MW_1
Fraction of Heat Input from Fuel
X_
Xoil
Gross Electrical Output
MW_
MW_1
Gross Steam Load (Flow)
SF_
SF_1
Hourly Emissions
Eh
Eh
Operating Time
T
T CS1
Example Formulas
Example #1: NOx Emission Rate Calculation for Coal-fired Unit. Assume you have a
bituminous coal-burning unit with a primary NOx system (assigned ID# 001) containing
the following components, identified in RT 510:
NOx Analyzer: Component ID# 100; Sample Acquisition Method: Dilution
C02 Analyzer: Component ID# 200; Sample Acquisition Method: Dilution
Submit RT 520 for the formula to compute the NOx emission rate. Report the formula ID
001 at column 11. At column 14, report the parameter "NOX". Referring to the
appendices to 40 CFR Part 75, note that the NOx emission rate should be determined by
using Equation F-6. Report "F-6" in the field for formula code at column 18. Record the
actual formula in the field for formula text at column 23. According to 40 CFR Part 75,
Appendix F, Equation F-6 is defined as follows:
100
E = K x C x F x
c %ca
(Equation F-6)
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Report the formula as it is defined in Equation F-6, replacing its variables with the
appropriate constants and references to the appropriate primary monitoring system and
component IDs. In this example, the conversion factor K for NOx is equal to 1.194 x 10"7
lb/scf/ppm, the Fc factor for bituminous coal is equal to 1800 scf C02/mmBtu, and the
symbols S#(100-001) and S#(200-001) refer to the concentration of NOx (in ppm) and
C02 (in percent) measured by the two monitors in the same primary NOx system. The
entry in column 23 for F#(001) would appear as follows:
E-h = 1.194 * 10**-7 * S#(100-001) * 1800 * (100/S#(200-001))
Example #2: NOx Emission Rate Calculation for Coal and Oil-fired Unit. Assume
you have the same monitoring system described in example #1 above, except that two
different fuels will be combusted: bituminous coal and oil. You may choose to include
two formulas: one to be used when coal is combusted, and one to be used when oil is
combusted. The formula for oil will have a different formula ID, and it will contain the
appropriate Fc factor for oil. In this example, you could create a formula #002, that would
appear as follows:
E-h = 1.194 * 10**-7 * S#(100-001) * 1420 * (100/S#(200-001))
If you intend to burn coal and oil simultaneously, you have two options:
• Use the formula with the highest Fc factor — in this case formula #001, the formula for
coal; or
• Instead of calculating two separate NOx formulas, use a pro-rated Fc factor. To do
this, first create a formula for the pro-rated factor in RT 520. Assign this formula a
unique formula ID, for example, formula ID "003". In column 14, report the
parameter "FC" for carbon-based F-factor. In column 18, report the appropriate
formula code. Referring to the appendices in 40 CFR Part 75, note that the pro-rated
Fc factor is determined by using Equation F-8. Report "F-8" in column 18. Then
report the actual formula in the field for formula text at column 23. Equation F-8 is
defined as follows:
Fc = E *, * (FX
i = 1
(Equation F-8)
Report the formula as it is defined in Equation F-8, replacing the summation notation with
the actual references to various fuels that will be combusted. In this example, report 1800
and 1420 as the Fc factors for coal and oil respectively, and Xcoal and Xoil to represent the
fraction of total heat input derived from coal and oil respectively. The entry beginning in
column 23 would therefore appear as follows:
Fc = (X(coal) * 1800) + (X(oil) * 1420)
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Then report a formula for the NOx emission rate calculation. This formula will be similar
to the other NOx formulas, except that it will have a different formula ID, and it will
contain a reference to the previously defined formula for the pro-rated Fc factor. In this
example, you could create a formula ID #004, that would appear as follows:
Eh = 1.194 * 10**-7 * (S#(100-001) * F#(003) * (100/S#(200-001)
The notation F#(003) is the reference to formula ID #003 that computes the pro-rated Fc
factor.
Example #3: Heat Input Apportionment Formulas for Common Stacks. Assume
you have two Acid Rain units (boilers 1 and 2) sharing a common stack. Formula ID
#100 calculates hourly heat input for the stack. You must calculate and report hourly heat
input for each of the two units. To do this, apportion the heat input at the common stack
as a ratio of the load from each unit to the load from all of the units at the stack. In this
example, create RTs 520 for Unit 1 and for Unit 2 containing unit heat input
apportionment formulas. For Unit 1, assign formula ID #101. Report the parameter "HI"
for heat input. Report F-21A as the equation code. Assuming you use gross electrical
output (in megawatts) as the equivalent of load, your formula in column 23 would appear
as follows:
HI 1 = (F#(100) * T CS1/T1) * MW_1 * T 1 /(MW_1 * T 1 + MW_2 * T 2)
F#(100) represents the heat input formula for the common stack; T CSl, T_1 and T_2
represent the hourly operating time for the common stack, Unit 1 and Unit 2, respectively;
MW_1 and MW_2 represent the gross electrical output for Units 1 and 2, respectively.
Create a second, similar formula record for the hourly heat input for Unit 2.
Example #4: Appendix D Heat Input Formula for Oil-Fired Unit. For an oil-fired
unit, you may report heat input using the hourly fuel flow rate and heat content. Assume
you have recorded in RT 510 a volumetric oil flow monitoring system (assigned System
ID# 200), which included the following components:
Flowmeter Measuring Main Oil Flow (in bbl/hr): Component ID# 001
Flowmeter Measuring Return Oil Flow (in bbl/hr): Component ID# 002
Create RT 520 for the formula to calculate the net volumetric flow rate of oil. First assign
a formula ID # and report it in column 11 (for example, formula ID # "200"). In column
14, report the parameter "FOIL". In column 18, report formula code N-OIL. Report the
formula in column 23. Since the flow of the consumed oil is determined by subtracting the
return flow from the flow of oil from the source, the entry in column 23 would appear as
follows:
Net Oil Flow Rate = S#(001-200) - S#(002-200)
Add another RT 520 to calculate the mass of oil consumed per hour. Assign and report a
formula ID # (for example, formula ID # "201"). Report the parameter "OILM" in
column 14. In the Table above, Equation D-3 is used to calculate the mass of oil
consumed per hour from the volumetric flow of oil consumed. Report "D-3" in column
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18. Report the actual formula in column 23. According to Appendix D, Equation D-3 is
defined as follows:
OILrate ~ ^dl-rate * ^oil
(Equation D-3)
Report the formula as it is defined in Equation D-3, replacing the variable for volumetric
oil flow with the appropriate reference. In this example, the symbol F#(200) refers to the
previously entered formula that calculated the volumetric flow of oil consumed. For
formula ID #201, the entry in column 23 would appear as follows:
MASSoil = F#(200) * DENSITY oil
Please note that you do not have to replace the variable indicating the density of the oil, if
this value is not a constant and it is not measured by a specific monitoring system
component.
Example #5: Appendix D Heat Input Formula for Combined Cycle Unit with duct
burner. Assume you have a combined cycle combustion turbine (CT) with a duct burner,
and that both the CT and the duct burner combust natural gas. Also assume that in RT
510, you have defined a gas monitoring system (assigned System ID# 300), which includes
the following components:
Flowmeter Measuring Gas Flow to the Turbine: Component ID# 001
Flowmeter Measuring Gas Flow to the Duct Burner: Component ID# 002
For this configuration, you must create two formula records (RTs 520) to represent the
hourly heat input rate to the unit. First, create a "net fuel flow" formula to calculate the
total gas flow rate for the unit. Assign a formula ID # to the net fuel flow equation and
report it in column 11 (for example, formula ID # "201"). Then, in column 14, report the
parameter "FGAS", and in column 18 report formula code N-GAS. Report the formula
text in column 23. Since the total, or net, hourly gas flow rate to the unit is determined
by adding the gas flow rate to the turbine and the gas flow rate to the duct burner, the
entry in column 23 would appear as follows:
Net Gas Flow Rate = S#(001-300) + S#(002-300)
Next, create a second RT 520 to calculate the total hourly heat input rate from gas
combustion. Assign and report a formula ID # (for example, formula ID # "202"). Report
the parameter "HI" in column 14. Then, from Table 20 above, select Equation D-6 or F-
20 (see below) to calculate the hourly heat input rate from the combustion of gas and
report a formula code of "D-6" (or "F-20") in column 18.
HI = (Q * GCV„)/106 (Eq. D-6)
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Report the formula text in RT 520, column 23 as it appears in Equation D-6, except that
Qg, the variable for gas flow rate, is replaced with a reference to formula 201, the net fuel
flow rate equation. Therefore, for formula ID # 202, the entry in column 23 would appear
as follows:
HIg = (F#(201) * GCVg)/106
Example #6: Heat Input Rate Summation Formulas for Multiple Stacks. Assume
that you have one unit (boiler 1) which has two multiple stacks (MSI and MS2). Formula
ID #100 calculates hourly heat input rate for MSI and Formula ID #200 calculates hourly
heat input rate for MS2.
You must calculate and report hourly heat input rate at the unit level. To do this, sum the
heat input rates from the multiple stacks adjusted for stack operating time. In this example
create RT 520 for Unit 1. Assign formula ID #102. Report the parameter "HI" for heat
input rate. Report F-21C as the formula code. Your formula in column 23 would appear
as follows:
HI_1 = (F#(100)*T_MS1 + (F#(200) * T MS2)/T 1
F#(100) represents the heat input rate formula for multiple stack MSI; F#(200) represents
the heat input rate formula for multiple stack MS2; T MSl, T MS2 and T_1 represent
the operating times for multiple stacks 1 and 2 and Unit 1, respectively, and HI_1
represents the total heat input rate for Unit 1.
(12) RT 530: Span Table
RT 530 contains information on the span and range values associated with the continuous
emission monitors installed a unit or stack and the time period in which these values are effective.
If you use a CEMS methodology you must include RT 530 for each parameter (e.g.. NOX, S02,
C02, 02, or FLOW) that is measured using CEMS. Note that for units that combust more than one type
of fuel, the maximum potential concentration (MPC) and maximum potential emission rate (MER) values
reported in RT 530 are based solely on the fuel that produces the highest pollutant concentration or
emission rate. Therefore, if you elect to use one of the fuel-specific missing data options in § 75.33,
75.16(c)(3), or 75.17(d)(2), you must, in addition to reporting the "conventional" MPC or MER values in
RT 530, report fuel-specific maximum potential values (one for each type of fuel), using RT 531.
For Appendix E units, use RT 530 to report the fuel-specific maximum potential NOx emission
rates (MERs) required for Appendix E missing data purposes. Report the MER for gas combustion using
a parameter code of "GNOX". For oil combustion, report the MER using a parameter code of "ONOX".
Submit records for all spans in use at that unit or stack during the testing or reporting period. If
the span value changes during the quarter, submit two RTs 530 for that parameter: one reflecting the
span value prior to the change (with the date of the change in the deactivation date field) and one
reflecting the new span value (with the date of the change in the activation date field).
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If S02, NOx, C02, or 02 emission concentrations vary such that dual ranges are required (e.g.. due
to fuel switching or emission controls), provide separate RTs 530 for the low scale and high scale values.
If you elect to use a default high range value (200% of MPC for S02 or NOx) instead of a dual
range or separate high scale monitor for hours requiring high scale readings, submit both high scale and
low scale span records, but in the high scale record, only report data in start columns 1 through 15,
column 17 (the MPC), column 30 (the NOx MER, if NOx is the parameter), columns 68 and 74 (the
activation date and hour of the default high range value), column 84 (indicator that default high range
option is used), and column 85 (the default high range value of 200% of MPC).
Field Descriptions and Instructions
Parameter Monitored (10). Identify the parameter monitored at the unit or stack using
the following uppercase codes:
C02 C02 Concentration (%)
FLOW Stack Flow (SCFH)
GNOX NOx MER for Gas Appendix E Missing Data Purposes
NOX NOx Concentration (ppm)
02 02 Concentration (%)
ONOX NOx MER for Oil for Appendix E Missing Data Purposes
S02 S02 Concentration (ppm) (ARP)
Scale (14). For S02, NOx, C02, or 02, report either "H" to indicate high scale or "L" to
indicate low scale. Do not leave this field blank for these parameters.
There is only a single scale (H) of values for flow rate. Do not leave this field blank for
flow.
Leave the scale blank for GNOX and ONOX records.
Method for Calculating MPC/MEC/MPF (15). For S02, NOx, and flow, report the
method used to determine the maximum potential (or expected) concentration (or flow
rate) using the appropriate uppercase codes.
F
Formula (S02, flow rate, and low-scale NOx only)
HD
Historical Data
TR
Test Results
TB
Table of Constants from Part 75 or Default Values from Part 75
(e.g.. 800 ppm NOx for coal-firing)
OL
Other Limit
GS
Low Scale Default for S02 for Gas Units
PL
NOx MEC based on permit limit
ME
NOx MPC based on manufacturer's estimate of uncontrolled emissions
If you use Equations A-la or A-lb from Appendix A to Part 75 or historical data to
determine maximum potential flow (MPF), submit documentation with your original
hardcopy monitoring plan submission and retain the supporting information in your files.
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Leave the method blank for 02, GNOX, and ONOX records.
Table 25 summarizes the recommended methods for determining MPC/MEC/MPF.
MPC/MEC/MPF (17). For NOx or S02, report either the maximum potential
concentration (MPC) or the maximum expected concentration (MEC) in ppm, as follows.
If a single, high-scale monitor range is used, report the MPC. For dual-span units, report
the MPC in a high-scale RT 530 and report the MEC in a second, low-scale RT 530. This
applies whether two monitor ranges are used or whether the default high range option is
used. MEC/MPC for NOx or S02 should be reported as an integer (no decimal places).
For flow rate, report the maximum potential flow rate in units of standard cubic feet per
hour (scfh) on a wet basis.
For C02, enter a default MPC value of 14.0% C02 for boilers and 6.0% C02 for turbines,
unless the MPC is determined based on historical data (use a code of "TB" in column 15 if
the default value is reported). If historical data are used (720 hours, minimum), report the
highest %C02 value observed in the historical lookback period as the MPC.
For 02 (for all units), leave this field blank.
For GNOX or ONOX records, report the NOx concentration used to calculate NOx MER.
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Table 26
CRITERIA FOR MPC/MEC/MPF DETERMINATIONS
Piirnmeter
Scale
Method I sod (o Determine
MP( /MIX /Ml»l
Select ion
Crileriii
Method
C ode
NOx
High
800 or 1600 ppm, as applicable
For coal-fired units
TB
400 ppm
For oil- or gas-fired units
TB
2000 ppm
Cement kilns
TB
500 ppm
Process heaters burning oil
TB
200 ppm
Process heaters burning only gaseous fuels
TB
Historical CEM Data
For initial determination or for changes in
MPC as described in Section 2.1.2.5 of
Appendix A
HD
Other Constant Values from App. A,
Tables 2-1 and 2-2
If historical data not available by boiler type
and fuel
TB
Test Results
If historical data not available
TR
Other, including other State/federal
requirements
As justified
OL
Manufacturer's estimate of
uncontrolled emissions
For initial MPC determination, principally
for new units
ME
Low
Equation A-2
For units with emission controls
F
Historical CEM Data
For initial determination or for changes in
MEC as described in Section 2.1.2.5 of
Appendix A
HD
Other, including other State/federal
requirements
As justified
OL
Test Results
If available
TR
Permit limit
For initial MEC determination, principally
for new units
PL
FLOW
N/A
Equation A-3a and Equation of
Continuity*
Based on %C02
F
Equation A-3b and Equation of
Continuity*
Based on %02
F
Historical Data
For changes in MPF, as described in Section
2.1.4.3 of Appendix A
HD
Test Results
If available
TR
S02
High
Equation A-la
Based on %C02
F
Equation A-lb
Based on %02
F
Historical CEM Data
For initial determination or for changes in
MPC as described in Section 2.1.1.5 of
Appendix A
HD
(cont.)
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Table 26
CRITERIA FOR MPC/MEC/MPF DETERMINATIONS (cont.)
Piiriiineter
Scsile
Method I sod (o Determine
MI'C /MIX /MPI
Selection
C'riteriii
Method
C ode
S02 (cont.)
High
(cont.)
Test Results
If available
TR
Other, including other State/federal
requirements
As justified
OL
Low
Equation A-2
For units with emission controls
F
Historical CEM Data
For initial determination or for changes in
MEC as described in Section 2.1.1.5 of
Appendix A
HD
<200 ppm (span value)
For units burning only very low sulfur fuel
(as defined in § 72.2)
GS
Other, including other State/federal
requirements
As justified
OL
* The maximum potential flow rate (MPF) is calculated using the Equation of Continuity: MPF = 60 x MPV x As. In
this equation, MPV is the maximum potential velocity (from Equation A-3a or A-3b or from test results), in units of
wet, standard feet per minute, and As is the cross-sectional area of the stack at the flow monitor location.
Maximum Potential NOx Emission Rate (30). If you use a NOx emission rate CEMS
you must calculate and report a maximum potential NOx emission rate (MER), based on
the MPC value for each unit or stack for use with missing data procedures. Also report
the fuel-specific NOx MER values in GNOX and ONOX records for use with Appendix E
Calculate NOx MER on a unit or stack basis by using one of the following formulas and
values.
E = K x C. x F, x
20.9
20.9-%a
(Equation F-5)
Where:
Cd
Fd (dscf/mmBtu)
%07,
NOx concentration (dry) (use MPC as reported in column 17)
Dry basis F-factor used for the unit in RTs 520
Maximum oxygen concentration during normal operating conditions, or use the
diluent cap value of 14.0% 02 for boilers and 19.0% 02for turbines or if MPC is
derived from historical data, you may use the 02 reading recorded at the hour of
the MPC
E = K x C xFx
c %ca
(Equation F-6)
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Where:
NOx concentration (wet) (use MPC as reported in column 17)
Carbon-based F-factor used for the unit in RTs 520
Minimum carbon dioxide concentration during normal operating conditions, or
use the diluent cap value of 5.0% C02 for boilers and 1.0% C02 for turbines
or if MPC is derived from historical data, you may use the C02 reading
recorded at the hour of the MPC
Please note that for NOx MER calculated using an F-6 equation you should use the
minimum %C02 value or for an F-5 equation the maximum %02 value (under normal
operating conditions). Alternatively, the appropriate diluent cap value may be used in the
MER calculation or, if the MPC is derived from historical CEM data, you may use the
diluent gas concentration recorded at the hour of the MPC.
Report maximum NOx emission rate only for high-scale NOx span, ONOX and GNOX
records. In all other RTs 530 leave this field blank.
Span Value in Units of Daily Calibration (36). Report the span value determined
according to the requirements of Part 75. If you are using a default high range value for
S02 or NOx, leave this field blank in the high scale RT 530.
For S02 and NOx, high-scale span values must be between 100% and 125% of the
maximum potential concentration, rounded up to the next highest multiple of 100 ppm (or
rounded up to the next 10 ppm if 125% of MPC is less than 500 ppm). Low-scale span
values must be between 100% and 125% of MEC, rounded upward to the next highest
multiple of 10 ppm.
For flow rate, the span value in column 36 is the calibration span value and must be
reported in the units used for daily calibrations. To determine the calibration span value
for monitors that are not calibrated in units of inches of H20, first convert the maximum
potential velocity (MPV) from units of wet standard feet per minute (wsfpm) to the units
used for daily calibration. Multiply the result by a factor no less than 1.00 and no more
than 1.25 and round up, retaining at least two significant figures.
For DP-type flow monitors that are calibrated in units of inches of H20, select a value
between 100% and 125% of the MPV. Then convert that value from units of wsfpm to
units of wet actual feet per second (wafps). Then use Equation 2-9 in EPA Reference
Method 2 (40 CFR 60, Appendix A) to convert the actual velocity to an equivalent delta-P
value in inches of H20. Retain at least two decimal places in the delta-P value. In
performing these calculations, the values of stack temperature, stack pressure, stack gas
molecular weight and the pitot tube coefficient may be estimated based on the results of
previous emission testing.
For C02 and 02, report the appropriate percentage, to the nearest 1%C02 or 02, not ppm.
Full Scale Range in Units of Daily Calibration (49). For S02, NOx, C02, 02, and flow
rate, report the full-scale range in the units used for daily calibrations. Select the range
such that the majority of the readings obtained during normal operation of the monitor are
between 20 and 80 percent of full-scale. See Section 2.1 of Appendix A to Part 75 for
r
Fc (scf C02/mmBtu) =
%C02
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allowable exceptions to this guideline. The full-scale range must be greater than or equal
to the span value. If you are using a default high range value for S02 or NOx, leave this
field blank in the high scale RT 530.
Daily Calibration Units of Measure (62). Report the units of calibration span value in
column 36. For S02 and NOx, report "PPM". For C02 or 02, report"%". For flow,
report one of the following uppercase codes to indicate the units used to report and
perform daily calibrations based on span. If you are using a default high range value for
S02 or NOx, leave this field blank in the high scale RT 530.
ACFH
Actual Cubic Feet Per Hour
ACFM
Actual Cubic Feet Per Minute
AFPM
Actual Feet Per Minute
INH20
Inches of Water
KACFH
Thousand Actual Cubic Feet Per Hour
KACFM
Thousand Actual Cubic Feet Per Minute
KAFPM
Thousand Actual Feet Per Minute
KSCFH
Thousand Standard Cubic Feet Per Hour
KSCFM
Thousand Standard Cubic Feet Per Minute
KSFPM
Thousand Standard Feet Per Minute
MACFH
Million Actual Cubic Feet Per Hour
MSCFH
Million Standard Cubic Feet Per Hour
SCFH
Standard Cubic Feet Per Hour
SCFM
Standard Cubic Feet Per Minute
SFPM
Standard Feet Per Minute
AMSEC
Actual Meters Per Second
SMSEC
Standard Meters Per Second
Span Effective Date and Hour (68, 74). Report the date and time that the current span
value (i.e.. the value in column 36) was first used to test the CEMS or to measure
emissions. For the initial certification of a monitoring system, this means that the span
effective date will precede the date of provisional certification—except when the
conditional data validation procedures of § 75.20 (b)(3) are applied to initial certification.
If you have elected to use a default high range value for S02 or NOx, report the date on
which the default high range was implemented in the DAHS.
Span Inactivation Date and Hour (76, 82). Leave these fields blank unless a span
change was made during the reporting quarter. If the span value has been changed, submit
two RTs 530.
In the first RT 530, report the last date and hour that the previous span value was used. If
you have discontinued the use of a default high range value for S02 or NOx in favor of
using a span value, report in the first RT 530 the last date and hour on which the default
high range was in use.
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In the second RT 530, report the date and hour on which the new span value became
effective. If you are changing from a span value to a default high range value for S02 or
NOx, report the date and hour on which the default high range was implemented in the
Dual Spans Required (84). For S02, NOx, C02 or 02, if a dual range analyzer is
required, indicate this and/or the monitoring approach used for the secondary scale, using
one of the following uppercase codes:
If you elect to install and operate two CEMS ranges, include code D in both the high and
low scale records for the parameter. If you elect to use a default high range value for all
hours in which a high range S02 or NOx CEM would be required, indicate this by
reporting the letter "O" in column 84 for both the high and low scale records for the
parameter.
Default High Range Value (85). Report the actual default value in this field in the high
scale record for the parameter if you report code "O" in column 84. The default high
range value must be 200% of the maximum potential concentration reported in column 17.
Report this value only in the high scale record for the parameter.
For the parameters C02, 02, FLOW, GNOX, or ONOX leave this field blank.
Flow Rate Span Value in SCFH (90). For the parameter FLOW, report the flow rate
span value, which is the product of the MPF (from column 17) and a factor no less than
1.00 and no greater than 1.25. This factor must be the same one that was used to
determine the calibration span value. Round the flow rate span value upward to the next
highest 1000 scfh.
Flow Rate Full Scale Value in SCFH (99). For the parameter FLOW, report the actual
full-scale range value expressed in units of scfh. The flow rate full-scale range value must
be greater than or equal to the flow rate span value.
(13) RT 531: Maximums, Minimums, Defaults, and Constants
Submit RT 531 to register various maximum values, minimum values, defaults and constants
which are used in the Part 75 emissions and heat input calculations or in the missing data routines.
Submit one record for each fuel type and parameter combination to define the applicable emission factor,
moisture content, maximum potential value, or diluent cap to be used as described below.
Situations Requiring Submission of RT 531
Use RT 531 to provide the following information:
DAHS.
D
O
Two CEMS Ranges Installed
Dual Range Required/Use of Optional Default High Range Value Elected
(S02 and NOx only)
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• Fuel-specific maximum potential S02 or NOx concentrations (MPCs), maximum potential NOx
emission rates (MERs), or maximum potential flow rates (MPFs), for units using fuel-specific
CEMS missing data option under § 75.33.
• Fuel-specific maximum potential S02 or NOx concentrations or maximum potential NOx
emission rates, for units with add-on emission controls and unmonitored bypass stacks, if the
fuel-specific MPC or MER is reported during hours when the flue gases are routed through
the bypass stack (see §§75.16 (c)(3) and 75.17 (d)(2)).
• Generic defaults for NOx, S02, and C02 emission rates (lb/mmBtu) for low mass emissions
units.
• Fuel and unit-specific NOx, S02, and C02 emission rate defaults for low mass emissions
(LME) units.
• Generic NOx emission rate defaults for low mass emissions units with NOx controls. Use this
value when the controls are not operating.
• Default values used to define maximum rated hourly heat input rate (mmBtu/hr) used by a low
mass emissions unit. This must be the same value reported in column 13 of RT 504.
• Default moisture values from § 75.11(b), used to estimate stack moisture content for wood or
coal-fired units.
• Site-specific default moisture percentages, approved by petition under § 75.66.
• Default S02 emission rates for gaseous fuel combustion, for units with S02 monitors which
use Equation F-23 and either 0.0006 lb/mmBtu (for pipeline natural gas) or (for natural gas or
"other" gaseous fuel) a site-specific default S02 emission rate, calculated using Equation D-
lh, to determine S02 mass emissions (see § 75.11(e)(1)).
• Diluent cap value based on boiler type (required only if you use the cap value for data
reporting).
• Maximum or minimum potential moisture percentage (required only if you monitor moisture
continuously or use a moisture look-up table). Use for missing data purposes.
• Minimum potential 02 used for missing data purposes.
• Default minimum fuel flow rate (see Part 75 Policy Manual Question 25.21).
Situations Not Requiring Submission of RT 531
Do not use RT 531 for the following information:
• Values for C02 or 02 used to calculate the maximum potential velocity (MPV), which is used
to determine the flow rate span value. Submit the information to support flow span
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calculations in hardcopy with the initial monitoring plan (and store on site). Do not report this
information electronically in the EDR.
• Maximum potential NOx emission rate (MER) values for oil and gas combustion, for
Appendix E units (these MER values are defined in RT 530, using "GNOX" and "ONOX"
parameters).
• Values used during hours of scale exceedances (unless required by the State).
• Maximum oil and gas fuel flow rate (already defined in RT 540).
• Maximum potential (or maximum expected) S02, NOx, C02, or flow rate values, for units
using the standard (non-fuel-specific) CEMS missing data routines in § 75.33. (These
maximum potential and expected values are defined in RT 530.)
• Default high range value for S02 or NOx (already defined in RT 530).
• Default S02 emission rates for Acid Rain Program units that use Appendix D to account for
S02 mass emissions from the combustion of gaseous fuel. For these units, report the default
S02 emission rates in RT 314.
• Appendix D density and GCV values for oil and gas. These values are defined in RTs 302 and
303.
Field Descriptions and Instructions
Parameter (10). Report the parameter for which a default or maximum value is defined
in the record using the following uppercase codes:
Low Mass Emissions Parameters
C02G C02 Default Emission Factor, from Table 31 (lb/mmBtu)
MHHI Maximum Rated Hourly Heat Input Rate (mmBtu/hr)
NOXG NOx Default Emission Factor, from Table 29 (lb/mmBtu)
NOXU Fuel and Unit-specific NOx Emission Rate (lb/mmBtu)
S02G S02 Default Emission Factor, from Table 30 (lb/mmBtu)
S02U Fuel and Unit-specific S02 Default Emission Factor, for Combustion of
"Other" Gaseous Fuel, Calculated Using Equation D-lh. This code must
also be used for fuel oil combustion, if you have an approved petition to
use a site-specific S02 emission rate (lb/mmBtu)
C02U Fuel and Unit-specific C02 Default Emission Factor, for Combustion of
"Other" Gaseous Fuel (ton/mmBtu)
Note: Report "NOXU" in the following cases: (1) for fuel-and-unit specific NOx emission
rates obtained by testing; and (2) for the maximum potential NOx emission rate, if
that value is reported in the interval from the first hour of use of the LME
methodology until the hour of completion of fuel-and-unit specific NOx emission
rate testing (see § 75.19 (a)(4)).
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Moisture Default Parameter
H20 Hourly Percent Moisture Content(% H20)
Diluent Cap Parameter
02X Maximum % Oxygen
C02M Minimum % C02
S(X Emission Rate Parameters for Gaseous Fuels
S02G S02 Generic Default Emission Factor for Pipeline Natural Gas (lb/mmBtu)
S02U Fuel and Unit-Specific Default Emission Factor for Natural Gas or for
"Other" Gaseous Fuel, Calculated Using Equation D-lh (lb/mmBtu)
Note: The above parameters apply only to units with installed S02 monitors, if Equation
F-23 is used to quantify S02 mass emissions during hours when only gaseous fuel
is combusted (see § 75.11 (e)(1)).
Other Parameters (Subject to EPA Approval of Petition)
MNHI Minimum Heat Input Rate (mmBtu/hr)
MNNX Minimum NOx Emission Rate (lb/mmBtu)
Other Parameters (Not Subject to EPA Approval of Petition)
MNOF Minimum Oil Flow Rate
MNGF Minimum Gas Flow Rate
Missing Data or Maximum for Unmonitored Bypass Stack
H20M Minimum Potential % Moisture
H20X Maximum Potential % Moisture
02M Minimum Potential % Oxygen
S02X Fuel-Specific Maximum Potential S02 Concentration (ppm)
NOCX Fuel-Specific Maximum Potential NOx Concentration (ppm)
NORX Fuel-Specific Maximum Potential NOx Emission Rate (lb/mmBtu)
FLOX Fuel-Specific Maximum Potential Flow Rate (scfh)
Value of Default, Maximum, Minimum, or Constant (14). Report the value to be used
to the number of decimal places consistent with the EDR.
If the parameter is "S02G" or "S02U", leave the field blank and report the S02 default in
column 65. Column 65 contains the proper number of decimal places (4) for reporting
default S02 emission rates for gaseous fuels, whereas this field does not.
For a C02 diluent cap value, report 5.0% for a boiler or 1.0% for a combustion turbine.
For an 02 diluent cap value, report 14.0% for a boiler or 19.0% for a turbine.
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EDR v2.2 Instructions: RT 531
For the maximum potential moisture percentage, report the site-specific value derived
from 720 or more hours of historical data. For the minimum potential moisture
percentage, either report a default value of 3.0% H20 or a site-specific value obtained
from 720 or more hours of historical data.
Tables 27 and 28 provide the fuel-specific moisture default values for coal-fired and
wood-burning units. Table 27 provides minimum default moisture values that are used in
all emission and heat input rate calculations requiring moisture corrections, except for
calculation of NOx emission rates using Equation 19-3, 19-4, or 19-8 from EPA Method
19 in Appendix A to 40 CFR 60. If Equation 19-3, 19-4, or 19-8 is used to calculate NOx
emission rate, use the appropriate maximum default moisture value from Table 28.
Table 27
FUEL-SPECIFIC MINIMUM DEFAULT MOISTURE VALUES
FOR S02, NOx OR HEAT INPUT RATE CALCULATIONS
l-lld
Minimum Moisture
Delimit Vsilue
Anthracite Coal
3.0%
Bituminous Coal
6.0%
Sub-bituminous Coal
8.0%
Lignite Coal
11.0%
Wood
13.0%
Table 28
FUEL-SPECIFIC MAXIMUM DEFAULT MOISTURE VALUES
FOR NOx EMISSION RATE CALCULATIONS
luel
M:i\imiim Moisture
Delimit Viiluc
Anthracite Coal
5.0%
Bituminous Coal
8.0%
Sub-bituminous Coal
12.0%
Lignite Coal
13.0%
Wood
15.0%
Table 29 contains the NOx emission factors for qualifying low mass emissions units, which
are based on the boiler type (as reported in RT 504) and the primary fuel combusted. Unit
and fuel-specific NOx emission rates may be determined for low mass emissions units by
emission testing, in lieu of using the defaults in Table 29.
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Table 29
NOx EMISSION FACTORS (LB/MMBTU)
FOR LOW MASS EMISSIONS UNITS
lioilor Typo
I'uol Type
\()s l-~mission l-'siclors
Turbine
Gas
0.7
Oil
1.2
Boiler
Gas
1.5
Oil
2
Table 30 contains the Part 75 S02 emission factors for low mass emissions units which are
based only on the primary fuel combusted.
Table 30
S02 EMISSION FACTORS (LB/MMBTU)
FOR LOW MASS EMISSIONS UNITS
I'uol Type
SO, Kinission l itcloi s
Pipeline Natural Gas
(as defined in § 72.2)
0.0006
Natural Gas
0.06
Residual Oil or Other Oil
2.1
Diesel Fuel
0.5
Table 31 contains fuel-specific C02 emission factors for low mass emissions units.
Table 31
C02 EMISSION FACTORS (TON/MMBTU)
FOR LOW MASS EMISSIONS UNITS
I'uol Typo
CO, Kinission l itcloi s
Natural Gas
0.059
Oil
0.081
Units of Measure (27). Identify the units of the default value using the uppercase codes
in Table 32 below.
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Table 32
UNITS OF MEASURE CODES BY PARAMETER
C ode
Description
PiiTiimeler (Col 10)
%H20
Percent Moisture
H20, H20M, H20X
LBMMBTU
Pounds Per Million Btu
MNNX, NOXG, NOXU, S02G,
S02U, NORX
MMBTUHR
Million Btu Per Hour
MHHI, MNHI
TNMMBTU
Tons Per Million Btu
C02G, C02U
%C02
Percent C02
C02M
%02
Percent 02
02X, 02M
SCFH
Standard Cubic Feet Per Hour
MNOF, FLOX
PPM
Parts per million
S02X, NOCX
GALHR
Gallons of Oil Per Hour
MNOF
BBLHR
Barrels of Oil Per Hour
MNOF
M3HR
Cubic Meters of Oil Per Hour
MNOF
LBHR
Pounds of Oil Per Hour
MNOF
HSCF
Hundred SCF of Gas Per Hour
MNGF
Purpose or Intended Use (34). Identify the purpose or intended use of the value for
reporting and emissions measurement using the following uppercase codes:
DC
Diluent Cap Value
DM
Default Minimum Fuel Flow Rate
F23
S02 Emission Rate Default for Use in Equation F-23
LM
Low Mass Emissions Unit Default
LMB
Low Mass Emission Unit Default for Base Load Hours
LMP
Low Mass Emissions Default for Peak Load Hours
MD
Missing Data (including maximum values reported for unmonitored by pass
stack hours)
PM
Primary Measurement Methodology
Use the codes LMB and LMP only for Low Mass Emissions units required to report
separate rates for base load and peak load hours (See §75.19(c)(l)(iv)(c)(9)).
Type of Fuel (37). Identify the type of fuel associated with the default using one of the
following uppercase codes.
For maximum rated heat input rate, maximum or minimum potential moisture or 02
values, or diluent cap values, report "NFS".
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Types of Fuel for Defining LME Defaults
BFG
Blast Furnace Gas
BUT
Butane (if measured as a gas)
CDG
Coal Derived Gas
COG
Coke Oven Gas
DGG
Digester Gas
DSL
Diesel Oil
LFG
Landfill Gas
LPG
Liquefied Petroleum Gas (if measured as a gas)
NFS
Non-fuel Specific (for MHHI)
NNG
Natural Gas
OGS
Other Gas
OIL
Residual Oil
OOL
Other Oil
PDG
Producer Gas
PNG
Pipeline Natural Gas (as defined in § 72.2)
PRG
Process Gas
PRP
Propane (if measured as a gas)
RFG
Refinery Gas
SRG
Unrefined Sour Gas
Types of Fuel for Defining Moisture Defaults for ARP and Subpart H Units
ANT
Anthracite Coal
BT
Bituminous Coal
CRF
Coal Refuse (culm or gob)
LIG
Lignite
SUB
Sub-bituminous Coal
W
Wood
Types of Fuel for S(X Emission Rate Default for Use in Equation F-23
NNG Natural Gas
PNG Pipeline Natural Gas
Types of Fuel for Fuel-Specific CEMS Missing Data
BFG
Blast Furnace Gas
BUT
Butane (if measured
as a gas)
C
Coal
CDG
Coal Derived Gas
COG
Coke Oven Gas
COF
Co-fired Fuels
CRF
Coal Refuse (culm or gob)
DGG
Digester Gas
DSL
Diesel Oil
LFG
Landfill Gas
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LPG
Liquefied Petroleum Gas (if measured as a gas)
NNG
Natural Gas
OGS
Other Gas
OIL
Residual Oil
OOL
Other Oil
OSF
Other Solid Fuel
PDG
Producer Gas
PNG
Pipeline Natural Gas (as defined in § 72.2)
PRG
Process Gas
PRP
Propane (if measured as a gas)
PRS
Process Sludge
PTC
Petroleum Coke
R
Refuse
RFG
Refinery Gas
SRG
Unrefined Sour Gas
TDF
Tire Derived Fuel
W
Wood
WL
Waste Liquid
Types of Fuel for Fuel-Specific MPC or MER Reporting (Bypass Stack Operating Hours')
BFG
Blast Furnace Gas
BUT
Butane (if measured as a gas)
C
Coal
CDG
Coal Derived Gas
COG
Coke Oven Gas
CRF
Coal Refuse (culm or gob)
DGG
Digester Gas
DSL
Diesel Oil
LFG
Landfill Gas
LPG
Liquefied Petroleum Gas (if measured as a gas)
NNG
Natural Gas
OGS
Other Gas
OIL
Residual Oil
OOL
Other Oil
OSF
Other Solid Fuel
PDG
Producer Gas
PNG
Pipeline Natural Gas (as defined in § 72.2)
PRG
Process Gas
PRP
Propane (if measured as a gas)
PRS
Process Sludge
PTC
Petroleum Coke
R
Refuse
RFG
Refinery Gas
SRG
Unrefined Sour Gas
TDF
Tire Derived Fuel
W
Wood
WL
Waste Liquid
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Indicator for Use for Controlled/Uncontrolled Hours (40). If the value is used only for
controlled or uncontrolled hours, indicate this using a "C" or "U", as appropriate. If the
use of the value is not related to the control status of the unit, report "A" for any hour.
Source of Value (41). Report the means of selecting or determining the Maximum,
Minimum, or Constant value using the following uppercase codes for the parameters
reported in column 10:
Code
Source of Value Description
Parameter
APP
DATA
DCPD
Approved (Petition)
Historical or Other Relevant Data
Diluent Cap Default from Part 75
MNNX, MNHI, H20, S02U
02M, H20M, H20X, FLOX,
S02X, NOCX, NORX,
NOXU
C02M, 02X
LME
MC
NPC
TEST
SAMP
CONT
DEF
Low Mass Emissions Generic
Default Emission Factor
Moisture Constant from Part 75
Nameplate Capacity (heat input
rate only)
Unit/Stack Testing
Fuel Sampling
Contract Maximum
Default Value
C02G, S02G, NOXG
H20
MHHI
NOXU, FLOX, S02X,
NOCX, NORX
S02G, S02U, C02U, S02X
S02G
S02G, H20M, H20X,
MNOF, MNGF, S02X,
NOCX, NORX
Note 1: Report code "DATA" in this field if you report the maximum potential NOx
emission rate in the interval from the first hour of use of the LME methodology
until the hour of completion of fuel-and-unit specific NOx emission rate testing
(see §75.19 (a)(4)).
Note 2: Report "APP" if you have an approved petition to use a site-specific S02
emission factor for fuel oil combustion.
Value Effective Date and Hour (45, 53). Report the date and hour on which you began
use of this default for purposes of reporting data of any kind (i.e.. certification test data or
emissions data) for the program.
Value No Longer Effective Date and Hour (55, 63). Report the date and hour on
which the value was changed or after which it will no longer be used. Submit a second
RT 531 with an effective date and hour to report a new value.
For values currently in use, leave this date blank.
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S02 Emission Factor (ARP) (65). For Acid Rain Program units that either: (a) use
Equation F-23, as described in § 75.11 (e)(1); or (b) use the low mass emissions
methodology in § 75.19 to quantify S02 mass emissions, report the S02 emission factor
appropriate for the type of fuel combusted in the unit.
For Units Using Equation F-23:
• For pipeline natural gas combustion, report 0.0006 lb/mmBtu;
• For natural gas combustion, report the default S02 emission rate (lb/mmBtu)
calculated using Equation D-lh;
• For "other" gaseous fuels that qualify under section 2.3.6 of Appendix D to use a
default S02 emission rate, report the emission rate (lb/mmBtu), calculated using
Equation D-lh.
For LME Units:
• Report the appropriate generic default S02 emission factor from Table 30, for fuel oil,
pipeline natural gas, or natural gas.
• For "other" gaseous fuels, report the fuel and unit-specific S02 default emission rate
derived from the 720-hour demonstration under section 2.3.6 of Appendix D.
For defaults not associated with S02 emission factors, leave this field blank.
(14) RT 532: Rectangular Duct WAF Data
For rectangular ducts or stacks with installed flow monitors, you may determine a wall effects
adjustment factor (WAF) using Conditional Test Method CTM-041 and apply the WAF to your flow rate
data. Conditional Test Method CTM-041 allows you to either:
• Determine a site-specific default WAF; or
• Make wall effects measurements and calculate an average WAF, based on three or
more test runs.
If you elect to measure wall effects, the measurements may be made at any load level (low, mid or
high) and may either be coupled with the test runs of a flow RATA or may be made separately. Once a
default or measured WAF has been determined, you may enter it into the programming of your flow
monitor as a correction to the cross-sectional area of the rectangular stack or duct, thereby adjusting the
measured stack gas flow rates for wall effects. Then, when a subsequent RATA of the flow monitor is
performed, the same WAF that is being used to correct the flow monitor readings should be applied to
the reference method test data.
All units/stacks currently applying a wall effects correction obtained using CTM-041 to flow rate
data must report RT 532 in each quarterly submission. For units not presently applying a wall effects
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December 2005
correction, but intending to begin using a WAF, report RT 532 beginning with the EDR for the calendar
quarter in which the WAF is determined, with one exception — if the unit is an ozone season-only
reporter and the WAF is determined outside the ozone season, report RT 532 beginning with the 2nd
quarter EDR for the next ozone season.
If a new WAF test has been performed (because the stack or ductwork is altered such that the
flow profile is significantly changed), report two RTs 532: one that ends the record that is no longer
effective, and one that reports the new wall effects adjustment factor data.
Field Descriptions and Instructions
Duct Width at Test Location (10). Report the width of the rectangular duct at the test
location (i.e.. dimension Lx in Figure 1 of CTM-041), to the nearest 0.1 ft.
Duct Depth at Test Location (15). Report the depth of the rectangular duct at the test
location (i.e.. dimension Ly in Figure 1 of CTM-041), to the nearest 0.1 ft.
WAF (20). Report the WAF applied to the flow rate data, to four decimal places, with a
leading zero (e.g.. 0.9750).
Method of Determining WAF (26). Indicate the WAF calculation approach, Le^, report
either "FT" if it is a measured value from a full test (CTM-041 § 8.1 and 8.2), "AT" if it is
a measured value from an abbreviated test (CTM-041 § 8.4.1), or "DF" if the WAF is a
default value (CTM-041 § 8.4.2).
WAF Effective Date and Hour (28, 36). Report the date and hour on which the WAF
was first applied to the flow rate data.
WAF No Longer Effective Date and Hour (38, 46). Report the date and hour on which
the WAF was last applied to the flow rate data. Leave this field blank if this WAF is still
being applied.
WAF Determination Date (48). Report the date the WAF applied in column 20 was
determined. Unless you are a first time user of CTM-041, this date must be on or prior to
the WAF Effective Date, with one exception. First time users of CTM-041 may
retroactively apply the rectangular duct WAF back to January 1 of the year in which the
rectangular duct WAF determination is made. Therefore, for first-time users, the effective
date in column 28 may be earlier than the WAF Determination Date.
Number of Test Runs (56). Report the number of runs in the WAF test (must be one for
default WAF and at least three for a measured WAF).
Number of Method 1 Traverse Points used in WAF Run(s) (58). Report the number
of Method 1 traverse points in the WAF test runs.
Number of Test Ports Used in WAF Test (60). Report the number of test ports at
which measurements were made during the WAF test runs.
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Number of Method 1 Traverse Points in Reference Flow RATA (62). Report the
number of Method 1 traverse points in the "reference" flow RATA test runs. The
reference flow RATA is either the RATA that accompanied the CTM-041 determination,
or if the WAF was determined separately from a RATA, the RATA that most recently
preceded the WAF determination. Consistent with CTM-041, the number of Method 1
traverse points in the reference flow RATA must equal the number of Method 1 traverse
points reported in column 58 for the WAF test run(s).
(15) RT 535: Unit and Stack Operating Load Data
Report this record type for each unit, stack, or pipe at which load-based missing data procedures
are applied, (i.e.. for units, stacks, or pipes with installed flow monitors, and/or NOx-diluent CEMS,
and/or NOx concentration CEMS, and/or fuel flowmeters). RT 535 establishes the maximum hourly
operating load, which is used to create load ranges for missing data purposes for the load-based missing
data procedures.
For units that do not produce electrical or steam load (e.g.. cement kilns, refinery process heaters,
etc.), RT 535 is required only if the owner or operator of the unit has, according to section 6.5.2 (e) of
Appendix A, provided a technical justification in the monitoring plan for an exemption from 3-load flow
RATA testing, and the justification is found to be acceptable by the permitting authority.
Field Descriptions and Instructions
Unit/Stack/Pipe ID (4). Submit one RT 535 for each unit ID, common stack ID,
multiple stack ID, common pipe ID, and multiple pipe ID at which load-based missing
data procedures are applied (whether for stack flow rate, NOx emission rate, NOx
concentration or fuel flow rate).
Load Units (10). Identify the type of load information reported in this record using one
of the following uppercase codes:
MW Electrical Capacity (in megawatts)
ST Steam (in units of 1000 lbs/hr)
For units that do not produce electrical or steam load, leave this field blank.
Maximum Hourly Gross Load (12). Define the maximum load associated with the unit,
stack or pipe at full capacity.
For boilers (including units with multiple stack exhaust configurations), this value is based
on one of the following: (1) the nameplate capacity; (2) the nameplate capacity as
derated; or (3) a value higher than nameplate, if the unit or stack historically operates at
levels exceeding nameplate.
For common stack (or common pipe) configurations, the maximum load will be the
highest sustainable combined operating load for the units serving the common stack (or
pipe).
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For multiple stack (or pipe) configurations, report one RT 535 for each stack (or pipe),
indicating the maximum hourly gross load for the associated unit in column 12 of each
record.
For combustion turbines, determine the maximum hourly gross load according to the
guidelines in Question 18.7 in the Part 75 Policy Manual.
For units that do not produce electrical or steam load, leave this field blank.
Reserved (18). This field, which was previously used only by units in the OTC NOx
Budget Program, has been reserved.
Exemption From Three-Level Flow RATAs (19). For peaking units and bypass stacks,
which qualify for an exemption from performing 3-load flow RATAs without any special
petition or justification (only single-load flow RATAs are required), report one of the
following uppercase codes to indicate the basis on which you qualify:
B Bypass Stack
P Peaking Unit
For units that receive an exemption from 3-level flow RATA testing based on an approved
petition under § 75.66 or (for non load-based units) based on acceptance by the permitting
authority of a technical justification provided in the monitoring plan, report one of the
following codes:
S Only single-level flow RATAs are required, based on EPA or State approval of a
petition or technical justification
2 Two-level flow RATAs are required for initial certification, recertiflcation and
routine quality-assurance, based on EPA or State approval of a petition or
technical justification
If you must routinely perform multi-load RATA testing for flow or, if this field is not
applicable (because there are no flow monitoring systems at the unit or stack), leave this
field blank.
Also leave this field blank if, in a particular calendar year, you qualify for a single-load
flow RATA under Part 75 because the unit has operated at a single load level for > 85.0%
of the time since the last annual flow RATA. You must use RT 695 to claim the
exemption from multi-load flow testing for that year.
Leave this field blank for common pipe (CP) and multiple pipe (MP) configurations.
(16) RT 536: Range of Operation and Normal Operating Load or Level
Submit RT 536 in each quarterly report for each unit, multiple stack or common stack with
installed CEMS.
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Also submit RT 536 (columns 1 through 21, only) in each quarterly report for a unit, common
pipe or multiple pipe, if the optional quarterly fuel flow-to-load test in Section 2.1.7 of Appendix D to
Part 75 is used to quality assure a fuel flowmeter installed at the unit or pipe location.
RT 536 defines the upper and lower boundaries of the "range of operation" for the unit (or units,
for a common stack or pipe). For units that produce electrical or steam load, the range of operation
extends from the minimum safe, stable operating load to the maximum sustainable load, and provides the
basis for defining the low, mid, and high operating load levels. For non load-based units (e.g.. cement
kilns, refinery process heaters, etc.), the range of operation extends from the minimum potential stack gas
velocity, in ft/sec (or, alternatively, from 0.0 ft/sec) to the maximum potential velocity.
RT 536 is also used to report the results of an analysis of historical load data for the unit or stack,
as described in Part 75 (see Section 6.5.2.1(c) of Appendix A). The results of the historical load data
analysis provide the basis for: (1) defining the normal operating load level (or levels) for the unit or
stack; (2) determining the two appropriate load levels at which to conduct annual 2-load flow RAT As;
(3) determining, for multi-load flow RAT As, the two appropriate load levels at which to calculate bias
adjustment factors, when a normal load bias test is failed; and (4) determining the appropriate load level
at which to conduct the quarterly flow-to-load ratio test. Note that for peaking units, the historical load
data analysis is not required.
Non load-based units are exempted from the historical load data analysis in section 6.5.2.1 (c) of
Appendix A. For these units, the most frequently-used operating levels and the normal operating level(s)
are determined by the owner or operator, using sound engineering judgment, based on operating
experience with the unit and knowledge of the industrial process.
For new or newly-affected units, in the initial monitoring plan submittal, use the best available
estimates of the upper and lower boundaries of the range of operation and determine the normal load (or
operating level) and the two most frequently-used load (or operating) levels based on the anticipated
manner of operating the unit. Report the date of submittal of the initial monitoring plan or the date on
which commercial operation of the unit begins (whichever is earlier) as the activation date in column 27.
Update the information in RT 536 when the manner of operating the unit(s) changes significantly
and a new historical load data analysis is performed (or, for non load-based units, a new engineering
assessment is made) which shows that the normal load(s) (or operating levels) and/or the two most
frequently-used load (or operating) levels have also changed. In that case, submit two RTs 536 for the
quarter in which the new data analysis (or, for non load-based units, the new engineering assessment) was
performed, (i.e.. one RT 536 to inactivate the results of the previous load data analysis or engineering
assessment and one RT 536 to activate the results of the new load data analysis or engineering
assessment).
Field Descriptions and Instructions
Upper Boundary of Range of Operation (10). For units that produce electrical or
steam load, report the upper boundary of the range of operation, either in units of
megawatts or 1000 lb/hr of steam, as appropriate. The upper boundary of the range of
operation must be equal to or less than the maximum hourly gross load reported in column
12 of RT 535.
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For single units (including units that have a multiple stack exhaust configuration), report
the maximum sustainable load, which is the higher of: (1) the nameplate capacity of the
unit (less any physical or regulatory deratings); or (2) the highest sustainable load, based
on a minimum of four representative quarters of historical operating data.
For a common stack (or pipe), report the sum of the maximum sustainable loads of all
units using the stack (or pipe) as the upper boundary of the range of operation. If that
combined load is unattainable in practice, report the highest sustainable combined load,
based on a minimum of four representative quarters of historical operating data.
For a multiple stack (or pipe) configuration, report one RT 536 for each stack (or pipe),
indicating the maximum sustainable load for the associated unit in column 10 of each
record.
For non load-based units, report the upper boundary of the range of operation in terms of
stack gas velocity (ft/sec), as described in section 6.5.2.1(a) of Appendix A.
Lower Boundary of Range of Operation (16). For units that produce electrical or
steam load, report the lower boundary of the range of operation, either in units of
megawatts or 1000 lb/hr of steam, as appropriate.
For single units (including units that have a multiple stack exhaust configuration), report
the minimum safe, sustainable load for the unit.
For a common stack (or pipe), report the lowest safe, sustainable load for any of the units
using the stack (or pipe) as the lower boundary of the range of operation. Alternatively,
for frequently operated units discharging to a common stack (or using a common pipe),
you may report the sum of the minimum safe, stable loads of the units serving the common
stack (or pipe) as the lower boundary of the operating range.
For a multiple stack (or pipe) configuration, report one RT 536 for each stack (or pipe),
indicating the minimum safe, stable load for the associated unit in column 16 of each
record.
For non load-based units, report the lower boundary of the range of operation in terms of
stack gas velocity (ft/sec), as described in section 6.5.2.1(a) of Appendix A.
Two Most Frequently-used Load or Operating Levels (22). Based on the results of
the historical load data analysis described in section 6.5.2.1(c) of Appendix A (for units
that produce electrical or steam load), or, based on knowledge of the unit and operating
experience with the industrial process (for non load-based units), report the two load (or
operating) levels ("L", "M", or "H") that are used the most frequently. Separate the
reported load (or operating) levels with a comma (i.e.. "L,M"). For non load-based units
that operate only at one level, report this operating level in column 22, and leave columns
23 and 24 blank.
For peaking units, leave this field blank.
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Designated Normal Load or Operating Level (25). For units that produce electrical or
steam load, based upon the results of the historical load data analysis described in section
6.5.2.1(c) of Appendix A, designate and report the most frequently-used load level ("L",
"M", or "H") as the "normal" load level. For all S02, NOx, and flow RATAs conducted at
the designated normal load, a bias test is required.
For non load-based units, designate the normal operating level based on knowledge of the
unit and operating experience with the industrial process.
For peaking units, leave this field blank.
Second Designated Normal Load or Operating Level (Optional) (26). For units that
produce electrical or steam load, based upon the results of the historical load data analysis,
you may elect to designate and report the second most frequently-used load level as an
additional normal load level. If you select this option, perform a bias test for all S02, NOx,
and flow RATAs conducted at this load level.
For non load-based units, you may designate a second normal operating level, based on
knowledge of the unit and operating experience with the industrial process.
For peaking units, leave this field blank.
Date of Historical Load Data Analysis or Operating Level Determination
(Activation Date) (27). For units that produce electrical or steam load, report the year,
month and day of the historical load data analysis (see sections 6.5.2.1 (c) and (d) of
Appendix A) that defines the range of operation, the two most frequently-used load levels,
and the normal load level(s). There is one exception to this: for the initial load analysis at
a particular unit or stack, report the activation date as the first day of the quarter in which
the data analysis is performed (i.e.. Jan 1, Apr 1, July 1 or Oct 1, as applicable), rather
than the actual date of the analysis, unless the two dates are the same.
Once the operating range and normal load level(s) have been established, Part 75 does not
require you to repeat the historical load analysis unless a significant change in the manner
of unit operation occurs, which may result in a re-designation of the operating range
and/or the normal load level(s) and/or the two most frequently-used load levels. At least
two quarters of representative data are required to document that such a change in unit
operation has occurred.
If, however, you elect to repeat the load analysis periodically, e.g.. prior to each annual
RATA, in order to confirm that nothing has changed (even though this is not required by
the regulation), do not change the activation date unless the new data analysis shows that
a re-designation of the operating range and/or the normal load and/or the two most
frequently-used load levels is necessary.
For non load-based units, report the date on which the determination of the operating
range, the most frequent operating level(s), and the normal operating level(s) is made.
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For peaking units, report the later of: (a) the date of program participation; or (b) the date
on which peaking status was first claimed for the unit.
When transitioning from non-peaking status to peaking unit status at the beginning of a
new calendar year or ozone season, make the transition in the 1st quarter EDR (for year-
round reporters) and in the 2nd quarter EDR (for ozone season-only reporters). Deactivate
the existing RT 536, as of December 31 of the previous year (for a year-round reporter) or
September 30 of the previous year (for an ozone season-only reporter). Then, activate a
new RT 536, as of January 1 of the current year (for a year-round reporter) or October 1
of the previous year (for an ozone season-only reporter). A new load analysis is not
required, because the whole operating range is considered normal for a peaking unit.
Therefore, in the new RT 536, leave columns 22 through 26 blank. RT 507 must also be
submitted, to claim peaking unit status.
Inactivation Date (35). Except as noted below, for units that produce electrical or
steam load, report an inactivation date only when a new historical load data analysis is
performed which indicates that either the range of operation and/or the two most
frequently-used load levels and/or the normal load level has changed. When this occurs,
submit one RT 536 with the results of the previous load data analysis and report the
inactivation date in this field. Submit a second RT 536 with the results of the new load
data analysis, leaving this field blank. The activation date in column 27 of the new RT
536 is the day after the inactivation date in column 35 the old RT 536.
For non load-based units, report an inactivation date only when a change in the manner of
unit or process operation results in a change in the operating range and/or the most
frequently-used operating levels, and/or the designated normal operating level(s). Should
this occur, submit two RT 536, one to inactivate the old information, and one to activate
the new information, as described immediately above for load-based units.
If the operating range, the two most frequently-used load levels and the normal load level
have not changed, leave this field blank.
For peaking units, leave this field blank, unless peaking status is lost at the end of a year or
ozone season, in which case you must deactivate the existing RT 536 information as of
December 31 (for a year-round reporter) or September 30 (for an ozone season-only
reporter) of that year. Then, you must perform a historical load analysis and activate a
new RT 536, as described in the column 27 instructions above, and indicate in RT 507
that peaking unit status has been lost. Make all of these transactions in the quarter in
which the RT 507 is updated, Le^, in the 1st quarter EDR submittal (for year round
reporters), or in the 2nd quarter EDR (for ozone season-only reporters).
(17) RT 540: Fuel Flowmeter Data
Report information on all fuel flowmeter systems in RT 540. Do not use this record to report
data on individual components. Report one RT 540 for each GAS, OILV, OILM, LTOL, or LTGS
system in RT 510, except as noted below.
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For systems comprised of multiple fuel flowmeters using different methods of calibration, report
multiple RTs 540 for the system, indicating the calibration method for each flowmeter in column 38 in the
subsequent records. All information in the other fields of the multiple RTs 540 will be the same.
Field Descriptions and Instructions
Parameter Monitored (13). Report the parameter measured by the system using one of
the following uppercase codes:
GAS Gas System
LTGS Long Term Gas Fuel Flow (LME)
LTOL Long Term Oil Fuel Flow (LME)
OILV Volumetric Oil Fuel Flow
OILM Mass of Oil Fuel Flow
Type of Fuel (17). Report the type of fuel measured by the system using one of the
following uppercase codes:
DSL
Diesel Oil
LPG
Liquefied Petroleum Gas (if measured as a gas)
NNG
Natural Gas
OGS
Other Gas
OIL
Residual Oil
OOL
Other Oil
PNG
Pipeline Natural Gas (as defined in § 72.2)
PRG
Process Gas
Maximum System Fuel Flow Rate (20). Report the maximum fuel flow rate for the
system. This maximum fuel flow rate is needed for missing data purposes. If the system is
comprised of main supply and return components, calculate the net system maximum fuel
flow rate assuming that the main supply is operating at the maximum potential fuel flow
rate, as defined in section 2.4.2.1 of Appendix D, and that the return flow rate is zero. For
a combined cycle turbine with a duct burner, if the fuel flowmeter system includes both the
turbine and duct burner flowmeter components, report the sum of the maximum potential
fuel flow rates of the component flowmeters.
Units of Measure for Maximum Fuel Flow Rate (30). Report the units of measure for
fuel flow rate provided by the system using one of the following uppercase codes:
Volumetric Flow of Oil
SCFH Standard cubic feet per hour
GALHR Gallons per hour
BBLHR Barrels per hour
M3HR Cubic meters per hour
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Mass of Oil
LBHR Pounds per hour
Gas flow
HSCF 100 standard cubic feet per hour
Source of Maximum Rate (35). Report either "URV" to indicate that the maximum rate
is based on the upper range value, or "UMX" to indicate that the maximum rate is
determined by the rate at which the unit can combust fuel.
Initial Accuracy Test Method (38). Identify the initial accuracy test methods for the fuel
flow meters. If you use an accuracy test method other than those identified in Part 75,
submit this information with your monitoring plan.
AG A3 Certification by Design, in Accordance with AGA Report No. 3
AGA7 AGA Report No. 7
API American Petroleum Institute Method Listed in Appendix D,
Section 2.1.5.1
ASME For any ASME Method Listed in Appendix D, Section 2.1.5.1
ILMM In-line (on-site) Comparison Against a Master Meter
LCRM Laboratory Comparison Against a Reference Meter
NIST NIST-traceable Method, Approved by Petition Under § 75.66
ISO International Organization for Standardization Method Listed in Appendix
D, Section 2.1.5.1
For uncertified billing meters, you may leave this field blank.
Ongoing Calibration Method [Reserved] (49). This field has been reserved. Leave this
field blank.
Submission Status (60). Report "A" when adding a new entry, "C" when correcting a
previous entry, "D" when deleting a previous entry, or "U" when resubmitting an
unchanged entry.
(18) RT 550: Reasons for Monitoring System Downtime or Missing Parameter
(Optional)
Report this record type to identify the reasons for any periods in which data are missing or
unavailable during the reporting period. If more than one reason is relevant because there are primary
and backup monitoring systems installed and certified, report multiple RTs 550, one for each system.
This record is optional beginning in the first quarter following the effective date of the 1999 Part 75 rule
revisions.
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Field Descriptions and Instructions
Parameter (10). For each record identify the parameter for which data are missing using
the following codes:
C02 C02 Concentration
FLOW Stack Flow
GAS Gas
H20 Moisture
NOX NOx Emission Rate
NOXC NOx Concentration
02 02 Concentration
OILM Mass of Oil
OILV Volumetric Flow of Oil
S02 S02 Concentration
Do not leave this field blank.
Monitoring System ID (14). Report the monitoring system ID for the system that was
not able to provide data. Do not report the component ID in this field, even if the problem
is caused by a specific component in the system. If a problem such as DAHS failure
causes data from all primary and backup systems for a pollutant to be unavailable and you
report the cause using Reason Code 1, 2, 3, 4, 5, or 6 in column 33, you may leave the
monitoring system ID blank.
Begin Date and Hour of Missing Data Period (17, 23). Report the beginning date and
hour of the missing data period.
End Date and Hour of Missing Data Period (25, 31). Report the end date and hour of
the missing data period. Leave this field blank if the missing data period continued beyond
the reporting date for this reporting period. Report the same RT 550 again with the actual
end date and hour in the report for the reporting period in which this occurs.
Missing Data Reason Code (33). Use the following codes to categorize reasons for
missing data.
1 DAHS Hardware Failure
2 DAHS Software Failure
3 DAHS Maintenance/Upgrade
4 PLC Hardware Failure
5 PLC Software Failure
6 PLC Maintenance/Upgrade
7 Out-of-Control: Calibration Test
8 Out-of-Control: Linearity Check
9 Out-of-Control: RATA
10 Monitor Off Line for Calibration
11 Monitor Off Line for Linearity Check
12 Routine Maintenance
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13
Analyzer Failure
14
Probe Failure
15
Sample Transport System Failure
16
Erratic Analyzer Response
17
Electrical Failure
18
Lightning
19
Range Exceeded
20
QA/QC Activities
21
Fuel Flowmeter Failure
22
Out-of-control: Fuel Flowmeter Calibration
23
Sampling Failure
24
Sample Loss or Contamination
25
Interference Check Failure
26
Leak Check Failure
99
Other (Describe)
Do not
leave this field blank.
Missing Data Description (35). If the reason code adequately characterizes the event,
leave the reason description field blank. If you reported the missing data code as "99",
you must describe the reason in this field.
Corrective Action Description (110). Provide a brief description of the actions taken to
address the reason for the missing data.
Similarly, if the corrective action is self-evident (such as conducting a successful daily
calibration), leave this field blank.
(19) RT 555: Monitoring System Recertification Events (OTC NBP)
RT 555 has been replaced by RT 556 for ARP or Subpart H units.
(20) RT 556: Monitoring System Recertification, Maintenance, or Other Events
In the normal course of maintaining and operating monitoring systems you may need to replace or
repair various components or change the type of equipment or software installed to measure and report
emissions. This may occur unexpectedly during normal operation or may be done according to a
maintenance schedule or prior to scheduled quality assurance tests (e.g.. linearity checks and RAT As).
Diagnostic testing and in some instances certification or recertification testing is required when such
repairs, component replacements, or equipment changes are made.
Use RT 556 to report certification, recertification and maintenance events and the status of any
required certification, recertification, or diagnostic testing. Typical certification, recertification and
maintenance events include:
• Replacement of an entire continuous emission monitoring system;
• Change-outs of analytical or other monitoring system components;
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• DAHS vendor changes or software version upgrades;
• Changing of the polynomial coefficient(s) or K factor(s) of a flow monitor or moisture
monitoring system;
• Modification to the flue gas handling system or unit operation that significantly changes the
flow or concentration profile;
• Probe location change, for gas monitoring systems;
• Flow monitor location change; and
• Other system modifications that require one or more tests, as determined in accordance with
the EPA policy (see "Part 75 Emissions Monitoring Policy Manual," Question 13.21 and
Questions 16.14 through 16.16) or through consultation with EPA Regional Office and
Headquarters staff.
RT 556 describes the particular certification, recertification or maintenance event, indicates which
quality assurance tests are required, and (if applicable) defines any time period(s) during which the
monitoring system was unable to provide quality-assured data, pending the outcome of the required
quality assurance tests. Data are considered quality-assured when all of the required QA tests have been
successfully completed. When "conditional" data validation is used, it must be done in accordance with
procedures in § 75.20(b)(3), prior to completing all of the required certification, recertification or
diagnostic testing. Under § 75.20(b)(3), the conditionally valid data status begins when a probationary
calibration error test is passed. If the required QA tests are then completed in a timely manner, with no
failures, the conditionally valid data are considered to be quality-assured, back to the hour of completion
of the probationary calibration error test.
Regarding recertifications, note that, with one exception (i.e.. changing of the polynomial
coefficient(s) or K factor(s) of a flow monitor or moisture monitoring system) the definition of a
"recertification event" is limited to those non-routine changes to a monitoring system or process which
require either: (1) RATA(s); (2) fuel flowmeter accuracy testing; (3) a full QA sequence of transmitter
tests and primary element inspections (for orifice, nozzle and venturi-type fuel flowmeters); or
(4) regeneration of an Appendix E NOx correlation curve. Submittal of a formal recertification
application is required only for recertification events.
Note that when a monitoring system is replaced, a new, unique system ID is assigned and the new
system must be tested for certification. When an analyzer is replaced in a previously certified system, if a
new system ID is assigned, this is also considered to be a certification event. If the old system ID is
retained, it is considered to be a recertification event (see Part 75 Policy Manual Question 13.4 for further
guidance).
Report RT 556 as follows:
• Whenever recertification testing or diagnostic testing is required as a result of changes made
to a previously-certified monitoring system (or as the result of changes in the manner of
operating the process). Follow the guidelines in Policy Manual Questions 13.21 and 16.14
through 16.16.
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• When a monitoring system is replaced with a new system (having a new system ID) and is
tested for certification.
• When the conditional data validation procedures described in § 75.20(b)(3) are applied to the
initial certification testing of the CEM systems on a new (or newly-affected) unit.
• When the conditional data validation procedures of § 75.20(b)(3) are used for a routine
quality assurance RATA or linearity check (see Sections 2.2.3(b)(3) and 2.3.2(b)(3) of
Appendix B).
• If a routine quality assurance test is done for the dual purposes of routine QA and
recertification (see Part 75, Appendix B, Section 2.4).
• For the required linearity checks of non-redundant backup monitors and temporary "like-kind
replacement" analyzers, when these monitors are brought into service (see § 75.20(d)(2)(iii)).
• When the polynomial coefficients or K-factor(s) of a flow monitor or moisture monitoring
system are changed, triggering an unscheduled RATA requirement.
• When a change from a non-CEMS-based monitoring methodology to a CEMS methodology
occurs (e.g.. changing from Appendix E to a CEMS for NOx), and the conditional data
validation procedures of § 75.20(b)(3) are applied during the CEMS certification process.
Do not report RT 556
• For the initial certification of the monitoring systems for a new unit or for a newly-affected
unit, if the conditional data validation procedures described in § 75.20(b)(3) are not applied
during the CEMS certification process.
• For the routine periodic quality assurance tests required under Appendices B, D, and E of Part
75, except when conditional data validation is used.
• If the only diagnostic test required for a particular event is a calibration error test.
• For any event listed in the Tables in Policy Manual Question 13.21 that does not require RT
556 to be submitted
• When a change from a CEMS-based monitoring methodology to a non-CEMS methodology
occurs (e.g.. switching from an S02 CEMS to Appendix D, or changing from a NOx CEMS to
Appendix E ). In such cases, simply use RT 585 to indicate changes in monitoring
methodology. However, if the opposite occurs, (i.e.. changing from a non-CEMS-based
methodology to CEMS), report RT 556 if the conditional data validation procedures of §
75.20(b)(3) are applied during the CEMS certification process.
RT 556 must provide a complete record of each certification, recertification or maintenance
event, the tests required, the date(s) and time(s) of any out-of-control periods, and the date and time of
successful completion of the required tests. If the time period extending from the hour of the change to
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the monitoring system to the hour of completion of the required tests spans two or more quarters, a RT
556 must be submitted in each successive quarterly report until closure is obtained. For instance, if a
change made to a CEMS requires a RATA and the RATA is not completed by the end of the quarter in
which the change to the system occurs, then, for that quarter, complete columns 1 through 30 of RT 556.
If conditional data validation is used complete also columns 31 through 40 and 51. Leave columns 41
and 49 (date and hour of completion of required tests) blank. If the RATA is passed in the next quarter,
submit RT 556 with the report for that quarter, containing the same information in columns 1 through 30
that was reported in the previous quarterly report. Then, to provide closure for this event, complete
columns 41 and 49 of RT 556 and leave column 51 blank.
If, for a Subpart H unit, you submit electronic quarterly reports only for the ozone season (for the
second and third calendar quarters (see § 75.74(c))), final resolution of all conditionally valid data
recorded during the ozone season is required no later than the deadline for submitting the third quarter
emissions report, either by using missing data substitution or by completing the required QA test(s). In
some cases, resubmittal of the emissions report for the second quarter may be required to fully resolve
conditionally valid data for the ozone season (see §§ 75.74(c)(3)(xi) and (xii)).
Field Descriptions and Instructions
Component ID (10). Report the component ID subject to recertification/diagnostic
testing, if a specific component is involved. If the event is system, not component specific,
leave this field blank. Event Codes that are generally system specific include: 5, 10, 120,
125, 130, 150, 185, 195, and 200.
Monitoring System ID (13). Report the monitoring system ID for the system affected by
the event. Do not leave this field blank for any event codes except for 1, 2, 3, 15 (DAHS
recertification events), or 700 (LME changes). If a new monitoring system ID is assigned
(e.g.. when an entire monitoring system is replaced or when an analyzer in a previously
certified monitoring system is replaced) report the new system ID number in this field.
Event Code (16). Report one of the following codes. If there is no applicable event
code, use the code "99" for "Other" and provide a brief description of the event in RT
910.
1
2
3
5
10
15
20
25
26
DAHS Vendor Change
DAHS Software Version Upgrade
DAHS Failure
Change or Insert New Temperature, Pressure, or Molecular Weight Correction
Algorithms in the DAHS, for a Dilution-type Monitoring System
Change or Insert New Mathematical Algorithms in the DAHS to Convert NO
Concentration to Total NOx
Change Missing Data Algorithms
Installation of Add-on S02 Emission Controls
Installation of Add-on NOx Emission Controls-Low Range Added
Installation of Add-on NOx Emission Controls-Low Range Not Added, but RATA
is Required (Stratification Detected)
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30 Addition of a Low-scale Measurement Range (Not associated with add-on control
installation)
35 Addition of a High-scale measurement range (Not associated with add-on control
installation)
99 Other
100 Permanent Gas Analyzer Replacement (Like-kind Analyzer, per Policy Question
7.22)
101 Permanent Gas Analyzer Replacement (Not Like-kind)
102 Replace or Repair any of These Components of an Extractive or Dilution-type
System—Photomultiplier, Lamp, Internal Analyzer Filter or Vacuum Pump,
Capillary Tube, 03 Generator, Reaction Chamber, N02 Converter, Ozonator
Dryer, Sample Cell, Optical Filters
105 Permanent Replacement of Umbilical Line
106 Replace or Repair any of These Components of an In-Situ Monitoring System —
Light Source, Projection Mirrors, UV Filter, Fiberoptic Cable, Spectrometer
Grating, Mirrors or Mirror Motor
107 Repair or Replace Circuit Board in an In-Situ System
108 Change the Location or Measurement Path of an In-Situ Monitor
109 Replacement of a Continuous Moisture Sensor
110 Gas Analyzer Probe Replacement (Same Location, Different Length)
120 Gas Monitoring System Complete Replacement
125 Initial Certification (Gas Monitoring System). Use this code only: (a) for CEM
certification at new and newly-affected units; or (b) when reconfiguration occurs
(e.g.. switching from common stack to unit-level monitoring)
130 Gas Monitoring System Probe Relocation
140 Temporary Use of a Like-kind Replacement Non-redundant Backup Analyzer
150 Temporary Use of a Regular Non-redundant Backup Monitoring System
160 Changes to the Mathematical Algorithm or K-factor(s) of a Moisture Monitoring
System
170 Change to the Span Value of a Gas Monitor
180 Critical Orifice Replacement (Same Size)
185 Critical Orifice Replacement (Different Size)
190 Probe Replacement — Dilution-extractive Monitoring System (Same Length,
Location, and Dilution Ratio)
191 Major Modification to Dilution Air Supply
192 Disassemble and Reassemble Dilution Probe for Service
195 Change from In-Stack to Out-of-Stack Dilution (or Vice-versa)
200 For Gas and/or Flow CEMS, Modification to the Flue Gas Handling System or
Unit Operation that Significantly Changes the Flow or Concentration Profile
300 Flow Monitor Complete Replacement
301 Changes to the Polynomial Coefficients or K-factor(s) of a Flow Monitor
302 Flow Monitor Transducer Replacement
305 Initial Certification (Flow Monitor) Use this code only: (a) for flow monitor
certification at new and newly-affected units, or (b) when reconfiguration occurs
(e.g.. switching from common stack to unit-level monitoring)
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310 Other Major Flow Monitor Component Replacement or Repair (e.g.. DP Probe,
Thermal Sensor, Transducer Electronics)
311 Flow Monitor Relocation
312 Stack Flow-to-load Ratio or GHR Test Failure
400 Fuel Flowmeter Replacement
401 Fuel Flowmeter Transmitter/Transducer Replacement
402 Fuel Flowmeter Primary Element Replacement (Orifice, Nozzle or Venturi-type,
Same Dimensions)
403 Fuel Flowmeter Primary Element Replacement (Orifice, Nozzle or Venturi-type,
Different Dimensions)
405 Fuel Flowmeter Primary Element Replacement (Other Types of Flowmeters)
410 Fuel Flow-to-load or GHR Test Failure
501 For Appendix E Systems, Modifications to the Flue Gas Handling System or Unit
Operation that Significantly Changes the Flow or Concentration Profile Requiring
a Retest Under Appendix E to Part 75 to Re-establish the NOx Correlation Curve
502 For Appendix E Units, Exceeding the Excess 02 Level for > 16 Consecutive
Operating Hours
503 For Appendix E Units, Exceeding the Water to Fuel or Steam to Fuel Rates for >
16 Consecutive Operating Hours
504 For Appendix E Units, Exceeding Other QA/QC Parameters for > 16 Consecutive
Operating Hours
600 Opacity Monitor Complete Replacement
610 Opacity Monitor Transceiver Replacement
620 Opacity Monitor Transceiver Factory Rebuild
630 Opacity Monitor Relocation
700 For a Low Mass Emissions (LME) Unit, a Change to the Unit or to the Fuel
Supply or Manner of Unit Operation, Requiring Redetermination of the Unit-
specific, Fuel-specific NOx Emission Rate
Code for Required Test (19). Report one of the following codes to designate which
specific tests are required for the specific event which occurred. Note that for CEMS,
these codes describe only the full QA tests that are required, not the abbreviated
diagnostic tests described in Question 13.21 of the Part 75 Policy Manual. You are not
required to report the results of the abbreviated diagnostic tests to EPA.
1 3-load RATA, 7-day Calibration Error Test
2 Normal Load RATA, 7-day Calibration Error Test, Linearity Check, Cycle Time
Test
3 3-load RATA, 7-day Calibration Error Test, DAHS Verification
4 Normal Load RATA, 7-day Calibration Error Test, Linearity Check, Cycle Time
Test, DAHS Verification
5 Normal Load RATA
6 3-load Flow RATA
7 2-load Flow RATA
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8
Normal Load RATA, Linearity Check
9
Linearity Check
10
Linearity Check, 7-day Calibration Error Test
11
Normal Load RATA, 7-day Calibration Error Test, Linearity Check
12
Normal Load RATA, Linearity Check, Cycle Time Test
13
Normal Load RATA, 7-day Calibration Error Test, Cycle Time Test
14
7-day Calibration Error Test, Cycle Time Test
15
Normal Load RATA, 7-day Calibration Error Test
16
Normal Load RATA, Cycle Time Test
17
Linearity Check, Cycle Time Test
18
7-day Calibration Error Test
19
Cycle Time Test
20
DAHS Verification (Formulas)
21
DAHS Verification (Missing Data Routines)
22
DAHS Verification (Formulas and Missing Data)
23
DAHS Verification (Formulas and Missing Data), Daily Calibration Error Test
24
Off-line Calibration Demonstration
25
Off-line Calibration Demonstration, 7-day Calibration Error Test
26
Abbreviated Stack Flow-to-load Ratio Test
27
3-load RATA, 7-day Calibration Error Test, Leak Check
28
Abbreviated Stack Flow-to-load Ratio Test, Leak Check
40
Angle of View, Angle of Projection, Mean Spectral Response, Response Time,
Calibration Drift Test, Stack Exit Correction Factor
42
Stack Exit Correction Factor
51
Fuel Flowmeter Accuracy Test
52
Fuel Flowmeter Transmitter Test, Primary Element Inspection
53
Fuel Flowmeter Transmitter Test
54
Primary Fuel Flowmeter Element Inspection
55
Abbreviated Fuel Flow-to-load Test
56
Fuel Flowmeter Transmitter Test, Primary Element Inspection, Re-determine Flow
Coefficients
57
Primary Element Inspection, Re-determine Flow Coefficients
75
Retest of the Appendix E NOx Correlation Curve
76
Re-determination of the Unit-specific, Fuel-specific NOx Emission Rate for a Low
Mass Emissions (LME) Unit
99
Other (Note that Recertification Application May Be Required)
Date and Hour of Event (21, 29). Report (if applicable) the date and hour at which the
monitoring system is deemed to be out-of-control (unable to provide quality-assured data)
as a result of changes made to the system.
For DAHS upgrades and failures, report (if applicable) the date and hour when the
monitoring system(s) associated with the DAHS are deemed out-of-control (unable to
provide quality-assured data).
If there is no out-of-control period associated with a particular event, report in columns 21
and 29 the date and hour of the beginning of the event. This date and hour must precede
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the date and hour of commencement of the required diagnostic or recertification tests.
Consider the following examples:
(1) For certifications and recertifications triggered by the replacement of a monitoring
system or an analyzer, report in columns 21 and 29 the date and hour on which the
replacement monitoring system or analyzer is first installed.
(2) For the initial certification of monitoring systems on new (or newly-affected) units,
use the following guideline. Report a date and hour that predates, but is close in time
to, the commencement date and hour of the certification testing. If you use the
conditional data validation procedures of § 75.20(b)(3), the beginning date and hour
of the certification event must precede the date and hour of the probationary
calibration error test.
(3) For Installation of Add-on controls (Event Codes 20 and 25), report the date on
which emissions first exited to the atmosphere through the new operating controls.
(See Policy Manual Question 16.14.)
(4) When a DAHS is replaced or the DAHS software version is upgraded, and the old
and new platforms or software versions are run in parallel (so that there may be a
smooth transition from the old to the new, with no monitoring system out-of-control
periods associated with the DAHS replacement or upgrade), report in columns 21
and 29 the date and hour at which the new DAHS platform or software version first
begins to be run in parallel with the old platform or version. Submit the RT 556 with
the electronic report for the calendar quarter in which data reporting with the new
DAHS or upgraded software version begins.
Beginning of Conditionally Valid Period (Probationary Calibration Error Test)
Date/Hour (31, 39). For gas CEMs or flow monitoring systems only, whenever you use
the conditional data validation procedures of § 75.20(b)(3), report the date and hour that a
probationary calibration error test was successfully completed according to the provisions
of § 75.20(b)(3). Data are conditionally valid from that date and hour until all required
tests are passed, provided that all tests are passed in succession, within the allotted
window of time, with no failures.
Note that in most instances, the allotted time for completing the required tests will be as
specified in § 75.20(b)(3)(iv). However, for the initial certification of the CEMS installed
on a new (or a newly affected) unit, the timelines in § 75.20(b)(3)(iv) are superseded by
the certification window provided in the applicable regulation (e.g.. the timeline specified
in § 75.4(b) — see also sections 6.2(a), 6.4(a), and 6.5(f)(1) in Part 75, Appendix A).
Also, when a new stack is constructed or when add-on S02 or NOx emission controls are
installed, a longer window of time is allotted in § 75.4(e) for the required certification,
recertification and/or diagnostic testing (see Part 75 Policy Manual, Questions 16.14
through 16.16).
Also, if the Event Code indicates initial certification, analyzer replacement, or complete
replacement of a monitoring system (Event Codes 100, 101, 120, 125, 300 or 305) and
conditional data validation is used, a BAF of 1.000 should be applied to the hourly data
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December 2005
(where applicable) from the beginning of the conditional data validation period to the
completion hour of the certification or recertification RATA.
If the conditional data validation procedures in § 75.20(b)(3) are not used, leave these
fields blank. Also, for excepted monitoring systems under Appendices D or E to Part 75,
leave these columns blank.
Date and Hour That Last Test Is Successfully Completed (41, 49). Report the date
and hour in which the last required certification, recertification or diagnostic test was
successfully completed.
Leave these fields blank if the required tests have not been successfully completed by the
end of the quarter.
Except for Subpart H units for which you report data on an ozone season-only basis, when
the conditional data validation procedures of § 75.20(b)(3) are used and the required QA
tests have not been completed successfully by the end of the quarter, leave the date and
hour in columns 41 and 49 blank and report the emissions data from the monitoring
system as conditionally valid, using the flag in column 51. For ozone season-only
reporters, you may only use the conditional data flag in the second quarter emissions
report.
Note that for year-round reporters, the final status of all conditionally valid data for each
calendar year must be resolved in the annual compliance certification report required
under § 72.90 (see § 75.20(b)(3)(ix)). For ozone season-only reporters, as previously
noted above, resolution of all conditionally valid data is required by the deadline for
submitting the third quarter emissions report.
If the required certification, recertification or diagnostic tests are successfully completed
after the end of a particular quarter but before the quarterly report deadline, you may
submit the results with the current quarterly report so that the use of a conditional data
flag is unnecessary. In such cases, report in columns 41 and 49 the date and hour in which
the last test is successfully completed, even though this date is after the end of the current
reporting quarter.
If you complete the required tests in a subsequent quarter, submit a RT 556 in the
electronic report for that quarter, to provide closure of the event. In columns 1 through
30 of this RT 556, report information identical to that reported in columns 1 through 30 of
the original RT 556 for the event. In columns 41 and 49, indicate the date and hour of
completion of the required tests, and leave column 51 blank.
For more information on reporting conditionally valid data, see Section III.D.
Indicator That Conditionally Valid Data Were Reported at End of Quarter (51).
For gas or flow monitoring systems only, report a "C" if data from the monitoring systems
are conditionally valid at the end of the quarter. This would occur if an event occurs and
you performed a successful probationary calibration error test in the current quarter, but
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did not complete all of the required tests by either the end of the quarter or before the
quarterly report deadline. Do not report a "C" if data that were conditionally valid during
the quarter were then subsequently validated by the successful completion of all required
tests. Ozone season-only reporters may not use this flag in the third quarter emissions
report. Full resolution of all conditionally valid data recorded during the ozone season is
required prior to submitting the third quarter report.
For excepted monitoring systems under Appendices D or E to Part 75, leave this column
blank.
(21) RT 560: Appendix E NOx Correlation Curve Segments
If you use Appendix E methodology to determine hourly NOx emission rate for a unit, submit one
set of RTs 560 for each fuel-specific correlation curve derived from the four-load emission testing
described in section 2.1 of Appendix E. (See also the instructions for RTs 650 through 653.) Include the
RTs 560 in each quarterly report.
For a typical Appendix E test, the following four RTs 560 must be submitted, each one
representing a segment of the correlation curve:
• One record (load level zero) representing the segment of the correlation curve below the
minimum heat input level represented by the lowest operating level; and
• Three records representing segments joining the test results from the adjacent operating levels
that were tested. If you performed more than four levels of testing there should be one
segment record for each additional operating level.
Order these records within the record type by operating level in ascending order (0 - 4+). The
graph below (Illustration 4) represents the relationship of operating level test data in RT 651 and
segments defined in RT 560. The reporting of segments in this record type replaces the requirement to
report formulas representing these segments in RT 520. Appendix E formulas are not required in RT
520.
Field Descriptions and Instructions
Operating Level (20). For the lowest segment, report an operating level of "0" (zero).
For all other segments, report the operating level associated with the lower bound of the
curve segment (e.g.. in Illustration 4, operating level "1" is associated with segment 2).
Segment ID (22). For each segment of the curve, assign and report a unique segment ID
consisting of three alphanumeric characters.
NOx Monitoring System ID (25). Report the monitoring system ID for the Appendix E
NOx emission rate system that was certified and that you use to report NOx emission rate
data.
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Illustration 4
EXAMPLE NOx CORRELATION CURVE SEGMENTS
0.280
Segment 2 • Oper Level 2
0.140
0
200 400 600 800 1000 1200
Heat Input (mmBtu/hr)
Heat Input #1 (Low) (28). For operating level 0 (zero), the low heat input rate value
should be zero. For all other segments, the low heat input rate value is the heat input rate
associated with the operating level for the record, as reported in RT 651. (For example, in
segment 2 above, the low heat input rate is 330 mmBtu/hr.)
Heat Input #2 (High) (35). For the highest operating level the high heat input rate value
is the highest heat input rate tested. For all other records, the high heat input rate is the
heat input rate value reported in RT 651 for the next operating level. (For example, in
segment 2 above, the high heat input rate value is 530 mmBtu/hr.)
NOx Rate #1 (42) For operating level zero, both NOx Rate #1 and NOx Rate #2 are the
NOx emission rate reported in column 23 for operating level 1 in RT 651. For all other
operating levels, NOx Rate #1 should be the NOx emission rate reported in RT 651
associated with the operating level for the record. (For example, in segment 2 above, NOx
Rate #1 is 0.180 lb/mmBtu.)
NOx Rate #2 (48) For operating level zero, NOx Rate #2 is the NOx emission rate
reported in column 23 for operating level 1 in RT 651. For all other operating levels, NOx
Rate #2 should be the NOx emission rate reported in RT 651 associated with the next
operating level for the record. (For example, in segment 2 above, NOx Rate #2 is 0.160
lb/mmBtu.)
Type of Fuel (54). Report in this field the type of fuel used during Appendix E testing
using the following codes:
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DSL
LPG
MIX
NNG
OGS
OIL
OOL
PDG
PNG
PRG
Diesel Oil
Liquefied Petroleum Gas
Mixture
Natural Gas
Other Gas
Residual Oil
Other Oil
Producer Gas
Pipeline Natural Gas (as defined in § 72.2)
Process Gas
Reserved (57). This field was used only by units in the OTC NOx Budget Program, and
therefore has been reserved.
(22) RT 585: Monitoring Methodology Information
Submit one or more RTs 585 for each unit to define the monitoring approaches used to measure
or estimate emissions. This record type is unit-specific; therefore, do not report RTs 585 for any
common or multiple stack IDs or pipe IDs. Submit a RT 585 for each pollutant or parameter measured
as required by the applicable program.
For example, if CS1 is a common stack for Units 1 and 2, report two sets of RTs 585: one set
for Unit 1, and one set for Unit 2. For Acid Rain units, each set of RTs 585 should have separate RTs
585 for parameters S02, NOXR, C02, HI, and OP, and, if applicable, H20. As another example, if
MSI A and MS IB are multiple stacks for Unit 1, report one set of RTs 585 for Unit 1.
If you use several methodologies or combination of methodologies, either as a backup or to
address different fuels, submit multiple RTs 585.
If you are required to correct for moisture when calculating emissions or heat input rate, report a
RT 585 for moisture (parameter H20) to define the methodology used to determine hourly moisture for
emissions calculations. If you are using a moisture default from Part 75, identify the fuel type in column
24 as C (Coal) or W (Wood). If you use a different moisture default that was approved by petition,
identify the fuel type in column 24 as NFS (Non fuel specific).
Where Subpart H and Acid Rain Program requirements overlap or are identical, duplicative
reporting of RT 585 is not required (e.g.. if Appendix E is used to determine the NOx emission rate for
both Acid Rain and Subpart H purposes, submit one RT 585 for the parameter NOXR).
If you change methodologies for a parameter during the reporting period, submit two RTs 585 for
the parameter: one indicating the date on which the use of the previous methodology was discontinued
and one indicating the date on which the replacement methodology begins.
For Acid Rain Program Units: Refer to Table 33, below. For all Acid Rain units, except for
units using the low mass emissions (LME) methodology under § 75.19, submit separate RTs 585 for
parameters S02, NOXR, C02, HI, and OP, and, if applicable, H20. Submit an additional RT 585 for
parameter NOXM if the unit is also subject to Subpart H and if you use a NOx concentration system and
stack flow monitor as either the primary or secondary methodology for determining NOx mass emissions.
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If a unit which has an S02 monitor combusts both high sulfur fuel (e.g.. coal or oil) and natural
gas, and uses a default S02 emission rate and Equation F-23 for hours in which natural gas is combusted
(see § 75.11(e)(1)), define two RTs 585 for parameter S02: one with a monitoring methodology code of
"CEM" in column 14 and fuel type code of "NFS" (Non-fuel Specific) in column 24 and one with the
methodology code of "F23" in column 14 and fuel type code of "PNG" or "NNG" in column 24. You
should also report two RTs 587 for this unit: one for the higher sulfur fuel and one for natural gas.
For a unit with S02 or NOx emission controls and a bypass stack, if the owner or operator elects
not to monitor at the bypass stack and to report the MPC or MER when the flue gases are routed
through the bypass stack (see 75.16 (c) and 75.17 (d)), report one or more additional RTs 585 for the
parameter "S02", "NOXR" or "NOXM" (as applicable). Use the following guidelines:
• Report one additional RT 585, using a methodology code of "BYMAX" if a single MPC or
MER value (i.e.. the value from RT 530) is reported for all bypass hours, and the S02 or NOx
MPC or MER value is determined in the usual manner according to Part 75, Appendix A (i.e..
based on the fuel with the highest sulfur content or the fuel that produces the highest NOx
emission rate).
• Report one additional RT 585 if you elect to report the fuel-specific MPC or MER during
bypass hours. Report a methodology code of "BYMAXFS" in RT 585, column 14, if the
MPC or MER values reported during bypass hours are fuel-specific. Define all fuel-specific
MPC and MER values in RT 531.
If a unit is exempted from opacity monitoring requirements because it is gas-fired or diesel-fired,
report a fuel type code of "PNG", "NNG", or "DSL" in column 24. If the unit has a wet scrubber and is
exempted from installing a COMS because it has entrained water droplets in the effluent, report a fuel
type code of "NFS" in column 24.
For Acid Rain Program Low Mass Emissions (LME) Units: Refer to Table 34, below.
Submit separate RTs 585 for parameters S02, NOXR, C02, HI, and OP. For parameters S02, NOXR,
C02, if you combust more than one type of fuel, submit a RT 585 for each fuel type. For parameter HI,
submit more than one RT 585 if you use the long-term fuel flow option and combust more than one type
of fuel.
For Non-Acid Rain Subpart H Units: Refer to Table 35, below. For all non-Acid Rain
Subpart H units, except for units using the low mass emissions (LME) methodology under § 75.19:
• If you calculate NOx mass emissions by determining NOx emission rate and heat input rate,
submit two RTs 585, one for NOx emission rate (NOXR) and one for heat input rate (HI);
• If you use a NOx concentration CEMS times stack flow to determine NOx mass emissions
either as a primary or backup methodology, submit a RT 585 to identify this NOx mass
emissions methodology (NOXM); and
• If applicable, submit RT 585 for moisture (H20).
For Non-Acid Rain Subpart H Low Mass Emissions (LME) Units: Refer to Table 36, below.
Submit RTs 585, to describe the methodology for NOx emission rate (NOXR) and to describe the
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EDR v2.2 Instructions: RT 585
methodology for heat input (HI). For parameters NOXR, if you combust more than one type of fuel,
submit a RT 585 for each fuel type. For parameter HI, submit more than one RT 585 if you use the long-
term fuel flow option and combust more than one type of fuel.
Field Descriptions and Instructions
Use Tables 33 through 36 below, in conjunction with the general instructions above, to
provide the appropriate information in each RT 585. Select the appropriate table based on
the programs applicable to the unit (e.g.. use Table 34 for an Acid Rain low mass
emissions (LME) unit).
Parameter (10). Report the parameter for which the monitoring methodology applies
using one of the codes listed in the first column of the appropriate table below.
Monitoring Methodology (14). Report one of the methodology codes listed in the third
column of the appropriate table below to describe the methodology used to monitor the
parameter.
Type of Fuel Associated with Methodology (24). Report the code for the type of fuel
associated with the methodology or value. Select one of the applicable fuel codes in the
fifth column of the appropriate table below. These codes are defined as follows:
CRF Coal Refuse (culm or gob)
DSL Diesel Oil
LPG Liquefied Petroleum Gas
NFS Non-fuel Specific
NNG Natural Gas
OGS Other Gas
OIL Residual Oil
OOL Other Oil
OSF Other Solid Fuel
PNG Pipeline Natural Gas (as defined in § 72.2)
PRG Process Gas
PRS Process Sludge
PTC Petroleum Coke
R Refuse
TDF Tire Dervied Fuel
W Wood
WL Waste Liquid
Primary/Secondary Methodology Indicator (27). Indicate whether you intend to use
this methodology as a primary or secondary (backup) methodology for the unit, parameter
and type of fuel by reporting the following uppercase codes:
P Primary
S Secondary
C
Coal
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Missing Data Approach for Methodology (28). Report the approach used for the
methodology to determine substituted values during periods of missing data as indicated
below:
SPTS Standard Part 75 Missing Data Procedures — Le^, the Normal, Non Fuel-Specific
CEMS procedures in § 75.33 or § 75.74(c)(7) (for non-ARP, Subpart H units
that report on an ozone season-only basis), or the Standard Appendix D Missing
Data Procedures, or the Standard Fuel-Specific Appendix E Missing Data
Procedures.
REV75 Inverse Part 75 Missing Data Procedures for Moisture or 02, Per § 75.36 or §
75.37
FSP75 Fuel-Specific Part 75 CEMS Missing Data Procedures in § 75.33. Use this code
if: (a) you do not co-fire fuels; or (b) if, when fuels are co-fired, substitute data
values for missing data lookbacks are drawn from the database for the fuel that
produces the highest emissions or flow rate.
FSP75C Fuel-Specific Part 75 CEMS Missing Data Procedures in § 75.33. Use this code
if you co-fire fuels and if substitute data values for missing data lookbacks are
drawn from a separate database for co-fired hours.
OZN75 Ozone Season vs. Non-Ozone Season NOx CEMS Missing Data Procedures in §
75.34 (a)(2), for Subpart H units that report year-round
NLB Non Load-Based Missing Data Procedures in § 75.33 or Appendix D, Section
2.4.2.3 — Operational Bins Not Used
NLBOP Non Load-Based CEMS Missing Data Procedures in § 75.33 — Using
Operational Bins or Appendix D, Section 2.4.2.3 — Approved Petition to Use
Operational Bins
NA Not Applicable
For all LME codes and the code for opacity use "NA".
Methodology Start Date (34). Report the actual date on which the methodology was
first used to determine emissions or heat input rate for the unit. This date must precede or
coincide with the date of any certification testing associated with the methodology, but
should not predate the installation date of the monitoring system(s). For opacity, report
the same starting date as for emission reporting, whether you are exempted from opacity
monitoring or not.
Methodology End Date (42). Report the actual date on which the methodology was last
used to determine emissions or heat input rate for the unit. If the methodology is currently
in use, either as a primary or secondary methodology, leave this field blank.
If you change methodologies either at the beginning of a reporting period or during a
reporting period, submit one RT 585 for the methodology which was previously used,
indicating the last day on which the methodology was used. Report a second RT 585 for
the new methodology. In the second record, leave this field blank.
Clean Air Markets Division, U.S. EPA
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December 2005
EDR v2.2 Instructions: RT 585
Table 33
ACID RAIN PROGRAM METHODOLOGIES AND PARAMETERS
Piiriimcler
("ode
(( ol 10)
Piirsimclcr
Description
.Methodology
Code
(Col 14)
Methodology Description
Acceptnhle l-'iiel Codes
(Col 24)
S02
S02 Emissions
CEM
Continuous Emission Monitoring
NFS
BYMAX
MPC for Highest-Sulfur Fuel
(Control Device Bypass Hours)
NFS
BYMAXFS
Fuel-Specific MPC
(Control Device Bypass Hours)
NFS
F23
Use of Default S02 Emission Rate and
CEMS For HI
NNG, PNG
AMS
Approved Alternative Monitoring
As approved
GFF
Gas Fuel Flow per Appendix D
LPG, NNG, OGS, PNG,
PRG
OFF
Oil Fuel Flow per Appendix D
DSL, OIL, OOL
NOXR
NOx Emission
Rate
AE
Appendix E
LPG, NNG, OGS, PNG,
PRG, DSL, OIL, OOL
CEM
Continuous Emission Monitoring
NFS
BYMAX
MER for Highest NOx Emitting Fuel
(Bypass Stack Operating Hours)
NFS
BYMAXFS
Fuel-Specific NOx MER
(Bypass Stack Operating Hours)
NFS
PEMS
Predictive Emissions Monitoring
System (as approved by petition)
LPG, NNG, OGS, PNG,
PRG, DSL, OIL, OOL
AMS
Approved Alternative Monitoring
As approved
(cont.)
Page 196
Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: RT 585
December 2005
Table 33
ACID RAIN PROGRAM METHODOLOGIES AND PARAMETERS (cont.)
Piiriimelcr
("ode
(( ol 10)
Piiriimelcr
Description
.Methodology
Code
(Col 14)
Methodology Description
Acceptable l-'iiel Codes
(Col 24)
C02
C02 Emissions
CEM
Continuous Emission Monitoring
NFS
FSA
Fuel Sampling and Analysis (if
Equation G-l or G-2 is used)
C, DSL, LPG, NFS, NNG,
OGS, OIL, OOL, PNG, PRG,
PRS, R, CRF, OSF, PTC,
TDF, WL
AMS
Approved Alternative Monitoring
As approved
GFF
Gas Fuel Flow per Appendix D (if
Equation G-4 is used)
LPG, NNG, OGS, PNG,
PRG
OFF
Oil Fuel Flow per Appendix D (if
Equation G-4 is used)
DSL, OIL, OOL
HI
Heat Input
CEM
Continuous Emission Monitoring
NFS
AMS
Approved Alternative Monitoring
As approved
GFF
Gas Fuel Flow per Appendix D
LPG, NNG, OGS, PNG,
PRG
OFF
Oil Fuel Flow per Appendix D
DSL, OIL, OOL
OP
Opacity
COM
Continuous Opacity Monitor
NFS
EXP
Exempted
PNG, NNG, DSL, NFS
H20
Moisture
MMS
Continuous Moisture Sensor
NFS
MDF
Moisture Default
C, W, NFS
MTB
Moisture Look-up Table
NFS
MWD
Wet/dry 02 Analyzers
NFS
NOXM
NOx Mass
CEM
NOx Concentration Times Stack Flow
NFS
Emissions
BYMAX
MPC for Highest NOx Emitting Fuel
(Bypass Stack Operating Hours)
NFS
BYMAXFS
Fuel-Specific NOx MPC
(Bypass Stack Operating Hours)
NFS
AMS
Approved Alternative Monitoring
As approved
Clean Air Markets Division, U.S. EPA
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December 2005
EDR v2.2 Instructions: RT 585
Table 34
ACID RAIN PROGRAM LOW MASS EMISSIONS (LME)
METHODOLOGIES AND PARAMETERS
Piiriimctcr
C "ode
(Col 10)
I'iirsimclcr
Description
Methodology
C "ode
(Col 14)
Methodology Description
Acceptable I'uel Codes
(Col 24)
S02
S02 Emissions
S02G
Generic S02 Default Value
DSL, NNG, OIL, OOL,
PNG
S02U
Fuel and Unit-Specific S02 Default
Value
OGS, PRG, DSL, OIL
NOXR
NOx Emission
Rate
NOXG
Generic NOx Emission Rate Default
DSL, NNG, OIL, OOL,
PNG
NOXU
Unit and Fuel-Specific NOx
Emission Rate
DSL, NNG, OIL, OOL,
PNG, PRG, OGS
C02
C02
Emissions
C02G
Generic C02 Default Value
DSL, NNG, OIL, OOL,
PNG
C02U
Fuel and Unit-Specific C02 Default
Value
OGS, PRG
HI
Heat Input
LTFF
Long Term Fuel Flow
DSL, NNG, OGS, OIL,
OOL, PNG, PRG
MHHI
Maximum Rated Hourly Heat Input
NFS
OP
Opacity
COM
Continuous Opacity Monitoring
NFS
EXP
Exempted
NNG, PNG, DSL, NFS
Page 198
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EDR v2.2 Instructions: RT 585
December 2005
Table 35
NON-ACID RAIN SUBPART H METHODOLOGIES AND PARAMETERS
I'iinimoler
C ode
(Col 10)
Piiriimcler
Description
Methodology
Code
(Col 14)
Methodology Description
Acceptable
I'uel C odes
(Col 24)
NOXR
NOx Emission
Rate
AE
Appendix E
LPG, NNG, OGS,
PNG, PRG, DSL,
OIL, OOL
CEM
Continuous Emission Monitoring
NFS
BYMAX
MER for Highest NOx Emitting Fuel
(Bypass Stack Operating Hours)
NFS
BYMAXFS
Fuel-Specific NOx MER
(Bypass Stack Operating Hours)
NFS
AMS
Approved Alternative Monitoring
As approved
HI
Heat Input
CEM
Continuous Emission Monitoring
NFS
AMS
Approved Alternative Monitoring
As approved
GFF
Gas Fuel Flow Per Appendix D
LPG, NNG, OGS,
PNG, PRG
OFF
Oil Fuel Flow Per Appendix D
DSL, OIL, OOL
EXP
Exempted from heat input monitoring
under State SIP or by special petition
NFS
NOXM
NOx Mass
Emissions
CEM
NOx Concentration times Stack Flow
NFS
BYMAX
MPC for Highest NOx Emitting Fuel
(Bypass Stack Operating Hours)
NFS
BYMAXFS
Fuel-Specific NOx MPC
(Bypass Stack Operating Hours)
NFS
AMS
Approved Alternative Monitoring
As approved
H20
Moisture
MMS
Continuous Moisture Sensor
NFS
MDF
Moisture Default
C, W, NFS
MTB
Moisture Look-up Table
NFS
MWD
Wet/dry 02 Analyzers
NFS
Clean Air Markets Division, U.S. EPA
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December 2005
EDR v2.2 Instructions: RT 586
Table 36
NON-ACID RAIN SUBPART H LOW MASS EMISSIONS (LME)
METHODOLOGIES AND PARAMETERS
I'iii'iimclcr
C "ode
(Col 10)
I'iininictcr
Description
Methodology
Code
(Col 14)
Methodology Description
Acceptable
I'uel C odes
(Col 24)
NOXR
NOx Emission
Rate
NOXG
Generic NOx Emission Rate Default
DSL, NNG,
OIL, OOL, PNG
NOXU
Unit and Fuel-Specific NOx
Emission Rate
DSL, NNG,
OIL, OOL,
PNG, PRG,
OGS
HI
Heat Input
LTFF
Long Term Fuel Flow
DSL, NNG,
OIL, OOL,
PNG, PRG,
OGS
MHHI
Maximum Rated Hourly Heat Input
NFS
(23) RT 586: Control Equipment Information
Report one or more RTs 586 to define the types of S02, NOx, and particulate control equipment
in place or planned for each unit. Do not report RTs 586 for any parameter (S02, NOx or particulate) for
which the unit is uncontrolled. Also, do not report RT 586 for a parameter if emissions of that
parameter are controlled by limiting production or by switching fuels.
This record type is unit-specific; do not report RTs 586 for any common or multiple stack ID or
pipe ID. If a common stack serving two units contains a control device, report this information for each
of the units associated with the common stack.
Field Descriptions and Instructions
Parameter (10). Report the parameter to be controlled using one of the following
uppercase codes:
S02 Sulfur Dioxide
NOX Nitrogen Oxides
PART Particulates (Opacity)
Control Equipment Code (14). Report the type of controls using the following
uppercase codes:
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December 2005
N(X Controls
CM Combustion Modification/Fuel Reburning
DLNB Dry Low NOx Premixed Technology (Turbines only)
H20 Water Injection (Turbines and Cyclone Boilers only)
LNB Low NOx Burner Technology (Dry Bottom Wall-fired Boilers or Process
Heaters only)
LNBO Low NOx Burner Technology with Overfire Air (Dry Bottom Wall-fired Boilers
or Process Heaters Only)
LNC1 Low NOx Burner Technology with Close-coupled OF A (Tangentially fired units
only)
LNC2 Low NOx Burner Technology with Separated OF A (Tangentially fired units
only)
LNC3 Low NOx Burner Technology with Close-coupled and Separated OF A
(Tangentially fired units only)
LNCB Low NOx Burner Technology for Cell Burners
NH3 Ammonia Injection
O Other
OF A Overfire Air
SCR Selective Catalytic Reduction
SNCR Selective Non-catalytic Reduction
STM Steam Injection
SO, Controls
DA Dual Alkali
DL Dry Lime FGD
FBL Fluidized Bed Limestone Injection
MO Magnesium Oxide
O Other
SB Sodium Based
WL Wet Lime FGD
WLS Wet Limestone
Particulate Controls
B Baghouse(s)
ESP Electrostatic Precipitator
HESP Hybrid Electrostatic Precipitator
WESP Wet Electrostatic Precipitator
WS Wet Scrubber
O Other
C Cyclone
Primary/Secondary Controls Indicator (20). Report whether you intend to use the
control methodology as a primary or secondary (backup) methodology for the unit by
using the following uppercase codes:
P Primary
S Secondary
Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: RT 587
Original Installation (21). For each parameter, report the letter "O" to indicate that the
control equipment was installed and operational as part of the original unit design. If the
control equipment was not part of the original unit design, leave this field blank.
Controls Install Date (22). If the control equipment was not part of the original
installation, report the approximate date on which controls were installed or will be
installed at the unit. Leave this field blank if it is not applicable.
Controls Optimization Date (30). If the control equipment was not part of the original
installation, report the approximate date on which optimization of the control equipment
was completed and the equipment fully operational at the unit. If there was no
optimization period, leave this field blank.
Controls Retirement Date (38). Report the date on which the control equipment was
removed or retired from the unit. Leave this field blank if the control equipment is still in
use.
Seasonal Controls Indicator (46). For Subpart H units, if the NOx control equipment is
used only during the ozone season, report an "S" in this field. Otherwise, leave this
column blank.
Submit RT 587 for each type of fuel burned at each unit. This is a unit-specific record type,
therefore do not report RT 587 for common or multiple stack IDs or pipe IDs. This record is used to
indicate the primary, secondary, emergency, and startup fuels combusted by each unit, to report changes
in the types of fuels combusted and to indicate when such changes occurred. (RT 587 replaces columns
55 and 95 of RT 502.)
Field Descriptions and Instructions
Fuel Types Combusted (10). Report one of the following uppercase codes to indicate
the types of fuel combusted by the unit:
CRF Coal Refuse (culm or gob)
DSL Diesel Oil
LPG Liquefied Petroleum Gas
NNG Natural Gas
OGS Other Gas
OIL Residual Oil
OOL Other Oil
OSF Other Solid Fuel
PNG Pipeline Natural Gas (as defined in § 72.2)
PRG Process Gas
PRS Process Sludge
PTC Petroleum Coke
R Refuse
(24) RT 587: Unit Fuel Type
C
Coal
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EDR v2.2 Instructions: RT 587
December 2005
TDF Tire-derived Fuel
W Wood
WL Waste Liquid
Diesel oil is defined in § 72.2 as low sulfur fuel oil of grades 1-D or 2-D, as defined by
ASTM D-975-91, grades 1-GT or 2-GT, as defined by ASTM D2880-90a, or grades 1 or
2, as defined by ASTM D396-90. By those definitions (specifically ASTM D396-90) and
for the purposes of this Program, kerosene is considered a subset of diesel oil and
therefore should be identified with the code DSL. If your fuel does not qualify as one of
these types, do not report the code DSL.
Fuel Type Start Date (13). Report the first date on which the unit combusted this fuel
type (or the best available estimate if the exact date is not known). The fuel type start
date must precede or coincide with the date of any monitoring system certifications while
combusting the fuel.
Fuel Type End Date (21). If the combustion of this fuel type has been permanently
discontinued at this unit, report the last date on which this fuel type was combusted at the
unit. If not applicable, leave this field blank.
Primary/Secondary/Emergency/Startup Fuel Indicator (29). Report whether the fuel
type listed in column 10 is the primary fuel (as defined in § 72.2), a backup (secondary)
fuel, a startup fuel, or an emergency fuel for this unit using the following uppercase codes:
E Emergency
I Ignition (Startup)
P Primary
S Backup (Secondary)
Ozone Season Fuel Switching Flag (30). If fuel switching (to a secondary fuel or fuels)
is used for seasonal control of ozone, report "S" in this field for the secondary fuel(s)
record(s). Otherwise leave this field blank.
Demonstration Method to Qualify for Monthly Fuel Sampling for GCV (31). Report
the method used to demonstrate that a unit using Appendix D qualifies for monthly GCV
fuel sampling (see section 2.3.5 of Appendix D) using one of the following uppercase
codes:
GHS 720 Hours of Data Using Hourly Sampling
GGC 720 Hours of Data Using an On-line Gas Chromatograph
GOC 720 Hours of Data Using an On-line Calorimeter
For units that have not performed this demonstration, leave this field blank.
Demonstration Method to Qualify for Daily or Annual Fuel Sampling for %S (ARP)
(34). Report the method used to demonstrate that an Acid Rain unit using Appendix D
qualifies for daily or annual % sulfur sampling (see section 2.3.6 of Appendix D) using one
of the following uppercase codes:
Clean Air Markets Division, U.S. EPA
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December 2005
EDR v2.2 Instructions: RT 587
SHS 720 Hours of Data Using Manual Hourly Sampling
SGC 720 Hours of Data Using On-line Gas Chromatograph
For units that have not performed this demonstration, leave this field blank.
D. Quality Assurance and Certification Data Reporting
All certification, recertification, and periodic quality assurance tests that affect data validation
must be reported in EDR format in a quarterly report. Report the appropriate test data and results for
each primary monitoring system, each redundant backup monitoring system, and each non-redundant
backup system used to report data during the quarter.
Do not report tests that are discontinued because of non-CEMS related equipment failures, such
as unit outages or reference method failures. Also do not report the results of trial runs and gas injections
that meet the acceptance criteria in § 75.20(b)(3)(vii)(E), which are part of the process of optimizing the
performance of a CEMS. The results of these tests are not used to establish the validity of hourly
emissions data. All completed, passed tests, all completed, failed tests, all tests which are discontinued
(aborted) because of CEMS failures, and all trial runs and gas injections that do not meet the acceptance
criteria in § 75.20(b)(3)(vii)(E) must be reported.
For initial certification and recertification, submit CEMS test data or LME qualification data to
the Administrator in electronic format in the appropriate quarterly report, as described below, and also as
a separate submittal as part of the initial certification application (within 45 days of completing all
required tests) or as part of the recertification application (within 45 days of completing all recertification
tests). For recertifications and required diagnostic tests, submit a corresponding RT 556 in the quarterly
report. Also submit a corresponding RT 556 for routine RATAs and linearity checks, if the conditional
data validation procedures in § 75.20(b)(3) are used.
Submit the results of all required quality assurance, certification, diagnostic, and recertification
tests as part of the electronic quarterly report for the calendar quarter in which the tests are completed.
There are three exceptions:
• For new units, where the initial certification tests are completed prior to the program
participation date, submit data for all certification tests in the first quarterly report;
• When a recertification or diagnostic test period continues past the end of the current quarter
and the recertification or diagnostic tests are completed within the first 30 days of the next
quarter (i.e.. in time to be submitted in the quarterly report for the current quarter). If the
tests are failed, replace conditionally valid data with substitute data and thereby avoid a
resubmission. If the tests are passed, report the data as quality-assured, and thereby avoid
having to use a conditional data flag ("C") in RT 556, column 51; and
• For a Subpart H unit for which you report data only during the ozone season, when required
QA tests are done outside of the ozone season (between October 1 of the previous year and
April 30 of the current year) which affect data validation in the current ozone season. Submit
the results of these QA tests in the quarterly report for the second calendar quarter of the
current year, or with the third quarter report, if the second quarter is a non-operating quarter
(see § 75.74(c)(6)(v)).
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EDR v2.2 Instructions: RT 600
December 2005
To ensure the completeness and quality of quality assurance data, EPA has developed and
released the Monitoring Data Checking Software (MDC) on the Clean Air Markets Division Home Page:
(URL:www.epa.gov/airmarkets/cems/mdc/htmY EPA strongly recommends that you use this software to
evaluate and correct any inconsistencies and omissions before submitting the quality assurance tests data
to EPA. EPA also uses this software to analyze quality assurance test data and provide feedback to the
source.
(1) RT 600: 7-day Calibration Error Test Data and Results
Report all 7-day calibration error tests performed for initial certification, recertification, or
diagnostic purposes, using RTs 600. For each day of the 7-day test, report the results of the zero and
upscale gas injections (or flow reference signals) in RT 600.
If a component is part of two systems report the 7-day calibration error test twice, once for each
system using the appropriate system IDs. For example, for a diluent monitor used as part of a C02
monitoring system and a NOx-diluent system, report C02 7-day calibration test twice. Report one set of
RTs 600, using the C02 system ID and the C02 component ID and the other set of RTs 600 using the
NOx-diluent system ID and the diluent component ID.
For moisture monitoring systems consisting of wet and dry-basis 02 monitors, report two 7-day
calibration tests only if the wet and dry readings are obtained from two different analyzers.
For flow monitoring systems comprised of two flow components, perform and report 7-day
calibration tests for each flow component in the system.
For dual range monitors, perform and report 7-day calibration tests at each range of the
instrument.
Field Descriptions and Instructions
Instrument Span (24). Report the appropriate span value from RT 530, column 36,
corresponding to the parameter monitored and the span scale ("L" or "H") reported in
column 24. Do not leave this field blank.
Reference Value (37). Report the certified (tag) value of the reference calibration gas, in
ppm (for S02 and NOx) or in %C02 or %02 (for C02 and 02). For flow monitors, report
the value of the reference signal, in the appropriate units. See the instructions for column
62 in RT 230.
Measured Value (50). Report the response of the gas analyzer to the reference
calibration gas, in ppm (for S02 and NOx) or in %C02 or %02 (for C02 and 02). For flow
monitors, report the response of the monitor to the reference signal.
Results (Calibration Error or |R - A|) (63). For the normal (concentration analyzer)
calibration error (CE) specification, report the results as the absolute value of the
difference between the reference value and the measured value (i.e.. |R - A|, as a
percentage of the instrument span). If the alternative low-emitter or diluent specification
is used, report the result as |R - A| in terms of ppm (for S02 and NOx) or in terms of
Clean Air Markets Division, U.S. EPA
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December 2005
EDR v2.2 Instructions: RT 600
%C02 or %02. If the calculated calibration error meets the standard specification, report
the result as a percentage of the span even though the result would also pass the
alternative specification. Only when the result does not pass the standard specification,
but does meet the alternative specification, should you report the absolute value of the
difference.
For low-span DP-type flow monitors using the alternate calibration error specification: (1)
report "0.0" in this field if the value of |R - A| is <0.01 inches of water; or (2) report
"0.1" in this field if the value of |R - A| is >0.01 , but <0.10 inches of water; or (3) if the
value of |R - A| is > 0.10 inches of water, report the result to the nearest 0.1 in. H20.
Alternative Performance Specification (APS) Flag (68). Report whether the test result
was determined using a normal specification ("0" (zero)) or the alternative performance
specification "1" allowed under Part 75.
Appendix A to Part 75 specifies that the calibration error of an 02 or C02 monitor is
always expressed in percent 02 or C02, rather than as a percentage of span. This is
considered to be the "normal" calibration error specification and should have a "0" flag in
RTs 230 and 600. The alternate performance specification flag in these record types
applies only to S02 and NOx pollutant concentration monitors at facilities that are low-
emitters of those pollutants.
Reference Signal or Calibration Gas Level (69). For each day of the
7-day calibration error test, reference gas injections or signal levels are required at two
levels. The same two gas levels or signals must be used for all days of the test. Indicate
"Z" if the reference gas injected or signal is a zero-level check (0 to 20% of span) and "H"
if a high-level calibration gas (80 to 100% of span) or a high-level flow monitor signal (50
to 70%) of span) is used. A mid-level calibration gas (50 to 60%> of span) may be used in
lieu of the high-level gas. If a mid-level gas is used, report "M" in this column.
Span Scale (70). Report whether the component (or the range of the instrument) tested is
high ("H") or ("L") low scale. If the monitoring system component only measures at a
single instrument range, enter "H" or leave this field blank.
Test Number (71). For each set of 7-day calibration error records which comprise a
single test, assign a unique test number for the system and component. You may reuse the
test number for different systems and components. You may also reuse the test number
for the same monitoring system, provided that the tests are performed and reported in
different quarters. If you submit data for an incomplete or aborted test, assign and report
a test number. If you submit hardcopy information on a test in a certification report or
submit other information about the test to EPA or a State agency, refer to the system and
component IDs, the test number, and test time period (quarter and year). Do not leave
this field blank.
(Note: If a single component ID is used to represent a dual-range analyzer (i.e.. if a
component type code of "S02A", "NOXA", "C02A", "02DA", or "02WA" is
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Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: RT 601-602
December 2005
assigned to the analyzer in column 23 of RT 510), use two different test numbers
for the low and high scale tests when reporting 7-day calibration error tests of the
low and high ranges in the same EDR submittal).
Reason for Test (73). Report the purpose of the test using one of the following
uppercase codes:
C Initial Certification
D Diagnostic
R Recertification
Do not leave this field blank.
(2) RTs 601 and 602: Linearity Check Data and Results
Report all linearity checks performed for initial certification, recertification, ongoing quality
assurance or diagnostic purposes using RTs 601 and 602. Use RT 601 to report the results of each
calibration gas injection. Use RT 602 to report the results for the set of injections at each gas level (low,
mid, and high). Linearity checks are required to be performed with the unit in operation. Therefore, do
not report RTs 601 and 602 for non-operating quarters.
If your gas monitors are configured such that injection of calibration gases forces all of the
analyzers into the calibration mode, when you perform a linearity check on one monitor you may (e.g.. if
you use tri-blend calibration gases) cause simultaneous (unscheduled) linearity checks of the other
analyzers to be done. You do not have to report the results of these unscheduled linearity tests as long as
they meet the linearity error specifications. However, if the results of these unscheduled tests indicate
that a monitoring system is out-of-control, you must report the results and consider it to be a failed
linearity check.
If you report data on a year-round basis, a linearity check of each gas monitor is required in each
QA operating quarter (i.e.. a calendar quarter with >168 unit or stack operating hours) for routine
quality assurance.
For Subpart H units or stacks for which you report data only in the ozone season (only in the
second and third quarters), linearity checks are required both inside and outside of the ozone season.
Pre-ozone season linearity checks are required under § 75.74(c)(2)(i) and may be done any time between
October 1 of the previous year and April 30 of the current year. Linearity checks are also required in the
second and third calendar quarters, if those quarters qualify as QA operating quarters. Note that for the
second calendar quarter, only the unit operating hours in the months of May and June are considered
when determining whether that quarter is a QA operating quarter (see § 75.74(c)(3)(ii)).
For dual-span units, a linearity check is required only on the range(s) used during the quarter.
For an S02 or NOx monitor with a span value of 30 ppm or less, linearity checks are not required.
If a calendar quarter is not a QA operating quarter; or if for a dual-span unit, a particular monitor
range was not used during the quarter, you may claim a linearity check exemption for that quarter,
Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: RT 601-602
subject to certain limitations (see RT 698 instructions). If an S02 or NOx monitor has a span value of <
30 ppm, you may claim an on-going linearity test exemption for that quarter (see RT 698 instructions).
Report all completed and aborted linearity tests that affect data validation. For a Subpart H unit
or stack for which you report data only in the ozone season, report the results of all pre-ozone season
linearity checks that affect data validation in the current ozone season, in the quarterly report for the
second calendar quarter of the current year (or with the third quarter report, if the second quarter is a
non-operating quarter).
An aborted test is treated as a failed test if the test is discontinued due to a monitor failure, and
the results must be reported, with one exception. For ozone season-only reporters, an aborted pre-ozone
season linearity check need not be reported if a subsequent linearity check is passed prior to the start of
the current ozone season.
It is not necessary to report or to treat as a failed test a linearity check which is discontinued
because of a failure which is unrelated to instrument performance, such as a power outage, unit outage,
or calibration gas problem. It is not necessary to report the results of trial gas injections that are part of
the process of optimizing the performance of a monitor, when the injections meet the acceptance criteria
in § 75.20(b)(3)(vii)(E). For discontinued tests and trial injections that do not affect data validation,
record the results as part of the official test log and maintain records on-site (or at an alternative location
known to the regulatory agency if on-site storage is not feasible).
If a component is part of two systems, report the linearity twice, once for each system using the
appropriate system/component IDs. For example, for a diluent monitor used as part of a C02 monitoring
system and a NOx-diluent system, report C02 linearity test twice. Report one set of RTs 601 and 602,
using the C02 system ID and the C02 component ID and another set using the NOx-diluent system ID
and the diluent component ID.
Submit one RT 601 for each gas injection in each reported linearity check. For completed tests
for normal span levels, there will generally be nine RTs 601 and three RTs 602.
If you report more than the nine required gas injections as part of a test because of State test
requirements, report all injections using the same test number. EPA will evaluate only the last three
injections at each level, as indicated by the date and time of the injection. Prior injections will be
disregarded in the calculation of results. Calculate and report results using only these injections.
If a required linearity test is not completed by the end of the quarter in which it is due, a 168
unit/stack operating hour grace period is allowed to perform the test.
For Subpart H units or stacks for which you report data only in the ozone season, a 168 unit/stack
operating hour grace period is conditionally allowed, when the required pre-ozone season linearity check
is not completed by April 30th (see § 75.74(c)(2)(i)(D)(/)). However, grace periods are not allowed for
the linearity checks required inside the ozone season (in the second and third calendar quarters) (see
§ 75.74(c)(3)(ii)).
To claim a grace period for a missed linearity test, follow the applicable instructions under RT
699.
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December 2005
Field Descriptions and Instructions for RT 601
Date and Time (16, 22). Report the date and time of each gas injection. Because gas
injections are sequential and cannot be simultaneous, the time of each gas injection must
be unique for each analyzer. Gas injections at each level must be performed sequentially,
so that two gas injections are never performed successively at the same level for the same
analyzer.
Instrument Span (26). Report the span of the component. The span value must be the
same as the span value reported in RT 530 for the unit or stack effective on the date and
hour of the linearity check. The span value must be the same for each of the gas
injections.
Reference Value (39). Report the certified (tag) value of the reference calibration gas for
each injection. The reference value must be in units of ppm for NOx and S02 and in %C02
or %02 for diluent gases.
Measured Value (52). Report the instrument measurement value to the number of
decimal places required for hourly measured data reported in the EDR. For example,
report NOx or S02 concentration to one decimal place.
Calibration Gas Level (65). Report the calibration gas level associated with the gas
injection as either "L", "M", or "H". For high level injections the calibration gas
concentration must be 80 to 100% of the span reported in column 25; for mid level, 50 to
60% of span; and for low level, 20 to 30% of span.
Span Scale (66). Report whether the test is for a high or low scale span by reporting
either "FT or "L". If the unit or stack only measures at a single instrument range, enter
"H" or leave this field blank.
Test Number (67). For each set of linearity records that comprise a single test at either
high or low scale, assign and report a unique test number for the system and component.
Use this same test number in RT 602 to report the results at each gas level.
(Note: If a single component ID is used to represent a dual-range analyzer (i.e.. if a
component type code of "S02A", "NOXA", "C02A", "02DA", or "02WA" is
assigned to the analyzer in column 23 of RT 510), use two different test numbers
for the low and high scale tests when reporting linearity checks of the low and high
ranges in the same EDR submittal.)
If you submit data for an incomplete or aborted test, assign and report a test number to the
reported RTs 601.
You may reuse the test number for different systems and components. You may also
reuse the test number for the same monitoring system, provided that the tests are
performed and reported in different quarters.
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EDR v2.2 Instructions: RT 601-602
If you submit hardcopy information for this test in a certification or recertification report
or submit other information about the test to EPA or the State agency, refer to the system
ID, component ID, test number, and test time period.
Do not leave this field blank.
Indicator of Aborted Test (69). Leave this field blank unless the linearity test was
aborted. If you abort the linearity check without completing all required gas injections,
report an "A" in column 69 for each of the gas injections associated with the test. The
monitoring system is considered out-of-control when a linearity test is aborted due to a
problem with the CEMS. Do not report RT 602 for an aborted test.
Field Descriptions and Instructions for RT 602
Date (16). Report the date of the linearity test. If the test period spans two or more
calendar days, report the date on which the test is completed.
Instrument Span (22). Report the span of the component. The span value should be the
same as the span value reported in RT 530, column 36, for the unit or stack as effective on
the date and hour of the linearity check. The span value and span scale in each RT 602
must be the same as the span value (and scale) for each of associated gas injections
reported in RTs 601.
Mean of Reference Values (35). Calculate and report the mean or average of the
reference values for the specified calibration gas level.
Mean of Measured Values (48). Calculate and report the mean or average of the
measured values for the specified calibration gas level.
Results (Linearity Error or I R - A I) (61). Calculate and report the linearity error for
each calibration gas level using Equation A-4 of Part 75, Appendix A, Section 7.1.
Alternatively, calculate the result I R - A I, as provided in Part 75, Appendix A, Section
3.2. If the calculated linearity error meets the standard specification, report the result as a
percentage of the reference gas tag value even though the result would also pass the
alternative specification. Only when the result does not pass the standard specification,
but does meet the alternative specification, should you report the absolute value of the
difference.
Alternative Performance Specification (APS) Flag (66). If you calculate the results
using the alternative performance specification in Section 3.2 of Appendix A to Part 75,
report a "1" in this field. For all other tests report "0" (zero). Do not leave this field
blank.
Calibration Gas Level (71). Report the calibration gas level associated with the results
as either "L" (low), "M" (mid), or "H" (high). Do not leave this field blank.
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EDR v2.2 Instructions: RT 603
December 2005
Span Scale (72). Report whether the test is for a high scale or low scale span value by
entering either "H", "L", or blank (for single range analyzer only) consistent with the scale
indicated in RTs 601.
Test Number (73). Report the test number used for the set of gas injections in the
corresponding set of RTs 601 (i.e.. for nine RTs 601 and three RTs 602). Do not leave
this field blank.
Reason for Test (75). Report the purpose of the test using one or more of the following
uppercase codes:
C Initial Certification
D Diagnostic
G Periodic Quality Assurance Test Performed in Grace Period
Q Periodic Quality Assurance
R Recertification
If more than one code applies, submit a two-letter code (for example, "RQ" for a linearity
check performed as a recertification test and to meet the quarterly linearity requirement).
Do not leave this field blank.
(3) RT 603: Flow Leak Check Results
Report in RT 603 all leak checks performed for differential pressure stack flow monitors. For
units or stacks for which you report data on a year-round basis, a leak check is required in each QA
operating quarter. If a calendar quarter is not a QA operating quarter, a leak check exemption for that
quarter may be claimed using RT 698. If a leak check is not completed by the end of the quarter in which
it is due, a 168 unit/stack operating hour grace period is allowed to complete the test (see RT 699
instructions).
For Subpart H units or stacks for which you report data only in the ozone season, leak checks are
required only during the ozone season (in the second and third calendar quarters), if those quarters
qualify as QA operating quarters. Note that for the second calendar quarter, only the unit operating
hours in the months of May and June are considered when determining whether that quarter is a QA
operating quarter (see § 75.74(c)(3)(iv)).
Do not report RT 603 for non-operating quarters.
Field Descriptions and Instructions
Status (24). Report the outcome of the test using the following uppercase codes:
F Fail
P Pass
Reason for Test (29). Report the purpose of the test using one or more of the following
uppercase codes:
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EDR v2.2 Instructions: RT 605
D Diagnostic
G Periodic Quality Assurance Test Performed in Grace Period
Q Periodic Quality Assurance
If more than one code applies, submit a two-letter code (for example, "DQ" for a test
performed as a diagnostic test and to meet the quarterly leak check requirement). Do not
leave this field blank.
(4) RT 605: Reference Data for Flow-to-load Ratio or Gross Heat Rate Evaluation
For units or stacks for which you report data on a year-round basis, this record type and its
companion RT 606 are required in each QA operating quarter (a quarter with > 168 unit or stack
operating hours), for units or stacks with flow monitoring systems. For a non-QA operating quarter, do
not report RT 605 or RT 606. Instead, report RT 698 to claim an exemption from the flow-to-load ratio
test for that quarter.
Units that do not produce electrical or steam load (e.g.. cement kilns) are exempted from the
requirement to perform flow-to-load testing.
For each primary and each redundant backup flow monitoring system, an evaluation of the flow-
to-load ratio or the gross heat rate (GHR) is required in each QA operating quarter. Only flow rate data
actually reported to EPA are to be included in the data evaluation. Do not analyze data recorded by
redundant backup flow monitors unless the data are reported in RT 220 as part of the official data record.
For Subpart H units or stacks for which you report data only in the ozone season, flow-to-load
ratio tests are only required during the ozone season. Therefore, for such units or stacks, report RTs 605
and 606 only for the second and third calendar quarters, if those quarters are QA operating quarters (see
§ 75.74(c)(3)(iii)).
In order to perform the quarterly flow-to-load or GHR evaluation, determine R,.ef, a reference
value of the flow-to-load ratio, or (GHR)ref, a reference value of the GHR. The value of R,.ef (or
(GHR)ref) is derived from data collected during a normal-load flow RATA. Update the baseline R,.ef or
(GHR)ref value each time that a normal-load flow RATA is conducted. RT 605 is used to report the
current value of R^ or (GHR)ref, derived from the results of the most recent normal load flow RATA.
When two load levels are designated as normal in RT 536, derive a separate reference flow-to-load ratio
or GHR value for each normal load level, and report the appropriate RT(s) 605 as described below in the
corresponding instructions for RT 606.
For common stacks, the reference flow-to-load ratio or GHR is derived from the stack flow rate
and the combined unit loads for the units serving the stack. Thus, report one RT 605 for each common
stack under the flow monitoring system associated with the common stack. For example, if CS1 is a
common stack serving Units 1 and 2, report one RT 605 for CS1 under the flow monitoring system ID
associated with common stack CS1.
For multiple stack configurations, you may determine the reference flow-to-load ratio or GHR on
a combined basis or an individual stack basis, Le^, either:
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EDR v2.2 Instructions: RT 605
December 2005
• Derive a single reference ratio or GHR value from the sum of the flow rates in the individual
stacks and the unit load, and report the reference value multiple times (i.e.. once under each
flow monitoring system ID associated with each of the stacks). For example, if MSI A and
MS1B are multiple stacks for Unit 1, report two RTs 605: one for multiple stack MS1A and
one for MS IB, under the flow monitoring system ID associated with each of the multiple
stacks; or
• Calculate a separate reference ratio for each stack at the time of the normal load flow RATA,
using the average reference method flow rate and the average unit load during the RATA. If
you used this method, report "S" in column 63 (see field description below).
Field Descriptions and Instructions
Monitoring System ID (10). Report the system ID of the flow monitoring system.
Reference Flow RATA End Date and Time (13, 21). Report the ending date and time
of the most recent passing normal load flow RATA for this monitoring system.
Test Number (25). Report the test number associated with the most recent passing
normal load flow RATA.
Average Gross Unit Load (27). Report Lavg, the average gross unit load during the most
recent normal load flow RATA (RT 610, column 64), in megawatts or 1000 lb/hr of
steam, as appropriate.
For common stacks, report the combined load for all units that were operating during the
RATA.
For multiple stack configurations, if you perform the flow-to-load test on an individual
stack basis, determine Lavg by summing the gross unit load values for all of the normal-load
flow RATA runs and dividing the result by the total number of RATA runs. If you
perform the flow-to-load test on a combined basis, determine Lavg by summing the gross
unit load values for all of the normal-load flow RATA runs and dividing the result by the
total number of RATA runs for all of the stacks (e.g.. for two 9-run RAT As performed on
stacks MSI and MS2, add the load values for all 18 RATA runs and divide the result by
18).
Operating Level (33). Report the operating load level during the most recent normal
load flow RATA (RT 611 column 116). Except for peaking units, the load level must be
"L", "M", or "H". For peaking units, the load level must be "N".
Average Reference Method Flow Rate During Reference Flow RATA (34). Report
the arithmetic mean of the flow rates (in scfh) measured by EPA Reference Method 2 (or
its allowable alternatives) during the most recent normal load flow RATA (RT 611,
column 48). For a multiple stack configuration, if you perform the test on a combined
basis, calculate the mean reference method flow rate for the unit by summing the mean
reference method flow rates measured during the flow RATAs at the individual stacks.
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EDR v2.2 Instructions: RT 606
Reference Flow/Load Ratio (44). If you used the flow-to-load methodology, calculate
and report R^, the reference value of the flow-to-load ratio, as follows. Divide the
average reference method flow rate from column 34 by the reference RATA load in
column 27 and multiply the result by 10"5. Round the ratio to two decimal places.
If you used the gross heat rate (GHR) methodology for the quarterly flow monitor
evaluation(s), leave this field blank.
Average Hourly Heat Input Rate During RATA (50). If you used the gross heat rate
(GHR) methodology, use the appropriate equation from Appendix F to Part 75 to
calculate (Heat Input)avg, the average hourly heat input during the most recent normal load
flow RATA. In the Appendix F equation, use the average hourly C02 concentration
recorded during the RATA test period and the average reference method flow rate from
column 34, above. Report this average hourly heat input rate, rounded to one decimal
place.
If you used the flow-to-load methodology for the quarterly flow monitor evaluations,
leave this field blank.
Reference Gross Heat Rate (GHR) Value (57). If you used the gross heat rate (GHR)
methodology, calculate and report (GHR)ref, the reference value of the gross heat rate, as
follows. Divide the average hourly heat input from column 50 by the reference RATA
load from column 27 and multiply the result by 1000. The units of the GHR will be either
Btu/kw-hr or Btu/lb of steam.
If you used the flow-to-load methodology for the quarterly flow monitor evaluations,
leave this field blank.
Separate Reference Ratios Calculated For Each Multiple Stack (63). If you have a
separate flow monitoring system at each multiple stack and elect to calculate separate
reference ratios for each stack, report "S". Otherwise, leave this field blank.
(5) RT 606: Quarterly Flow-to-load Ratio or Gross Heat Rate Check
This record type is required only for units or common stacks with flow monitoring systems. RT
606 summarizes the results of the quarterly flow-to-load ratio or gross heat rate quality assurance test
required under Section 2.2.5 of Appendix B to Part 75. Submit RT 606 only for QA operating quarters.
For a non-QA operating quarter, do not report RT 606. Rather, report RT 698 to claim an exemption
from the flow-to-load ratio test for that quarter.
Units that do not produce electrical or steam load (e.g.. cement kilns) are exempted from the
requirement to perform flow-to-load testing.
For units or stacks for which you report data on a year-round basis, submit one RT 606 for each
QA operating quarter, for each primary flow monitoring system and for each redundant backup flow
monitoring system. For Subpart H units or stacks for which you report data only in the ozone season,
report RTs 606 only for the second and third calendar quarters, if those quarters are QA operating
quarters.
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December 2005
Note that for multiple stack configurations, if you elect to perform the data analysis on a
combined basis, rather than for each individual stack, you will obtain only a single test result, since the
flow-to-load ratio or GHR analysis is done at the unit level, not at the stack level. Therefore, you must
report this same test result multiple times (i.e.. once under each flow monitoring system ID associated
with each of the multiple stacks).
When two load levels are designated as normal in RT 536, perform the quarterly flow-to-load
ratio or GHR evaluation at the higher load level if sufficient data are available for the analysis.
Otherwise, perform the evaluation at the lower load level. If the test is performed at the higher load
level, report RTs 605 and 606 only for that load level. If there are insufficient data available at the higher
load level and the test is done at the lower load level, report RTs 605 and 606 for both load levels,
indicating a test result of "P" or "F" (as appropriate) for the lower load level in column 25 of RT 606, and
indicating a test result of "E" or "N" (as appropriate) for the higher load level in column 25 of RT 606. If
there are insufficient data at both load levels, report RTs 605 and 606 for both load levels, indicating a
test result of "E" or "N" (as appropriate) for both load levels in column 25 of RT 606.
For rectangular stacks or ducts with installed flow monitors, when you apply a wall effects
adjustment factor (WAF) to the data from the flow monitor, the WAF is entered into the programming of
the flow monitor as a correction to the stack or duct cross-sectional area. As soon as the wall effects
correction is applied, the measured stack gas flow rates at a given load level will decrease, possibly by 5
percent or more. This reduction in the reported flow rates may adversely impact the quarterly flow-to-
load (Q/L) ratio test, and may even cause a test failure, if the data from the most recent normal load flow
RATA (i.e.. the RATA on which the reference Q/L ratio is based) were not corrected for wall effects.
Note that this effect is only temporary, and will disappear when the next normal load flow RATA is done
and the appropriate WAF is applied to the reference method data. However, in the interim period while
the effect is still present, EPA recommends the following:
• Report the reference flow-to-load ratio information in RT 605 in the usual manner. Do not
attempt to make any adjustment to the reference method flow rate data recorded during the
previous normal load RATA.
• Perform the quarterly flow-to-load ratio test in the usual manner and assess the impact of the
wall effects adjustment that was applied to the stack flow rates.
— If the test is passed, report the results in RT 606, in the usual manner.
— If the test is failed, you may copy your quarterly flow rate data, export it outside the
DAHS environment, and remove the wall effects correction from each hourly flow rate, by
dividing it by the WAF. Then, re-run the flow-to-load analysis. Report the results of the
test in RT 606 and put a note in RT 9101 indicating that the WAF was removed from the
flow rate data before running the flow-to-load ratio test. Keep the results of the data
analysis on-site, in a format suitable for inspection.
• In your quarterly EDR, you must report the wall effects-adjusted flow rates in columns 29 and
39 of RT 220, as measured by your flow monitor and as recorded by your DAHS, whether or
not you remove the WAF from the flow rate data to perform the flow-to-load ratio test.
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EDR v2.2 Instructions: RT 606
Field Descriptions and Instructions
Monitoring System ID (10). Report the system ID of the flow monitoring system on which
the flow-to-load ratio or GHR test is performed.
Calendar Quarter and Year (13). Report the quarter and year for which the flow-to-load
ratio or GHR data analysis is performed (this will be the same as the quarter and year reported
in RT 100).
Test Basis Indicator (18). Report whether you used the flow-to-load or gross heat rate
methodology for the quarterly data analysis using the following uppercase codes:
H Gross Heat Rate
Q Flow-to-load Ratio
Leave this field blank if you report a results code of "E" or "N" in column 25.
Bias Adjusted Flow Rates Used (19). Report whether bias-adiusted flow rate values have
been used in the quarterly flow-to-load ratio data analysis ("Y" or "N"). All flow-to-load
ratios or GHRs must be calculated in a consistent manner (i.e.. using unadjusted flow rates in
all calculations or using bias-adjusted flow rates in all calculations).
Do not leave this field blank unless you report a results code of "E" or "N" in column 25.
Average Absolute % Difference Between Reference Ratio (or GHR) and Hourly Ratios
(or GHR Values) (20). Report the value of Ef, which is the arithmetic average of the
absolute percent differences between the reference flow-to-load ratio (or reference GHR) and
the individual hourly flow-to-load ratios (or hourly GHRs) used in the data analysis. Leave
this field blank if you report a results code of "E" or "N" in column 25.
Result (25). If, for a particular flow monitor, the value of Ef is within the applicable limit in
Section 2.2.5 of Appendix B to Part 75, report the result as "P" (pass).
If Ef is not within the applicable limit, report the result as "F" (fail).
Report the result as "N" if a flow-to-load analysis is not required for the monitoring system
because there were fewer than 168 hours of quality-assured flow rate data recorded by the
monitoring system during the quarter at loads within ±10% of Lavg (the average load during
the most recent normal load flow RATA). A test result of "N" may be due to infrequent unit
operation or infrequent usage of a flow monitoring system (e.g.. a redundant backup flow
monitoring system which is used for less than 168 hours in a quarter).
Report the test result as "E" if fewer than 168 hours of quality-assured flow rate data remain
for analysis, after excluding hourly flow rate data from the analysis for the allowable reasons
described in columns 30 through 53 of RT 606.
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EDR v2.2 Instructions: RT 606
December 2005
Number of Hours Used in Quarterly Flow-to-load or GHR Analysis (26). Report the
number of hours of quality-assured flow rate data that were used for the flow-to-load or GHR
evaluation of the flow monitoring system. A minimum of 168 hours of quality-assured flow
rate data are required. Leave this field blank or report zero if you report a results code of "E"
or "N" in column 25.
Number of Hours Excluded for Different Type of Fuel (30). Report the number of hours
(if any) of flow rate data excluded from the flow-to-load or GHR analysis because the fuel
combusted was different than the fuel combusted during the reference flow RATA. A fuel is
considered different if it is in a different state of matter (solid, liquid, or gas) from the fuel
burned during the RATA or if the fuel is a different classification of coal (e.g.. bituminous
versus sub-bituminous). Also, for units that co-fire different types of fuel, if the reference
RATA was done while co-firing, then hours in which a single fuel was combusted may be
excluded from the data analysis (and vice-versa for co-fired hours, if the reference RATA was
done while combusting only one type of fuel). Leave this field blank or report zero if you are
not claiming any excluded hours for this reason or if you report a results code of "N" in
column 25.
Number of Hours Excluded for Load Ramping Up or Down (34). Report the number of
hours (if any) of flow rate data excluded from the data analysis because of ramping (i.e.. the
hourly load differed by more than ±15% from the load during the previous or subsequent
hour). Leave this field blank or report zero if you are not claiming any excluded hours for this
reason or if you report a results code of "N" in column 25.
Number of Hours Excluded for Scrubber Bypass (38). For units with wet scrubbers,
report the number of hours (if any) of flow rate data excluded from the data analysis because
the scrubber was entirely bypassed. Leave this field blank or report zero if you are not
claiming any excluded hours for this reason or if you report a results code of "N" in column
25.
Number of Excluded Hours Preceding a Normal Load Flow RATA (42). If a normal load
flow RATA of the monitoring system was performed and passed during the quarter, you may
exclude all flow rate data recorded by the monitoring system prior to completion of the RATA
from the flow-to-load or GHR analysis. Report the number of hours (if any) of flow rate data
excluded for this reason. Leave this field blank or report zero if you are not claiming any
excluded hours for this reason or if you report a results code of "N" in column 25.
Number of Excluded Hours Preceding a Successful Diagnostic Test, Following a
Documented Monitor Repair, or Following a Major Component Replacement (46). If a
documented repair or major flow monitor component replacement occurred during the quarter
to correct a problem with the flow monitoring system accuracy, and if a subsequent
abbreviated flow-to-load test was passed in accordance with Section 2.2.5.3 of Appendix B to
Part 75 to verify that the monitoring system was generating accurate data, you may exclude all
flow rate data recorded by the monitoring system prior to completion of the abbreviated flow-
to-load test from the flow-to-load or GHR analysis. Report the number of hours (if any) of
flow rate data excluded for this reason. Leave this field blank or report zero if you are not
claiming any excluded hours for this reason or if you report a results code of "N" in column
25.
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EDR v2.2 Instructions: RT 610-611
Number of Hours Excluded for Flue Gases Discharging Simultaneously Through a
Main Stack and Bypass Stack (50). For a unit with a main stack and a bypass stack (e.g.. a
unit with a wet scrubber), report the number of hours (if any) of flow rate data excluded from
the flow-to-load or GHR analysis because flue gases were flowing through both stacks
simultaneously. Leave this field blank or report zero if you are not claiming any excluded
hours for this reason or if you report a results code of "N" in column 25.
(6) RTs 610 and 611: Relative Accuracy Test Audit (RATA) and Bias Test Data
and Results
Report the results of all relative accuracy tests performed for initial certification, recertification or
ongoing quality assurance using RTs 610 and 611. RT 610 reports the results of each run. RT 611
reports the relative accuracy for the load level. Follow the rounding conventions discussed in Section
II.C.(7)(d).
For units or stacks for which you report data on a year-round basis, for routine quality assurance,
a RATA of each CEMS is required either semiannually (i.e.. once every two QA operating quarters) or
annually (i.e.. once every four QA operating quarters), depending on the relative accuracy percentage
obtained in the previous RATA. If a calendar quarter is not a QA operating quarter, a RATA deadline
extension of one quarter may be claimed. Part 75 also allows extension of S02 RATA deadlines based on
the type of fuel combusted during the quarter and provides conditional RATA exemptions in certain
instances. (Refer to the RT 697 instructions for details.) If a required RATA is not completed by the end
of the quarter in which it is due, a 720 unit/stack operating hour grace period is allowed to perform the
test. To claim a grace period for a missed RATA, follow the applicable instructions under RT 699.
For Subpart H units or stacks for which you report data only in the ozone season, RAT As must
be performed to quality-assure the NOx mass emissions data recorded in the ozone season. Note that the
QA operating quarter method of determining RATA deadlines and data validation status does not apply
to these units or stacks. Instead, a successful RATA resulting in a semiannual (or annual) frequency
validates data from a CEMS for two (or four) calendar quarters (not QA operating quarters) following
the quarter in which the RATA is passed (see §§ 75.74(c)(2)(ii)(F) and (G) and § 75.74(c)(3)(vii)). The
RATA grace period provisions in Section 2.3.3 of Appendix B also do not apply to these units or stacks.
However, a grace period is conditionally allowed within the ozone season, when the data validation
window from the previous RATA has expired prior to the start of the current ozone season (see
§ 75.74(c)(2)(ii)(H)). To claim this grace period, follow the applicable instructions under RT 699.
Report the results of all completed and aborted RAT As which affect data validation. For Subpart
H units or stacks for which you report data only in the ozone season, report the results of all pre-ozone
season RAT As which affect data validation in the current ozone season, in the quarterly report for the
second calendar quarter of the current year (or in the third quarter report, if the second quarter is a non-
operating quarter).
An aborted test is a RATA which is discontinued due to a monitor failure and is treated as a failed
test. The results of aborted RATAs must be reported, with one exception. For ozone season-only
reporters, an aborted pre-ozone season RATA need not be reported if a subsequent RATA is passed
prior to the start of the current ozone season. For an aborted RATA, report only RTs 610, using a run
status flag of "9" in column 62 for each run. Do not report RT 611 for an aborted RATA.
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It is not necessary to report or to treat as a failed test, a RATA which is discontinued because of a
failure which is unrelated to instrument performance, such as a power outage, unit outage, unit stability
problems or reference monitor failure. Also do not report the results of trial RATA runs that are part of
the process of optimizing the performance of a monitor, when the injections meet the acceptance criteria
in § 75.20(b)(3)(vii)(E). For trial runs that do not affect data validation, record the results as part of the
official test log and maintain records on-site (or at an alternative location known to the regulatory agency
if on-site storage is not feasible).
Field Descriptions and Instructions for RT 610
Monitoring System ID (10). Report the system ID. The monitoring system ID is an
essential identifier for this record type. Relative accuracy tests are performed and reported
only on a system basis. For example, the relative accuracy test for a NOx-diluent monitoring
system is performed only on a lb/mmBtu basis, not on an individual component basis.
Run Start and End Date and Time (13, 19, 23, 29). Report the precise start and end time
for each individual run. Run times must not overlap.
Units of Measure (33). Report the units of measure in which the run results are reported
using one of the following codes:
1 ppm
2 lb/mmBtu
3 scfh (wet basis)
4 %C02
5 %02
7 %H20
Value from CEM System Being Tested (34). Report the measured value from the
monitoring system being tested in the appropriate units for the run. Report these values to the
same precision as is required for hourly data in the EDR (i.e.. to the nearest 0.1 ppm, 0.1%
C02, 02, or H20, 0.001 lb/mmBtu or 1000 scfh, as applicable).
For flow monitors installed on rectangular stacks or ducts, if you are using Conditional Test
Method CTM-041 to apply a correction for wall effects, the reference method and flow
monitor run values reported in RT 610 will be wall effects-adjusted flow rates.
Value from Reference Method, Adjusted as Necessary for Moisture and/or Calibration
Bias (47). Report the measured value from the reference method monitor to which the
monitoring system is being compared. This value should reflect adjustment, as necessary, for
moisture and/or calibration bias. Also report these values to the same precision as required
for hourly data.
For flow monitors installed on rectangular stacks or ducts, if you are using Conditional Test
Method CTM-041 to apply a correction for wall effects, the reference method values reported
in RT 610 will be wall effects-adjusted flow rates.
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Run Number (60). Assign and report a run number to each measurement, beginning with the
number " 1" for each load level. Because all runs must be reported whether or not they are
used to calculate the relative accuracy test, run numbers must be consecutive and in
chronological order. Do not skip a run number.
RATA Run Status Flag (62). Report whether the run data were used to determine relative
accuracy using one of the following codes:
0 Run Not Used in RATA Calculation
1 Run Used in RATA Calculation
9 Test Aborted
The code "9" was originally defined under the Acid Rain Program to indicate a test which was
not used (either because the test was aborted or because a more favorable RATA result was
obtained on a subsequent attempt). This code is no longer allowed for completed RATAs.
The use of code "9" is reserved exclusively for aborted tests. Report all completed RATAs,
whether passed or failed, using only run status flags of "1" or "0".
Operating Level (63). Report the load level at which the relative accuracy test was
performed. For RATAs of monitoring systems installed on peaking units, report "N" in this
field. For all other RATAs, use only the letters "L", "M", and "H" to indicate the operating
level.
Use one of the following uppercase codes:
L Low
M Mid
H High
N Normal (for peaking units only)
Gross Unit Load or Average Velocity at Operating Level (64). For load-based units,
report the load level in megawatts or steam load during each RATA run. The units for this
value (either megawatts or steam in 1000 lb/hr) should be consistent with the units used to
define load levels in RT 535 of the monitoring plan.
For units that do not produce electrical or steam load (e.g.. cement kilns, refinery process
heaters, etc.), report the average stack gas velocity at the operating level being tested. To
determine the appropriate average velocity, first divide the range of operation (which is
defined in RT 536 in terms of stack gas velocity) into low, mid and high operating levels, as
described in section 6.5.2.1 (b) of Appendix A. Then, report the velocity at the midpoint of
the tested level for each of the RATA runs (e.g.. if the RATA is done at the "high" operating
level and the high level extends from 40 to 60 ft/sec, report 50 ft/sec as the average velocity
for each RATA run.
Do not leave this field blank and do not report zero in this field.
Test Number (70). Assign and report a test number to each set of relative accuracy runs
which comprise a relative accuracy test. For all runs associated with all load levels of a multi-
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load flow or heat input RATA, assign and report a single, unique test number for the set of
test records.
For example, assign the test number "1" to a normal load relative accuracy test for a NOx-
diluent system. If this test is aborted or fails and a new test is subsequently passed, assign the
test number "2" to the successful second test. For test number "2" there will be a minimum of
nine RTs 610 (one for each run) and one RT 611 (with the test result).
For a 2-load flow RATA or a 3-load flow RATA assign the same test number to all the low,
mid and high level runs (as applicable) of the test in RT 610 and assign this same test number
to the corresponding RTs 611 that represent the results for each load level. For example, if a
3-load RATA was performed at low, mid and high load levels, a test number of" 1" is
assigned. Each RATA run at each of the three load levels will therefore have a test number of
" 1". The corresponding RT 611 for each of the three load levels will also have a test number
of" 1". The test number links together the three-load levels as a single "test". The test
number also (when used in conjunction with the operating level) distinguishes each set of
load-specific runs within the 3-load RATA.
You may use the same test number (e.g.. "1") for RAT As of different monitoring systems in
the same calendar quarter.
You may reuse the test number for the same monitoring system, provided that the tests are
performed and reported in different quarters and files.
If you submit data for an incomplete, aborted test, assign and report a unique test number to
the set of reported RTs 610.
If you submit hardcopy information on this test in a certification or recertification report or
submit other information about the test to EPA or a State agency, refer to the monitoring
system ID, the test number, and test time period.
Do not leave this field blank.
Field Descriptions and Instructions for RT 611
Monitoring System ID (10). Report the same monitoring system ID submitted in RT 610
for the test. Do not leave this field blank.
RATA End Date and Time (13,19). Report the date and time of completion of the last run
performed as part of the test, whether or not the run was used in the calculation.
Reference Method Used (23). Report the primary reference method(s) used to determine
relative accuracy, using the codes below. Enter only one code per RATA.
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Reference Methods
(1) For gas monitoring system RAT As in which a single primary reference method from
Appendix A of 40 CFR 60 is used (i.e.. for RATAs of S02, C02, or NOx
concentration monitoring systems, RATAs of 02 monitoring systems or moisture
monitoring systems), report the number and letter associated with the primary
reference method.
For gas monitoring system RATAs in which two primary reference methods are used
(i.e.. for NOx-diluent monitoring system RATAs), indicate the numbers and letters of
the two primary methods, separated by a comma. Do not leave any blank spaces
between the alphanumeric characters in the code.
Code Commonly Used RATA Method(s)
6C
S02 RATA Using RM 6C
7E
NOx Concentration System RATA Using RM 7E
3A
C02 or 02 Monitoring System RATA Using RM 3 A
4
Moisture Monitoring System RATA Using RM 4
7E,3A
NOx-diluent Monitoring System RATA Using RM 7E and RM 3 A
20
NOx RATA Using RM 20
For flow RATAs use one of the following uppercase codes (no other codes are
acceptable):
Code
Commonly Used RATA Method(s)
2
Method 2, Without Wall Effects Adjustment
M2H
Method 2, With Measured Method 2H Wall Effects Adjustment
D2H
Method 2, With Default Method 2H Wall Effects Adjustment
2F
Method 2F, Without Wall Effects Adjustment
2G
Method 2G, Without Wall Effects Adjustment
2FH
Method 2F, With Method 2H Wall Effects Adjustment (either
measured or default)
2GH
Method 2G, With Method 2H Wall Effects Adjustment (either
measured or default)
2J
Method 2, with WAF (either measured or default) from Conditional
Test Method CTM-041
2FJ
Method 2F, with WAF (either measured or default) from
Conditional Test Method CTM-041
2GJ
Method 2G, with WAF (either measured or default) from
Conditional Test Method CTM-041
Units of Measure (34). Report the units of measure in which the run results are reported
using one of the following codes.
1 ppm
2 lb/mmBtu
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3 scfh
4 %C02
5 %02
7 %H20
Units of measure reported in RTs 611 must be consistent with the units reported for the test in
RTs 610.
RATA Calculation Fields (35 through 110). Report the results of the relative accuracy test
and interim values, as required and defined for the appropriate test method and in Part 75,
Appendix A.
Bias Adjustment Factor at this Load Level (111). For each passed RATA report the bias
adjustment factor (BAF) at each load level tested, as described below. Leave this field blank
if the RATA is failed.
Load-level BAFs for Single-load RATAs:
(1) For RATAs of C02, 02, or H20 monitoring systems, always report a BAF of 1.000,
since a bias test is not required for these systems.
(2) For RATAs of S02 and NOx monitoring systems and for single-load flow RATAs,
report 1.000 in this field if the bias test is passed and report the calculated BAF if the
bias test is failed.
(3) For a unit that qualifies as a low emitter of S02 or NOx (see Appendix B to Part 75,
Section 2.3.1.2, paragraphs (e) and (f)), if the calculated BAF exceeds 1.111, you
may either report the calculated BAF or a default value of 1.111 as the bias
adjustment factor report the BAF that will actually be applied to the S02 or NOx
emissions data. That is, report either the calculated BAF or a default BAF of 1.111,
whichever will be used in the emission calculations (see Section 7.6.5 of Appendix A
to Part 75).
Load-level BAFs for a Multiple-load Flow RATA: Determine the appropriate BAF for
each tested load level, as follows:
(1) For simplicity, EPA recommends that you perform a bias test and determine a BAF at
all load levels tested. If you choose this option, report a load-level BAF of 1.000 if
the bias test is passed and report the calculated load-level BAF if the bias test is
failed.
(2) If you do not choose option (1) above, the minimum bias test and BAF reporting
requirements are as follows:
• Perform a bias test at each tested load level ("L", "M", or "H") which is designated
as a normal load in RT 536;
• If the bias test is passed, report a BAF of 1.000 for the load level;
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• If a bias test is failed at any designated normal load, you must determine and report
the load-level BAFs for the two most frequently-used load levels (as specified in
RT 536, column 22).
Operating Level (116). Report the load level as "H", "M", "L", or "N", consistent with the
load level reported in RT 610, column 63.
Average Gross Unit Load (or Average Velocity at Operating Level) (117). For load-based
units, report the average gross unit load in megawatts or steam load for all runs
used in the relative accuracy calculation for this load level. For units that do not produce
electrical or steam load, report the average velocity in ft/sec at the tested operating level (see RT
610, column 64 instructions).
Indication of Normal Load (or Operating Level) (127). If a peaking unit is being tested,
leave this field blank. Otherwise, if the load (or operating) level (i.e.. "L", "M", or "H") at which
the RATA is performed is designated as a normal load in column 25 or 26 of RT 536, report
"N" in this field. This applies to both gas and flow RATAs. If the load (or operating) level
being tested is not designated as normal in RT 536, leave this field blank.
Alternative Performance Specification (APS) Flag (128). Report "0" for relative accuracy
based on a determination of relative accuracy as a percentage of the mean of the reference
method (RM) value. Report a " 1" for relative accuracy determined by taking the absolute value
of the difference between the RM and CEM mean values. The alternative relative accuracy
specifications apply only to: (1) low-emitting S02 and NOx monitoring systems; (2) C02 and 02
monitoring systems; and (3) moisture monitoring systems.
Test Number (129). Report the test number assigned for this test, consistent with the
instructions for RT 610.
Reason for RATA (131). Report the purpose of the test using one or more of the following
uppercase codes:
C Initial Certification
D Diagnostic
G Periodic Quality Assurance Test Performed in Grace Period
Q Periodic Quality Assurance
R Recertification
If more than one code applies, submit a two-letter code (e.g.. "RQ" for a RATA test performed
as a recertification test and to meet the annual RATA requirement, "QD" to indicate that a test is
performed both for routine quality assurance and as a diagnostic). Do not leave this field blank.
Number of Load (or Operating) Levels Comprising Test (133). Report for all tests the
number of load (or operating) level tests which are required for a successful RATA. For gas
RATAs, report "1". For flow RATAs, report "1", "2", or "3", as appropriate. Do not leave this
field blank.
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EDR v2.2 Instructions: RT 614-616
December 2005
System Bias Adjustment Factor for a Multiple-load (Multiple-Level) Flow RATA (134).
This field applies only to multiple-load (or multiple-level) flow RATAs. If the flow monitoring
system passed the relative accuracy test at all tested load (or operating) levels, report the BAF
that will be applied to the subsequent data reported from the monitoring system. Determine the
system BAF as follows:
1. Report a system BAF of 1.000 if the bias test was passed at all load (or operating) levels
designated as normal (see column 111 instructions, above); or
2. Report the higher of the two BAFs calculated at the two most frequently used load (or
operating) levels (as defined in RT 536, column 22), if the bias test was failed at any
designated normal load (or operating) level.
If the monitoring system failed the relative accuracy test at any load (or operating) level or if you
performed only a single-load (or single-level) flow RATA for the system, leave this field blank.
(7) RTs 614, 615, 616, and 617: Reference Method Supporting Data for Flow
RATA Tests
As described in detail in the paragraphs below, RATA support records 614 through 617 are
required only for flow RATAs in which: (1) Method 2F or 2G is used, without adjustment for wall
effects; or (2) Method 2F or 2G is used, with adjustment for wall effects, either in accordance with
Method 2H or Conditional Test Method CTM-041; or (3) the stack is circular, Method 2 is used, and a
calculated wall effects adjustment factor is determined by direct measurement using Method 2H and
applied to each test run; or (4) the stack or duct is rectangular, Method 2 is used, and a calculated or
default wall effects adjustment factor is determined by direct measurement using CTM-041 and applied to
each test run.
For Methods 2F and 2G, submit RT 614 and 615 only for the test runs that are actually used to
calculate relative accuracy (i.e.. runs flagged with a "1" in RT 610, column 62). One RT 614 is required
per test run and one RT 615 is required for each Method 1 traverse point in each test run. For multi-load
flow RATAs, submit RTs 614 and 615 for each load level tested.
For regular Method 2 (circular stacks), submit RT 614 and 615 only for the run(s) in each flow
RATA that are used to derive a calculated wall effects adjustment factor. One RT 614 is required for
each of those runs and one RT 615 is required for each Method 1 traverse point in each of those runs.
For multi-load flow RATAs, submit the required RTs 614 and 615 for each load level at which a
calculated wall effects adjustment factor is determined.
Submit RT 616 only for flow RATAs at circular stacks in which regular Method 2 is used and a
default wall effects adjustment factor (WAF) from Method 2H is applied to each test run. For multi-load
flow RATAs, submit one RT 616 for each load level at which the default WAF is applied.
Submit RT 617 only for flow RATAs at rectangular stacks or ducts in which regular Method 2 is
used and a default or calculated wall effects adjustment factor (WAF) from Conditional Test Method
CTM-041 is applied to each test run. For multi-load flow RATAs, submit one RT 617 for each load level
at which the WAF is applied.
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The reporting requirements for RTs 614, 615, and 616 are summarized in Table 37, and the
requirements for RT 617 are summarized in Table 3 7A.
Table 37
SUMMARY OF EDR REPORTING REQUIREMENTS FOR
RECORD TYPES 614, 615, and 616
C ase
No.
Case
Description
Reference
Melhod(s) I sell
Reference
Method C ode
RT 611: 23
Required KI)R Record Types
610/611
6I4/6I51
616
1
Method 2, with
no wall effects
adjustments
2
2
Y
N
N
2
Method 2 with
default WAF
2 and 2H
D2H
Y
N
Y
3
Method 2 with
calculated WAF
2 and 2H
M2H
Y
Y**
N
4
Method 2F, with
no wall effects
adjustments
2F
2F
Y
Y
N
5
Method 2F with
calculated or
default WAF
2F and 2H
2FH
Y
Y
N
6
Method 2G, with
no wall effects
adjustments
2G
2G
Y
Y
N
7
Method 2G with
calculated or
default WAF
2F and 2H
2GH
Y
Y
N
* When RTs 614 and 615 are required, report them only for RATA runs that are used in the relative accuracy
calculations (i.e.. run status flag in RT 610:62 = "1").
** For reference method code "M2H," report RTs 614 and 615 for a particular RATA run only if the run is both
used in the relative accuracy calculations (i.e.. run status flag in RT 610:62 = "1") and used to derive a
calculated WAF.
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Table 37A
FLOW RATA SUPPORT RECORDS
(Rectangular Stacks or Ducts, with Wall Effects Adjustment)
Test Method I sed
Reference Method
Code RT 611: 23
Required KI)R Record Types
610/611
614/615-
616
617
Method 2 with calculated or
default WAF from CTM-041
2J
Y
N
N
Y
Method 2F with calculated or
default WAF from CTM-041
2FJ
Y
Y
N
N
Method 2G with calculated
or default WAF from CTM-
041
2GJ
Y
Y
N
N
* When RTs 614 and 615 are required, report them only for RATA runs that are used in the relative accuracy
calculations (i.e.. run status flag in RT 610:62 = "1").
Field Descriptions and Instructions for RT 614 (Run Level Data)
Monitoring System ID (10). Report the system ID for the flow monitoring system (from
RT 510 of the monitoring plan) being tested for relative accuracy.
Test Number (13). Report the same test number as for the corresponding RT 610 for the
test run.
Operating Level (15). Report the same operating level as in the corresponding RT 610
for the test run.
Run Number (16). Report the same run number as in the corresponding RT 610.
Run Start and End Date and Time (18, 26, 30, 38). Report the same run starting and
ending date(s) and time(s) as reported in the corresponding RT 610.
Flow Rate Reference Method(s) Used (42). Report one of the following uppercase
codes to indicate which flow rate reference method(s) from Appendix A to 40 CFR Part
60 were used for the test.
2F Method 2F, Without Wall Effects Adjustment
2G Method 2G, Without Wall Effects Adjustment
2FH Method 2F, With Method 2H Wall Effects Adjustment (either measured or
default)
2GH Method 2G, With Method 2H Wall Effects Adjustment (either measured or
default)
M2H Method 2, With Measured Method 2H Wall Effects Adjustment
2FJ Method 2F, With WAF (either measured or default) from Conditional Test
Method CTM-041
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2GJ Method 2G, With WAF (either measured or default) from Conditional Test
Method CTM-041
This code must be the same as the codes submitted in column 23 of RT 611. Note that
codes "2" and "2J" and "D2H" do not appear on the list above. Reporting of RT 614 is
not required for those method codes.
Number of Traverse Points (45). Report the number of Method 1 traverse points used
for the test run. If Method 2H is used to calculate a wall effects adjustment factor from
the test data for this run, the number of traverse points must be at least 16.
Barometric Pressure (47). Report the barometric pressure, in inches of mercury, for the
test run.
Stack Static Pressure (52). Report the stack static pressure, in inches of water, for the
run. If Pg is negative, include the minus sign. Note that there is a "floating" decimal point
in this field, to allow you to report negative pressures less than -9.9 inches of water. That
is, you may report negative static pressures to one decimal place instead of two (e.g.. -
15.1 in. H20).
% C02/02 in Stack Gas, Dry Basis and C02/02 Reference Method (57, 62, 67).
Report the dry-basis %C02 and %02 in the stack gas for the test run, in columns 57 and
62, respectively. Report in column 67 which reference method, 3 or 3 A, was used to
measure the diluent gas concentrations.
% Moisture in Stack Gas (71). Report the stack gas moisture percentage for the test
run.
Stack Gas Wet and Dry Molecular Weight (76, 81). Report the molecular weight of
the stack gas for the test run, on both a dry basis (column 76) and a wet basis (column
81). Use Equation 3-1 in Method 3 to calculate Md and Equation 2-6 in Method 2 to
calculate Mg.
Stack Diameter at Test Port Location (86). Report the stack diameter in feet at the test
port location. For rectangular stacks or ducts, report the equivalent diameter, calculated
as follows: determine the actual cross-sectional area of the rectangular duct, in ft2; set this
area equal to the area of a circle, (1/4 tt d2); and solve for "d," the equivalent circular
diameter (ft).
Stack or Duct Cross-sectional Area at Test Port (91). Report the cross-sectional area
of the stack or duct in square feet at the test port location. For a rectangular stack or
duct, report the actual cross-sectional area — do not adjust the area for wall effects.
Average Velocity for Run, Not Accounting for Wall Effects (97). Report the average
velocity for the test run in feet per second, without considering wall effects. The
calculated average run velocity is the arithmetic average of the calculated point velocities
at the Method 1 traverse points (i.e.. the average of all of the velocity values reported in
RT 615, column 81 for this test run).
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Average Velocity for Run, Accounting for Wall Effects (103). If the stack is circular
and a wall effects adjustment factor (WAF) is to be derived using the data from this test
run, report the average run velocity, considering wall effects. Calculate this value using
the appropriate point velocity values from RT 615, columns 81 and 87, in Equation 2H-17
of Method 2H. If no wall effects adjustment factor is to be derived from the run data,
leave this field blank. Also leave this field blank if the stack or duct is rectangular.
Calculated Wall Effects Adjustment Factor (WAF) Derived from this Run (109). If
the stack is circular and test data from this run are used to derive a wall effects adjustment
factor (WAF) in accordance with Equation 2H-19 of Method 2H, calculate the WAF by
dividing the adjusted velocity value in column 103 by the unadjusted velocity value in
column 97 and report the result in column 109.
If the test data from this run are not used to derive a WAF, leave this field as blank or
zero. Also leave this field blank if the stack or duct is rectangular.
Report the calculated WAF result in this field even if a default WAF is applied to this run.
Calculated or Rectangular Duct WAF Applied to All Runs of This RATA (115). For
circular stacks, if no wall effects adjustment is applied to the test runs of this RATA or if a
default is WAF applied, leave this field as blank or zero. Otherwise, report the value of
the calculated WAF applied to this test run and to all of the other runs of this RATA. The
term "WAF" is defined in sections 12.2, 12.7.1, and 12.7.2 of Method 2H as "the wall
effects adjustment factor that is applied to the average velocity, unadjusted for wall
effects, in order to obtain the final wall effects-adjusted stack gas velocity...." Therefore,
WAF may be either a default value (as discussed in the column 121 instructions), a WAF
calculated from a single run (as discussed in the column 109 instructions), or an average
value calculated from multiple single-run WAFs.
Note the following instances in which a WAF value reported in column 109 must be
adjusted upward before using it to determine WAF: (1) If a WAF reported in column 109
is less than 0.9800 and was derived from a partial wall effects traverse (according to
Section 8.2.2 of Method 2H), adjust the WAF value upward to 0.9800; and (2) If a WAF
reported in column 109 is less than 0.9700 and was derived from a complete wall effects
traverse (according to Section 8.2.3 of Method 2H), adjust the WAF value upward to
0.9700.
For rectangular stacks or ducts, if no wall effects adjustment is applied to the test runs of
this RATA, leave this field blank. Otherwise, report to four decimal places the WAF
(either measured or default) that is being applied to all runs of this RATA. The WAF
reported in this field must equal the WAF reported in RT 532, column 20.
Default WAF Applied to All Runs of This RATA (121). For circular stacks, if a default
WAF is applied to this test run and to all of the other runs of this RATA, report the
appropriate value from Method 2H. For brick and mortar stacks, use a default WAF of
0.9900. For all other stacks, use a default WAF of 0.9950. If no wall effects adjustment is
applied to the test runs of this RATA or if a calculated WAF is applied, leave this field as
blank or zero. Also leave this field blank if the stack or duct is rectangular.
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EDR v2.2 Instructions: RT 614-616
Average Stack Flow Rate, Wet Basis, Adjusted if Applicable for Wall Effects (127).
Report the average stack gas flow rate for the test run, in scfh (wet basis). If wall effects
are not considered, calculate the average flow rate according to the applicable equation in
Method 2, 2F or 2G, using the unadjusted average run velocity from column 97 of this
record in the calculations. If the stack is circular and wall effects adjustments are applied,
however, first obtain the wall effects-adjusted average velocity by multiplying the
calculated WAF from column 115 or the default WAF from column 121 of this record (as
appropriate) by the unadjusted average velocity in column 97, in accordance with
Equation 2H-21 of Method 2H. Then, following the provisions of section 12.7 in Method
2H, use the final wall effects-adjusted velocity, obtained from Equation 2H-21, in the
applicable equation from Method 2, 2F, or 2G to calculate the wall effects-adjusted stack
gas flow rate and report this adjusted flow rate in column 127. The flow rate value
reported in column 127 must match the flow rate reported for this test run in RT 610,
column 47.
For a rectangular stack or duct, if Conditional Test Method CTM-041 is used to
determine a WAF, calculate the average stack gas flow rate (in scfh), adjusted for wall
effects, using the following equation:
Qavg = 3600 (AJ (vavg) (WAF) (Tstd/Ts) (Ps/Pstd)
Where:
Qavg = Average stack gas flow rate for the run, adjusted for wall effects, wet basis (scfh)
\ = Stack or duct cross-sectional area at the test location, from column 91 (ft2)
vavg = Average stack gas velocity for the run, not accounting for wall effects, from
column 97 (ft/sec)
WAF = Wall effects adjustment factor, from column 115
Ts = Average stack temperature (°R)
Tstd = Standard temperature (528 °R)
Ps = Stack pressure, Le^, sum of barometric and static pressures (in. Hg)
Pstd = Standard pressure (29.92 in. Hg)
3600 = Conversion factor (sec/hr)
Note: The Equation above is essentially the same as Equation 25b in CTM-041, except
that the flow rate is expressed in scfh, rather than scf/sec.
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December 2005
Field Descriptions and Instructions for RT 615 (Traverse Point Level Data)
Monitoring System ID (10). Report the system ID for the flow monitoring system (from
RT 510 of the monitoring plan) being tested for relative accuracy.
Test Number (13). Report the same test number as in the corresponding RT 610 for the
test run.
Operating Level (15). Report the same operating level as in the corresponding RT 610
for the test run.
Run Number (16). Report the same run number as in the corresponding RT 610 for the
test run.
Reference Method Probe Type (18). Report the type of probe employed in reference
method using one of the following uppercase codes:
AS
Type S (automated)
DA
Prism-shaped 3-D Pitot (without thermocouple)
DAT
Prism-shaped 3-D Pitot (with thermocouple)
P
Prandtl
S
Type S (manual)
SPH
Spherical 3-D Probe
Probe ID (22). Report the permanent identification number engraved (or otherwise
marked) on the probe being used to measure velocity at the traverse point.
Pressure Measurement Device Type (33). Report the type of pressure measurement
device employed in reference method using one of the following uppercase codes:
ET Electronic Manometer or Electronic Pressure Transducer
MG Mechanical Pressure Gauge (e.g.. Magnehelic® gauge)
MN Fluid Manometer
Method 1 Traverse Point ID (35). Assign a unique alphanumeric designation to each of
the Method 1 traverse points. Maintain the same point numbering scheme throughout the
RATA. Do not leave any of the columns 35 through 37 blank. Use leading zeros to fill
in, as necessary. For example, if the traverse points are numbered consecutively from 1
through 16, report them as "001", "002", "003", etc.
Probe or Pitot Velocity Calibration Coefficient (38). Report the value of the probe or
pitot tube velocity calibration coefficient. For a Type-S or Prandtl pitot tube, this will be
Cp. For a 3-dimensional probe, this will be the appropriate F2 coefficient.
Date of Latest Probe or Pitot Tube Calibration (43). Report the year, month, and day
of the latest successful wind tunnel calibration of the probe or pitot tube.
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EDR v2.2 Instructions: RT 614-616
Average Velocity Differential Pressure at Traverse Point (51). Report the sight-
weighted or integrated average velocity differential pressure, in inches of H20, recorded at
the Method 1 traverse point, unless the data acquisition system provides a continuous
readout of the square root of the differential pressure, in which case, leave this field blank.
For Method 2 or 2G, report the average AP value. For a 3-dimensional probe, report the
average value of (P, - P2).
Note: If you report the average differential pressure in this field, do not report data in column
56.
Average of Square Roots of Velocity Differential Pressures at Traverse Point (56). If
the data acquisition system electronically provides an integrated average of the square
roots of all differential pressure readings recorded at the Method 1 traverse point (rather
than providing an average of the differential pressure values themselves), report the
integrated average of the square roots. Otherwise, leave this field blank.
Note: If you report the integrated average of the square roots of the differential pressures in this
field, do not report data in column 51.
Stack Temperature at Traverse Point (61). Report the stack temperature measured at
the traverse point, in degrees Fahrenheit.
Exterior Method 1 Traverse Point Identifier (66). For circular stacks, if the traverse
point is one of the four Method 1 points closest to the stack wall and if this test run is
used to determine a wall effects adjustment factor (WAF), report "W" in column 66.
Otherwise, leave this field blank. Also leave this field blank if the stack or duct is
rectangular.
Number of Wall Effects Points Used to Derive Replacement Velocity (67). For
circular stacks, if a "W" is reported in column 66, indicating that the traverse point is an
exterior Method 1 traverse point, report the number of wall effects points used to generate
the replacement velocity at the traverse point. The total number of wall effects points
reported in column 67 should include: (1) all 1-inch incremented points at which actual
wall effects measurements were made; (2) all 1-inch incremented points at which actual
wall effects measurements were not made, but for which the velocity obtained at a
subsequent wall effects traverse point was used, as provided under Section 8.7.1.2 of
Method 2H; and (3) the traverse point located at d,.em (as defined in Section 3.3 of Method
2H), if a velocity measurement was taken at that point.
Leave this field blank if the stack or duct is rectangular.
Yaw Angle of Flow at Traverse Point (69). If Method 2 is used for the velocity
traverse, leave this field blank. If Method 2F or 2G is used for the velocity traverse,
report the measured yaw angle at the traverse point. If the yaw angle is negative, be sure
to include the minus sign.
Pitch Angle of Flow at Traverse Point (75). If Method 2 or 2G is used for the velocity
traverse, leave this field blank. If Method 2F is used for the velocity traverse, report the
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EDR v2.2 Instructions: RT 614-616
December 2005
measured pitch angle of the traverse point. If the pitch angle is negative, be sure to
include the minus sign.
Calculated Velocity at Traverse Point, Not Accounting for Wall Effects (81). Using
the appropriate equation from Method 2, 2F, or 2G (as applicable), calculate the velocity
at the traverse point, in actual ft/sec. Use the average differential pressure at the traverse
point from column 51 of this record or the average of the square roots of the differential
pressures from column 56 of this record (whichever is appropriate) in the calculations,
along with the stack temperature from column 61 of this record and the supporting run-
level information from columns 47 through 85 of RT 614. Round off the result to two
decimal places. Do not adjust the calculated point velocity for wall effects.
Calculated Replacement Velocity at Traverse Point, Accounting for Wall Effects
(87). For circular stacks, leave this field as blank or zero unless the traverse point is one
of the four exterior Method 1 traverse points (indicated by a "W" in column 66). If a "W"
is indicated in column 66, report the replacement point velocity for the traverse point, in
actual ft/sec, corrected for wall effects in accordance with Equation 2H-15 of Method 2H
(see also Form 2H-1 or Form 2H-2 and accompanying instructions in Method 2H).
Leave this field blank if the stack or duct is rectangular.
Field Descriptions and Instructions for RT 616
Monitoring System ID (10). Report the ID of the flow monitoring system for which the
RATA was performed.
Test Number (13). Report the test number as reported in the corresponding RTs
610/611.
Operating Level (15). Report the operating level as reported in the corresponding RTs
610/611.
RATA End Date and Time (16, 24). Report the end date and time as reported in the
corresponding RT 611.
Default Wall Effects Adjustment Factor Used (28). Report the default wall effects
adjustment factor (WAF) applied to each run of the flow RATA for this operating level, in
accordance with Method 2H. For brick and masonry stacks, use a default WAF of
0.9900. For all other stacks, use a default WAF of 0.9950.
Field Descriptions and Instructions for RT 617
For rectangular stacks or ducts with installed flow monitors, when Method 2J (i.e.. regular
Method 2 with a calculated or default WAF) is used for a flow RATA, RT 617 must be
reported Report one RT 617 for each operating level of the applicable flow RATA. Do
not report RT 617 when using Method 2FJ or 2GJ.
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EDR v2.2 Instructions: RT 621
Field Descriptions and Instructions
Monitoring System ID (10). Report the system ID of the flow monitor for which the
RATA is performed (RT 610/611).
Test Number (13). Report the test number of the flow RATA (RT 611).
Operating Level (15). Report the load level as "H", "M", or "L", consistent with the
operating level in the applicable RT 611.
RATA End Date and Time (16, 24). Report the date and time on which the RATA was
completed for this operating level.
Number of Method 1 Traverse Points (28). Report the number of Method 1 traverse
points in the test runs. The number of Method 1 traverse points reported in RT 617 must
equal the number of Method 1 traverse points reported in RT 532, column 58.
Wall Effects Adjustment Factor (30). Report the WAF currently applied. The WAF
reported in RT 617 must equal the WAF reported in RT 532, column 20.
(8) RT 620: Cycle Time/Response Time Data and Results [Replaced]
This record type was retired and replaced by RT 621.
(9) RT 621: Cycle Time Test Data and Results
The cycle time test is required for initial certification of a gas CEMS and may be required for
recertification or as a diagnostic test. The cycle time test is not a required periodic quality assurance test
under Appendix B to Part 75. Submit RT 621 only when a cycle time test of a gas monitoring system is
required for initial certification, recertification, or diagnostic purposes. Perform the cycle time test
according to the procedures under 40 CFR Part 75, Appendix A, Section 6.4. An upscale and a
downscale cycle time test is required for each analyzer component of each gas monitoring system.
Separate RTs 621 are required for the upscale and downscale tests for each analyzer component.
Field Descriptions and Instructions
Component ID (10). Report the component ID (from RT 510) of the gas analyzer being
tested.
Monitoring System ID (13). Report the monitoring system ID (from RT 510) of the gas
analyzer being tested. For time-sharing, each probe location should have a different
monitoring system ID. In such cases, report separate RTs 621 for each time-shared
monitoring system.
Date (16). Report the date on which the cycle time test was performed.
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Start Time (22). Report the start of the cycle time test which was the hour and minute at
which the calibration gas flow was stopped after obtaining a stable calibration gas reading
(i.e.. point "B" in Figure 6 in Section 6.4 of Appendix A to Part 75).
End Time (26). Report the end of the cycle time test which was the hour and minute at
which 95.0% of the step change between the starting stable calibration gas value and the
ending stable stack emissions value was achieved (see Figure 6 in Appendix A).
Component Cycle Time (30). Report the upscale or downscale cycle time (as
appropriate) for the analyzer component being tested. For time-sharing, the same analyzer
component can have different component cycle times, depending on which monitoring
system (probe location) is being tested.
Stable Starting Monitor Value (32). Report the stable analyzer response to the
calibration gas at the beginning of the cycle time test (see point B in Figure 6 in Appendix
A).
Stable Ending Monitor Value (45). Report the final, stable analyzer response to the
stack emissions (see point C in Figure 6 in Appendix A).
Calibration Gas Value (58). Report the certified tag value of the calibration gas used for
the cycle time test.
Calibration Gas Level (71). If the upscale response of an analyzer was checked (i.e..
from a zero-level calibration gas to stack emissions), report the calibration gas level as
"Z". If the downscale response was tested (i.e.. from a high-level calibration gas to stack
emissions), report the calibration gas level as "H".
Total or System Cycle Time (72). For an S02 or C02 pollutant concentration monitor,
report the longer of the upscale and downscale cycle times as the system cycle time.
Therefore, even if the upscale and downscale component cycle times are different, both
the upscale and downscale RTs 621 will have the same system cycle time. For NOx-
diluent monitoring systems, report the system cycle time as the longest component cycle
time observed during any of the upscale or downscale tests of the pollutant and diluent
analyzers. Therefore all four of the RTs 621 for the cycle time test of a NOx-diluent
monitoring system (i.e.. the two upscale and two downscale test results) will have the
same system cycle time. If time-sharing is used, determine the total cycle time as follows.
Identify the longest component cycle time obtained for each of the time-shared systems.
Add these longest component cycle times together and then add an appropriate amount of
time (as determined by the CEMS manufacturer) to account for all purge cycles at the
different probe locations, to obtain the total cycle time. Report this total cycle time in RT
621 as the system cycle time for each of the time-shared systems.
Reason for Test (74). Indicate the purpose of the test using one of the following
uppercase codes:
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EDR v2.2 Instructions: RT 623
C Initial Certification
D Diagnostic
R Recertification
Do not leave this field blank.
Test Number (76). For each set of records which comprise a single test, assign a unique
test number for the system and component. For S02 and C02 pollutant concentration
monitors, two RTs 621 comprise a cycle time test of the monitoring system (i.e.. the
upscale and downscale test results). For NOx-diluent systems, four RTs 621 comprise a
system cycle time test (i.e.. the upscale and downscale test results for each analyzer). You
may reuse the test number for different systems and components. You may also reuse the
test number for the same monitoring system, provided that the tests are performed and
reported in different quarters. If you submit data for an incomplete or aborted test, assign
and report a test number. If you submit hardcopy information on a test in a certification
report or submit other information about the test to EPA or a State agency, refer to the
system and component IDs, the test number, and test time period (quarter and year). Do
not leave this field blank.
Note: If a single component ID is used to represent a dual-range analyzer (i.e.. if a
component type code of "S02A", "NOXA", "C02A", "02DA", or "02WA" is assigned
to the analyzer in column 23 of RT 510), use two different test numbers for the low and
high scale cycle time tests when reporting low and high scale tests in the same EDR
submittal. Also, for NOx-diluent systems, when only the NOx component or the diluent
component (but not both) has two ranges, report under one test number the high range
test of the dual-range component (i.e.. upscale and downscale results) along with the
upscale and downscale results obtained for the single-range component, and report under
a second test number the low range test of the dual-range component (upscale and
downscale results) along with the upscale and downscale results obtained for of the single-
range component. If both the NOx and diluent components have two ranges, report the
high range tests of the two components (upscale and downscale results) together under
one test number and report the low range tests of the two components together under a
second test number.
(10) RT 623: Qualifying Test for Off-line Calibration Error Tests
To use an off-line daily calibration error check (a calibration error test performed during a period
in which a unit is not operating) to validate CEMS data, a demonstration that the results of an off-line
calibration are comparable to the results of an on-line calibration is required. Report the results of this
demonstration in RT 623. For each off-line/on-line calibration demonstration, submit four records for
each component analyzer in each monitoring system (two for the high (or mid) level calibration gas
injections and two for the zero level injections). RT 623 serves as the official record that the required
off-line/on-line calibration demonstration has been passed. Report RT 623 in each calendar quarter in
which off-line calibrations are used to validate data. For simplicity, you may include RTs 623 in every
quarterly report, whether or not an off-line calibration was performed during the quarter.
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EDR v2.2 Instructions: RT 624
January 2003
Field Descriptions and Instructions
Columns 1 through 72. See the instructions for these fields for RT 230.
Off-line/On-line Indicator (73). Identify calibrations performed during a non-operating
hours with the code "OFF" and during operating hours with the code "ON". Do not leave
this field blank.
Reason for Test (76). Indicate the purpose of the test using one of the following
uppercase codes:
C Initial Demonstration
D Diagnostic
Do not leave this field blank.
Test Number (77). For each set of records which comprise a single test, assign a unique
test number for the system and component. You may reuse the test number for different
systems and components. You may also reuse the test number for the same monitoring
system, provided that the tests are performed and reported in different quarters. Do not
submit data for an incomplete or aborted test. If you submit hardcopy information on a
test in a certification report or submit other information about the test to EPA or a State
agency, refer to the system and component IDs, the test number, and test time period
(quarter and year). Do not leave this field blank.
(11) RT 624: Other QA Activities
Use this record to report primary element inspections for orifice, venturi, and nozzle fuel
flowmeters. Primary element inspections are required once every 12 calendar quarters; however, the
optional fuel flow-to-load ratio test in Section 2.1.7 of Appendix D may be used to extend the interval
between successive inspections up to 20 calendar quarters. Also use this record for tank drop accuracy
tests performed on fuel flowmeters for qualifying low mass emissions (LME) units under § 75.19.
For a Subpart H unit, stack, or pipe for which you report data only in the ozone season, if a
required primary element inspection is done outside the ozone season (from October 1 of previous year
to April 30 of the current year) and is used to validate data in the current ozone season, report the results
of the inspection in the quarterly report for the second calendar quarter of the current year (or in the third
quarter report, if the second quarter is a non-operating quarter).
Do not report RT 624 for non-operating quarters.
Field Descriptions and Instructions
Parameter (16). Report the system parameter for the monitoring system tested.
Activity/Test Completion Date/Hour (20, 28). Report the date and hour in which the
test was completed.
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EDR v2.2 Instructions: RT 627
QA Test Activity Description (30). Report the type of test or other activity (for
example, orifice inspection, etc.).
Test Result (50). Report whether the system or component passed ("P") or failed ("F")
the test.
Reason for Test (51). Report the purpose of the test using the following uppercase
codes:
C Initial Certification
D Diagnostic
Q Periodic Quality Assurance
R Recertification
If more than one code applies, submit a two-letter code (e.g.. "RQ" for a test performed as
a recertification test and to meet the periodic quality assurance requirement). Do not
leave this field blank.
QA Test Code (53). Report the test code for this type of test or other activity.
01 Primary Element Visual Inspection for Orifice, Nozzle, and Venturi Types
02 Fuel Flowmeter/Tank Drop Accuracy Test (LME only)
03 Leak Check Performed on Moisture Sensors
04 PEMS daily calibration error test
05 Periodic check of PEMS accuracy with a portable analyzer
99 Other
(12) RT 627: Fuel Flowmeter Accuracy Test
Report fuel flowmeter accuracy test results in RT 627 if you calibrate the meter with a flowing
fluid , Le^, if the flowmeter is calibrated in a laboratory or by an in-line calibration against a reference
flowmeter. (See Sections 2.1.5.1 and 2.1.5.2 of Appendix D to Part 75.) Flowmeter accuracy tests are
required once every four "fuel flowmeter QA operating quarters" (as defined in § 72.2); however, the
optional fuel flow-to-load ratio test in Section 2.1.7 of Appendix D may be used to extend the interval
between successive accuracy tests up to 20 calendar quarters. If fuel flowmeter components are rotated
(as described in paragraph (d) of the RT 510 instructions), report the results of the accuracy test for
rotated components only when they are re-installed for use, Le^, do not report accuracy test results if the
meter is temporarily put into in storage after being recalibrated. A "fuel flowmeter QA operating quarter"
is counted against a flowmeter only when the meter has been re-installed, not if it is in storage (see Part
75 Policy Manual, Questions 25.17 and 25.18).
For fuel flowmeter systems with multiple flowmeter components (e.g.. a system with a main
supply meter and a return meter, or a system consisting of multiple flowmeters supplying the same type of
fuel to a unit, or a multicomponent system where different flowmeters are rotated in and out), report a
separate RT 627 for each installed flowmeter component.
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EDR v2.2 Instructions: RT 627
December 2005
For a Subpart H unit or pipe for which you report data only in the ozone season, you must include
all of the fuel flowmeter QA operating quarters in the entire year, when determining the deadline for the
next accuracy test (see § 75.74(c)(4)). If the required flowmeter accuracy test for an ozone season-only
reporter is done outside the ozone season (from October 1 of previous year to April 30 of current year)
and is used to validate data in the current ozone season, report the results of the test in the quarterly
report for the second calendar quarter of the current year (or in the third quarter report, if the second
quarter is a non-operating quarter).
Do not report RT 627 for non-operating quarters.
Field Descriptions and Instructions
Component and Monitoring System ID (10, 13). Report the component and
monitoring system IDs for the fuel flowmeter being tested. If fuel flowmeters are rotated
(as described in paragraph (d) of the introductory text to the RT 510 instructions),
whenever a recalibrated flowmeter is reinstalled, report the ID number of the system into
which the flowmeter is reinstalled. For a system with multiple flowmeter components,
report a separate RT 627 for each installed flowmeter component
Test Completion Date and Hour (16, 24). Report the date and hour that all test runs
were completed. For multiple-component systems, if the test completion dates and hours
for the individual flowmeters are not the same, report the latest of these dates and hours.
Reinstallation Date and Hour (26, 34). For laboratory tests that were not performed in-
line at the unit, report the date and hour that the fuel flowmeter was reinstalled. If in-line
tests were performed, leave these fields blank.
Accuracy at Low Fuel Flow Rate (36). Report the accuracy as a percentage of upper
range value, using Equation D-l of Appendix D. Round to one decimal place.
Highest Accuracy at Mid Fuel Flow Rate (41). Report the accuracy as a percentage of
upper range value, using Equation D-l of Appendix D. Round to one decimal place. If
accuracy testing is done at two or more mid-range fuel flow rates, report the highest
accuracy from all of the mid-level test results in this field and do not report the other mid-
level results.
Accuracy at High Fuel Flow Rate (46). Report the accuracy as a percentage of upper
range value, using Equation D-l of Appendix D. Round to one decimal place.
Test Method (51). Report the type of test using the following uppercase codes:
I Inline Comparison at the Unit
L Lab Comparison
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EDR v2.2 Instructions: RT 628
Test Result (52). Report the test result using the following uppercase codes:
A Aborted
F Failed
P Passed
Do not leave this field blank.
Test Number (53). Report a unique test number assigned to the test for the monitoring
system and quarter/year. Do not leave this field blank.
(13) RT 628: Accuracy Test for Orifice, Nozzle, or Venturi Type Fuel Flowmeters
For orifice, nozzle, and venturi-type fuel flowmeters, submit RT 628 to report the results of
transmitter or transducer accuracy tests performed under Section 2.1.6.1 of Appendix D to Part 75.
Transmitter/transducer accuracy tests are required once every four "fuel flowmeter QA operating
quarters" (as defined in § 72.2); however, the optional fuel flow-to-load ratio test in Section 2.1.7 of
Appendix D may be used to extend the interval between successive accuracy tests up to 20 calendar
quarters.
For a Subpart H unit or pipe for which you report data only in the ozone season, you must include
all fuel flowmeter QA operating quarters in the entire year, when determining the deadline for the next
accuracy test (see § 75.74(c)(4)). If the required accuracy test for an ozone season-only reporter is done
outside the ozone season (from October 1 of previous year to April 30 of the current year) and is used to
validate data in the current ozone season, report the results of the test in the quarterly report for the
second calendar quarter of the current year (or in the third quarter report, if the second quarter is a non-
operating quarter).
Do not report RT 628 for non-operating quarters.
Field Descriptions and Instructions
Component and Monitoring System ID (10, 13). Report the component and
monitoring system IDs for the fuel flowmeter being tested. For the component ID, use the
ID for component type GFFM or OFFM.
Test Completion Date and Hour (16, 24). Report the date and hour that all test runs on
all three transmitters (temperature, pressure, and differential pressure) were completed.
Accuracy Determination at Low Level (26). Report one of the following: (1) the
highest accuracy for any of the three transmitters, obtained using Equation D-la of
Appendix D; (2) the sum of the accuracies of the three transmitters; or (3) the total fuel
flowmeter accuracy, as determined using AGA Report No. 3 Uncertainty Guidelines.
Round to one decimal place.
Accuracy Determination Methodology for Low Level (31). Report the method used to
determine accuracy results for this level using one of the following uppercase codes:
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December 2005
ACT Actual Accuracy for Individual Components (must be < 1.0% of full scale to
pass)
AGA3 Total Flowmeter Accuracy From AGA Report No. 3 Uncertainty Guidelines
(must be < 2.0% of upper range value to pass)
SUM Sum of the Accuracy of All Components (must be < 4.0% to pass)
Highest Accuracy Determination at Mid Level (35). Report one of the following:
(1) the highest accuracy for any of the three transmitters, obtained using Equation D-la of
Appendix D; (2) the sum of the accuracies of the three transmitters; or (3) the total fuel
flowmeter accuracy, as determined using AGA Report No. 3 Uncertainty Guidelines. If
accuracy testing is done at two or more mid-level points, then, for Option 1, report the
highest individual accuracy value from all of the mid-level tests of all three transmitters. If
option (2) is used, first determine the highest accuracy for each of the three transmitters at
all mid-level points tested. Then, take the sum of these three highest accuracy values.
Round to one decimal place.
Accuracy Determination Methodology for Mid Level (40). Report the method used to
determine accuracy results for this level using one of the following uppercase codes:
ACT Actual Accuracy for Individual Components (must be < 1.0% of full scale to
pass)
AGA3 Total Flowmeter Accuracy from AGA Report No. 3 Uncertainty Guidelines
(must be < 2.0% of upper range value to pass)
SUM Sum of the Accuracy of All Components (must be < 4.0% to pass)
Accuracy Determination at High Level (44). Report one of the following: (1) the
highest accuracy for any of the three transmitters, obtained using Equation D-la of
Appendix D; or (2) the sum of the accuracies of the three transmitters; or (3) the total fuel
flowmeter accuracy, as determined using AGA Report No. 3 Uncertainty Guidelines.
Round to one decimal place.
Accuracy Determination Methodology for High Level (49). Report the method used
to determine accuracy results for this level using one of the following uppercase codes:
ACT Actual Accuracy for Individual Components (must be < 1.0% of full scale to
pass)
AGA3 Total Flowmeter Accuracy from AGA Report No. 3 Uncertainty Guidelines
(must be < 2.0% of upper range value to pass)
SUM Sum of the Accuracy of All Components (must be < 4.0% to pass)
Test Result (53). Report the overall test result using the following upper case codes:
A Aborted
F Failed (accuracy requirement not met at one or more levels tested)
P Passed (accuracy requirement met at all levels tested)
Do not leave this field blank.
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EDR v2.2 Instructions: RT 629
Test Number (54). Report a unique test number to the test for the monitoring system
and quarter/year. Do not leave this field blank.
(14) RT 629: Baseline Data for Fuel Flow-to-load Ratio or Gross Heat Rate Check
for Fuel Flowmeters
If you elect to use the optional fuel flow-to-load ratio test provisions of Section 2.1.7 of
Appendix D to Part 75 to extend the deadline for required fuel flowmeter accuracy tests, report RT 629
and its companion RT 630 for each operating quarter. According to the provisions of Section 2.1.7.1,
this record type must be supported by at least 168 hours of baseline fuel flow-to-load ratio or gross heat
rate (GHR) data.
The baseline data must be generated no more than four calendar quarters after the last successful
flowmeter accuracy test was completed, unless flowmeters are rotated in and out of different systems and
are temporarily kept in storage after being recalibrated. In the case where a meter is put into temporary
storage, you may count the calendar quarter in which the flowmeter is reinstalled as the first quarter in
the baseline data collection period.
For orifice, nozzle, and venturi fuel flowmeters, the baseline data must be generated no more than
four calendar quarters after completion of the last full quality assurance sequence (i.e.. flowmeter
transmitter test and primary element inspection).
For units or pipes for which you report data on a year-round basis, report this record type for
operating quarters in which the data collection for the baseline fuel flow-to-load ratio or GHR is in
progress and for every subsequent operating quarter in which the optional fuel flow-to-load quality
assurance test procedure is used for periodic quality assurance.
If you select the fuel flow-to-load ratio test option for a Subpart H unit or pipe for which you
report data only in the ozone season, fuel flow-to-load ratio tests are required only during the ozone
season. Therefore, for such units or pipes, report RT 629 only for the second and third calendar quarters,
if those quarters are operating quarters (see § 75.74(c)(3)(v)).
Report RT 629 for each fuel flowmeter system that will be quality-assured using the baseline data.
Do not report RT 629 for non-operating quarters. However, note that you must report RT 696 for all
quarters (including non-operating quarters) in which you claim an accuracy test deadline extension (see
RT 696 instructions).
For common pipe configurations, a single baseline fuel flow-to-load ratio or GHR is derived from
the average common pipe fuel flow rate and the hourly loads for all units that received fuel from the
common pipe. Thus, report only one RT 629 for the common pipe. For example, if CP1 is a common
pipe for Units 1 and 2, report one RT 629 for CP1 under the fuel flowmeter system ID associated with
common pipe CP1.
Field Descriptions and Instructions
Unit/Pipe ID (4). Report the unit or pipe ID associated with the fuel flowmeter system to
be quality-assured.
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December 2005
Monitoring System ID (10). Report the system ID of the fuel flowmeter system to be
quality-assured using the baseline data.
Completion Date and Hour of Most Recent Primary Element Inspection (13, 21).
For orifice, nozzle, or venturi fuel flowmeters required to perform a visual inspection of
the primary element as periodic quality assurance (under Section 2.1.6.6 of Appendix D),
report the date and hour of the most recent primary element inspection. For all other
types of fuel flowmeters, leave these fields as blank or zero.
Completion Date and Hour of Most Recent Flowmeter or Transmitter Accuracy
Test (23, 31). For orifice, nozzle, and venturi fuel flowmeters required to perform a
transmitter accuracy test as periodic quality assurance (under Section 2.1.6 of Appendix
D), report the date and hour of the most recent transmitter accuracy test (according to
Sections 2.1.6.1 through 2.1.6.5 of Appendix D). For all other fuel flowmeters, report the
date and hour of the most recent flowmeter system accuracy test (according to Section
2.1.5.1 or 2.1.5.2 of Appendix D). For systems with multiple fuel flowmeter components,
if the completion dates and hours of the accuracy tests of the individual component meters
are different, report the latest of these dates in this field (see Part 75 Policy Manual,
Question 25.19). When flowmeter components are rotated among different systems (as
described in paragraph (d) of RT 510 introductory text), report the latest accuracy test
completion date of any installed component, as the system accuracy test date.
Beginning Date and Hour of Baseline Period (33, 41). Report the date and hour of the
first hour of operation of the fuel flowmeter after completion of the most recent accuracy
test.
Completion Date and Hour of Baseline Period (43, 51). Report the last date and hour
of data that was used as baseline data to develop the baseline fuel flow-to-load ratio or
baseline GHR. Note: there must be at least 168 hours of baseline data collected within
four calendar quarters of the most recent flowmeter accuracy test or (for orifice, nozzle
and venturi-type fuel flowmeters) within four calendar quarters of the most recent full QA
test sequence, (i.e.. transmitter accuracy tests and primary element inspection) in order to
use the optional quality assurance procedures from Section 2.1.7 of Appendix D. If the
baseline data period is still in progress, leave these fields and subsequent fields as blank or
zero and skip to column 99.
Average Fuel Flow Rate (53). Report the hourly average fuel flow rate during unit
operation measured by the fuel flowmeter system during the baseline period (i.e.. Qbase
from Equation D-lb in Section 2.1.7.1 of Appendix D). If you report the average hourly
heat input rate in column 76, you may leave this field as blank or zero.
For a system with more than one fuel flowmeter for the identical type of fuel, you must
determine the net hourly fuel flow rate for each hour in the baseline data collection period.
The net fuel flow rate may represent the difference between the values measured for the
main supply and recirculating fuel lines, or may represent the sum of fuel flow for two fuel
flowmeters measuring the same type of fuel to the unit. For a combined cycle turbine with
auxiliary firing (e.g.. a duct burner), if the duct burner operates infrequently (i.e.. < 25% of
the unit operating hours, on average), you may establish the baseline for the fuel
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EDR v2.2 Instructions: RT 629
flowmeter system using the hours when only the combustion turbine is in operation. Add
together all of the net hourly fuel flow rates and divide by the number of hours in the
baseline data collection period to obtain Qbase.
Average Load (63). Report the average unit load during the baseline period (i.e.. Lavg
from Equation D-lc in Section 2.1.7.1 of Appendix D). For a common pipe, add together
all of the hourly operating loads for all units that received fuel through the common pipe
header during the baseline data collection period. Divide the result by the number of
hours in the baseline data collection period to obtain Lavg. For a combined cycle turbine
with auxiliary firing, if the duct burner operates infrequently and you establish the baseline
using hours when only the turbine is in operation, use the corresponding hourly electrical
outputs from the turbine to determine Lavg.
Baseline Fuel Flow-to-load Ratio (69). Report the baseline fuel flow-to-load ratio
calculated as R,,ase from Equation D-1B in Section 2.1.7.1 of Appendix D. If you report
the baseline GHR in column 83, you may leave this field as blank or zero.
Units of Fuel Flow-to-load (75). Report the code for the units of the baseline fuel-flow-
to-load ratio. Codes 1 and 2 apply to gas combustion. Codes 3 and 4 apply to oil
combustion. If column 69 (the baseline fuel flow-to-load ratio) is blank, leave this field as
blank or zero.
1 100 scfh/MWe 4 (lb/hr)/klb per hour steam load
2 100 scfh/klb per hour of steam load 5 (gal/hr)/MWe
3 (lb/hr)/MWe 6 (gal/hr)/klb per hour of steam load
Report codes 5 and 6 only for non-Acid Rain Subpart H units using volumetric oil
flowmeters.
Average Hourly Heat Input Rate (76). Report the average heat input rate for the
baseline hours in mmBtu/hr. If you report the average fuel flow rate in column 53, you
may leave this field as blank or zero.
Baseline GHR (83). Report the baseline value of the gross heat rate calculated as
(GHR)base from Equation D-1C in Section 2.1.7.1 of Appendix D. If you provide the
baseline fuel flow-to-load ratio in column 69, you may leave this field as blank or zero.
Units of Baseline GHR (89). Report the code for the units of the baseline GHR as
follows:
1 Btu/kwh
2 Btu/lb of steam load
If column 83 (the baseline GHR) is blank (or zero) also leave this field blank (or zero).
Number of Hours Excluded Due to Co-firing or Combustion of a Different Fuel (90).
If single-fuel combustion is the principal mode of operation, report the number of hours (if
any) of fuel flow rate data excluded from the fuel flow-to-load or GHR analysis because
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December 2005
the unit was co-firing different fuels. If co-firing is the principal mode of operation, report
the number of single-fuel hours (if any) excluded from the data analysis. Leave this field as
blank or zero if you are not claiming any excluded hours for this reason.
Number of Hours Excluded Due to Ramping (93). Report the number of hours from
the baseline period excluded from the baseline data because they met the criteria of
ramping hours in Section 2.1.7.1 of Appendix D. Leave this field as blank or zero if you
are not claiming any excluded hours for this reason.
Number of Excluded Hours in Lower 25% of Range of Operation (96). Report the
number of hours from the baseline period that were excluded from the baseline data
because the unit load during the hour was in the lower 25.0% of the range of operation
and was not considered normal. Leave this field as blank or zero if you are not claiming
any excluded hours for this reason.
Flag Indicating Baseline Data Collection is in Progress and That Fewer Than Four
Calendar Quarters Have Elapsed Since Quarter of the Last Flowmeter QA Test
(99). If the baseline data collection period is still in progress, and fewer than four calendar
quarters have elapsed since the quarter of the last successful fuel flowmeter accuracy test,
report a "B" in column 99. For a flowmeter that was placed in temporary storage and
subsequently reinstalled, report "B" if the baseline data collection period is in progress and
fewer than four quarters have elapsed since the flowmeter was reinstalled. Otherwise,
leave this field blank.
(15) RT 630: Quarterly Fuel Flow-to-load Test for Fuel Flowmeters
Report RT 630 every operating quarter, for units using the optional fuel flowmeter quality
assurance provisions of Section 2.1.7 of Appendix D to Part 75 (i.e.. the fuel flow-to-load ratio or GHR
test) to extend the deadline for fuel flowmeter accuracy tests. Do not report RT 630 for non-operating
quarters.
For common pipe configurations, report only one RT 630 for the common pipe. For example, if
CP1 is a common pipe for Units 1 and 2, report one RT 630 for CP1 under the fuel flowmeter system ID
associated with common pipe CP1.
If a system contains more than one fuel flowmeter component (e.g.. the main fuel flowmeter
component and a return meter component or multiple fuel flowmeters feeding a single unit), you must
submit a separate RT 630 for each flowmeter in the system, applying the result of the system fuel flow-to-
load ratio test to each component. If fuel flowmeters are rotated among different systems (as described
in paragraph (d) of the RT 510 introductory instructions), report RT 630 only for the installed flowmeter
component(s).
For a combined-cycle combustion turbine (CT) with a duct burner, if the fuel flowmeters serving
the CT and the duct burner are represented as components of a single fuel flowmeter monitoring system
in RT 510, you may perform the fuel flow-to-load ratio test using only the turbine fuel flow rate and load,
provided that the duct burner is used, on average, for < 25% of the unit operating hours. If you perform
the fuel flow-to-load ratio test in this way, submit separate RTs 630 for the CT and duct burner fuel
flowmeter components, and apply the results of the test to each component flowmeter.
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EDR v2.2 Instructions: RT 630
For a Subpart H unit or pipe for which you report data only in the ozone season, fuel flow-to-load
ratio tests are required only during the ozone season. Therefore, for such units or pipes, report RT 630
only for the second and third calendar quarters, if those quarters are operating quarters (see
§ 75.74(c)(3)(v)).
If a "B" is reported in column 99 of RT 629 (indicating that the baseline data collection period is
still in progress), fill in only columns 1 through 20 and 27 of RT 630.
Note that you must report RT 696 in addition to RTs 629 and 630 to claim the allowable
accuracy test deadline extensions associated with the fuel flow-to-load or GHR methodology. The RTs
696 are required for all calendar quarters, including non-operating quarters and (for ozone season-only
reporters) quarters outside the ozone season, for as long as you continue to claim deadline extensions
using the fuel flow-to-load or GHR methodology (see the RT 696 instructions for further discussion).
Field Descriptions and Instructions
Unit/Pipe ID (4). Report the unit or pipe ID associated with the fuel flowmeter system to
be quality-assured.
Monitoring System ID (10). Report the system ID of the fuel flowmeter system to be
quality-assured.
Component ID (13). Report the component ID of the fuel flowmeter to be quality-
assured. If a system contains more than one fuel flowmeter component (e.g.. the main fuel
flowmeter component and a return meter component or multiple fuel flowmeters feeding a
single unit), submit a separate RT 630 under each flowmeter component ID. If fuel
flowmeter components are routinely rotated among this unit (or pipe) and other unit(s) (or
pipe(s)) — submit a RT 630 for each installed flowmeter component in the system.
Calendar Quarter and Year (16). Report the calendar quarter and year of data that is
being quality assured (QYYYY).
Test Basis Indicator (21). Report a "Q" if the quarterly analysis compares the hourly fuel
flow-to-load ratios (using Equation D-1E in Section 2.1.7.2 of Appendix D). Report an
"H" if the quarterly analysis compares the hourly gross heat rates (using Equation D-1F in
Section 2.1.7.2 of Appendix D). Leave this field blank if you report a results code of "E",
"B", or "N" in column 27.
Quarterly Average Absolute % Difference Between Baseline Ratio (or Baseline
GHR) and Hourly Quarterly Ratios (or GHR Values) (22). Perform the quarterly
analysis according to the provisions of Section 2.1.7.2 of Appendix D. If 168 hours of
data are available, calculate and report the value of Ef using Equation D-1G.
Note: In the quarter in which the baseline data collection is completed, there must be at
least 168 hours of data subsequent to completing baseline data collection in order to
perform a fuel flow-to-load or GHR test for that quarter. Leave this field as blank or zero
if you report a results code of "E", "B", or "N" in column 27.
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Result (27). If the value of Ef is within the applicable limit in Section 2.1.7.2 of Appendix
D, report "P" to indicate that the fuel flowmeter system passed the quarterly evaluation.
If the value of Ef is not within the applicable limit, report "F" to indicate that the fuel
flowmeter system failed the quarterly evaluation (refer to Section 2.1.7.4 for the
consequences of a failed fuel flow-to-load test).
If the quarter is not a fuel flowmeter QA operating quarter (if fewer than 168 hours of
data were recorded in the quarter by the fuel flowmeter system to be tested), report "N".
If, after excluding hours of data according to the optional data exclusion provisions (see
Section 2.1.7.3 of Appendix D), fewer than 168 hours of data remain for the quarter for
the fuel flowmeter system to be tested, report "E".
If the baseline data collection period is still in progress at the end of the reporting quarter
and fewer than four calendar quarters have elapsed since quarter of the last successful fuel
flowmeter accuracy test (or since the quarter of reinstallation of the flowmeter — see RT
629, column 99 instructions), report "B".
Number of Hours Used in the Quarterly Data Analysis (28). Report the number of
hours of quality-assured fuel flow rate data that were used for the fuel flow-to-load or
GHR evaluation of the fuel flowmeter system. A minimum of 168 hours of quality-
assured fuel flow rate data are required for the analysis. Leave this field as blank or zero if
you report a results code of "E", "B", or "N" in column 27.
Number of Hours Excluded Due to Co-firing or Combustion of a Different Fuel (32).
If single-fuel combustion is the principal mode of operation, report the number of hours (if
any) of fuel flow rate data excluded from the fuel flow-to-load or GHR analysis because
the unit was co-firing different fuels. If co-firing is the principal mode of operation, report
the number of single-fuel hours (if any) excluded from the data analysis. Leave this field
as blank or zero if you are not claiming any excluded hours for this reason or if you report
a results code of "B" or "N" in column 27.
Number of Hours Excluded Due to Ramping (36). Report the number of hours (if any)
of fuel flow rate data excluded from the data analysis because of ramping (i.e.. the hourly
load differed by more than ±15% from the load during either the hour before or the hour
after). Leave this field as blank or zero if you are not claiming any excluded hours for this
reason or if you report a results code of "B" or "N" in column 27.
Number of Excluded Hours in Lower 25% of Range of Operation (40). Report the
number of hours (if any) of fuel flow rate data excluded from the data analysis because the
unit load was in the lower 25.0% of the range of operation (from minimum safe, stable
load to maximum sustainable load, as indicated in RT 536). This exclusion is not allowed
if operation in this lower portion of the range is considered normal for the unit. Leave this
field as blank or zero if you are not claiming any excluded hours for this reason or if you
report a results code of "B" or "N" in column 27.
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EDR v2.2 Instructions: RT 640-641
(16) RTs 630 and 631: Alternative Monitoring System Approval Petition Results
and Statistics [Renumbered]
These record types were renumbered as RTs 640 and 641.
(17) RTs 640 and 641: Alternative Monitoring System Approval Petition Data,
Results, and Statistics
RTs 640 and 641 are used to report data for a petition to use an alternative monitoring system
under Subpart E of Part 75. If you plan to petition EPA under Subpart E, contact EPA to obtain
directions for reporting this information.
(18) RT 645: Qualifying Data for Low Mass Emissions Units Excepted
Methodology
You may use the low mass emissions (LME) methodology under § 75.19 for determining and
reporting hourly S02, NOx, and C02 emissions and heat input for each unit which qualifies as a LME unit.
Record type 645 provides the initial evidence that a unit qualifies for LME status. However, unlike RT
507 (which is used to claim peaking unit or gas-fired unit status), RT 645 is not designed to be updated
from year-to-year. Rather, on-going LME status is demonstrated by the cumulative S02 and NOx mass
emissions reported in the 300-level EDR records. In view of this, submit RT 645 only as follows: (1) as
part of the certification application; and (2) in the quarterly report for the first quarter in which the low
mass emissions excepted methodology is used to report data.
For Acid Rain units, use this record type to qualify as a low mass emissions unit by demonstrating
that the unit emits no more than 25 tons of S02 and less than 100 tons of NOx for each year during a
three year period. If the unit is also subject to Subpart H, no more than 50 of the allowable annual tons
of NOx may be emitted during the ozone season. Therefore, for Subpart H, Acid Rain Units, you must
submit two RTs 645, Le^, one to demonstrate that the unit meets the <100 tons per year NOx emission
criterion, and one to demonstrate that the unit emits no more than 50 tons of NOx per ozone season.
For a non-Acid Rain Subpart H unit that reports data on an ozone season-only basis, use this
record type to qualify as a low mass emissions unit by demonstrating that the unit emits no more than 50
tons of NOx for each ozone season during a three-year period. For a non-Acid Rain Subpart H unit that
reports data year-round, you must submit two RTs 645, as described in the preceding paragraph.
Both in the certification application and in the EDR report for the first quarter in which the
excepted methodology is used (unless that quarter is a non-operating quarter), submit the annual
measured/projected/estimated S02 and/or NOx mass emissions for the three calendar years or ozone
seasons immediately preceding the date of the certification application. Projections may be used, as
necessary, for Year 1, Year 2, or Year 3 (or for Ozone Season 1, 2, or 3), when:
• Actual measured data (e.g.. EDR reports) or reasonable estimates of actual emissions derived
from other sources (e.g.. Part 60 monitoring data, process operating data, fuel usage records,
etc.) are not available (e.g.. for a new unit); or
• One or more of the past three years is not representative of current unit operation (e.g.. if
controls were recently installed); or
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December 2005
• The owner or operator takes a Federally enforceable permit restriction on unit operating
hours.
If the calendar quarter of the first LME report is a non-operating quarter, do not submit RT 645
with the EDR report for that quarter. Rather, submit RT 645 in the first subsequent unit operating
quarter.
If only historical data are being used to qualify, Year 1 would be three years before the year of the
application. If only projected data are being used, Year 1 would be the calendar year of the application.
Similarly, if only historical data are being used, Year 3 would be one year before the calendar year of the
application or if only projected data were being used, Year 3 would be two years after the year of the
application The appropriate calendar years for Ozone Seasons 1, 2, and 3 are determined in a similar
manner.
If a qualifying LME unit emits more than the allowable number of tons of S02 or NOx in a
particular year or ozone season, the unit loses its LME status. Should this occur, the owner or operator
must install and certify monitoring systems in a timely manner, as described in § 75.19. If LME status is
lost, submit RTs 585 indicating changes in monitoring methodologies with the appropriate effective
dates.
For more information on the default emission factors for low mass emissions units, see the
instructions for submitting the appropriate defaults in RT 531. For information on emission testing of a
group of identical LME units, refer to the RT 660 instructions.
Field Descriptions and Instructions
Calendar Year of Application (10). Report the calendar year for which the certification
application for approval to use the low mass emissions excepted methodology was
submitted. Note that for an existing affected unit switching to LME from another
monitoring methodology, use of the LME methodology may not begin until the first
operating hour of the next calendar year or ozone season following the date of the
application.
Type of Qualification (14). Indicate the type of qualification using one of the following
codes:
OS Ozone Season
YR Annual
If the unit is subject to both the Acid Rain Program and Subpart H, or if the unit is subject
only to Subpart H, but reports data on a year-round basis, submit two RTs 645, one coded
"YR", to demonstrate that the unit meets the <100 tons per year NOx emission criterion,
and one coded "OS" to demonstrate that the 50 tons per year ozone season threshold is
met.
Ozone Season or Years 1 -3 (16, 40, 64). Report the three calendar years used for the
measured, estimated or projected S02 and/or NOx mass emissions.
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EDR v2.2 Instructions: RT 650
Ozone Season or Years 1-3 Measured/Projected/Estimated NOx Mass Emissions
(20, 44, 68). Report the NOx mass emissions for each of the three years or ozone seasons
based on either measured or estimated NOx mass emissions or projected NOx mass
emissions, as appropriate according to § 75.19. For Acid Rain-affected Subpart H units
and for non-Acid Rain Subpart H units reporting on a year-round basis, report the annual
NOx mass emissions if the value reported in column 14 is "YR" and report the ozone
season NOx mass emissions if the value in column 14 is "OS". Round and report this
value to one decimal place.
[Reserved] (24, 48, 72) These fields, which had required reporting of calculated NOx
emissions in addition to actual emissions, have been reserved.
Years 1-3 Measured/Projected/Estimated S02 Mass Emissions (ARP) (28, 52, 76).
Report the S02 mass emissions for each of the three years based on either measured or
estimated S02 mass emissions or projected S02 mass emissions, as appropriate according
to § 75.19. Round and report this value to one decimal place. Leave this field blank for
non-Acid Rain Subpart H units. Also leave this field blank for Acid Rain Subpart H units
if the value reported in column 14 is "OS".
[Reserved] (32, 56, 80). These fields, which had required reporting of calculated S02
emissions in addition to actual emissions, have been reserved.
Years 1-3 Ozone Season or Annual Operating Hours (36, 60, 84). Report the
number of unit operating hours (as defined in § 72.2) for each of the three years or ozone
seasons.
(19) RT 650: NOx Emission Rate Correlation Test Data
This record type can be used for two purposes: (1) for reporting Appendix E test results for oil
and gas fired peaking units; and (2) for reporting the results of unit-specific, fuel-specific NOx emission
rate testing for LME units. Report only the results of full Appendix E or LME emission tests. If a test is
aborted or if certain test runs are discarded as invalid, keep a record of this in the test log, but do not
report partial tests or invalid runs in RT 650. The only acceptable reasons for aborting a test or
discarding test runs are: (1) the reference test method was not used properly or malfunctioned; or (2) a
problem with the unit or process prevented the test from being done at the load level or conditions
specified in the regulation.
NOx/Heat Input Correlation Curves
To establish a NOx/heat input rate correlation curve based on Appendix E to Part 75, you must
perform reference method testing at a minimum of four load levels. Report the test data from a minimum
of three runs for each load level in RT 650. Report the test results reference method, test at each load
level in RT 651. For each run at each load level reported in RT 650, also report the oil and/or gas
combusted and the heat input associated with each fuel in RTs 652 and 653. Use the four RTs 651 to
define the upper and lower bounds of each of the NOx correlation curve segments reported in RTs 560.
Assign a unique test number to the data and results and report this test number in all record types
associated with the test.
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Unit-specific, Fuel-specific NOx Emission Rate Tests (LME Only)
To establish a unit-specific, fuel-specific NOx emission rate for qualifying low mass emissions
units under the Acid Rain Program or Subpart H, perform Appendix E reference method testing at each
of the required load levels, as described above and as described in §§ 75.19 (c)(l)(iv)(A), (I) and (J).
Report the results of each run in RTs 650. Indicate each test run used to calculate the highest 3-run
average NOx emission rate, by reporting an "H" in column 68 of the appropriate RT 650. Report only
three records with this indicator; for all other records leave this field blank. Also report the highest three-
run average in column 69. Do not report any RTs 651 for these tests. Assign a unique test number to
the test and report this test number in each of the RTs 650 .
Field Descriptions and Instructions for RT 650
Monitoring System ID for Appendix E NOx System (Appendix E Only) (10). Report
the monitoring system ID for the NOx Appendix E system defined in the monitoring plan.
This system is comprised only of a DAHS component. For LME unit-default tests, leave
this field blank.
Reference Method Run Start Date (13). Report the date on which the run started.
Reference Method Run Start Time (19). Report the precise start time for the run.
Reference Method Run End Date (23). Report the date on which the run ended.
Reference Method Run End Time (29). Report the precise end time for the run.
Reference Method Response Time (33). Report the response time according to
Method 20 of Appendix A to Part 60 (if Method 20 is used — otherwise, leave blank) in
seconds for the run. This value determines the sampling time for the run.
Value From Reference Method During Run (36). Report the reference method value
for the run in NOx pounds per mmBtu, rounded to three decimal places.
Run Number (44). Assign a run number to each run. You may assign run numbers
either consecutively for each test (i.e.. run numbers 1 through 12 for each of the three runs
at four load levels) or for each load level within the test (i.e.. 1 through 3 for the runs at
each load level). At a minimum, runs must be numbered consecutively in time order
within a load level. Within a load level, do not skip or repeat a run number.
Operating Level (46). Report the operating level for each set of runs using " 1" as the
indicator for the lowest level.
Type of Fuel Combusted (48). Report the type of fuel combusted during the test using
the following uppercase codes:
A Natural Gas
D Diesel Oil
G Other Gas
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EDR v2.2 Instructions: RT 650
L
Liquefied Petroleum Gas
M
Mixture
N
Pipeline Natural Gas
O
Residual Oil
P
Process Gas
R
Producer Gas
X
Other Oil
Total Heat Input During the Run (49). For all Appendix E tests, report the total heat
input in mmBtu for the time period of the run. This value should also be in reported in RT
652 or RT 653. For LME unit-specific, fuel-specific NOx emission rate testing, leave this
field blank.
[Reserved] (56). This field, previously used to report elapsed time, has been reserved.
Leave this field blank.
Hourly Heat Input Rate During Run (59). For Appendix E runs, report the total heat
input divided by the duration of the run (as calculated from the start and end times). For
LME unit-specific, fuel-specific NOx emission rate tests leave this field blank.
Test Number (66). For all runs which comprise an Appendix E or LME unit-default test
at all load levels for a specific fuel, assign and report a unique test number for the set of
test records.
For example, for a 4-load Appendix E test performed while combusting natural gas,
assign the same test number " 1" to each test run at each of the four load levels. In other
words, all twelve records are assigned the same test number, "1". Also report this test
number in column 51 of RT 651 (the summary of the test results), in column 60 of RT
653 (which provides supporting data for heat input from the fuel flow meter), and in
column 18 of each of the RTs 560 used to define the correlation curve segments resulting
from the test.
If you test the unit for gas and assign test number " 1" to the twelve run records and then
conduct a separate test for oil or a fuel mixture, you must assign a different unique test
number to the test data for the second fuel.
You may use the same test number (e.g.. "1") for Appendix E tests of different monitoring
systems conducted in the same calendar quarter.
You may reuse the test number for the same monitoring system, provided that the tests are
performed and reported in different quarters and files.
Flag to Indicate this Run Used to Calculate Highest 3-run NOx Emission Rate
Average at any Tested Load Level (LME Only) (68). If you performed unit-specific,
fuel-specific NOx emission rate tests to determine the highest NOx emission rate, identify
and flag the three runs that are used to determine the highest 3-run average NOx emission
rate at any tested load level by reporting an "H" in this field. Flag only these 3 runs.
Leave this field blank for all other test runs.
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NOx Default Rate (Highest 3-run average) (LME Only)(69). Report the default NOx
emission rate for the LME unit as the highest 3-run average obtained at any tested load.
Base Load or Peak Load Test (LME Only) (75). If the LME unit is required to have
separate default NOx emission rates for base and peak load hours (see
§ 75.19(c)(l)(iv)(C)(9)), use the appropriate code to indicate whether the test was
performed at base load or peak load and, if at base load, whether an additional test was
performed at peak load.
B This test was performed at base load and an additional test was performed at peak
load.
P This test was performed at peak load
A This test was performed at base load and the resulting NOx default rate will be
multiplied by 1.15 to determine the NOx default rate for peak hours.
NOx Default Rate for Peak Load Hours (LME Only) (76). If you reported an A in
column 75, report the default rate for peak load hours in this field as the base-load
emission rate from column 69 multiplied by 1.15. Otherwise, leave this field blank.
(20) RT 651: NOx Emission Rate Correlation Results
For each Appendix E test, report the test results in RT 651. The number of RTs 651 required
corresponds to the number of loads tested. For example, if the Appendix E tests were performed at four
unique load levels, report four RTs 651. Do not report RT 651 for fuel-and-unit-specific tests of LME
units.
Field Descriptions and Instructions
Monitoring System ID for Appendix E NOx System (10). Report the monitoring
system ID for the NOx Appendix E system defined in the monitoring plan. This system is
comprised of only a DAHS component.
Completion Date of Last Run in Level (13). Report the end date of the last run
completed at the operating level.
Completion Time of Last Run in Level (19). Report the end time of the last run
completed at the operating level.
Arithmetic Mean of Reference Method Values at This Level (23). Calculate and
report the average NOx emission rate (as reported in RT 650) from all runs at this
operating level. Round the average to three decimal places.
F-factor Converting NOx Concentrations to Emission Rates (31). Report the F-factor
used to calculate the NOx emission rate for the run. This F-factor should be consistent
with the type of fuel combusted during the test.
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Average Heat Input Rate at This Level (41). Calculate and report the average heat
input rate from all runs at this operating level. Round to one decimal place.
Operating Level (48). Report the operating level represented by the data, using " 1" as
the lowest level.
Type of Fuel Combusted (50). Report the type of fuel combusted using the same fuel
code represented in RT 650, column 48 for the test.
Test Number (51). Report the same test number as reported in RT 650, column 66 for
test.
(21) RT 652: Heat Input from Oil Combusted During Test
For any Appendix E test used to establish a NOx emission rate curve for use during hours in which
oil is combusted, report a companion RT 652. RT 652 verifies the calculation of heat input during the
run. There should be one RT 652 for each run reported in RT 650 when any of the fuel combusted was
oil. Do not report RT 652 for LME unit tests.
Field Descriptions and Instructions
Monitoring System ID for Oil Fuel Flow System (10). Report the monitoring system
ID for the certified OILV or OILM system used to measure the value or mass of oil
combusted during the run. This monitoring system should be defined in the monitoring
plan system data (RTs 510).
Run Start Date (13). Report the start date for the run as in the companion RT 650.
Run Start Time (19). Report the exact start time for the run as in the companion RT
650.
Run End Date (23). Report the end date for the run as in the companion RT 650.
Run End Time (29). Report the exact end time for the run as in the companion RT 650.
Run Number (33). Report the run number assigned to the run and reported in the
corresponding RT 650.
Mass of Oil Combusted During Run (35). This value is either measured directly by a
fuel flowmeter system or calculated from the volume of oil measured by a fuel flowmeter
system. All values must be reported in units of pounds (oil mass), not as oil mass flow
rate.
Use an equation similar to Equation D-3 to convert oil volume to mass (in lbs), where the
density of the oil is determined by the applicable ASTM procedures in Part 75.
If you use oil volume and GCV to determine heat input for the run, leave this field blank.
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Gross Calorific Value (GCV) of Oil (45). Report the heat content or gross calorific
value (GCV) of the oil used to calculate heat input during the run. Report this value in
units consistent with the units used to report the mass or volume of oil combusted as
described below.
Heat Input From Oil During Run (55). Calculate and report the total heat input from
oil by multiplying the heat content (GCV) of the fuel by either the oil mass or the oil
volume combusted during the run. Report this value in units of mmBtu rounded to one
decimal place.
Volume of Oil Combusted During Run (62). If the fuel flow system measures the
volumetric flow of oil, report the volume of oil combusted during the run, as measured. If
the fuel flow system measures mass of oil directly, leave this column blank.
Units of Measure for Volume of Oil (72). Report the units of measure used to measure
volumetric flow using one of the following uppercase codes:
BBL Barrels
GAL Gallons
M3 Cubic meter
SCF Standard cubic feet
If you calculate hourly heat input directly from the volumetric flow, be sure to use
corresponding units for gross calorific value of the fuel.
Density of Oil (77). If you use volume of oil combusted, you may elect to sample the
density of the oil and use the density to calculate the mass of oil during the run. However,
it is not necessary to sample and report density for this purpose. If you elect not to use
this option, you may leave this field blank.
Units of Measure for Density of Oil (85). If you sample and report density of the oil,
report the units of measure for density using one of the following uppercase codes.
Otherwise, leave this field blank. The units must correspond to the units of measure for
oil volume.
Volume of Oil UnitsDensitv of Oil Units
BBL BarrelLBBBLPounds per barrel
GAL GallonLBGALPounds per gallon
M3H Cubic meterLBM3Pounds per cubic meter
SCF Standard cubic feetLBSCFPounds per standard cubic feet
Test Number (90). Report the test number assigned and reported for the Appendix E test
associated with this run.
Units of Measure for GCV (92). Report the units of measure for GCV which
corresponds to the mass or volume of oil combusted and is used in the calculation of heat
input during the run using one of the following uppercase codes.
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BTUBBL Btu per barrel
BTUGAL Btu per gallon
BTULB Btu per pound
BTUM3 Btu per cubic meter
BTUSCF Btu per standard cubic feet
(22) RT 653: Heat Input From Gas Combusted During Test
For any Appendix E test used to establish a NOx emission rate curve for use during hours in which
gas is combusted, report a companion RT 653. This RT 653 verifies the calculation of heat input during
the run. There should be one RT 653 for each run reported in RT 650 when any of the fuel combusted
was gas. Do not report RT 653 for LME unit tests.
Field Descriptions and Instructions
Monitoring System ID for Gas Fuel Flow System (10). Report the monitoring system
ID for the certified GAS system used to measure the volume of gas combusted during the
run. This monitoring system should be defined in the monitoring plan system data (RTs
510).
Run Start Date (13). Report the start date for the run as in the companion RT 650.
Run Start Time (19). Report the exact start time for the run as in the companion RT
Run End Date (23). Report the end date for the run as in the companion RT 650.
Run End Time (29). Report the exact end time for the run as in the companion RT 650.
Volume of Gas Combusted During Run (33). This value is the gas measured directly
by a gas fuel flowmeter system during the run. All values must be reported in units of 100
standard cubic feet (gas volumes), not as gas volumetric flow rates).
Gross Calorific Value of Gas (43). Report the heat content or gross calorific value
(GCV) of the gas from the appropriate sample to calculate heat input during the run.
Report this value in Btu per 100 scf.
Heat Input From Gas During Run (53). Calculate and report the total heat input from
gas by multiplying the heat content (GCV) of the fuel by the volume of gas combusted.
Report this value in units of mmBtu rounded to one decimal place.
Test Number (60). Report the test number assigned and reported for the Appendix E test
associated with this run.
650.
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(23) RT 660: Requirements and Results for Unit Group Testing (LME Units Only)
If you perform representative tests for a group of identical low mass emisions (LME) units, to
determine unit-specific defaults, report the required RTs 650, as described above for each test associated
with the identical unit group.
In addition, submit a RT 660 for each unit that is part of the identical unit group, indicating
whether or not testing was performed at that unit. If the identical units are required to have separate
default NOx emission rates for base and peak load hours (see § 75.19(c)(l)(iv)(C)(9)), submit two RTs
660 for each unit: one to report the base load rate and one to report the peak load rate. Use the flag in
column 66 to indicate which rate is being reported.
Include RTs 660 in group ID, ORISPL code and unit ID order at the bottom of the quarterly
report or certification file. For each identical unit in the group, the full set of RTs 660 must be included
in each quarterly report.
Field Descriptions and Instructions
Group ID (4). Assign and report a group ID, beginning with the letters "GP" and
followed by the ORIS code or facility ID of one of the units in the group. If a single
facility has more than one group, begin each group ID with the letter "G" followed by a
unique one digit number for the group (and then the ORIS code). This will ensure that the
group ID number is unique. Do not leave this field blank.
Each group ID should be associated with a set of units and the group of tests performed
to establish the default rate for these units. If you retest one or more units (potentially
affecting the default rate for the group) assign a new unique group ID and resubmit the
entire set of RTs 660 in each quarterly report for all units in the group.
ORIS Code (or Facility ID), Plant Name, Unit ID (12, 18, 38). Include identifying
information for each unit in the group. There will be one RT 660 for each unit, including
the unit identified in column 4. Do not leave these fields blank.
Test Status (44). Indicate whether a test was performed for the unit identified in this
record by reporting one of the following uppercase codes:
AE Appendix E Testing
NT No Testing Performed
Test Date for Unit (46). If tests are performed at the unit, report the date on which the
testing was completed. If no tests were performed, leave this field blank.
Default Rate from Identical Unit Testing (54). If the purpose of the tests is to establish
a unit-specific, fuel-specific NOx emission rate, report the resulting rate to three decimal
places. The unit-specific, fuel-specific NOx emission rate is the highest of the default
rates from all tests performed for the group.
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EDR v2.2 Instructions: RT 695
[Reserved] (60). This field, which had previously identified the purpose of the identical
group testing, has been reserved.
Type of Fuel (62). Report the type of fuel combusted using the same fuel code
represented in RT 650, column 48 for the test.
[Reserved] (63). This field, which had previously been used only by OTC sources, has
been reserved.
Base-Peak Load Indicator (66). For combustion turbines that operate principally at base
load (or at a set-point temperature), but are capable of operating at a higher peak load (or
higher internal operating temperature), fuel and unit-specific NOx emission rate testing
may be done either: (1) at base load only (with a 1.15 multiplier applied to the tested
emission rate during peak load hours); or (2) at both base load and peak load.
If the units in the identical group of turbines are not of this type, leave this field blank.
If the units in the group are of this type, then submit two RTs 660 for each unit: one to
define the base load default rate and one to define the peak load default rate. Indicate
whether the rate in column 54 is for base or peak load conditions, using the appropriate
code below.
B Value in column 54 applies to base load hours
P Value in column 54 applies to peak load hours
(24) RT 695: Single-load or Single-level Flow RATA Claim
Record type 695 does not apply to flow monitors installed on peaking units or bypass stacks,
since only single-load RATAs are required for these monitors. RT 695 also does not apply if an
exemption from multiple-load flow RATAs has been granted by EPA or by the permitting agency, either
in response to a petition under § 75.66 or to a technical justification submitted in the monitoring plan
under section 6.5.2 (e) of Appendix A.
For all other load-based units (or stacks) with stack flow monitoring systems, Section 2.3.1.3(c)
of Appendix B to Part 75 allows you to perform the required annual flow RATA at a single-load (low,
mid or high) instead of conducting a multiple-load RATA if the unit (or stack) has operated at one load
level for > 85.0% of the time since the last annual flow RATA. Whenever you use this provision of
Appendix B, submit RT 695 to document that the unit (or stack) qualifies for a single-load flow RATA.
RT 695 summarizes the historical load data for the unit (or stack) since the last annual flow RATA.
Submit a separate RT 695 for each flow monitoring system for which a single-load flow RATA claim is
made. Submit the RT(s) 695 in the same quarterly report as the single-load flow RATA(s).
Units that do not produce electrical or steam load and report data on a year-round basis may
submit single-level flow RATA claims in the manner described in the preceding paragraph, except that the
words "single-load" and "load level" are replaced, respectively, with the words "single-level" and
"operating level".
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Note that this option to claim single-load (or single-level) flow RATAs is not available to Subpart
H units or stacks for which you report data on an ozone season-only basis, instead of year-round. For
such units or stacks, two-load flow RATAs are required for routine quality-assurance, and three-load
RATAs are required for initial certification, at least once every five years thereafter, and whenever the
polynomial coefficients or K-factor(s) of the flow monitor are changed (see § 75.74(c)(2)(ii)(C)).
Field Descriptions and Instructions
Monitoring System ID (10). Report the identification number of the flow monitoring
system for which the single-load RATA claim is being made.
End Date of Last Annual Flow RATA (13). Report the year, month and day of
completion of the last annual flow RATA for the monitoring system. If the last annual
flow RATA was a multi-load (or multi-level) RATA, report the date on which testing of
the last load (or operating) level was completed. This date is the beginning of the
historical load (or operating level) data collection period that is used to make the single-
load flow RATA claim. Alternatively, you may use the first day of the calendar quarter in
which the last annual flow RATA was performed as the beginning of the data collection
period.
End Date of Historical Load Data Collection Period (21). Report the year, month and
day of the end of the historical load (or operating level) data collection period used to
make the single-load (or single-level) flow RATA claim. This date must be no more than
21 days prior to the date of commencement of the current annual flow RATA.
Alternatively, if you begin the data collection period on the first day of the quarter of the
last annual flow RATA, you may use the last day of the calendar quarter immediately
preceding the quarter of this year's flow RATA as the end date of the data collection
period.
Historical Percent Usage of Low Load or Operating Level (29). Based on the results
of the historical load (or operating level) data analysis, report the percentage of the time
that the unit (or stack) operated at the low load (or operating) level (0 to 30.0%
(inclusive) of the range of operation) in the historical data collection period.
Historical Percent Usage of Mid Load or Operating Level (34). Based on the results
of the historical load (or operating level) data analysis, report the percentage of the time
that the unit (or stack) operated at the mid load (or operating) level (> 30.0% and
< 60.0% (of the range of operation) in the historical data collection period. .
Historical Percent Usage of High Load or Operating Level (39). Based on the results
of the historical load (or operating level) data analysis, report the percentage of the time
that the unit (or stack) operated at the high load (or operating) level (> 60.0% of the range
of operation) in the historical data collection period.
Load or Operating Level for the Single-load (or Single-level) Flow RATA (44).
Indicate the load (or operating) level (L, M, or H) at which the claimed single-load (or
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single-level) flow RATA will be performed. The percent usage of the selected load (or
operating) level in the historical data collection period, must be greater than or equal to
85.0%.
(25) RT 696: Fuel Flowmeter Accuracy Test Extension
All Part 75 fuel flowmeters are required to undergo periodic accuracy tests. For orifice, nozzle,
and venturi-type flowmeters, periodic visual inspections of the primary element are also required. The
term "accuracy test" refers either to: (a) calibrating the flowmeter with a flowing fluid in a laboratory; or
(2) calibrating the flowmeter against a certified in-line "master meter"at the affected facility; or (3) for
flowmeters that are certified by design (i.e.. orifice, nozzle, and venturi-type meters), calibrating the
pressure, temperature and differential pressure transmitters using NIST- traceable equipment.
Each time that you perform an accuracy test of a fuel flowmeter, the projected deadline (without
extensions) for the next accuracy test is the end of the fourth calendar quarter following the quarter of the
test (e.g.. for a test done in 1st quarter, 2005, the projected deadline is March 31, 2006). There is one
exception to this — when a flowmeter is calibrated in the lab, the projected deadline is reckoned from the
quarter of reinstallation of the flowmeter, which may not be the same as the quarter in which it was tested
(see Part 75 Policy Manual, Questions # 25.17 through 25.19). For orifice, nozzle, and venturi-type
flowmeters, the projected deadline for the next primary element inspection (PEI) is the end of the twelfth
calendar quarter following the quarter of the PEI.
These projected test deadlines must be met unless a flowmeter qualifies for one or more deadline
extensions. There are two possible ways of extending projected fuel flowmeter test deadlines:
• The first way is to use the "QA quarter " method. Part 75 requires accuracy tests to be done
once every four "fuel flowmeter QA operating quarters," or "QA quarters," for short. A "QA
quarter" is a calendar quarter in which the fuel measured by the flowmeter is combusted for at
least 168 hours. Only QA quarters count toward the deadline for the next test. Therefore, for
each "non-QA" quarter, you may extend the projected accuracy test deadline by one quarter,
up to a maximum of 20 calendar quarters from the quarter of the previous QA test. This
method of extending the accuracy test deadline is advantageous for units that seldom have
"QA" quarters, either because they operate infrequently or seldom burn a particular type of
fuel. Note that this method may only be used to extend accuracy test deadlines, not PEI
deadlines.
• The second way is to use the optional "fuel flow-to-load ratio" or "gross heat rate (GHR)"
methodology described in Part 75, Appendix D, Section 2.1.7. This methodology allows you
to extend both accuracy test and PEI deadlines. If you wish to apply this method to an orifice,
nozzle or venturi-type flowmeter, you must first perform a complete QA test sequence (i.e.. a
transmitter accuracy test and a PEI) in the same quarter before you begin using the method.
After completing the flowmeter accuracy test or QA test sequence (as applicable), the method
requires you to collect at least 168 hours of baseline data, in order to develop a reference
flow-to-load ratio or gross heat rate. Then, in each subsequent operating quarter, you must
analyze your hourly fuel flow rate and load data and compare it against the reference value.
You may claim a one-quarter extension of the deadline for the next accuracy test or QA test
sequence (up to a maximum of 20 quarters between successive tests or QA sequences) for
each baseline data collection quarter (up to a maximum of four) and for each subsequent
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quarter in which the results of the data analysis are satisfactory (see RT 630 Instructions for
further discussion). The fuel flow-to-load or GHR method is advantageous for units that have
frequent "QA quarters" because they consistently burn a particular type of fuel for more than
168 hours per quarter.
Submit RT 696 to claim all allowable extensions of fuel flowmeter accuracy test deadlines. Test
deadlines may only be extended one quarter at a time. Therefore, you must submit RT 696 for every
calendar quarter, including non-operating quarters, for as long as the deadline continues to be extended.
Note that if you are using the optional fuel flow-to-load ratio or GHR methodology to extend the
accuracy test deadline, the RT 696 claims must be submitted in addition to the required RTs 629 and 630.
When you make an extension claim for a non-operating quarter (i.e.. a quarter
with zero operating hours), do not submit the RT 696 claim record in the EDR for that quarter. Rather,
submit this claim record in the report for the next required reporting quarter in which the unit operates
(see Section II.C(14) of these Instructions). For year-round reporters, the term "required reporting
quarter" refers to any of the four calendar quarters in the year; for ozone season-only reporters it refers
only to the second and third calendar quarters.
To determine whether you can extend the accuracy test deadline by using the "QA quarter"
method for a Subpart H unit or pipe for which you report data only in the ozone season, you must include
all calendar quarters for the entire year in the determination, not just the reporting quarters (see
§75.74(c)(4)). When the optional fuel flow-to-load ratio or GHR methodology is used for an ozone
season-only reporter, accuracy test deadline extensions may be claimed, as described in the second
bulleted item above, for the quarters inside the ozone season (the second and third calendar quarters).
Automatic deadline extensions may be claimed for the calendar quarters outside the ozone season (the
fourth and first calendar quarters), since no fuel flow-to-load ratio tests are required in those quarters.
For the quarters outside the ozone season (the fourth quarter of the previous year and the first quarter of
the current year ), submit the necessary RT 696 claims in the quarterly report for the second calendar
quarter of the current year (or, if the second quarter is a non-operating quarter, submit the RTs 696 in the
next required reporting quarter in which the unit operates).
Field Descriptions and Instructions
Monitoring System ID (10). Report the system ID for which an accuracy test deadline
extension is being claimed.
Date of Last Accuracy Test (13). Report the date on which a successful accuracy test
for the system was last performed. Do not leave this field blank.
Accuracy Test Expiration Date Without Extension (21). Report the projected deadline
for the next required accuracy test. Do not leave this field blank.
The date in column 21 will always be the last day in a particular calendar quarter. If an
extension of the original projected test deadline was claimed in one or more previous
quarters, the date reported in this field must reflect those previous extensions. For
example, if the original projected test deadline was June 30, 2006 and a RT 696 was
submitted last quarter, extending the projected deadline to September 30, 2006, then you
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must report September 30, 2006 as the "accuracy test expiration date without extension"
when making an extension claim this quarter.
Accuracy Test Expiration Date with Extension (29). Report the date on which the
accuracy test will expire with the claimed extension. This date will always be the last day
in the calendar quarter following the expiration date reported in column 21. Therefore,
for the example given in the column 21 instructions above, since the reported accuracy
test expiration date without extension is September 30, 2006, the extended deadline will
be December 31, 2006. Do not leave this field blank.
Type of Extension (37). Report one of the following the appropriate codes for the type
of extension claimed.
1 Extension because calendar quarter was not a fuel flowmeter QA operating quarter
(fuel flow rate data were recorded by the flowmeter system for fewer than 168
hours)
2 Extension claimed because fuel flow-to-load ratio test was performed and passed
this quarter (see Section 2.1.7 of Appendix D)
3 Extension claimed because the baseline data collection period for the fuel flow-to-
load ratio test is still in progress, and fewer than four calendar quarters have
elapsed since quarter of the last successful fuel flowmeter accuracy test
4 Extension claimed because fewer than 168 hours of fuel flowmeter data remained
for fuel flow-to-load ratio analysis, after allowable data exclusions were taken
under Section 2.1.7.3 of Appendix D
5 Extension claimed for the first or fourth calendar quarter of the year, for a unit
reporting data on an ozone season-only basis, and using the fuel flow-to-load ratio
test to extend the flowmeter accuracy test deadline. Fuel flow-to-load ratio testing
is not required outside the ozone season for this source.
Quarter and Year (39). Report the quarter and year for which the exemption is claimed
(QYYYY).
(26) RT 697: RATA Deadline Extension or Exemption
Submit RT 697 to claim all allowable extensions of RATA deadlines and all on-going or
conditional RATA exemptions. RATA deadlines may only be extended one quarter at a time, and RATA
exemptions must be claimed one quarter at a time. Therefore, you must submit RT 697 for every
calendar quarter, including non-operating quarters, for as long as the deadline continues to be extended
or the exemption continues to be claimed.
The allowable RATA extensions and exemptions described in RT 697 (see codes 1 through 10
under the column 37 instructions, below) may be claimed by any qualifying source that reports data on a
year-round basis. However, for Subpart H units or stacks for which you report data only in the ozone
season, none of the RATA deadline extensions apply. Only the conditional RATA exemption for non-
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redundant backup monitors (code 5) or exemptions related to the load range for testing (code 9 or 10)
may be claimed. For ozone season-only reporters, RATA deadline extensions may not be claimed using
code 1, because the RATA deadlines for these sources are determined on a calendar quarter basis, rather
than a QA operating quarter basis. Also, RATA extensions and exemptions using codes 2, 3, and 4 apply
only to S02 monitors, and are not appropriate for ozone season-only reporters, since for these sources
you report only NOx mass emissions, not S02 emissions.
For year-round reporters, there is a limit to the extension of RATA deadlines. A RATA deadline
may not be extended beyond the end of the eighth calendar quarter following the quarter in which the last
RATA was performed. Therefore, if the reporting quarter is the eighth calendar quarter since the quarter
of the last RATA, a deadline extension cannot be claimed.
When claiming a RATA deadline extension, submit RT 697 in the quarterly report for the quarter
in which the monitoring system qualifies for an extension (except as noted below for non-operating
quarters). For instance, if the RATA deadline is the end of the fourth calendar quarter of 2000 and in the
first quarter, 2000, the unit operates only 100 hours (i.e.. the first quarter is not a QA operating quarter),
submit RT 697 with the first quarter, 2000, quarterly report, in order to claim an allowable RATA
deadline extension until first quarter, 2001.
If the unit does not operate for one or more consecutive quarters and you would like to claim a
RATA deadline extension, do not submit RT 697 with the quarterly report(s) for the non-operating
quarter(s). Instead, submit RT 697 for each of the non-operating quarter(s) in the quarterly report from
the first quarter in which you resume operation of the unit (see Section II. C. 14 of these instructions).
For on-going and conditional RATA exemptions, submit RT 697 for each quarter, including non-
operating quarters, for as long as the exemption continues to be claimed. Also submit RT 697 when any
previously claimed RATA-exempt status is lost. However, do not submit an exemption claim for a non-
operating quarter with the quarterly report for that quarter. Rather, submit the claim in the next required
reporting quarter in which the unit operates.
For year-round reporters, the term "required reporting quarter" refers to any of the four calendar
quarters in the year, and for ozone season-only reporters it refers only to the second and third calendar
quarters.
Field Descriptions and Instructions
Monitoring System ID (10). Report the system ID of the primary or redundant backup
monitoring system for which a RATA deadline extension, exemption or loss of exemption
is being claimed. Do not leave this field blank.
Date of Last RATA (13). Leave this field blank if no previous RATA exists because the
system has maintained a RATA exemption. Otherwise, report the date on which a
successful RATA of the system was last completed. For codes 9 and 10, report the
completion date of the RATA to which the exemption applies.
RATA Expiration Date Without Extension (21). Report the projected deadline for the
next required RATA. If you are claiming an exemption from RATA requirements (code
3, 4, 5, 9 or 10), leave this field blank.
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The date in column 21 will always be the last day in a particular calendar quarter. If an
extension of the original projected RATA deadline was claimed in one or more previous
quarters, the date reported in this field must reflect those previous extensions. For
example, if the original projected RATA deadline was June 30, 2000 and a RT 697 was
submitted in the previous quarter, extending the projected deadline to September 30,
2000, report September 30, 2000 as the "RATA expiration date without extension" when
making an extension claim this quarter.
RATA Expiration Date With Extension (29). Report the date on which the RATA will
expire with the claimed extension. Report in this field only if an extension of a RATA
deadline is being claimed. This date will always be the last day in the calendar quarter
following the expiration date reported in column 21.
Type of RATA Extension or Exemption Claimed or Lost (37). Report the appropriate
code (1 through 9), that describes the type of RATA extension or exemption claimed or
lost.
1 RATA Deadline Extension Claimed for the Monitoring System Identified in
Column 10. There were fewer than 168 unit or stack operating hours this
quarter. Since this is not a "QA operating quarter," the RATA deadline is
moved forward by one calendar quarter.
2 S(X RATA Deadline Extension Claimed. Only very low sulfur fuel (as defined in
§ 72.2) was combusted this quarter.
This code applies to units that combust both very low sulfur fuel and higher-
sulfur fuel(s) as primary and backup fuels and account for S02 emissions with an
S02 monitor. This code does not apply to units for which the higher-sulfur fuel
is used only as an emergency backup fuel or for short-term testing. Code 2 may
be used to claim a one quarter extension of the S02 RATA deadline, if very low
sulfur fuel is the only fuel combusted in the unit(s) during the quarter and if no
more than eight calendar quarters have elapsed since the quarter in which the last
S02 RATA was performed.
3 Ongoing S(X RATA Exemption Claimed. Only very low sulfur fuel (as defined
in § 72.2) was combusted this quarter.
Codes 3 and 6 apply only to units that combust very low sulfur fuel exclusively
(as certified by the designated representative) and which account for S02
emissions with an S02 monitoring system. Submit RT 697 each quarter to claim
continued RATA-exempt status for the S02 monitor. If higher sulfur fuel is
burned in the unit and the on-going S02 RATA-exempt status is lost, enter code
6 in this field in lieu of 3.
4 Conditional SO^ RATA Exemption Claimed. Year-to-date usage of fuel with a
sulfur content higher than very low sulfur fuel is less than 480 hours.
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Codes 4 and 7 apply only to units that: (1) combust very low sulfur fuel as the
primary fuel; (2) use higher sulfur fuel only as emergency backup fuel or for
short-term testing; and (3) use an S02 monitoring system to account for S02
emissions. Such units are entitled to an exemption from S02 RATAs, provided
that the annual usage of higher sulfur fuel is 480 hours or less. Submit RT 697
each quarter to claim a continued S02 RATA exemption, by certifying that the
year-to-date usage of higher sulfur fuel has not exceeded 480 hours. If the
annual higher sulfur fuel usage exceeds 480 hours and the S02 RATA-exempt
status is lost, report code 7 in this field in lieu of 4.
5 Conditional RATA Exemption Claimed. Year-to-date usage of a regular non-
redundant backup monitoring system at this unit/stack is < 720 hours and fewer
than 8 full quarters have elapsed since last RATA.
This code applies only to regular non-redundant backup monitoring systems (i.e..
systems that have their own separate probes and sample interfaces). If such a
system is used for 720 hours or less per year at a particular unit or stack and if
fewer than eight quarters have elapsed following the quarter in which the last
RATA of the system was performed at that location, no RATA is required.
Submit RT 697 for each quarter in which the non-redundant backup system is
used for data reporting, to certify that the year-to-date usage of the system at
that location has not exceeded 720 hours and that fewer than eight quarters have
elapsed since the last RATA. If the year-to-date usage (or current ozone season
usage, for ozone season-only reporters) of the system exceeds 720 hours or if
eight quarters have elapsed following the quarter of the last RATA, the RATA-
exempt status is lost. If this occurs, report code 8 in this field in lieu of 5.
6 Ongoing S(X RATA Exemption Lost. Fuel with a sulfur content higher than
very low sulfur fuel as defined in § 72.2 combusted this quarter. Note that when
on-going S02 RATA-exempt status is lost, you may still qualify for a conditional
S02 RATA exemption. If so, you may claim that status by submitting a second
RT 697 with code "4" reported in this field.
7 Conditional S(X RATA Exemption Lost. Year-to-date usage of fuel with a
sulfur content higher than very low sulfur fuel as defined in § 72.2 exceeded 480
hours. When conditionally-exempt status is lost, this triggers an S02 RATA
requirement (see § 75.21(a)(7)).
8 Conditional RATA Exemption Lost. Year-to-date usage (or current ozone
season usage, for ozone season-only reporters) of a regular non-redundant
backup monitoring system exceeded 720 hours at this unit or stack. When
conditionally-exempt status is lost, this triggers a RATA requirement for the
non-redundant backup monitoring system (see § 75.20(d)(2)(v)).
9 Exemption From Performing Single-Load RATA at Normal Load. Due to
unusual circumstances, you have requested and obtained permission from EPA
to perform a required single-load RATA at a load level other than the normal
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load designated in RT 536. EPA recommends that you document in RT 910 the
date on which permission to test at a non-normal load was obtained.
10 Exemption From Performing Multiple-Load Flow RATA within the Prescribed
Load Range. Due to unusual circumstances or process operating conditions, you
have requested and obtained permission from CAMD to perform a required
multiple-load flow RATA based on operating load ranges other than those
defined in the active RT 536. EPA recommends that you document in RT 910
the date on which permission to test using the alternative load range was
obtained.
Year-to-date Hours Usage of Fuel with Sulfur Content Higher Than Very Low
Sulfur Fuel (39). If you claim a conditional S02 RATA exemption under code 4, report
the cumulative number of hours in the current calendar year in which fuel with a sulfur
content higher than very low sulfur fuel as defined in § 72.2 has been combusted.
Otherwise, leave this field blank.
Year-to-date Hours of Regular Non-redundant Backup CEMS Use at This
Unit/Stack (43). For each regular non-redundant backup monitoring system used to
report data during the quarter and for which a conditional RATA exemption is being
claimed under code 5, report (as applicable) the cumulative number of hours for which the
non-redundant backup system has been used at this same unit/stack location in the current
calendar year. Otherwise, leave this field blank.
Quarter and Year (47). Report the quarter and year for which the extension or
exemption is claimed (QYYYY).
(27) RT 698: Quarterly QA Test Exemption Claim
For units or stacks for which you report data on a year-round basis, Part 75 requires the following
quarterly tests to be performed for routine quality assurance: (1) linearity checks of all gas monitors are
required in each QA operating quarter; (2) a leak check of each differential pressure-type flow monitor is
required in each QA operating quarter; and (3) a flow-to-load ratio test is required in each QA operating
quarter for each flow monitor.
For Subpart H units or stacks for which you report data only in the ozone season (in the second
and third quarters), pre-ozone season linearity checks are required under § 75.74(c)(2)(i). These checks
may be done any time between October 1 of the previous year and April 30 of the current year. In
addition, linearity checks and (if applicable) leak checks of DP-type flow monitors are required during
the ozone season (in the second and third calendar quarters), if those quarters qualify as QA operating
quarters (see RT 601, 602, and 603 instructions), and flow-to-load ratio tests (if applicable) are required
in the second and third calendar quarters, if those quarters are QA operating quarters.
Part 75 allows exemptions from these quarterly QA test requirements in the following instances.
These exemptions may be claimed using RT 698:
(A) For units or stacks for which you report data on a year-round basis:
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1. Linearity check, leak check, and flow-to-load ratio test exemptions may be claimed for
any operating quarter that does not qualify as a QA operating quarter (the unit or stack
operates for less than 168 hours);
2. A linearity check exemption may be claimed for a particular monitor range (e.g.. the
high or low range of a dual-span unit) if the range is not used during the quarter;
3. For S02 and NOx span values of 30 ppm or less, an on-going linearity check exemption
may be claimed; and
4. For complex exhaust configurations, an on-going flow-to-load ratio test exemption may
be claimed if approved by petition to the Administrator under § 75.66 and Section 7.8 of
Appendix A to Part 75.
(B) For Subpart H units or stacks for which you report data only in the ozone season, the same
quarterly QA test exemptions as described in paragraph (A), above, may be claimed, for the
required reporting quarters (the second and third calendar quarters).
For ozone season-only reporters, you may not claim an exemption from the required pre-ozone
season linearity check unless your unit qualifies for the on-going exemption described in (B), above (i.e..
for an S02 or NOx span value < 30 ppm). Note that a 168 unit/stack operating hour grace period is
conditionally allowed when the pre-ozone season linearity check is not completed by April 30th (see
§ 75.74(c)(2)(i)(D)(7) and the RT 699 instructions).
If you elect to claim an exemption from the quarterly linearity test, leak check or flow-to-load
ratio test requirement for a particular quarter, or if you have received an on-going exemption from the
quarterly flow-to-load or GHR test by an approved petition, submit RT 698. Submit the record in the
quarter for which the exemption is claimed (except as noted below for non-operating quarters). For
example, if a linearity check would be due by December 31, 2000, submit RT 698 in the fourth quarter
2000 quarterly report.
Quarterly QA test exemptions must be claimed one quarter at a time. Therefore, you must submit
RT 698 for every calendar quarter, including non-operating quarters, for which an exemption is claimed.
However, do not submit an exemption claim for a non-operating quarter with the quarterly report for that
quarter. Instead, submit the claim in the next required reporting quarter in which the unit operates. Note
that if the unit operates for <168 hours in a quarter and if, for a particular monitor, a valid grace period
claim (RT 699) is submitted which covers the entire quarter, it is not necessary to submit RT 698 for that
monitor for that quarter.
For year-round reporters, the term "required reporting quarter" refers to any of the four calendar
quarters in the year, and for ozone season-only reporters it refers only to the second and third calendar
quarters.
For units or stacks for which you report data on a year-round basis, linearity check exemptions
for a particular monitor or range may only be claimed for three consecutive calendar quarters following
the quarter in which the last linearity check was performed, except for the low span S02 and NOx monitor
exemption (see code "4" under "Basis for Exemption" below), which is an on-going exemption. If the
reporting quarter is the fourth calendar quarter since the quarter of the last linearity test, a linearity test
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must be completed either within the reporting quarter or within a 168 unit operating hour grace period
following the end of the reporting quarter (see Section 2.2.3(f) of Appendix B). When the grace period is
used, a grace period claim (RT 699) must be submitted.
For Subpart H units or stacks for which you report data only in the ozone season, the provisions
in Section 2.2.3(f) of Appendix B, pertaining to the minimum frequency of linearity checks and to grace
periods, are inapplicable. Rather, for these units and stacks, linearity checks must be done both outside
and within the ozone season, at the frequency specified in § 75.74(c)(2)(i) and § 75.74(c)(3)(ii). Grace
periods are conditionally allowed for the required pre-ozone season linearity checks, but not for the
linearity checks required within the ozone season (see § 75.74(c)(2)(i)(D)(7) and § 75.74(c)(3)(ii)).
Field Descriptions and Instructions
Component and Monitoring System ID (10,13). Submit a record for each affected
component and monitoring system ID for which an exemption is claimed. For a flow
monitoring system with two or more component monitors (e.g.. an "X-pattern"
configuration), report only one RT 698, under the monitoring system ID, and leave the
component ID blank.
Basis for Exemption (16). Report the reason for the exemption using one of the
following codes:
1 Fewer than 168 Unit/Stack Operating Hours in Quarter (not a QA
operating quarter)
2 Analyzer Range Not Used During Calendar Quarter (dual span only)
3 Flow-to-load Test Exemption, by Approved Petition
4 S02 or NOx monitor span value <30 ppm
Type of Test (17). If a linearity test exemption is claimed, report "L" in this field. If a
quarterly flow-to-load test exemption is claimed, report "F". If a leak check exemption is
claimed for a differential pressure-type flow monitor, report "K".
Quarter and Year (18). Report the quarter and year for which the exemption is claimed
(QYYYY).
Span Scale (23). If a linearity test exemption is claimed, indicate whether the exemption
is for the low or high measurement scale. If it is for the low scale, report "L". If it is for
the high scale, either leave blank or report "H". Leave blank for all flow-to-load test or
leak check exemptions.
(28) RT 699: QA Test Extension Claim Based on Grace Period
If you elect to claim a grace period extension of a QA test deadline, submit a RT 699 to claim the
test deadline extension. For units or stacks for which you report data on a year-round basis, the
allowable grace period for a linearity check or a leak check is 168 unit or stack operating hours after the
end of the quarter in which the check was required. For a RATA, the allowable grace period is 720 unit
or stack operating hours after the expiration of the RATA deadline.
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For Subpart H units or stacks for which you report data only in the ozone season, the length of
the allowable grace periods is the same as for year-round reporters (168 unit or stack operating hours for
linearity checks and 720 unit or stack operating hours for RATAs). However, for these sources, the
grace period begins with the first unit operating or stack operating hour in the current ozone season (the
first operating hour on or after May first) and ends either: (a) on the date and hour of completion of the
required Q A test; (b) on the date and hour at which the maximum allowable number of operating hours in
the grace period is reached; or (c) at the end of the third calendar quarter, whichever of these dates and
hours occurs first.
In contrast with the grace periods allowed for year-round reporters, grace periods for Subpart H
units or stacks for which you report data only in the ozone season are allowed only when linearity checks
and RATAs required prior to the current ozone season are not completed by April 30th, and only if
certain conditions are met. These conditions are: (1) that a linearity check or RATA (as applicable) was
passed on or after January first of the previous calendar year; and (2) that the unit or stack on which the
monitor is located operated for fewer than 336 hours during the previous ozone season (see
§§ 75.74(c)(2)(i)(D)(7) and 75.74(c)(2)(ii)(H)(/)). If a source does not meet conditions (1) and (2)
above and cannot qualify for a grace period, the conditional data validation provisions of § 75.20(b)(3)
may be still be used, subject to certain restrictions (see § 75.74(c)(3)(vi)).
When a grace period begins and ends in a single calendar quarter, submit RT 699 in the quarterly
report for the quarter containing the grace period. For example, if the linearity test is due by December
31, 1999, but is actually completed in a grace period in the first quarter of 2000, submit a RT 699 in the
first quarter 2000 quarterly report. Note that RT 699 must also be submitted when the allowable grace
period expires in the reporting quarter, without the required QA test having been completed (this serves
as a claim of data validity during the grace period).
For units or stacks for which you report data year-round, when a grace period spans two or more
calendar quarters (e.g.. for an infrequently-operated unit), submit RTs 699 for each operating quarter,
starting with the quarter in which the grace period begins (the first operating quarter after the QA test
deadline (see column 17 instructions, below)) and ending either with the quarter in which the grace
period expires or the quarter in which the required QA test is completed, whichever occurs first. If any
non-operating quarters occur during this time span, do not report RT 699 for those quarters (no data
validation claim is required for a non-operating quarter).
For Subpart H units or stacks for which you report data only in the ozone season, if the grace
period begins in the second quarter and ends in the third quarter, submit RTs 699 for both quarters. If
the second quarter is a non-operating quarter and the grace period begins and ends in the third quarter,
submit RT 699 only for the third quarter.
Field Descriptions and Instructions
Component and Monitoring System ID (10,13). Submit a record for each affected
test, identifying it by component and monitoring system ID for linearity or leak tests and
by system ID only for relative accuracy tests.
Type of Test (16). Report the type of test affected using one of the following codes:
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K
L
R
Leak Check
Linearity
RATA
Beginning of Grace Period (17). Report the date on which the grace period begins.
This will be the date of the first unit or stack operating hour in a required reporting
quarter, after expiration of the QA test deadline. For year-round reporters, the QA test
deadline will always expire at the end of a calendar quarter. For ozone season-only
reporters, since grace periods apply only to required pre-ozone season linearity checks and
RATAs, the QA test deadline will always expire at the last hour of the day on April 30th.
For year-round reporters, the term "required reporting quarter" refers to any of the four
calendar quarters in the year, and for Subpart H sources that report data only in the ozone
season it refers only to the second and third quarters.
Date and Hour of Completion of Required QA Test (25, 33). If the required QA test
is completed in the reporting quarter, within the grace period, report the date and hour in
which the test was completed. If the test was not completed within the allowable grace
period and the grace period expired within the reporting quarter, leave these fields blank.
Also leave these fields blank if, at the end of the quarter, the QA test has not been
completed and the grace period has not yet expired.
Number of Unit/Stack Operating Hours From Beginning of Grace Period to
Completion of QA Test or Maximum Allowable Grace Period (35). Leave this field
blank if, at the end of the reporting quarter, the required QA test has not been completed
and the grace period has not yet expired. If the QA test was completed in the reporting
quarter, within the grace period, report the number of unit or stack operating hours (as
defined in § 72.2) from the beginning of the grace period until the hour of completion of
the QA test. If the required QA test was not completed within the grace period, and the
grace period expired within the reporting quarter, report the maximum allowable grace
period (720 or 168 unit or stack operating hours, as applicable) to claim data validity
during the grace period. When the required QA test is not completed by the end of the
grace period, the monitoring system is considered out-of-control in the first hour
following the expiration of the grace period.
Date and Hour of End of Grace Period (38, 46). If, at the end of the reporting quarter,
the grace period has not yet expired and the QA test has not yet been completed, leave
these fields blank. Otherwise, report the date and hour within the reporting quarter on
which the grace period ended or expired. If you report data on a year-round basis, this
will either be the date and hour within the grace period on which the required test was
passed or the date and hour on which the maximum allowable number of operating hours
was reached, and the grace period expired. For Subpart H sources that report data only in
the ozone season, there is one additional possibility for the third calendar quarter. If, at
the end of the third quarter, the maximum number of allowable operating hours in the
grace period have not yet elapsed and the required QA test has not yet been completed,
report the last hour in the third quarter as the end of the grace period.
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E. Electronic Compliance Certification Records
The RTs 900-level enable electronic versions of the DR/ADR/AAR/AAAR signature, certification
statements, and other cover letter information to be directly included in the electronic quarterly report.
For Acid Rain units, RTs 900 and 901 are an optional replacement for the hardcopy DR/ADR
signature required to accompany a quarterly report submission. However, if RTs 900 and 901 are not
included with an Acid Rain quarterly report file, then a hardcopy cover letter with, at a minimum, the
DR/ADR certification statement and signature must be submitted to EPA. Although it is not required,
EPA strongly encourages the use of RTs 900 and 901, rather than hard copy cover letters.
For Subpart H units, RTs 940 and 941 are an optional replacement for the hardcopy AAR/AAAR
signature required to accompany a quarterly report submission. However, if RTs 940 and 941 are not
included with a Subpart H unit quarterly report file, then a hardcopy cover letter with, at a minimum, the
AAR/AAAR certification statement and signature must be submitted to EPA. Although it is not required,
EPA strongly encourages the use of RTs 940 and 941, rather than hard copy cover letters.
For units subject to both the Acid Rain Program and Subpart H, owners and operators are
strongly encouraged (but not required) to designate the same person as DR (for the Acid Rain Program)
and as AAR (for Subpart H). Designating the same person for these responsibilities facilitates, among
other things, the submission and certification of electronic reporting of quarterly reports. When a
quarterly report is submitted electronically, only one representative is authorized by EPA to submit a data
file directly to the mainframe. If the DR and the AAR are not the same, EPA requires both the DR and
the AAR to submit a statement to the EPA granting authorization to the other representative to
electronically submit the quarterly reports for which they are jointly responsible. If the DR and AAR sign
the joint certification statement, RTs 900, 901, 940, and 941 can be contained in the quarterly report. If
the DR and AAR do not sign and submit the authorization statement, either the DR or AAR may submit
the quarterly report (and use the appropriate certification records to certify the submittal) while the
certifying official not submitting the quarterly report must submit to EPA a signed hard copy certification
letter each quarter. EPA will contact the AAR and DR if they are required to provide the joint
authorization statement and have not completed it.
The seven record types for certification are:
Record Type Description
900
Acid Rain Program Part 75 Certification and DR/ADR Signature
901
Acid Rain Program Part 72 Certification Statement, verbatim
910
Cover Letter Text, File Specific (Optional)
920
Cover Letter Text, Not File Specific (Optional)
940
Subpart H Certification and AAR/AAAR Signature
941
Subpart H Certification Statement, verbatim
999
Contact Person Information (Optional)
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(1) RT 900: Part 75 Certification Statement and Designated Representative
Signature (ARP)
Each quarterly report should contain only one RT 900, containing the applicable Part 75
certification statement and signature. RT 900 identifies (by last name, first name, and middle initial) the
DR or ADR responsible for signing the cover letter, and also indicates the signature date. RT 900 also
contains one of three codes (CERTIFY, CERTIFY CONTROLLED, or CERTIFY DEFERRED) to
identify the appropriate Part 75 certification statement required for the quarterly report:
(a) For most reports that contain data for certified units, the code "CERTIFY" is appropriate.
This code is also appropriate for a report submitted for a unit that did not operate during the
quarter. Use this code unless another code applies.
(b) If the quarterly report contains data for a stack or unit with add-on emission controls, then
the code "CERTIFY CONTROLLED" is appropriate to indicate that the designated
representative certifies that for all hours where data are substituted following the provisions
of § 75.34(a)(1), that the add-on emission controls were operating within the range of
parameters listed in the monitoring plan and that the substitute values recorded during the
quarter do not systematically underestimate S02 or NOx emissions and that the controls were
operating properly during any periods of missing data.
(c) While owners and operators of affected units that are shut down on their compliance deadline
do not have to begin reporting until required to do by the applicable rule deadline (see
Section C.(13) on "Data Reporting Requirements for Uncertified Units"), data for a deferred
unit can optionally be reported at any time on or after the compliance deadline that would
have been applicable to them if they had been operating. If data for a deferred unit are
reported, even though it is not yet certified and is still not operating, continue to report in
every quarter until you notify EPA that the unit has been retired. If the owner or operator of
a unit in this circumstance chooses to report, he or she should use the code "CERTIFY
DEFERRED".
A footnote for RT 900 contains the certification text represented by each certification code.
(2) RT 901: Part 72 Certification Statement (ARP)
Submit RTs 901 to include the Acid Rain Program Part 72 verbatim certification statement:
I am authorized to make this submission on behalf of the owners and operators of the affected
source or affected units for which the submission is made. I certify under penalty of law that I
have personally examined, and am familiar with, the statements and information submitted in this
document and all its attachments. Based on my inquiry of those individuals with primary
responsibility for obtaining the information, I certify that the statements and information are to the
best of my knowledge and belief true, accurate, and complete. I am aware that there are
significant penalties for submitting false statements and information or omitting required
statements and information, including the possibility of fine or imprisonment.
Make sure that the text for each line does not go beyond column 73 (beginning at column 6 and
ending at column 67). Each RT 901 contains a number (in columns 4 and 5) indicating which of the lines
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of certification text is contained in that record, followed by that line of the certification text (verbatim) as
shown in the following example for the first line of the certification statement:
Example RT 901
901011 am authorized to make this submission on behalf of the owners
90102 and operators of the affected source.
(3) RT 910: Cover Letter Text, File-specific (Optional)
RT 910 allows for electronic reporting of cover letter information which would otherwise be
provided in a hardcopy cover letter. RT 910 can be used to report information that is specific to the
quarterly report for any Program. An example of an issue that may be outlined in RT 910 is if the DR
uses a code of 999 (other) in column 16 of RT 556 to describe a monitoring system certification event.
The DR can use the RT 910 to provide an additional explanation about the event. If the DR/AAR is
requesting permission to deviate from the requirements of the Acid Rain Program, the DR/AAR should
send that petition under separate cover.
RT 910 is optional; if you do not need to report any additional, file-specific information, only
include RTs 900 and 901 (Acid Rain Program) and/or RTs 940 and 941 (Subpart H) in the quarterly
report. You may include as many RTs 910 as necessary to convey additional information. In the last RT
910, include the word "END" to indicate that this is the last record in the set.
(4) RT 920: Cover Letter Text, Not File-specific (Optional)
RT 920 allows for electronic reporting of cover letter information that would otherwise be
provided in a hardcopy cover letter. RT 920 can be used to report information that is not specific to the
quarterly report (use RT 910 to report information that directly relates to the quarterly report).
RT 920 is optional; if you do not need to report any additional information that is not specific to
the quarterly report only include RTs 900 and 901 (Acid Rain Program) and/or RTs 940 and 941
(Subpart H) in the quarterly report. Include as many RTs 920 as necessary to convey additional
information that is not specific to the quarterly report. In the last RT 920, include the word "END" to
indicate that this is the last record in the set.
(5) RT 940: Subpart H Certification Statement and Authorized Account
Representative Signature
For Subpart H units, each quarterly report should contain only one RT 940, containing the
applicable program certifications and signatures. RT 940 identifies (by last name, first name, and middle
initial) the AAR or AAAR responsible for signing the cover letter, and also indicates the signature date.
RT 940 also contains one of three codes (CERTIFY, CERTIFY CONTROLLED, or CERTIFY
DEFERRED) to identify the appropriate certification statement required for the quarterly report:
(a) For most reports that contain data for certified units, the code "CERTIFY" is appropriate.
This code is also appropriate for a report submitted for a unit that did not operate during the
quarter. Use this code unless another code applies.
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(b) If the quarterly report contains data for a stack or unit with add-on emission controls, then
the code "CERTIFY CONTROLLED" is appropriate.
(c) "CERTIFY DEFERRED" may be reported for a non-operating, affected unit that is not yet
certified under Subpart H.
A footnote for RT 940 contains the certification text represented by each of these three
certification codes, see the footnote pertaining to RT 940.
(6) RT 941: Subpart H General Certification Statement
Submit RT 941 to include the appropriate Subpart H verbatim certification statement. Ask your
State for the exact text of the certification statement. Make sure that the text for each line does not go
beyond column 73 (beginning at column 6 and ending at column 67). Each RT 941 contains a number (in
columns 4 and 5) indicating which of the lines of certification text is contained in that record, followed by
that line of the certification text (verbatim) as shown in the following example for the first line of the
certification statement:
Example RT 941
94101 I am authorized to make this submission on behalf of the owners
94102 and operators of the affected source.
(7) RT 999: Contact Person Record (Optional)
This optional record can be used to identify a contact person (including the DR, ADR, AAR,
AAAR, Environmental Manager or CEMS contact) who can respond to questions regarding the quarterly
report. It also provides a place to update contact information, (i.e.. phone or e-mail address information).
Page 274
Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: Appendix A
December 2005
APPENDIX A:
GUIDELINES FOR PREPARATION OF EDR SUBMITTALS
I INTRODUCTION
Under the Acid Rain Program and Subpart H there are three principal types of electronic reports
which must be submitted in EDR format. These are: (1) monitoring plan submittals; (2) certification and
recertification applications; and (3) quarterly emissions reports. This appendix explains which EDR
record types are associated with each type of submittal. The "basic" or essential record types for each
type of submittal are presented in Section II and supplementary tables are provided in Section III, which
give additional record types that must be reported for specific monitoring methodologies. The guidelines
in Sections II and III apply to all affected units except for units that qualify to use the low mass emissions
(LME) unit methodology under § 75.19. EDR reporting guidelines for LME units are presented in
Section IV of this appendix.
II BASIC ELEMENTS OF AN EDR SUBMITTAL
A. Monitoring Plans
The following record types are the basic elements of a monitoring plan submittal:
Table A
BASIC MONITORING PLAN RECORD TYPES
Record Type
Description
IVo^riim Applicability it ml Comments
100
Facility Identification
ARP, Subpart H
503
Stack and Pipe Definition
ARP, Subpart H for certain configurations.
See Table D below.
504
Unit Information
ARP, Subpart H
505
Program Indicator for Report
ARP, Subpart H
506
EIA Cross reference Information
ARP, Subpart H
535
Unit and Stack Operating Load
Data
ARP, Subpart H
Required for any unit, stack or pipe using load-based missing
data procedures, either for NOx, stack flow rate or fuel flow rate
585
Monitoring Methodology
Information
ARP, Subpart H
586
Control Equipment Information
ARP, Subpart H (if emission controls are present).
See Table D below.
587
Unit Fuel Type
ARP, Subpart H
Other 5XX
Records
-
See Tables A-l through A-13 below for additional 500-level
records that may be required for specific monitoring
methodologies.
9XX Records
-
RTs 900, 901, 910, 920, 940, 941, and 999 are optional.
Hardcopy cover letters and certification statements may be
submitted in lieu of these records.
Clean Air Markets Division, U.S. EPA
A-l
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December 2005
EDR v2.2 Instructions: Appendix A
B. Certification or Recertification Application
The following record types are the basic elements of a certification or recertification application
submittal. Note that a certification or recertification application includes the basic monitoring plan
elements from Section II. A, plus the results of the required certification or recertification tests.
Table B
CERTIFICATION AND RECERTIFICATION BASIC RECORD TYPES
Record Type
Description
IVo^nini Applicability siihI Comments
100
Facility Identification
ARP, Subpart H
503
Stack and Pipe Definition
ARP, Subpart H for certain configurations.
See Table D below.
504
Unit Information
ARP, Subpart H
505
Program Indicator for Report
ARP, Subpart H
506
EIA Cross reference Information
ARP, Subpart H
535
Unit and Stack Operating Load
Data
ARP, Subpart H
Required for any unit, stack or pipe using load-based missing
data procedures, either for NOx, stack flow rate or fuel flow
rate.
585
Monitoring Methodology
Information
ARP, Subpart H
586
Control Equipment Information
ARP, Subpart H (if emission controls are present). See Table D
below.
587
Unit Fuel Type
ARP, Subpart H
Other 5XX
Records
-
See Tables A-l through A-13 below for additional 500-level
records that may be required for specific monitoring
methodologies.
6XX Records
-
Submit the results of all QA tests required for certification or
recertification in the appropriate 600-level records. See Tables
A-l through A-13 below.
900
Certifications
ARP
Hard copy certification may be provided in lieu of this record
type.
901
Certifications
ARP
Hard copy certification may be provided in lieu of this record
type.
910
Comments
ARP, Subpart H
920
Comments
ARP, Subpart H
940
Certifications
Subpart H
Hard copy certification may be provided in lieu of this record
type.
941
Certifications
Subpart H
Hard copy certification may be provided in lieu of this record
type.
999
Contact Information
ARP, Subpart H
Page A-2
Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: Appendix A
December 2005
C. Quarterly Emissions Report
The following record types are the basic elements of a quarterly emissions report submittal. Note
that a quarterly emissions report includes the basic monitoring plan elements from Section II. A, plus
additional information.
Table C
QUARTERLY EMISSIONS REPORT RECORD TYPES
Record Type
Description
IVo^nim Applicability it ml Comments
100
Facility Identification
ARP, Subpart H
101
Record Types Submitted
ARP, Subpart H (Optional)
102
Facility Location and Identification
Information
ARP, Subpart H
2XX Records
-
For units with CEMS, report hourly emission data in the
appropriate 200-level records. See Tables A-l through A-7b,
below.
300
Operating Data
ARP, Subpart H
Report one RT 300 for each hour for each unit stack or pipe
location except for units, stacks or pipes which did not
operate during the entire quarter.
301
Quarterly Cumulative Emissions
Data
ARP
307
Cumulative NOx Mass Emissions
Data
Subpart H
328
NOx Mass Emissions
Subpart H
Other 3 XX
Records
-
Other 300-level records are required for specific monitoring
methodologies. See Tables A-l through A-13, below for
details.
503
Stack and Pipe Definition
ARP, Subpart H for certain configurations. See Table D
below.
504
Unit Information
ARP, Subpart H
505
Program Indicator for Report
ARP, Subpart H
506
EIA Cross Reference Information
ARP, Subpart H
535
Unit/Stack Operating Load Data
ARP, Subpart H
Report for any unit, stack or pipe using load-based missing
data procedures, either for NOx, stack flow rate or fuel flow
rate.
585
Monitoring Methodology
Information
ARP, Subpart H
586
Control Equipment Information
ARP, Subpart H (if emission controls are present).
See Table D below.
587
Unit Fuel Type
ARP, Subpart H
(cont.)
Clean Air Markets Division, U.S. EPA
A-3
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December 2005
EDR v2.2 Instructions: Appendix A
Table C
QUARTERLY EMISSIONS REPORT RECORD TYPES (cont.)
Record Type
Description
IVo^nim Applicability it ml Comments
Other 5XX
Records
-
See Tables A-l through A-13, below for additional 500-lcvcl
records that may be required for specific monitoring
methodologies.
6XX Records
-
Submit the results of all QA tests required for certification,
recertification and on-going quality assurance in the
appropriate 600-level records. See Tables A-l through A-13.
900
Certifications
ARP
Hard copy certification may be provided in lieu of this record
type.
901
Certifications
ARP
Hard copy certification may be provided in lieu of this record
type.
910
Comments
ARP, Subpart H
920
Comments
ARP, Subpart H
940
Certifications
Subpart H
Hard copy certification may be provided in lieu of this record
type.
941
Certifications
Subpart H
Hard copy certification may be provided in lieu of this record
type.
999
Contact Information
ARP, Subpart H
D. Required Records for All Reports Based on Operational Configuration
The following records are required for all types of EDR submittals, if certain operational
configurations (i.e.. control equipment, pipes, or stacks) exist.
Table D
RECORD TYPES REQUIRED FOR SPECIFIC
OPERATIONAL CONFIGURATIONS
Record T\pc
Description
Prn^riim Applicability :ind Comments
503
Stack and Pipe Definition
ARP, Subpart H
If a unit is monitored at a common stack or pipe (a stack or pipe
serving more than one unit) or has multiple stacks or pipes (where
emissions are measured at more than one stack exit or fuel source),
you must define these monitoring locations in RTs 503 in every EDR
submission.
586
Control Equipment Information
ARP, Subpart H
If a unit has NOx, S02 or particulate control equipment, you must
submit one RT 586 for each type of controls installed.
Page A-4
Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: Appendix A
December 2005
III SUPPLEMENTARY TABLES
Tables A-l through A-13, below, identify additional EDR record types that are either required or
optional for specific monitoring methodologies. Use these tables in conjunction with Section II of this
Appendix (Basic Elements of an EDR Submittal) to ensure that all of the essential information is reported
in each monitoring plan submittal, each certification or recertification application and each quarterly
emissions report.
A. Determining Applicable Program Requirements
To determine which additional methodology-specific EDR record types to report for a unit or
facility, you must first identify the program(s) under which the unit is regulated. There are three
possibilities:
(1) EPA Acid Rain Program (ARP only);
(2) ARP and Subpart H State NOx mass trading program (ARP and Subpart H); or
(3) Subpart H State NOx mass trading program (Subpart H only)
Once you have determined the program applicability for a unit, use Table A-l to determine which
pollutant and parameter information must be reported under the applicable program(s).
Table A-l
REQUIRED POLLUTANT AND PARAMETER INFORMATION BY PROGRAM
Program
Applicability
S02 Mass
I'linissions
C02 Mass
I'lmissioiis
NOx Mass
Minissioiis
NO, 1'mission
Rate
Ileal Input
Opacity
ARP Only
Required
Required
§ 75.19 LME
units only
Required
Required
Required
ARP and
Subpart H
Required
Required
Required
Required
Required
Required
Subpart H
Only
Not required
Not required
Required
Required only
for units using
NOx emission
rate and heat
input rate to
determine
NOx mass
emissions
Required only
for units using
NOx emission
rate and heat
input rate to
determine
NOx mass
emissions, or
if required by
a State rule.
Not Required
B. Determining the Available Monitoring Methodologies
For each applicable pollutant or parameter from Table A-l, determine the monitoring
methodology to be used. Table A-2 summarizes the allowable monitoring methodologies for various
pollutants and parameters. A parenthetical statement at the end of each listed methodology option
Clean Air Markets Division, U.S. EPA
A-5
-------
December 2005
EDR v2.2 Instructions: Appendix A
indicates which of the remaining tables in this section (i.e.. Tables A-3 through A-13) must be consulted
to determine the appropriate EDR record types to report.
Table A-2
ALLOWABLE MONITORING METHODOLOGIES
I'olliiliinl or
Piii'iiiiK'k'r
Monitoring Mcdiodoloiiv Options
S02 Mass
Emissions
1. S02 concentration CEMS and stack flow monitor (use Tables A-3 and A-6 and, if moisture
correction is necessary, Tables A-7a through A-7d)
2. Appendix D, fuel flowmeter and fuel sampling (use Table A-10)
3. Default S02 emission rate and heat input rate from a flow monitor and a diluent CEMS, under
§ 75.11(e)(1) (use Table A-6 and either Table A-6a or Table A-4a, as applicable)
4. Low mass emissions methodology under § 75.19 - for qualifying units (use Table A-14 in
Section IV)
C02 Mass
Emissions
1. C02 concentration CEMS and stack flow monitor (use Tables A-5, A-6, and, if moisture
correction is necessary, Tables A-7a through A-7d)
2. Appendix G (use Table A-12)
3. Low mass emissions methodology under § 75.19 - for qualifying units (use Table A-14 in
Section IV)
NOx Mass
Emissions
1. NOx concentration CEMS and stack flow monitor (Use Tables A-4a and A-6, and, if moisture
correction is necessary, Tables A-7a through A-7d)
2. NOx emission rate determined using a NOx-diluent CEMS and heat input rate determined
using a flow monitor and diluent CEMS (use Tables A-4a and A-6, and, if moisture correction
is necessary, Tables A-7a through A-7d)
3. NOx emission rate determined using a NOx-diluent CEMS and heat input rate determined
using a fuel flowmeter and the procedures of Appendix D (use Tables A-4a, if moisture
correction is necessary, Tables A-7a through A-7d, and Tables A-10 and A-ll).
4. NOx emission rate determined using Appendix E and heat input rate determined using a fuel
flowmeter and the procedures of Appendix D (for peaking units only) (use Tables A-10 and A-
11)
5. Low mass emissions methodology under § 75.19 - for qualifying units (use Table A-14 in
Section IV)
NOx Emission
Rate
1. NOx-diluent CEMS with F-factor (use Table A-4a and, if moisture correction is necessary,
Tables A-7a through A-7d)
2. Appendix E NOx correlation curve for qualifying peaking units (use Table D-l 1)
3. Low mass emissions methodology under § 75.19 - for qualifying units (use Table A-14 in
Section IV)
Heat Input
1. Stack flow monitor, diluent monitor, and F factor (use Tables A-6 and either Table A-4a or A-
6a, as applicable)
2. Appendix D fuel flowmeter and fuel GCV sampling (use Table A-10)
3. Low mass emissions methodology under § 75.19 - for qualifying units (use Table A-14 in
Section IV)
Opacity
Continuous opacity monitor (COM) (use Table A-8)
Page A-6
Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: Appendix A
December 2005
C. Interpreting Tables A-3 Through A-13
In Tables A-3 through A-13, below, the first column in each table identifies the record type. The
second column gives a brief description of the record type.
The third, fourth, and fifth columns indicate whether the record type must be reported for a
particular type of submittal. The third column header, "MP", refers to monitoring plan submittals. The
fourth column header, "CT", stands for certification or recertification applications. The fifth column
header, "QT", refers to quarterly emissions report submittals. The letter codes in columns 3 through 5
are defined as follows:
Y This record type is required for this type of submittal (monitoring plan,
certification/recertification application or quarterly emissions report)
N This record type is not appropriate for this type of submittal.
O This record type is appropriate, but optional for this type of submittal.
A This record type may be required for this submittal. If any doubt exists as to the need to
submit this record type, consult the appropriate EDR instructions.
T This record type is required each time a quality assurance test (e.g.. a RATA or linearity
check) is performed.
UA This record type must be updated each year or ozone season to demonstrate continuing
qualification for or compliance with various rule provisions (e.g.. peaking unit status).
Column 6 in each table lists the programs applicable to the record type. The information in this
column indicates whether a certain record type is required for the Acid Rain Program, (ARP), or for
Subpart H NOx mass emission reporting (Subpart H), or both. Column 6 also provides brief reporting
instructions for certain record types.
Once you have determined which record types have to be submitted, read the general reporting
instructions and the column-specific instructions for those record types to ensure that the data elements in
each record type are properly reported and that each record type is reported for the appropriate number
of hours or situations and under the appropriate unit or stack ID(s).
D. Reporting Data for an S02 CEMS
Table A-3 describes record types required for an Acid Rain Program unit or stack at which a S02
concentration monitor and a flow monitor are used to determine S02 mass emissions. This Table
describes record types applicable to the S02 CEMS only. To determine S02 mass emissions also requires
a flow monitor (see Table A-6). If S02 concentration is measured on a dry basis, a moisture monitoring
system or an appropriate moisture default value must be used to correctly calculate S02 mass emissions
(see Tables A-7a through A-7d).
Clean Air Markets Division, U.S. EPA
A-7
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December 2005
EDR v2.2 Instructions: Appendix A
Table A-3
RECORD TYPES FOR S02 CEMS METHODOLOGY
Record
Tj pc
Description
IMP
CT
QT
I'l'o^i'iim Applicability iiml ( oiniiiciUs
200
S02 Concentration Data
N
N
Y
ARP
230
Daily Calibration Test Data and
Results
N
N
Y
ARP
310
S02 Mass Emissions Data
N
N
Y
ARP
507
Data to Qualify as a Peaking Unit
A
A
A
ARP
To claim exemption from 7-day calibration error test
510
Monitoring Systems Analytical
Components Table
Y
Y
Y
ARP
See RT 510 instructions.
520
Formula Table
Y
Y
Y
ARP
Report S02 mass emission formula.
530
Span Table
Y
Y
Y
ARP
Report span value(s) for S02.
536
Range of Operation, Normal Load
and Load Usage
Y
Y
Y
ARP
Required for any unit or common stack with CEMS.
550
Reason for Monitoring System
Downtime or Missing Parameter
N
N
O
ARP
Optional record type.
556
Monitoring System Recertification,
Maintenance, or Other Events
N
A
A
ARP
Report RT 556 for recertifications, diagnostic tests
and whenever the conditional data validation
procedures of § 75.20(b)(3) are applied.
600
7-Day Calibration Error Test Data
and Results
N
Y
T
ARP
Report for each 7-day cal error test performed for
certification or recertification.
601
Linearity Check Data
N
Y
T
ARP
Report RTs 601 each time a linearity check is
performed for certification, recertification or for on-
going QA/QC.
602
Linearity Check Results
N
Y
T
ARP
Report RTs 602 each time a linearity check is
performed for certification, recertification or for on-
going QA/QC.
610
RATA and Bias Test Data
N
Y
T
ARP
Report RTs 610 each time a RATA is performed for
certification, recertification or for on-going QA/QC.
611
RATA and Bias Test Results
N
Y
T
ARP
Report RT 611 each time a RATA is performed for
certification, recertification or for on-going QA/QC.
621
Cycle Time Test Data and Results
N
Y
T
ARP
Report RT 621 each time a cycle time test is
performed for certification or recertification.
623
Qualifying Test for Off Line
Calibration Demonstration
N
N
A
ARP
Report when off-line calibrations are used to validate
emission data.
(cont.)
Page A-8
Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: Appendix A
December 2005
Table A-3
RECORD TYPES FOR S02 CEMS METHODOLOGY (cont.)
Record
Tj pc
Description
IMP
CT
QT
Pro^mm Applicability iind ( oiiiincnls
697
RATA Deadline Extension or
Exemption
N
N
A
ARP
Report when claiming a RATA deadline extension or
a RATA exemption. (See instructions.)
698
QA Test Quarterly Exemption
N
N
A
ARP
Report when claiming a quarterly linearity test
exemption under Part 75, Appendix B, Section 2.2.1.
699
QA Test Extension Based on Grace
Period
N
N
A
ARP
Report when claiming a RATA test deadline extension
under Appendix B, Section 2.3.3 or when claiming a
linearity test deadline extension under Appendix B,
Section 2.2.4.
E. Reporting Data for a NOx Emission Rate System
Table A-4a describes record types required for a unit or stack at which NOx emission rate is
monitored with a NOx-diluent CEMS. A NOx-diluent CEMS is comprised of a NOx concentration
monitor and a diluent (02 or C02) monitor. This type of system is used to determine NOx emission rate.
Depending upon the equation used to calculate the NOx emission rate, a moisture correction may be
necessary (see Tables A-7a through A-7d).
Under Subpart H, the NOx concentration component of a NOx-diluent system may be used with a
flow monitor to determine NOx mass emissions, in which case duplicate reporting of RT 201 is required
(see instructions for RT 201). The diluent component of a NOx-diluent system may also be used to
determine heat input rate, moisture or C02 mass emissions. In cases where the diluent monitor is used
for multiple purposes carefully review the reporting instructions to determine if multiple RTs 210 or 211
are required. Note that the following record types listed in this table must be reported separately for the
NOx and diluent component monitors: RTs 230, 510, 530, 600, 601, 602, 621, 623, 698, and 699
(linearity check grace period, only).
Table A-4a
RECORD TYPES FOR NOx-DILUENT CEMS
Record
Tj pc
Description
IVIP
CT
QT
Proiinini Applicability ;ind ( ommcnls
201
NOx Concentration Data
N
N
Y
ARP, Subpart H
210 or 211
C02 Concentration Data or
02 Concentration Data
N
N
Y
ARP, Subpart H
Report RT 210 or 211, depending on the type of
diluent monitor used.
230
Daily Calibration Test Data and
Results
N
N
Y
ARP, Subpart H
Report separate RTs 230 for the NOx concentration
monitor and the diluent monitor.
(cont.)
Clean Air Markets Division, U.S. EPA
A-9
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December 2005
EDR v2.2 Instructions: Appendix A
Table A-4a
RECORD TYPES FOR NOx-DILUENT CEMS (cont.)
Record
Tj |)0
Di'scriplion
IVIP
CT
QT
Pro^mm \|>plic;il>ilil> iiiul Com men (n
320
NOx Emission Rate Data
N
N
Y
ARP, Subpart H
507
Data to Qualify as a Peaking Unit
A
A
A
ARP, Subpart H
To claim exemption from 7-day calibration error test
510
Monitoring Systems Analytical
Components Table
Y
Y
Y
ARP, Subpart H
See RT 510 instructions.
520
Formula Table
Y
Y
Y
ARP, Subpart H
Report NOx emission rate formula used.
530
Span Table
Y
Y
Y
ARP, Subpart H
Report span value(s) for NOx and diluent (C02 or 02).
536
Range of Operation, Normal Load
and Load Usage
Y
Y
Y
ARP, Subpart H
Required for any unit or common stack with CEMS.
550
Reason for Monitoring System
Downtime or Missing Parameter
N
N
O
ARP, Subpart H
Optional record type
556
Monitoring System Recertification,
Maintenance, or Other Events
N
A
A
ARP, Subpart H
Report for recertifications, diagnostic tests and
whenever the conditional data validation procedures of
§75.20(b)(3) are applied.
600
7-Day Calibration Error Test Data
and Results
N
Y
T
ARP, Subpart H
Report for each 7-day cal error test performed for
certification or recertification.
601
Linearity Check Data
N
Y
T
ARP, Subpart H
Report RTs 601 each time a linearity check is
performed for certification, recertification or for on-
going QA/QC.
602
Linearity Check Results
N
Y
T
ARP, Subpart H
Report RTs 602 each time a linearity check is
performed for certification, recertification or for on-
going QA/QC.
610
RATA and Bias Test Data
N
Y
T
ARP, Subpart H
Report RTs 610 each time a RATA is performed for
certification, recertification or for on-going QA/QC.
611
RATA and Bias Test Results
N
Y
T
ARP, Subpart H
Report RT 611 each time a RATA is performed for
certification, recertification or for on-going QA/QC.
621
Cycle Time Test Data and Results
N
Y
T
ARP, Subpart H
Report RT 621 each time a cycle time test is
performed for certification or recertification.
623
Qualifying Test for Off Line
Calibration Demonstration
N
N
A
ARP, Subpart H
Report when off-line calibrations are used to validate
emission data.
697
RATA Deadline Extension or
Exemption
N
N
A
ARP, Subpart H
Report when claiming a RATA deadline extension or a
RATA exemption. (See instructions.)
(cont.)
Page A-10
Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: Appendix A
December 2005
Table A-4a
RECORD TYPES FOR NOx-DILUENT CEMS (cont.)
Record
Tj |)C
Description
IVIP
CT
QT
Pro^mm \|>plic;il>ilil> iiiul Com men (n
698
QA Test Quarterly Exemption
N
N
A
ARP, Subpart H
Report when claiming a quarterly linearity test
exemption under Part 75, Appendix B, Section 2.2.1.
699
QA Test Extension Based on Grace
Period
N
N
A
ARP, Subpart H
Report when claiming a RATA test deadline extension
under Appendix B, Section 2.3.3 or when claiming a
linearity test deadline extension under Appendix B,
Section 2.2.4.
F. Reporting Data from a NOx Concentration Monitoring System
Table A-4b describes record types required for Subpart H units or stacks at which a NOx
concentration monitor and a flow rate monitoring system (see Table A-6) are used to determine NOx
mass emissions. If NOx concentration is measured on a dry basis, a moisture correction will be needed
(see Tables A-7a through A-7d). The NOx concentration CEMS may also be used to determine NOx
emission rate as part of a NOx-diluent system (see Table A-4a).
Table A-4b
RECORD TYPES FOR NOx CONCENTRATION CEMS
Record
Tj pe
Description
IMP
CT
QT
Pro^mm Applicability iind Comments
201
NOx Concentration Data
N
N
Y
Subpart H
230
Daily Calibration Test Data/Results
N
N
Y
Subpart H
507
Data to Qualify as a Peaking Unit
A
A
A
Subpart H
To claim exemption from 7-day calibration error test
510
Monitoring Systems Analytical
Components Table
Y
Y
Y
Subpart H
See RT 510 instructions.
520
Formula Table
Y
Y
Y
Subpart H
Report NOx mass emission formula.
530
Span Table
Y
Y
Y
Subpart H
Report span value(s) for NOx.
536
Range of Operation, Normal Load
and Load Usage
Y
Y
Y
Subpart H
Required for any unit or common stack with CEMS.
550
Reason for Monitoring System
Downtime or Missing Parameter
N
N
O
Subpart H
Optional record type.
(cont.)
Clean Air Markets Division, U.S. EPA
A-ll
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December 2005
EDR v2.2 Instructions: Appendix A
Table A-4b
RECORD TYPES FOR NOx CONCENTRATION CEMS (cont.)
Record
Tj pc
Description
IMP
CT
QT
Proiinini Applicability iiml ( oininciils
556
Monitoring System Recertification,
Maintenance, or Other Events
N
A
A
Subpart H
Report RT 556 for recertifications, diagnostic tests
and whenever the conditional data validation
procedures of § 75.20(b)(3) are applied.
600
7-Day Calibration Error Test Data
and Results
N
Y
T
Subpart H
Report for each 7-day cal error test performed for
certification or recertification.
601
Linearity Check Data
N
Y
T
Subpart H
Report RTs 601 each time a linearity check is
performed for certification, recertification or for on-
going QA/QC.
602
Linearity Check Results
N
Y
T
Subpart H
Report RTs 602 each time a linearity check is
performed for certification, recertification or for on-
going QA/QC.
610
RATA and Bias Test Data
N
Y
T
Subpart H
Report RTs 610 each time a RATA is performed for
certification, recertification or for on-going QA/QC.
611
RATA and Bias Test Results
N
Y
T
Subpart H
Report RT 611 each time a RATA is performed for
certification, recertification or for on-going QA/QC.
623
Qualifying Test for Off Line
Calibration Demonstration
N
N
A
Subpart H
Report when off-line calibrations are used to validate
emission data.
697
RATA Deadline Extension or
Exemption
N
N
A
Subpart H
Report when claiming a RATA deadline extension or
a RATA exemption. (See instructions.)
698
QA Test Quarterly Exemption
N
N
A
Subpart H
Report when claiming a quarterly linearity test
exemption under Part 75, Appendix B, Section 2.2.1.
699
QA Test Extension Based on Grace
Period
N
N
A
Subpart H
Report when claiming a RATA test deadline extension
under Appendix B, Section 2.3.3 or when claiming a
linearity test deadline extension under Appendix B,
Section 2.2.4.
G. Reporting Data for a C02 CEMS
Table A-5 summarizes record types required for Acid Rain Program units or stacks at which a
C02 CEMS and a flow monitoring system (see Table A-6) are used to determine C02 mass emissions. If
C02 concentration is measured on a dry basis, a moisture monitoring system or an appropriate moisture
default value must be used to correctly calculate C02 mass emissions (see Tables A-7a through A-7d).
Note that when a C02 CEMS is used for C02 mass emissions and also for diluent purposes there will be
some duplication of reporting. Carefully review the instructions to determine the appropriate reporting of
all record types.
Page A-12
Clean Air Markets Division, U.S. EPA
-------
EDR v2.2 Instructions: Appendix A
December 2005
Table A-5
RECORD TYPES FOR C02 CEMS
Record Tjpc
IK'scriplinn
MP
CT
QT
1'i'o^i'iiin A|)|)lic;il)ili(\ iiml Com men Is
202
C02 Concentration
N
N
Y
ARP
211
02 Concentration Data
N
N
Y
ARP
Report only if hourly oxygen concentration values and
Equation F-14a or F-14b are used to determine hourly
C02 concentration.
230
Daily Calibration Test/Results
N
N
Y
ARP
330
C02 Mass Emissions Data
N
N
Y
ARP
507
Data to Qualify as a Peaking Unit
A
A
A
ARP
To claim exemption from 7-day calibration error test
510
Monitoring Systems Analytical
Components Table
Y
Y
Y
ARP
See RT 510 instructions.
520
Formula Table
Y
Y
Y
ARP
Report C02 mass emission formula.
530
Span Table
Y
Y
Y
ARP
Report span value(s) for C02 or 02.
536
Range of Operation, Normal
Load, and Load Usage
Y
Y
Y
ARP
Required for any unit or common stack with CEMS
550
Reason for Monitoring System
Downtime or Missing Parameter
N
N
O
ARP
Optional record type.
556
Monitoring System
Recertification, Maintenance, or
Other Events
N
A
A
ARP
Report RT 556 for recertifications, diagnostic tests and
whenever the conditional data validation procedures of
§ 75.20(b)(3) are applied.
600
7-Day Calibration Error Test Data
and Results
N
Y
T
ARP
Report for each 7-day cal error test performed for
certification or recertification.
601
Linearity Check Data
N
Y
T
ARP
Report RTs 601 each time a linearity check is performed
for certification, recertification or for on-going QA/QC.
602
Linearity Check Results
N
Y
T
ARP
Report RTs 602 each time a linearity check is performed
for certification, recertification or for on-going QA/QC.
610
RATA and Bias Test Data
N
Y
T
ARP
Report RTs 610 each time a RATA is performed for
certification, recertification or for on-going QA/QC.
611
RATA and Bias Test Results
N
Y
T
ARP
Report RT 611 each time a RATA is performed for
certification, recertification or for on-going QA/QC.
621
Cycle Time Test Data and Results
N
Y
T
ARP
Report RT 621 each time a cycle time test is performed
for certification or recertification.
623
Qualifying Test for Off Line
Calibration Demonstration
N
N
A
ARP
Report when off-line calibrations are used to validate
emission data.
697
RATA Deadline Extension or
Exemption
N
N
A
ARP
Report when claiming a RATA deadline extension or a
RATA exemption. (See instructions.)
(cont.)
Clean Air Markets Division, U.S. EPA
A-13
-------
December 2005
EDR v2.2 Instructions: Appendix A
Table A-5
RECORD TYPES FOR C02 CEMS (cont.)
Record l\pc
Description
MP
CT
QT
Pro^mm Applicability iind (ommcnls
698
QA Test Quarterly Exemption
VI
VI
A
AR1>
Report when claiming a quarterly linearity test exemption
under Part 75, Appendix B, Section 2.2.1.
699
QA Test Extension Based on
Grace Period
N
N
A
ARP
Report when claiming a RATA test deadline extension
under Appendix B, Section 2.3.3 or when claiming a
linearity test deadline extension under Appendix B,
Section 2.2.4.
H. Reporting Data for a Stack Flow Monitoring System
Table A-6a describes record types required for units or stacks at which a flow monitor is used to
continuously measure the stack gas volumetric flow rate.
Table A-6a
RECORD TYPES FOR FLOW MONITORING SYSTEMS
Record
Tj pe
Description
IMP
CT
QT
Pro^riim Applicability ;ind (ommcnls
220
Volumetric l'low Data
VI
M
Y
ARP, Subpart 11
230
Daily Calibration Test Data and
Results
N
N
Y
ARP, Subpart H
231
Flow Daily Interference Check
Results
N
N
Y
ARP, Subpart H
507
Data to Qualify as a Peaking Unit
UA
A
UA
ARP, Subpart H
Report RT 507 if exemption from multi-load flow
RATAs is claimed or if exemption from 7-day
calibration error test is claimed, because the unit
qualifies as a peaking unit.
510
Monitoring Systems/ Analytical
Components Table
Y
Y
Y
ARP, Subpart H
See RT 510 instructions.
520
Formula Table
Y
Y
Y
ARP, Subpart H
530
Span Table
Y
Y
Y
ARP, Subpart H
Report both a calibration span value and a flow rate
span value.
536
Range of Operation, Normal Load,
and Load Usage
Y
Y
Y
ARP, Subpart H
Required for any unit or common stack with CEMS.
550
Reason for Monitoring System
Downtime or Missing Parameter
N
N
O
ARP, Subpart H
Optional record type.
556
Monitoring System Recertification,
Maintenance, or Other Events
N
A
A
ARP, Subpart H
Report RT 556 for recertifications, diagnostic tests
and whenever the conditional data validation
procedures of § 75.20(b)(3) are applied.
(cont.)
Page A-14
Clean Air Markets Division, U.S. EPA
-------
EDR v2.2 Instructions: Appendix A
December 2005
Table A-6a
RECORD TYPES FOR FLOW MONITORING SYSTEM (cont.)
Record
Tj po
Di'scriplinn
IMP
CT
QT
Prn^i'iim Appliciihilih iiiid ( umim-nls
600
7-Day Calibration Error Test Data
and Results
N
Y
T
ARP, Subpart H
Report RTs 600 each time a 7-day cal error test is
performed for certification or recertification.
603
Flow Leak Check Results
N
Y
T
ARP, Subpart H
Required for differential pressure type flow monitors
605
Reference Data for Flow-to-Load
Ratio or Gross Heat Rate Evaluation
N
N
A
ARP, Subpart H
Report RT 605 each quarter, unless exempted by an
approved petition under Section 7.8 of Appendix A.
606
Quarterly Flow-to-Load Ratio or
Gross Heat Rate Check
N
N
A
ARP, Subpart H
Report each quarter, unless exempted by an approved
petition under Section 7.8 of Appendix A.
610
RATA and Bias Test Data
N
Y
T
ARP, Subpart H
Report RTs 610 each time a RATA is performed for
certification, recertification or for on-going QA/QC.
611
RATA and Bias Test Results
N
Y
T
ARP, Subpart H
Report RTs 611 each time a RATA is performed for
certification, recertification or for on-going QA/QC.
614
Reference Method Supporting Data
for Flow RATA Tests
N
A
A
ARP, Subpart H
Report to support the use of Methods 2F and 2G and
whenever a wall effects factor is calculated using
Method 2H.
615
Reference Method Supporting Data
for Flow RATA Tests
N
A
A
ARP, Subpart H
Report to support the use of Methods 2F and 2G and
whenever a wall effects adjustment factor (WAF) is
calculated using Method 2H.
616
Reference Method Supporting Data
for Flow RATA Tests
N
A
A
ARP, Subpart H
Report to support the use of Method 2 when a default
WAF is used in accordance with Method 2H.
623
Qualifying Test for Off Line
Calibration Demonstration
N
N
A
ARP
Report when off-line calibrations are used to validate
emission data.
695
Single Load Flow RATA Claim
N
N
A
ARP, Subpart H
Report when using the provisions of Appendix B,
Section 2.3.1.3(c) to claim a single load annual flow
RATA.
697
RATA Deadline Extension or
Exemption
N
N
A
ARP, Subpart H
Report when claiming a RATA deadline extension or
a RATA exemption. (See instructions.)
698
QA Test Quarterly Exemption
N
N
A
ARP, Subpart H
Report when claiming a quarterly leak check
exemption for a DP-type monitor under Part 75,
Appendix B, Section 2.2.2 or when claiming an
exemption from flow-to-load ratio testing under
Section 7.8 of Appendix A.
699
QA Test Extension Based on Grace
Period
N
N
A
ARP, Subpart H
Report when claiming a RATA test deadline
extension under Appendix B, Section 2.3.3 or when
claiming a leak check deadline extension under
Appendix B, Section 2.2.4.
Clean Air Markets Division, U.S. EPA
A-15
-------
December 2005
EDR v2.2 Instructions: Appendix A
I. Reporting Data for a Diluent Monitor Used for Heat Input Rate Only
Table A-6b describes record types necessary to support a diluent monitor used in conjunction
with a flow monitoring system to determine hourly heat input rate but is not used to determine NOx
emission rate. Depending upon the equation used to calculate the heat input rate, a moisture correction
may be necessary (see Tables A-7a through 7d).
rNote: If the same diluent monitor is used for determining both heat input rate and the NOx emission rate,
disregard this Table and report only the records required under Table C-4 for the NOx-diluent CEMS.]
Table A-6b
RECORD TYPES FOR DILUENT MONITORS USED FOR
HEAT INPUT RATE ONLY
Record
Tj pc
Description
IMP
CT
QT
I'roiii iuii Applicability :iikI ( oininciils
210 or 211
C02 Concentration Data
02 Concentration Data
N
N
Y
ARP, Subpart H
Report RT 210 or 211, depending on the type of
diluent monitor used.
230
Daily Calibration Test Data and
Results
N
N
Y
ARP, Subpart H
507
Data to Qualify as a Peaking Unit
A
A
A
ARP, Subpart H
To claim exemption from 7-day calibration error test
510
Monitoring Systems Analytical
Components Table
Y
Y
Y
ARP, Subpart H
See RT 510 instructions.
520
Formula Table
Y
Y
Y
ARP, Subpart H
Report heat input rate formula used.
530
Span Table
Y
Y
Y
ARP, Subpart H
Report span value for the diluent CEMS.
536
Range of Operation, Normal Load,
and Load Usage
Y
Y
Y
ARP, Subpart H
Required for any unit or common stack with CEMS.
550
Reason for Monitoring System
Downtime or Missing Parameter
N
N
O
ARP, Subpart H
Optional record type.
556
Monitoring System Recertification,
Maintenance, or Other Events
N
A
A
ARP, Subpart H
Report RT 556 for recertifications, diagnostic tests and
whenever the conditional data validation procedures of
§ 75.20(b)(3) are applied.
600
7-Day Calibration Error Test Data
and Results
N
Y
T
ARP, Subpart H
Report for each 7-day cal error test performed for
certification or recertification.
601
Linearity Check Data
N
Y
T
ARP, Subpart H
Report RTs 601 each time a linearity check is
performed for certification, recertification or for on-
going QA/QC.
602
Linearity Check Results
N
Y
T
ARP, Subpart H
Report RTs 602 each time a linearity check is
performed for certification, recertification or for on-
going QA/QC.
(cont.)
Page A-16
Clean Air Markets Division, U.S. EPA
-------
EDR v2.2 Instructions: Appendix A
December 2005
Table A-6b
RECORD TYPES FOR DILUENT MONITORS USED FOR
HEAT INPUT RATE ONLY (cont.)
Record
Tj pc
Description
IMP
CT
QT
I'l'o^i'iim \|)|)lic;il)ili(> iind ( oiiinu'iUs
610
RATA and Bias Test Data
N
Y
T
ARP, Subpart H
Report RTs 610 each time a RATA is performed for
certification, recertification or for on-going QA/QC.
611
RATA and Bias Test Results
N
Y
T
ARP, Subpart H
Report RT 611 each time a RATA is performed for
certification, recertification or for on-going QA/QC.
621
Cycle Time Test Data and Results
N
Y
T
ARP, Subpart H
Report RT 621 each time a cycle time test is performed
for certification or recertification.
623
Qualifying Test for Off Line
Calibration Demonstration
N
N
A
ARP, Subpart H
Report when off-line calibrations are used to validate
emission data.
697
RATA Deadline Extension or
Exemption
N
N
A
ARP, Subpart H
Report when claiming a RATA deadline extension or a
RATA exemption (See instructions).
698
QA Test Quarterly Exemption
N
N
A
ARP, Subpart H
Report when claiming a quarterly linearity test
exemption under Part 75, Appendix B, Section 2.2.1.
699
QA Test Extension Based on Grace
Period
N
N
A
ARP, Subpart H
Report when claiming a RATA test deadline extension
under Appendix B, Section 2.3.3 or when claiming a
linearity test deadline extension under Appendix B,
Section 2.2.4.
J. Reporting Moisture Data
Tables A-7a through A-7d below summarize reporting for the four different methods of
determining hourly stack gas moisture content. Moisture corrections are required in the following
situations:
• When S02, NOx, and C02 mass emissions are determined using a wet-basis stack flow monitor
and an S02, NOx, or C02 pollutant concentration monitor that measures on a dry basis (see
Equations F-2 and F-14b from Appendix F of 40 CFR Part 75 and Equation N-2 in the (RT
520 instructions); or
• When heat input rate is determined using Equation F-16, F-17, or F-18 from Appendix F of
40 CFR Part 75; or
• When NOx emission rate is determined using Equation 19-3, 19-4, 19-5, 19-8, or 19-9 from
Method 19 in Appendix A of 40 CFR Part 60.
Clean Air Markets Division, U.S. EPA
A-17
-------
December 2005
EDR v2.2 Instructions: Appendix A
(1) Reporting for Wet/Dry 02 CEMS
Table A-7a describes record types required for units or stacks at which wet and dry-basis 02
monitors are used to determine moisture. Note that certain record types are required for both the wet
and dry oxygen monitors.
Table A-7a
RECORD TYPES FOR WET/DRY 02 CEMS
Record
Tj pc
Description
IMP
CT
QT
Pro^mm A|)|)lic;il)ilil\ iind ( oniincnls
211
02 Concentration Data
N
N
Y
ARP, Subpart H
Report separate RTs 211 for the readings from the wet
and dry oxygen monitors.
212
Moisture Data
N
N
Y
ARP, Subpart H
230
Daily Calibration Test Data and
Results
N
N
Y
ARP, Subpart H
Report only one RT 230 if the wet and dry 02 readings
are obtained by a single analyzer.
510
Monitoring Systems Analytical
Components Table
Y
Y
Y
ARP, Subpart H
See RT 510 instructions.
520
Formula Table
Y
Y
Y
ARP, Subpart H
Report moisture formula M-l.
530
Span Table
Y
Y
Y
ARP, Subpart H
Report span value(s) for 02.
536
Range of Operation, Normal Load,
and Load Usage
Y
Y
Y
ARP, Subpart H
Required for any unit or common stack with CEMS.
550
Reason for Monitoring System
Downtime or Missing Parameter
N
N
O
ARP, Subpart H
Optional record type.
556
Monitoring System Recertification,
Maintenance, or Other Events
N
A
A
ARP, Subpart H
Report RT 556 for recertifications, diagnostic tests
and whenever the conditional data validation
procedures of § 75.20(b)(3) are applied.
600
7-Day Calibration Error Test Data
and Results
N
Y
T
ARP, Subpart H
Report for each 7-day cal error test performed for
certification or recertification.
601
Linearity Check Data
N
Y
T
ARP, Subpart H
Report RTs 601 each time a linearity check is
performed for certification, recertification or for on-
going QA/QC.
602
Linearity Check Results
N
Y
T
ARP, Subpart H
Report RTs 602 each time a linearity check is
performed for certification, recertification or for on-
going QA/QC.
610
RATA and Bias Test Data
N
Y
T
ARP, Subpart H
Report RTs 610 each time a RATA is performed for
certification, recertification or for on-going QA/QC.
611
RATA and Bias Test Results
N
Y
T
ARP, Subpart H
Report RT 611 each time a RATA is performed for
certification, recertification or for on-going QA/QC.
(cont.)
Page A-18
Clean Air Markets Division, U.S. EPA
-------
EDR v2.2 Instructions: Appendix A
December 2005
Table A-7a
RECORD TYPES FOR WET/DRY 02 CEMS (cont.)
Record
Tj ik-
Description
IMP
CT
QT
Pro^mm Applicidiilih iiiid Com men Is
MI
Cycle Time Test Data and Results
N
Y
T
ARP, Subpart H
Report RT 621 each time a cycle time test is
performed for certification or recertification.
623
Qualifying Test for Off Line
Calibration Demonstration
N
N
A
ARP, Subpart H
Report when off-line calibrations are used to validate
emission data.
697
RATA Deadline Extension or
Exemption
N
N
A
ARP, Subpart H
Report when claiming a RATA deadline extension or
a RATA exemption. (See instructions.)
698
QA Test Quarterly Exemption
N
N
A
ARP, Subpart H
Report when claiming a quarterly linearity test
exemption under Part 75, Appendix B, Section 2.2.1.
699
QA Test Extension Based on Grace
Period
N
N
A
ARP, Subpart H
Report when claiming a RATA test deadline
extension under Appendix B, Section 2.3.3 or when
claiming a linearity test deadline extension under
Appendix B, Section 2.2.4.
(2) Reporting for Continuous Moisture Sensors
Table A-7b describes record types required for units or stacks at which a continuous moisture
sensor is used to determine percent moisture.
Table A-7b
RECORD TYPES FOR CONTINUOUS MOISTURE SENSOR
Record
Tj pc
Description
IMP
CT
QT
Pro!£r;im Applicidiilih
-------
December 2005
EDR v2.2 Instructions: Appendix A
Table A-7b
RECORD TYPES FOR CONTINUOUS MOISTURE SENSOR (cont.)
Record
Tj pc
Description
IMP
CT
QT
Pro^mm Applicability iiml (oniincnls
611
RATA and Bias Test Results
N
Y
T
ARP, Subpart H
Report RT 611 each time a RATA is performed for
certification, recertification or for on-going QA/QC.
697
RATA Deadline Extension or
Exemption
N
N
A
ARP, Subpart H
Report when claiming a RATA deadline extension or
a RATA exemption (See instructions).
699
QA Test Extension Based on Grace
Period
N
N
A
ARP, Subpart H
Report when claiming a RATA test deadline
extension under Appendix B, Section 2.3.3.
(3) Reporting for Use of Default % Moisture
When a default moisture constant is used to account for the stack gas moisture content, report the
value inRT 531 (see §§ 75.11(b) and 75.12). Do not report hourly RTs 212.
Table A-7c
RECORD TYPES FOR DEFAULT % MOISTURE
Kccorri
Tj pc
Description
M
P
CT
QT
Pro^riim Applicability ;nul ( ommcnls
531
Maximums Minimums Defaults and
Constants
Y
Y
Y
ARP, Subpart H
Applies to coal and wood-fired units, only.
(4) Reporting for Use of Temperature and a Look-up Table
Report the record types in Table A-7d when a temperature sensor and a look-up table are used to
determine % moisture. This method may only be used for saturated gas streams.
Table A-7d
RECORD TYPES FOR REPORTING % MOISTURE
FOR SATURATED GAS STREAMS
Kccord
Tj pc
Dcscriplion
M
P
CT
QT
Pro^riim Applicability ;nul ( oniincnls
212
Moisture Data
N
N
Y
ARP, Subpart H
510
Monitoring Systems Analytical
Components Table
Y
Y
Y
ARP, Subpart H
550
Reason for Monitoring System
Downtime or Missing Parameter
N
N
O
ARP, Subpart H
Optional record type.
556
Monitoring System Recertification,
Maintenance, or Other Events
N
A
A
ARP, Subpart H
Report RT 556 only for recertifications.
Page A-20
Clean Air Markets Division, U.S. EPA
-------
EDR v2.2 Instructions: Appendix A
December 2005
K. Reporting for Opacity Monitoring
Table A-8 describes the record types that are required to document compliance with the Acid
Rain Program opacity monitoring requirements of § 75.14. Do not report hourly opacity readings in the
quarterly report.
Table A-8
RECORD TYPES FOR OPACITY MONITORS
Kccord
Tj |)l'
Ik'M'ripliun
IMP"
CT"
QT
I'ro^i'iim \|)|)lic;ihili(> iind Com men Is
507
Data to Qualify as a Gas-fired
Unit
UA
A
UA
ARP
Report RT 507 only if an exemption from opacity
monitoring is claimed because the unit qualifies as
gas-fired.
510
Monitoring Systems Analytical
Components Table
A
A
A
ARP
Report RT 510 only if installation of an opacity
monitor is required under § 75.14. See RT 510
instructions.
556
Monitoring System
Recertification, Maintenance, or
Other Events
N
A
A
ARP
Report RT 556 only for opacity monitor
recertifications.
** Note: The results of opacity monitor certification and recertification tests are submitted only in hardcopy, to the State and Regional
EPA offices, and are not submitted in EDR format.
L. Summary of Hourly Emissions and QA Reporting for CEMS
Table A-9 compares the hourly emissions data and quality-assurance reporting requirements for
different types of CEMS. For more details on reporting from each type of monitoring system see Tables
A-3 through A-7d above.
Clean Air Markets Division, U.S. EPA
A-21
-------
December 2005
EDR v2.2 Instructions: Appendix A
Table A-9
COMPARISON OF CEMS REPORTING
Record
Tj |)0
Description
IMP
CT
QT
Pro^riim A|)|)lic;il)ili(\ In Monitoring Sjslcm l >pc
so2
NO,
Cone
co2
1 LOW
NOx -
diluent
200
S02 Concentration Data
N
N
Y
ARP
-
-
-
-
201
NOx Concentration Data
N
N
Y
-
ARP
SUBH
-
-
ARP
SUBH
202
C02 Concentration Data
N
N
Y
-
-
ARP
-
-
210 or
211
C02 or 02 Diluent Data
N
N
A
-
-
-
-
ARP
SUBH
212
Moisture Data
N
N
A
ARP
ARP
SUBH
ARP
-
ARP
SUBH
220
Volumetric Flow Rate Data
N
N
A
-
-
-
ARP
SUBH
-
230
Daily Calibration Error Test Data
and Results
N
N
Y
ARP
ARP
SUBH
ARP
ARP
SUBH
ARP
SUBH
231
Flow Interference Check
N
N
Y
-
-
-
ARP
SUBH
-
310
S02 Mass Emissions Data
N
N
Y
ARP
-
-
-
-
320
NOx Emission Rate
N
N
Y
-
-
-
-
ARP
SUBH
330
C02 Mass Emissions Data
N
N
Y
-
-
ARP
-
-
600
7- Day Calibration Error Test
Data and Results
N
Y**
T
ARP
Cert/
Recert
ARP
SUBH
Cert/
Recert
ARP
Cert/
Recert
ARP
SUBH
Cert/
Recert
ARP
SUBH
Cert/
Recert
601 - 602
Linearity Check
N
Y
T
ARP
ARP
SUBH
ARP
-
ARP
SUBH
603
Leak Check
N
Y
T
-
-
-
ARP
SUBH
-
605 - 606
Reference and Quarterly Data for
Flow-to-Load Ratio Test
N
Y
T
-
-
-
ARP
SUBH
-
610-611
RATA and Bias Test Data
N
Y
T
ARP
ARP
SUBH
ARP
ARP
SUBH
ARP
SUBH
614-616
Supporting Data for Flow
RATAs
N
Y
T
-
-
-
ARP
SUBH
-
(cont.)
Page A-22
Clean Air Markets Division, U.S. EPA
-------
EDR v2.2 Instructions: Appendix A
December 2005
Table A-9
COMPARISON OF CEMS REPORTING (cont.)
Record
Tj ik-
Description
IMP
CT
QT
Pro^riim Applicability In Monitoring System Type
so2
NO,
Cone.
co2
1 LOW
NOx -
diluent
MI
Cycle Time Test Data and
Results
N
Y
T
ARP
Cert/
Recert
ARP
SUBH
Cert/
Recert
ARP
Cert/
Recert
ARP
SUBH
Cert/
Recert
ARP
SUBH
Cert/
Recert
623
Qualifying Test for Off Line
Calibration Demonstration
N
A
A
ARP
ARP
SUBH
ARP
ARP
SUBH
ARP
SUBH
697
RATA Deadline Extension or
Exemption
N
N
A
ARP
ARP
SUBH
ARP
ARP
SUBH
ARP
SUBH
698
Quarterly QA Test Exemption
N
N
A
ARP
ARP
SUBH
ARP
ARP
SUBH
ARP
SUBH
699
QA Test Extension Based on
Grace Period
N
N
A
ARP
ARP
SUBH
ARP
ARP
SUBH
ARP
SUBH
Unless exempted (for peaking units and S02 or NOx monitors with span values < 50 ppm).
M. Reporting for Appendix D
Table A-10 summarizes the EDR reporting requirements for units using the procedures of
Appendix D for hourly heat input rate determinations and for S02 mass emissions estimation.
Table A-10
RECORD TYPES FOR APPENDIX D
Record
Tj pc
Description
IMP
CT
QT
I'lOlii iim \pplic;il>ilil> ;ind Comments
302, 303
Hourly Heat Input Rate
N
N
Y
ARP, Subpart H
Must be paired with RT 313 or 314 when reporting
S02 mass emissions.
313, 314
S02 Mass Emissions
N
N
Y
ARP
Not required when using Appendix D to determine
heat input rate only.
510
Monitoring System Analytical
Systems Data
Y
Y
Y
ARP, Subpart H
See RT 510 instructions.
520
Formula Table
Y
Y
Y
ARP, Subpart H
Report the formulas used to calculate heat input and
S02 mass emissions.
(cont.)
Clean Air Markets Division, U.S. EPA
A-23
-------
December 2005
EDR v2.2 Instructions: Appendix A
Table A-10
RECORD TYPES FOR APPENDIX D (cont.)
Record
Tj pc
Description
IMP
CT
QT
I'lOlii iim Applicability iiml ( oiiimcnls
530
Span Table
Y
Y
Y
ARP, Subpart H
Report maximum NOx emission rate in GNOX or
ONOX span records for gas and oil respectively.
536
Range of Operation, Normal Load,
and Load Usage
A
A
A
ARP, Subpart H
Required if the optional fuel flow-to-load ratio
methodology in Section 2.1.7 of Appendix D is used.
540
Fuel Flowmeter Data
Y
Y
Y
ARP, Subpart H
Report a RT 540 for each fuel flowmeter monitoring
system.
550
Reason for Monitoring System
Downtime or Missing Parameter
N
N
O
ARP, Subpart H
Optional record type.
556
Monitoring System Recertification,
Maintenance, or Other Events
N
A
A
ARP, Subpart H
Report RT 556 only for fuel flowmeter
recertifications and when an abbreviated fuel flow-to-
load ratio diagnostic test is performed (see Section
2.1.7.4 of Appendix D).
624
Other QA Activities
N
A
A
ARP, Subpart H
Report when visual inspection of orifice, nozzle or
venturi flowmeters are performed.
627
Fuel Flowmeter Accuracy Test
N
A
T
ARP, Subpart H
Report only for fuel flowmeters that are certified and
quality assured by periodic accuracy tests according to
Section 2.1.5.1 or 2.1.5.2 of Appendix D.
628
Fuel Flowmeter Accuracy Test for
Orifice, Nozzle and Venturi
Flowmeter
N
A
T
ARP, Subpart H
Report only for orifice, nozzle and venturi-type
flowmeters that are quality assured by periodic
transmitter/transducer calibrations.
629
Fuel Flow-to-load Ration Test
Baseline Data
N
N
A
ARP, Subpart H
Report if quarterly fuel flow-to-load ratio test in
Section 2.1.7 of Appendix D is used to extend fuel
flowmeter accuracy test deadlines.
630
Quarterly Fuel Flow-to-load Ratio
Test Results
N
N
A
ARP, Subpart H
Report if quarterly fuel flow-to-load ratio test in
Section 2.1.7 of Appendix D is used to extend fuel
flowmeter accuracy test deadlines.
696
Fuel Flowmeter Accuracy Test
Extension
N
N
A
ARP, Subpart H
Use RT 696 to claim allowable extensions of fuel
flowmeter accuracy test deadlines.
N. Reporting for Appendix E
Table A-l 1 summarizes the record types specific to reporting NOx emission rate using the
methodology under Appendix E of part 75. If you use this methodology, you must also report the
Page A-24
Clean Air Markets Division, U.S. EPA
-------
EDR v2.2 Instructions: Appendix A
December 2005
appropriate record types to support the use of a fuel flowmeter for heat input rate determination under
Appendix D (see Table A-10).
Table A-ll
RECORD TYPES FOR APPENDIX E
Riionl
T\|k-
IK'siripiioii
MP
CT
QT
Pro;;nun \|>|>lk;il>ilil\ ;iihI ( 0111111111 Is
323
NOx Emission Rate Alternative
Estimation Parameters for Oil and
Gas
N
N
A
ARD, Subpart H
The use of this record type is limited to units that co-fire a
consistent combination of fuels and perform Appendix E
testing while combusting the fuel mixture.
324
NOx Emission Rate Estimation
Based on Appendix E
N
N
A
ARP, Subpart H
Report RT 324 for units that combust a single fuel. Report
two or more for units that combust multiple fuels ("e.g.. oil
and gas) but perform Appendix E tests based on single fuel
combustion.
325
NOx Emission Rate Estimation
Based on Appendix E for Multiple
Fuel Hours
N
N
A
ARP, Subpart H
For units that have separate NOx emission rate-heat input
rate correlation curves for each type of fuel combusted, use
RT 325 to report a combined NOx emission rate for any
hour in which the unit combusts more than one type of
fuel.
507
Data to Qualify as a Peaking Unit
UA
Y
UA
ARP, Subpart H
To use Appendix E, the unit must qualify as a peaking unit.
510
Monitoring Systems Analytical
Components Table
Y
Y
Y
ARP, Subpart H
See RT 510 instructions.
550
Reason for Monitoring System
Downtime or Missing Parameter
N
N
O
ARP, Subpart H
Optional record type.
556
Monitoring System Recertification,
Maintenance, or Other Events
N
N
T
ARP, Subpart H
Report RT 556 only when Appendix E recertification tests
are performed.
560
Appendix E NOx Correlation Curve
Segments
N
Y
Y
ARP, Subpart H
Report RTs 560 for each NOx correlation curve derived
from Appendix E testing. Report this record type in lieu of
providing formulas in RT 520.
650
NOx Emission Rate Correlation
Data
N
Y
T
ARP, Subpart H
Report RT 650 for each Appendix E test run performed for
certification, recertification or on-going quality assurance.
651
Appendix E NOx Emission Rate
Correlation Results
N
Y
T
ARP, Subpart H
Report RT 651 for each Appendix E load level test for each
certification, recertification or on-going quality test.
652
Oil Fuel Flow During Test
N
Y
T
ARP, Subpart H
Report RT 652 for each Appendix E test run performed
while combusting oil.
653
Gas Fuel Flow During Test
N
Y
T
ARP, Subpart H
Report RT 653 for each Appendix E test run performed
while combusting gas.
Clean Air Markets Division, U.S. EPA
A-25
-------
December 2005
EDR v2.2 Instructions: Appendix A
O. Reporting for Appendix G
Table A-12 summarizes the record types used when Appendix G of Part 75 is used to estimate
C02 mass emissions. If you use a fuel flowmeter in conjunction with the Appendix G Methodology you
must report the appropriate record types for the fuel flowmeter (see Table A-10, above).
Table A-12
RECORD TYPES FOR APPENDIX G
Record
Tj pc
Description
IMP
CT
QT
Pro^mm Applicability iind Comments
330
C02 Mass Emissions Data
N
N
Y
ARP
Report RT 330 for hours in which Equation G-4 is
used to determine hourly C02 mass emissions for gas-
fired units.
331
C02 Mass Emissions Estimations
Parameters
N
N
Y
ARP
520
Formula Table
Y
Y
Y
ARP
Report C02 mass emission formula(s).
P. Other Records for Special Circumstances
Table A-13 describes record types used for special situations under the Acid Rain Program or
Subpart H.
Table A-13
RECORD TYPES FOR SPECIAL SITUATIONS
Record
Tj |)e
Description
M
P
CT
QT
I'ro^i'iini Applicability ;ind Comments
260,
261,
262
Reference Method Backup
Data
N
N
A
ARP, Subpart H
Report these record types when reference
methods are used as backup monitors to
obtain hourly emission data or flow rate data.
624
Other QA Activities
N
A
A
ARP, Subpart H
Report RT 624 when non-standard QA
activities are performed.
IV REQUIRED REPORTING FOR LOW MASS EMISSIONS (LME) UNITS
Table A-14 includes all record types required for the low mass emissions (LME) methodology
under § 75.19. To qualify to use the LME methodology, a unit must have less than 100 tons of NOx
mass emissions per year and <25 tons of S02 mass emissions per year. A non-Acid Rain Subpart H unit
that reports data only for the ozone season may qualify for LME if the NOx emissions do not exceed 50
tons of NOx mass emissions per ozone season. Subpart H units that report data year-round may qualify
Page A-26
Clean Air Markets Division, U.S. EPA
-------
EDR v2.2 Instructions: Appendix A
December 2005
for LME status if the NOx mass emissions do not exceed 50 tons per ozone season, and are less than 100
tons per year.
Table A-14
RECORD TYPES FOR LOW MASS EMISSIONS UNITS
Record
Tj |)l'
Description
IMP
CT
QT
Pro^mm Appliciihilil.t iiml ( oniincnls
100
Facility Identification
Y
Y
Y
ARP, Subpart H
102
Facility Location and Identification
Information
Y
Y
Y
ARP, Subpart H
301
Quarterly Cumulative Emissions Data
N
N
Y
ARP
305
Quarterly Heat Input from Long Term
Fuel Flow Measurements for
Qualifying Low Mass Emission Units
N
N
A
ARP, Subpart H
Used only by units using the long term fuel flow
methodology to determine hourly heat input.
307
Cumulative NOx Mass Emissions
Data
N
N
Y
ARP, Subpart H
360
Hourly Emissions Data for Low Mass
Emissions Units
N
N
Y
ARP, Subpart H
503
Pipe header definition
A
A
A
ARP, Subpart H
Report RT 503 for any unit which has a single long
term fuel flow meter serving multiple units.
504
Unit Information
Y
Y
Y
ARP, Subpart H
505
Program Indicator for Report
Y
Y
Y
ARP, Subpart H
506
EIA Cross Reference Information
Y
Y
Y
ARP, Subpart H
507
Data to Qualify as a Gas-fired Unit
UA
UA
UA
ARP
Report RT 507 only if an exemption from opacity
monitoring is claimed because the unit qualifies as
gas-fired per § 72.2.
508
Subpart H Reporting Frequency
Change
A
A
A
Subpart H, only
510
Monitoring Systems/Analytical
Components Table
A
A
A
ARP, Subpart H
Required only for: (1) a unit using the long term fuel
flow methodology; or (2) an ARP unit required to
monitor opacity under § 75.14.
531
Maximums, Minimums, Defaults, and
Constants
Y
Y
Y
ARP, Subpart H
535
Unit and Stack Operating Load Data
A
A
A
ARP, Subpart H. Submit RT 535 only if a certified
Appendix D fuel flowmeter is used for long-term fuel
flow.
536
Range of Operation and Normal
Operating Load or Level
A
A
A
ARP, Subpart H
540
Fuel Flowmeter Data
A
A
A
ARP, Subpart H
556
Monitoring System Recertification,
Maintenance, or Other Events
N
N
T
ARP, Subpart H
Report RT 556 only: (1) when changes to the unit,
emission controls or manner of operation require
Appendix E testing to be performed, to re-determine
the fuel-specific, unit-specific NOx emission rate; or
(2) for opacity monitor recertifications.
585
Monitoring Methodology Information
Y
Y
Y
ARP, Subpart H
(cont.)
Clean Air Markets Division, U.S. EPA
A-27
-------
December 2005
EDR v2.2 Instructions: Appendix A
Table A-14
RECORD TYPES FOR LOW MASS EMISSIONS UNITS (cont.)
Record
Tj |)l'
Description
IMP
CT
QT
Proiinim Appliciihilil.t iiml ( oniincnls
586
Control Equipment Information
A
A
A
ARP, Subpart II
587
Unit Fuel Type
Y
Y
Y
ARP, Subpart H
624
Other QA Activities
N
A
T
ARP, Subpart H
If you use a certified Appendix D orifice, nozzle or
venturi-type fuel flowmeter for long-term fuel flow,
report RT 624 when a visual inspection of the primary
element is performed.
627
Fuel Flowmeter Accuracy Test
N
A
T
ARP, Subpart H
If you use a certified Appendix D fuel flowmeter for
long-term fuel flow, report RT 627 when you perform
a periodic accuracy test of the flowmeter.
628
Fuel Flowmeter Accuracy Test for
Orifice, Nozzle and Venturi
Flowmeter
N
A
T
ARP, Subpart H
If you use a certified Appendix D orifice, nozzle or
venturi-type fuel flowmeter for long-term fuel flow,
report RT 628 when periodic transmitter or transducer
calibrations are performed.
629
Baseline Data for Fuel Flow-to-load
Ratio or Gross Heat Rate Check for
Fuel Flowmeters
N
N
A
ARP, Subpart H
If you use a certified Appendix D fuel flowmeter for
long-term fuel flow, report RT 629 if you use the fuel
flow-to-load or GHR test to extend the flowmeter
accuracy test deadline.
630
Quarterly Fuel Flow-to-load Ratio
Test Results
N
N
A
ARP, Subpart H
If you use a certified Appendix D fuel flowmeter for
long-term fuel flow, report RT 630 if you use the fuel
flow-to-load or GHR test to extend the flowmeter
accuracy test deadline.
645
Qualifying Data for Low Mass
Emission Units
A
A
A
ARP, Subpart H
Submit only with initial monitoring plan, certification
application, and first quarterly report.
650
NOx Emission Rate Correlation Test
Data
N
A
T
ARP, Subpart H
Report RT 650 each time an Appendix E test is
performed for the purpose of determining a fuel-
specific, unit-specific NOx emission rate. See RT 650
general instructions.
660
Identical Unit Testing
A
A
A
ARP, Subpart H
Required only for units which perform identical unit
testing. Submit RT(s) 660 for each unit in the group.
696
Fuel Flowmeter Accuracy Test
Extension
N
N
A
ARP, Subpart H
If you use a certified Appendix D fuel flowmeter for
long-term fuel flow, report RT 696 to claim allowable
extensions of fuel flowmeter accuracy test deadlines.
900
Certifications
N
N
O
ARP
Hard copy certification may be provided in lieu of this
record type.
901
Certifications
N
N
O
ARP
Hard copy certification may be provided in lieu of this
record type.
910
Comments
N
N
o
ARP, Subpart H
920
Comments
N
N
o
ARP, Subpart H
(cont.)
Page A-28
Clean Air Markets Division, U.S. EPA
-------
EDR v2.2 Instructions: Appendix A
December 2005
Table A-14
RECORD TYPES FOR LOW MASS EMISSIONS UNITS (cont.)
Record
Tj |)l'
Description
IMP
CT
QT
Proiinim Appliciihilil.t iiml ( oniincnls
940
Certifications
N
N
O
Subpart H
Hard copy certification may be provided in lieu of this
record type.
941
Certifications
N
N
O
Subpart H
Hard copy certification may be provided in lieu of this
record type.
999
Contact Information
N
N
o
ARP, Subpart H
V REPORTING FOR PREDICTIVE EMISSION MONITORING SYSTEMS (PEMS)
A. Introduction
Table A-15, below includes the essential EDR record types for units that have received approval
under Subpart E of Part 75 to use predictive emissions monitoring systems (PEMS) to report NOx
emissions. The scope of Table A-15 is limited to affected oil and gas-fired units (i.e.. boilers and
combustion turbines) that:
• Have a single unit-single stack exhaust configuration;
• Use Appendix D methodology to quantify unit heat input;
• Use Appendices D and G to account for S02 and C02 mass emissions (if the units are in the
Acid Rain Program);and
• Do not co-fire oil and gas.
For PEMS reporting, EDR version 2.2 must be used, since fuel-specific missing data substitution
for NOx emission rate is required. For hourly NOx emission rate reporting, RT 320 is used. Hourly 200-
level records are not reported for either NOx concentration or diluent gas (02 or C02) concentration.
For units that burn more than one fuel type, separate PEMS are required for each fuel. Each
PEMS should be reported as a separate monitoring system with a unique monitoring system ID in RT
510. Each PEMS will require its own set of certification, recertification, and quality assurance tests.
B. Interpreting Table A-15
In Table A-15, the first column identifies the record type. The second column gives a brief
description of the record type. The third, fourth, and fifth columns indicate whether the record type must
be reported for a particular type of submittal. The third column header, "MP", refers to monitoring plan
submittals. The fourth column header, "CT", stands for certification or recertification applications. The
fifth column header, "QT", refers to electronic data report submittals. The letter codes in columns 3
through 5 are defined as follows:
Y This record type is required for this type of submittal (monitoring plan,
certification/recertification application or electronic data report)
Clean Air Markets Division, U.S. EPA
A-29
-------
December 2005
EDR v2.2 Instructions: Appendix A
N This record type is not appropriate for this type of submittal.
O This record type is appropriate, but optional for this type of submittal.
A This record type may be required for this submittal. If any doubt exists as to the need to
submit this record type, consult the appropriate EDR instructions.
T This record type is required each time a quality assurance test (e.g.. a RATA) is performed.
Table A-15
EDR RECORD TYPES FOR UNITS WITH PEMS
Record
Tj pc
Description
MP
CT
QT
Pro^mm Applicability iind Commcnls
100
Facility Identification
Y
Y
Y
ARP, Subpart H
101
Record Types Submitted
O
O
O
ARP, Subpart H
102
Facility Location and Identification
Information
Y
Y
Y
ARP, Subpart H
300
Operating Data
N
N
Y
ARP, Subpart H
• Report one RT 300 for each hour in the quarter,
except when a unit does not operate during the entire
quarter.
• For each operating hour, report the fuel combusted
in column 64.
301
Quarterly Cumulative Emissions
N
N
Y
ARP
• Quarterly NOx emission rate is the arithmetic
average of the RT 320, col 42 values
302
Oil Fuel Flow
N
N
Y
ARP, Subpart H
• For ARP units, must be paired with RT 313 when
reporting S02 mass emissions.
303
Gas Fuel Flow
N
N
Y
ARP, Subpart H
• For ARP units, must be paired with RT 314 when
reporting S02 mass emissions.
307
Cumulative NOx Mass Emissions
N
N
Y
Subpart H
313
S02 Mass Emissions (Oil)
N
N
Y
ARP
314
S02 Mass Emissions (Gas)
N
N
Y
ARP
320
NOx Emission Rate Estimation
N
N
Y
ARP, Subpart H
• (See supplementary reporting instructions)
328
NOx Mass Emissions
N
N
Y
Subpart H
• (See supplementary reporting instructions)
330
C02 Mass Emissions Data
N
N
A
ARP
• Report RT 330 for hours in which Equation G-4 is
used to determine hourly C02 mass emissions for gas
or oil-fired units.
331
C02 Mass Emissions Estimation
Parameters
N
N
A
ARP
• Report RT 331 if you estimate C02 mass emissions
using fuel sampling and Equation G-l
504
Unit Information
Y
Y
Y
ARP, Subpart H
(cont.)
Page A-30
Clean Air Markets Division, U.S. EPA
-------
EDR v2.2 Instructions: Appendix A
December 2005
Table A-15
EDR RECORD TYPES FOR UNITS WITH PEMS (cont.)
Record
Tj pc
Description
IMP
CT
QT
Pro^i'iim \|)|)lic;il)ili(> iiml ( nmmcnls
505
Program Indicator for Report
Y
Y
Y
ARP, Subpart II
506
EIA Cross Reference Information
Y
Y
Y
ARP, Subpart H
507
Peaking Unit or ARP Gas-Fired Unit
Qualification Data
A
A
A
ARP
508
Subpart H Reporting Frequency
Change
N
N
A
Subpart H
510
Monitoring Systems/Analytical
Components Table
Y
Y
Y
ARP, Subpart H
• (See supplementary reporting instructions)
520
Formula Table
Y
Y
Y
ARP, Subpart H
• Report formulas for S02 and C02 mass emissions
(ARP units,only), NOx mass emissions (Subpart H
units), and unit heat input rate.
531
Defaults and Constants
Y
Y
Y
ARP, Subpart H
• (See supplementary reporting instructions)
535
Unit and Stack Operating Load Data
Y
Y
Y
ARP, Subpart H
Required for any unit using load-based missing data
procedures for NOx or fuel flow rate.
536
Range of Operation, Normal Load,
and Load Usage
Y
Y
Y
ARP, Subpart H
• Report RT 536 to define operating range and
normal load for RATA testing
540
Fuel Flowmeter Data
Y
Y
Y
ARP, Subpart H
550
Reasons for Monitoring System
Downtime or Missing Parameter
N
N
A
ARP, Subpart H
• (See supplementary reporting instructions)
556
Monitoring System Recertification,
Maintenance, or Other Events
N
N
A
ARP, Subpart H
• Report RT 556 for recertification of the PEMS or
fuel flowmeters
• (See supplementary reporting instructions)
585
Monitoring Methodology
Information
Y
Y
Y
ARP, Subpart H
• (See supplementary reporting instructions)
586
Control Equipment Information
A
A
A
ARP, Subpart H
587
Unit Fuel Type
Y
Y
Y
ARP, Subpart H
610
RATA and Bias Test Data
N
Y
T
ARP, Subpart H
• Report RTs 610 each time a RATA is performed
for certification, recertification or for on-going
QA/QC.
• (See supplementary reporting instructions)
611
RATA and Bias Test Results
N
Y
T
ARP, Subpart H
• Report RT 611 each time a RATA is performed for
certification, recertification or for on-going QA/QC.
• (See supplementary reporting instructions)
624
Other QA Activities
N
N
Y
ARP, Subpart H
• Report RT 624 for PEMS daily QA/QC and for
PEMS periodic accuracy checks using a reference
method, or a portable analyzer.
• (See supplementary reporting instructions)
(cont.)
Clean Air Markets Division, U.S. EPA
A-31
-------
December 2005
EDR v2.2 Instructions: Appendix A
Table A-15
EDR RECORD TYPES FOR UNITS WITH PEMS (cont.)
Record
Tj pc
Description
IMP
CT
QT
Pro^i'iim \|)|)lic;il)ili(> iiml ( oiiiiiiciKn
627
Fuel Flowmeter Accuracy Test
N
A
T
ARP, Subpart H
• Report only for fuel flowmeters that are certified
and quality assured by periodic accuracy tests
according to Section 2.1.5.1 or 2.1.5.2 of Appendix D.
628
Fuel Flowmeter Accuracy Test for
Orifice, Nozzle and Venturi
Flowmeter
N
A
T
ARP, Subpart H
• Report only for orifice, nozzle and venturi-type
flowmeters that are quality assured by periodic
transmitter/transducer calibrations.
629
Fuel Flow-to-load Ratio Test
Baseline Data
N
N
A
ARP, Subpart H
• Report if quarterly fuel flow-to-load ratio test in
Section 2.1.7 of Appendix D is used to extend fuel
flowmeter accuracy test deadlines.
630
Quarterly Fuel Flow-to-load Ratio
Test Results
N
N
A
ARP, Subpart H
• Report if quarterly fuel flow-to-load ratio test in
Section 2.1.7 of Appendix D is used to extend fuel
flowmeter accuracy test deadlines.
640
Alternative Monitoring System
Approval Petition Data
N
Y
A
ARP, Subpart H
• Report when certifying a PEMS
641
Alternative Monitoring System
Approval Petition Results and
Statistics
N
Y
A
ARP, Subpart H
• Report when certifying or recertifying a PEMS
696
Fuel Flowmeter Accuracy Test
Extension
N
N
A
ARP, Subpart H
• Use RT 696 to claim allowable extensions of fuel
flowmeter accuracy test deadlines.
697
RATA Deadline Extension or
Exemption
N
N
A
ARP, Subpart H
• Report when claiming a RATA deadline extension
Appendix B, Section 2.3.3.
699
QA Test Extension Based on Grace
Period
N
N
A
ARP, Subpart H
• Report when claiming a QA test deadline extension
under Appendix B, Section 2.2.4.
900
Certifications
Y
Y
Y
ARP
901
Certifications
Y
Y
Y
ARP
910
Comments
Y
Y
Y
ARP, Subpart H
• (See supplementary reporting instructions)
920
Comments
O
O
O
ARP, Subpart H
940
Certifications
Y
Y
Y
Subpart F[
941
Certifications
Y
Y
Y
Subpart F[
999
Contact Information
O
O
O
ARP, Subpart H
Page A-32
Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: Appendix A
December 2005
C. Supplementary EDR Reporting Instructions for PEMS
For a unit with an approved petition to use a predictive emissions monitoring system (PEMS), use
the following supplementary instructions, in conjunction with this v2.2 Reporting Instructions document,
to prepare the required EDR submittals.
RT 320
Monitoring System ID (10). Report the monitoring system ID (from RT 510, column 13) of the
PEMS used to determine the NOx emission rate during the hour.
F-Factor (26). Leave this field blank.
Average NOx Emission Rate for the Hour (36). Report the average unadjusted NOx emission
rate for the hour (lb/mmBtu), rounded to three decimal places, as determined by the PEMS. For
hours in which you use missing data procedures, leave this field blank.
Adjusted Average NOx Emission Rate for the Hour (42). For each hour in which you report
NOx emission rate in column 36, apply the appropriate adjustment factor (1.000 or the BAF) to
the unadjusted average emission rate, and report the result rounded to three decimal places. For
each hour in which you use missing data procedures, report the appropriate substitute value.
Formula ID (50). Leave this field blank.
Method of Determination Code (53). Report "03" when you use the PEMS to determine the
NOx emissions rate. Report "12" when you report the fuel-specific maximum NOx emission rate
(e.g.. during hours of startup or shutdown or when NOx controls (if any) are not functioning
properly). During hours when you use other missing data procedures, report the appropriate
MODC listed in the EDR instructions.
RT 328
NOx Methodology for the Hour (45). Report "NOXR-PEMS".
RT 510
The PEMS monitoring system consists of either one or two data acquisition and handling system
(DAHS) components. For single-component PEMS systems or for systems where the PEMS
software and standard DAHS software have the same manufacturer/provider, model or version
number, etc., report one RT 510 for the PEMS system. If the PEMS software and the standard
DAHS software have different manufacturer/providers, model or version numbers, etc., report
each as a separate RT 510 with the same PEMS monitoring system ID.
Component ID (10). Report the three-character alphanumeric ID for each DAHS component.
Monitoring System ID (13). Create a unique three-character alphanumeric ID for each PEMS
monitoring system. Define a separate NOx PEMS system for each fuel type. For sources
Clean Air Markets Division, U.S. EPA
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December 2005
EDR v2.2 Instructions: Appendix A
switching from NOx CEMS or Appendix E to PEMS, do not re-use the CEMS or Appendix E
system ID numbers.
System Parameter Monitored (17). If your PEMS is approved for NOx emission rate
(lb/mmBtu) and if you use the NOx emission rate to calculate NOx mass emissions, report "NOX"
for the system parameter monitored. If your PEMS is approved for NOx concentration (ppm) and
if you calculate NOx mass emissions as the product of NOx concentration times flow rate, report
"NOXC" for the system parameter monitored.
Primary/Backup Designation (21). Report "PE" to indicate that this is a predictive emissions
monitoring system.
Component Type Code (23). Report "DAHS" as the component type code.
Sample Acquisition Method (27). Leave this field blank.
Manufacturer (30). Report the name of the manufacturer or developer of the software
component.
Model/Version (55). Report the model/version of the software component.
Serial Number (70). Report the serial number, if applicable — otherwise leave blank.
RT 531
Parameter (10). Report "NORX" as the parameter monitored. (You should report one 531
record for each fuel type.)
Default Value (14). Report the fuel-specific maximum potential NOx emission rate (MER), in
units of lb/mmBtu.
Units of Measure (27). Report "LBMMBTU".
Purpose or Intended Use (34). Report "MD" for missing data.
Type of Fuel (37). Report the fuel type code for the fuel. (See the EDR Instructions for RT 531
for the list of available codes.)
Indicator of Use (40). Report "A" for any hour.
Source of Value (41). Report "DEF" for default value.
RT 550
Parameter (10). Report "NOX".
Monitoring System ID (14). Report the monitoring system ID, from RT 510, of the NOx PEMS
system.
Page A-34
Clean Air Markets Division, U.S. EPA
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EDR v2.2 Instructions: Appendix A
December 2005
RT 556
Component ID (10). Report the PEMS component ID subject to recertification/diagnostic
testing, if a specific component is involved. If the event is system, not component, specific, leave
this field blank.
Monitoring System ID (13). Report the monitoring system ID, from RT 510, of the NOx PEMS
system.
Event Code (16). Report code "99" (i.e.. "Other").
Code for Required Test (19). Codes for PEMS systems are:
80 PEMS sensor validation system (minimum data capture check), train or retrain (if
manufacturer recommends), sensor validation system (alarm system set-up and failed sensor
alert check), daily QA/QC, 3 operating level RATA, statistical tests, and normal operating
level bias test; and
81 PEMS daily QA/QC, and PEMS check with reference method or portable analyzer.
Beginning of Conditionally Valid Period (31, 39). If conditional data validation is used, report
the date and hour that the probationary PEMS daily QA/QC test was successfully completed
according to the provisions of §75.20(b)(3)(ii).
Note: For PEMS, you may only use conditional data validation if the "event" in column 16
requires RATA testing. If you elect to use conditional data validation, you must complete
the RATA within the allotted time in §75.20(b)(3)(iv).
RT 585
Parameter (10). If your PEMS is approved for NOx emission rate (lb/mmBtu) and if you use the
NOx emission rate to calculate NOx mass emissions, report "NOXR" as the parameter code
associated with the PEMS. If your PEMS is approved for NOx concentration (ppm) and if you
calculate NOx mass emissions as the product of NOx concentration times flow rate, report
"NOXM" as the parameter code associated with the PEMS. Report one RT 585 for each generic
fuel type combusted.
Monitoring Methodology (14). Report "PEMS" as the monitoring methodology for the PEMS.
Missing Data Approach for Methodology (28). Report "FSP75" for the fuel-specific missing
data approach for the PEMS methodology.
RT 610
Units of Measure (33). Report "2" (lb/mmBtu) as the units of measure.
Value from CEM System Being Tested (34). Report the average value recorded by the PEMS,
for each RATA run.
Clean Air Markets Division, U.S. EPA
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December 2005
EDR v2.2 Instructions: Appendix A
RT 611
Units of Measure (34). Report "2" (lb/mmBtu) as the units of measure.
Arithmetic Mean of CEM Values (35). Report the arithmetic mean of all the RTs 610 PEMS
values associated with the RATA.
Number of Load Levels Comprising Test (133). Report "1" or "3" (if certification or recert).
BAF for a Multiple-Load RATA (134) Leave this field blank.
RT 624
Component ID (10). Report the PEMS software component ID from RT 510.
Monitoring System ID (13). Report the NOx monitoring system ID from RT 510.
Parameter (16). Report "NOX".
QA Test Activity Description (30). Fill in appropriately.
Reason for Test (51). Report "Q".
QA Test Code (53). Report one of the following codes, as appropriate:
04 PEMS daily QA/QC
05 Periodic check of PEMS accuracy with a portable analyzer, or reference method
RT 640
Submit RT 640 only with the Subpart E application for initial certification of the PEMS. Do not submit
RT 640 for PEMS recertification.
Component ID (10). Report the PEMS software component ID from RT 510.
Monitoring System ID (13). Report the NOx monitoring system ID from RT 510.
RT 641
Submit RT 641 with the Subpart E application for initial certification of the PEMS and for all
recertifications of the PEMS. For initial certification, fill in all applicable data fields in RT 641. For
PEMS recertification, report only the data elements in start columns 1 throughl3, column 95 (the F-
statistic), column 108 (Critical value of F at 95% confidence level for sample size), and column 121
(Coefficient of correlation (Pearson's r) of CEM and AMS data).
Component ID (10). Report the PEMS software component ID from RT 510.
Monitoring System ID (13). Report the NOx monitoring system ID from RT 510.
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EDR v2.2 Instructions: Appendix A
December 2005
RT 910
Text (4). Briefly describe the PEMS.
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