ECMPS Reporting Instructions
 

Monitoring Plan
 

United States Environmental Protection Agency
 

Office of Air and Radiation
 

Clean Air Markets Division
 

1310 L Street, NW
 

Washington, DC 20005 

March 07, 2012September 19, 2012
 

 

 

 

 

Table of Contents March 07, 2012September 19, 2012
 

Table of Contents 

Page 

1.0 Introduction: The Monitoring Plan .................................................................................... 1
 

2.0 Monitoring Plan (Root Element) .......................................................................................... 5
 

2.1 Monitoring Plan Comment Data........................................................................................ 7
 

2.2 Unit Stack Configuration Data........................................................................................... 9
 

2.3 Monitoring Location Data................................................................................................ 11
 

3.0 Stack Pipe Data .................................................................................................................... 13
 

4.0 Unit Data ............................................................................................................................... 17
 

4.1 Unit Capacity Data........................................................................................................... 19
 

4.2 Unit Control Data............................................................................................................. 21
 

4.3 Unit Fuel Data.................................................................................................................. 25
 

5.0 Monitoring Location Attribute Data.................................................................................. 29
 

6.0 Monitoring Method Data .................................................................................................... 33
 

7.0 Component Data .................................................................................................................. 41
 

7.1 Analyzer Range Data ....................................................................................................... 49
 

8.0 Monitoring System Data...................................................................................................... 53
 

8.1 Monitoring System Fuel Flow Data................................................................................. 63
 

8.2 Monitoring System Component Data .............................................................................. 67
 

9.0 Monitoring Formula Data................................................................................................... 69
 

10.0 Monitoring Default Data ................................................................................................... 91
 

11.0 Monitoring Span Data ..................................................................................................... 109
 

12.0 Rectangular Duct WAF Data.......................................................................................... 119
 

13.0 Monitoring Load Data..................................................................................................... 123
 

14.0 Monitoring Qualification Data ....................................................................................... 131
 

14.1 Monitoring Qual LME Data......................................................................................... 135
 

14.2 Monitoring Qual Percent Data ..................................................................................... 141
 

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March 07, 2012September 19, 2012 Table of Contents 

List of Tables 

Page 

Table 1 Stack Pipe ID Prefixes .................................................................................................... 14
 

Table 2 Parameter Codes and Descriptions ................................................................................. 22
 

Table 3 Control Codes and Descriptions ..................................................................................... 22
 

Table 4 Unit Fuel Codes and Descriptions .................................................................................. 26
 

Table Unit Fuel Indicator Codes and Descriptions................................................................... 27
 

Table 6 Demonstration Method to Qualify for Monthly Fuel Sampling for GCV Codes and 

Descriptions.................................................................................................................. 27
 

Table 7 Demonstration Method to Qualify for Daily or Annual Fuel Sampling for %S (ARP)
 

Codes and Descriptions................................................................................................ 28
 

Table 8 Duct/Stack Material Codes and Description................................................................... 31
 

Table 9 Duct/Stack Shape Codes and Descriptions..................................................................... 31
 

Table Parameter Codes and Descriptions for Monitoring Methods ....................................... 34
 

Table 11 Measured Parameters and Applicable Monitoring Methods ........................................ 35
 

Table 12 Substitute Data Codes and Descriptions....................................................................... 37
 

Table 13 Bypass Approach Codes and Descriptions ................................................................... 38
 

Table 14 Component Type Codes and Descriptions................................................................... 43
 

Table Sample Acquisition Method Codes for Components ................................................... 44
 

Table 16 Basis Codes and Descriptions for CEM Analyzer Components................................... 46
 

Table 17 Analyzer Range Codes and Descriptions...................................................................... 50
 

Table 18 System Type Codes and Descriptions .......................................................................... 54
 

Table 19 System Designation Code and Descriptions................................................................. 56
 

Table Monitoring System Fuel Codes and Descriptions ........................................................ 57
 

Table 21 Units of Measure for Maximum Fuel Flow Rate Codes and Descriptions................... 64
 

Table 22 Parameter Codes and Descriptions for Monitoring Formula....................................... 70
 

Table 23 F-Factor* Reference Table ........................................................................................... 72
 

Table 24 SO2 Formula References............................................................................................... 74
 

Table SO2 Emission Formulas................................................................................................ 74
 

Table 26 NOx Emission Rate Formula Reference Table ............................................................. 76
 

Table 27 NOx Emission Rate Formulas (lb/mmBtu) ................................................................... 77
 

Table 28 Moisture Formulas........................................................................................................ 78
 

Table 29 CO2 Formula Reference Table...................................................................................... 78
 

Table CO2 Concentration and Mass Emission Rate Formulas ............................................... 79
 

Table 31 Heat Input Formula Reference Table............................................................................ 81
 

Table 32 Heat Input Formulas ..................................................................................................... 83
 

Table 33 Apportionment and Summation Formulas.................................................................... 85
 

Table 34 NOx Mass Emissions Formulas (lbs/hr)........................................................................ 86
 

Table Miscellaneous Formula Codes...................................................................................... 87
 

Table 36 Representations for Electronic Reporting of Formulas ................................................ 88
 

Table 37 Parameter Codes and Descriptions for Monitoring Default ......................................... 94
 

Table 38 Rounding Rules for Default Values.............................................................................. 96
 

Table 39 Fuel-Specific Minimum Default Moisture Values for SO2, NOx, CO2, and Heat Input
 

Rate Calculations.......................................................................................................... 98
 

Table 40 Fuel-Specific Maximum Default Moisture Values for NOx Emission Rate Calculations
 

...................................................................................................................................... 98
 

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Table of Contents March 07, 2012September 19, 2012
 

Table 41 NOx Emission Factors (lb/mmBtu) for Low Mass Emissions Units ............................ 99
 

Table 42 SO2 Emission Factors (lb/mmBtu) for Low Mass Emissions Units............................. 99
 

Table 43 CO2 Emission Factors (ton/mmBtu) for Low Mass Emissions Units .......................... 99
 

Table 44 Units of Measure Codes by Parameter ....................................................................... 100
 

Table 45 Default Purpose Codes and Descriptions.................................................................... 101
 

Table 46 Monitoring Default Fuel Codes and Descriptions ...................................................... 101
 

Table 47 Monitoring Default Operating Condition Codes and Descriptions ............................ 105
 

Table 48 Default Source Codes and Descriptions ..................................................................... 105
 

Table 49 Component Type Codes and Descriptions for Monitor Span ..................................... 110
 

Table 50 Provision for Calculating MPC/MEC/MPF Codes and Descriptions......................... 111
 

Table 51 Criteria for MPC/MEC/MPF Determinations............................................................. 112
 

Table 52 Flow Span Calibration Units of Measure ................................................................... 115
 

Table 53 WAF Method Code and Descriptions......................................................................... 121
 

Table 54 Maximum Load Value Codes and Descriptions......................................................... 125
 

Table 55 Qualification Type Codes and Descriptions ............................................................... 132
 

Table 56 Data Requirements for Monitoring Qual LME........................................................... 136
 

Table 57 Qualification Data Type Code and Descriptions ........................................................ 142
 

Table 58 Example Data for Qualification Based on Historical and Projected Data.................. 144
 

Table 59 Example of Gas-Fired Qualification Based on Unit Operating Data ......................... 145
 

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March 07, 2012September 19, 2012 Table of Contents 

List of Figures 

Page 

Figure 1 Monitoring Plan XML Schema Complex Elements........................................................ 3
 

Figure 2 MONITORING PLAN XML Elements................................................................................. 5
 

Figure 3 MONITORING PLAN COMMENT DATA XML Elements ..................................................... 7
 

Figure 4 UNIT STACK CONFIGURATION DATA XML Elements...................................................... 9
 

Figure 5 MONITORING LOCATION DATA Elements ...................................................................... 11
 

Figure 6 STACK PIPE DATA Elements .......................................................................................... 13
 

Figure 7 UNIT DATA XML Elements ........................................................................................... 17
 

Figure 8 UNIT CAPACITY DATA XML Elements.......................................................................... 19
 

Figure 9 UNIT CONTROL DATA XML Elements........................................................................... 21
 

Figure 10 UNIT FUEL DATA XML Elements................................................................................ 25
 

Figure 11 MONITORING LOCATION ATTRIBUTE DATA XML Elements ....................................... 29
 

Figure 12 MONITORING METHOD DATA XML Elements............................................................. 33
 

Figure 13 COMPONENT DATA XML Elements............................................................................. 41
 

Figure 14 ANALYZER RANGE DATA XML Elements ................................................................... 49
 

Figure 15 MONITORING SYSTEM DATA XML Elements .............................................................. 53
 

Figure 16 MONITORING SYSTEM FUEL FLOW DATA XML Elements........................................... 63
 

Figure 17 MONITORING SYSTEM COMPONENT DATA XML Elements ......................................... 67
 

Figure 18 MONITORING FORMULA DATA XML Elements ........................................................... 69
 

Figure 19 MONITORING DEFAULT DATA XML Elements ............................................................ 91
 

Figure 20 MONITORING SPAN DATA XML Elements................................................................. 109
 

Figure 21 RECTANGULAR DUCT WAF DATA XML Elements ................................................... 119
 

Figure 22 MONITORING LOAD DATA XML Elements................................................................ 123
 

Figure 23 MONITORING QUALIFICATION DATA XML Elements................................................ 131
 

Figure 24 MONITORING QUAL LME DATA XML Elements....................................................... 135
 

Figure 25 MONITORING QUAL PERCENT DATA XML Elements ................................................ 141
 

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1.0 Introduction: The Monitoring Plan March 07, 2012September 19, 2012 

ECMPS Reporting Instructions
 

Monitoring Plan
 

1.0 INTRODUCTION: The Monitoring Plan 

About This Document 

In the Emissions Collection and Monitoring Plan System (ECMPS), data must be submitted to 

the EPA through the Client Tool using extensible-markup language (XML) format. XML files 

must contain certain data elements, which are defined in the XML schema. (Note: More 

information about the ECMPS XML Schemas can be found in the XML Schema Description 

Documents.) 

The purpose of the reporting instructions is to provide the necessary information for owners and 

operators to meet the reporting requirements for sources affected by: 

1) The Acid Rain Program (ARP); 

2) The Clean Air Interstate Rule (CAIR); and 

3) Other programs required to report data using these XML schemas. 

These instructions explain how to report the required data for the applicable regulations. Owners 

and operators of units should refer to the applicable regulations for information about what data 

are required to be reported. 

The Monitoring Plan XML Schema is made up of a root element, complex elements, and simple 

elements. A simple element is a single piece of data. A complex element is a group of simple 

elements which are logically grouped together. The root element is the base of the XML 

schema. 

The elements are related to each other in parent-child relationships. The root element is the 

parent element of the entire schema. Complex elements are children of the root element, and 

complex elements can also be children of other complex elements. If a complex element is 

dependent on a parent complex element, the child complex element cannot be included in the 

XML file unless the appropriate parent complex element is also included. Figure 1 below 

illustrates the relationships between the monitoring plan root element and the complex elements. 

This document provides instructions on how the required data should be reported using this data 

structure. A separate section is provided for each complex element, its dependencies, and its 

simple elements. In addition, there are "specific considerations" that apply to particular types of 

monitoring plan configurations. 

About Monitoring Plan Data 

The Monitoring Plan describes how a monitoring configuration monitors its emissions. 

Monitoring plan data define relationships between stacks, pipes, and units, specify locations at a 

Environmental Protection Agency Monitoring Plan Reporting Instructions -- Page 1 
 

 

March 07, 2012September 19, 2012 1.0 Introduction: The Monitoring Plan 

facility from which emissions are monitored, and identify systems of monitoring equipment by
 

detailing the individual system components. Monitoring plan data also provide operational
 

characteristics and qualifications for certain special types of monitoring (e.g., Low Mass
 

Emissions monitoring). 

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1.0 Introduction: The Monitoring Plan March 07, 2012September 19, 2012 

Figure 1 

Monitoring Plan XML Schema Complex Elements
 

Parent 

and 

Child 

Child Only 

Root 

Element 

LEGEND 

2.0 Monitoring Plan 

2.3 

Monitoring 

Location 

2.1
 

Monitoring 

Plan Comment
 

2.2
 

Unit Stack
 

Configuration 

3.0 

Stack Pipe 

Data 

4.0 

Unit Data 

4.1 

Unit 

Capacity 

4.2 

Unit 

Control 

4.3 

10.0 

Monitoring 

Default 

12.0 

Rectangular 

Duct WAF 

6.0 

Monitoring 

Method 

11.0 

Monitoring 

Span 

9.0 

Monitoring 

Formula 

8.0 

Monitoring 

System 

7.0 

Component 

8.2 

Monitoring 

System 

Component 

14.2 

Monitoring 

Qualification 

LME 

14.1 

Monitoring 

Qualification 

Percent 

Unit Fuel 

13.0 

Monitoring 

Load 

5.0 

Monitoring 

Location 

Attribute 

7.1 

Analyzer 

Range 14.0 

Monitoring 

Qualification 

7.2 

Calibration 

Standard 

8.1 

Monitoring 

System 

Fuel Flow 

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2.0 Monitoring Plan March 07, 2012September 19, 2012 

2.0 MONITORING PLAN (Root Element) 

Figure 2 

MONITORING PLAN XML Elements
 

Description of Data 

The MONITORING PLAN root element defines the configuration of the monitoring plan and is the 

"keystone" record for building a monitoring plan. Hence the MONITORING PLAN record includes 

essential identifying information for a complete monitoring plan. Submit one MONITORING PLAN 

record for each monitoring plan and ensure that it is the first data record reported. 

Dependencies for MONITORING PLAN 

The MONITORING PLAN record is not dependent on any other elements of the monitoring plan. 

The following complex elements specify additional monitoring plan data and are dependent on 

the MONITORING PLAN record: 

● MONITORING PLAN COMMENT DATA 

● UNIT STACK CONFIGURATION DATA 

● MONITORING LOCATION DATA 

These complex elements cannot be submitted for a monitoring plan unless an applicable 

MONITORING PLAN record is included. 

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March 07, 2012September 19, 2012 2.0 Monitoring Plan 

MONITORING PLAN Elements 

Instructions for completing each element of the MONITORING PLAN section are provided below: 

ORIS Code 

Element Name: ORISCode 

Report the code that indicates the unique identifying number given to a plant by the Energy 

Information Administration (EIA) and remains unchanged under ownership changes.
 

Version 

Element Name: Version 

Report the XML schema version number. Note that this is a numeric field -- do not include a "v" 

before the number. 

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2.1 Monitoring Plan Comment Data March 07, 2012September 19, 2012 

2.1 MONITORING PLAN COMMENT DATA 

Figure 3 

MONITORING PLAN COMMENT DATA XML Elements
 

Description of Data 

If necessary, you may submit a MONITORING PLAN COMMENT DATA record with each monitoring 

plan submission or revision. The MONITORING PLAN COMMENT DATA record allows you to 

include comments regarding the monitoring plan submission. If you do not have any comments 

on the plan, omit the MONITORING PLAN COMMENT DATA complex element entirely. 

Dependencies for MONITORING PLAN COMMENT DATA 

The MONITORING PLAN COMMENT DATA record is dependent on the MONITORING PLAN record. 

No other records are dependent upon the MONITORING PLAN COMMENT DATA record. 

MONITORING PLAN COMMENT DATA Elements 

Instructions for completing each element of the MONITORING PLAN COMMENT DATA section are 

provided below: 

Monitoring Plan Comment 

Element Name: MonitoringPlanComment 

Report any comments concerning the monitoring plan. 

Begin Date 

Element Name: BeginDate 

Report the date on which the comment became effective. 

End Date 

Element Name: EndDate 

If applicable, report the last date on the comment was effective. This value should be left blank 

for active records. 

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2.2 Unit Stack Configuration Data March 07, 2012September 19, 2012 

2.2 UNIT STACK CONFIGURATION DATA 

Figure 4 

UNIT STACK CONFIGURATION DATA XML Elements
 

Description of Data 

Submit a UNIT STACK CONFIGURATION DATA record for each unit-stack relationship defined in 

the monitoring plan. Each UNIT STACK CONFIGURATION DATA record identifies a specific 

configuration or relationship between a unit and a monitored stack through which it exhausts, or 

a unit and a pipe that serves the unit. This relationship defines the configuration and methods 

used for monitoring. See the instructions for the STACK PIPE DATA record for more information 

about when and how to define multiple and common stacks and pipes. 

Dependencies for UNIT STACK CONFIGURATION DATA 

The UNIT STACK CONFIGURATION DATA record is dependent on the MONITORING PLAN record. 

No other records are dependent upon the UNIT STACK CONFIGURATION DATA record. 

Unit Stack Configuration Data Elements 

Instructions for completing each element of the UNIT STACK CONFIGURATION DATA section are 

provided below: 

Stack Pipe ID 

Element Name: StackPipeID 

Report the Stack Pipe ID that corresponds to the monitoring location. This is the alphanumeric 

code assigned by a source to identify a multiple or common stack or pipe at which emissions are 

determined. 

Unit ID 

Element Name: UnitID 

Report the applicable Unit ID for the unit that is linked to the stack or pipe. This is the one to six 

alphanumeric character code assigned by a source to identify a unit. 

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March 07, 2012September 19, 2012 2.2 Unit Stack Configuration Data 

Begin Date 

Element Name: BeginDate 

Report the date on which some or all of the emissions from the unit were first measured at the 

common or multiple stack/pipe. This data should be equal to or later than the ActiveDate for the 

StackPipe, as reported in the STACK PIPE DATA record. 

End Date 

Element Name: EndDate 

If the unit is no longer linked to the stack or pipe in terms of monitored emissions, report the last 

date on which the emissions from the unit were measured at the common or multiple stack/pipe. 

For an active relationship, leave this field blank. 

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2.3 Monitoring Location Data March 07, 2012September 19, 2012 

2.3 MONITORING LOCATION DATA 

Figure 5 

MONITORING LOCATION DATA Elements
 

Description of Data 

The MONITORING LOCATION DATA record is used to identify the unit(s) in the monitoring plan, 

as well as any stack(s) or pipe(s) defined as a monitoring location. Submit a MONITORING 

LOCATION DATA record for each stack, pipe, and unit in the monitoring plan. See instructions for 

the STACK PIPE DATA record for more information about defining stacks and pipes. 

Dependencies for Monitoring Location Data 

The MONITORING LOCATION DATA record is dependent on the MONITORING PLAN record. 

The following complex elements specify additional monitoring location data and are dependent 

on the MONITORING LOCATION DATA record: 

● STACK PIPE DATA 

● UNIT DATA 

These complex elements cannot be submitted for a monitoring location unless an applicable 

MONITORING LOCATION DATA record is included. 

MONITORING LOCATION DATA Elements 

Instructions for completing each element of the MONITORING LOCATION DATA section are 

provided below: 

Stack Pipe ID 

Element Name: StackPipeID 

If this record is for a stack or pipe, report the Stack Pipe ID that corresponds to the monitoring 

location. This is the alphanumeric code assigned by a source to identify the stack or pipe. If this 

record is for a unit, leave this field blank. 

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March 07, 2012September 19, 2012 2.3 Monitoring Location Data 

Unit ID 

Element Name: UnitID 

If this record is for a unit, report the Unit ID that corresponds to the monitoring location being 

described. This is the alphanumeric code assigned by a source to identify a unit. If this record is 

for a Stack or Pipe, leave this field blank. 

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3.0 Stack Pipe Data 

3.0 STACK PIPE DATA 

March 07, 2012September 19, 2012 

Figure 6 

STACK PIPE DATA Elements 

Description of Data 

Submit a STACK PIPE DATA record describing each stack or pipe at which emissions from more 

than one unit are measured or determined (i.e., a common stack or pipe) or stacks from which 

partial emissions from a unit are measured (i.e., a multiple stack). Bypass stacks should be 

defined as monitoring locations only if the emissions from the bypass are monitored (as opposed 

to using maximum potential or other appropriate substitute data values). 

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March 07, 2012September 19, 2012	 3.0 Stack Pipe Data 

Types of Stacks and Pipes 

When assigning IDs to stacks or pipes, consider the following types of stacks and pipes and the
 

associated ID prefix:
 

●	 Common Stacks: If a stack serves more than one unit and emissions are monitored at 

that stack, it must be defined as a "common stack" for reporting purposes. Assign a 

common stack ID beginning with the prefix "CS" followed by one to four alphanumeric 

characters. 

●	 Common Pipes: If a fuel pipe serves more than one unit and fuel flow is monitored at 

that common pipe header, it must be defined as a "common pipe" for reporting purposes. 

Assign a pipe ID beginning with the prefix "CP" followed by one to four additional 

alphanumeric characters. If more than one fuel type is associated with the same group of 

units, it is not necessary to report a common pipe for each fuel type; rather, define one 

"common pipe" and define separate fuel flow monitoring systems for each fuel type at the 

pipe. 

●	 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 that 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 one to four alphanumeric characters. 

●	 Multiple Pipes: For a combined cycle (CC) 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, i.e., one for each fuel 

flowmeter location. Assign a pipe ID beginning with the prefix "MP" followed by one to 

four alphanumeric characters. Consult with the EPA Clean Air Markets Division or state 

agency prior to initial monitoring plan submission if a facility has this configuration. 

Table 1 summarizes the information above: 

Table 1 

Stack Pipe ID Prefixes
 

Prefix Description 

CS Common Stack 

CP Common Pipe 

MS Multiple Stack or Duct 

MP Multiple Pipe 

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3.0 Stack Pipe Data March 07, 2012September 19, 2012 

Dependencies for STACK PIPE DATA 

The STACK PIPE DATA record is dependent on the MONITORING LOCATION DATA record. 

The following complex elements specify additional monitoring plan data and are dependent on 

the STACK PIPE DATA record:
 

● MONITORING LOCATION ATTRIB DATA 

● MONITORING METHOD DATA 

● MONITORING FORMULA DATA 

● MONITORING DEFAULT DATA 

● MONITORING SPAN DATA 

● MONITORING LOAD DATA 

● COMPONENT DATA 

● MONITORING SYSTEM DATA 

● MONITORING QUALIFICATION DATA 

● RECTANGULAR DUCT WAF DATA 

These complex elements cannot be submitted for a stack or pipe unless an applicable STACK PIPE 

DATA record is included. 

STACK PIPE DATA Elements 

Instructions for completing each element of the STACK PIPE DATA section are provided below: 

Active Date 

Element Name: ActiveDate 

Report either the date emissions first went through the stack or, for a stack or pipe existing prior 

to the date that the associated unit(s) became subject to the applicable program, report that 

program effective date. For a stack or pipe that became operational after the associated unit's 

program effective date, report the actual date on which emissions first exited the stack or fuel 

was combusted at the pipe or stack location by an affected unit. 

Retire Date 

Element Name: RetireDate 

If applicable, 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 and pipes, 

leave this field blank. 

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4.0 Unit Data 

4.0 UNIT DATA 

March 07, 2012September 19, 2012 

Figure 7 

UNIT DATA XML Elements 

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March 07, 2012September 19, 2012 4.0 Unit Data 

Description of Data 

The UNIT DATA record is used to define, for each unit identified in the MONITORING LOCATION
 

DATA record, whether that unit is a non-load-based unit under Part 75. Submit a UNIT DATA
 

record for each unit that is part of the monitoring plan configuration, whether or not monitoring
 

is to be performed at the unit level. Information regarding the unit's heat input capacity,
 

associated controls, and available fuels will be linked to each unit identified by a UNIT DATA
 

record. 

Dependencies for UNIT DATA 

The UNIT DATA record is dependent on the MONITORING LOCATION DATA record. 

The following complex elements specify additional unit data and are dependent on the UNIT 

DATA record:
 

● MONITORING LOCATION ATTRIBUTE DATA 

● UNIT CAPACITY DATA 

● UNIT CONTROL DATA 

● UNIT FUEL DATA 

● MONITORING METHOD DATA 

● MONITORING FORMULA DATA 

● MONITORING DEFAULT DATA 

● MONITORING SPAN DATA 

● MONITORING LOAD DATA 

● COMPONENT DATA 

● MONITORING SYSTEM DATA 

● MONITORING QUALIFICATION DATA 

● RECTANGULAR DUCT WAF DATA 

These complex elements cannot be submitted for a unit unless an applicable UNIT DATA record
 

is included. See the instructions for each complex element to determine whether or not to 

include it for a particular unit.
 

UNIT DATA Elements 

Instructions for completing each element of the UNIT DATA section are provided below: 

Non Load Based Indicator 

Element Name: NonLoadBasedIndicator 

Report a non load-based indicator value of "1" if the unit does not produce electrical or steam
 

load. Report a "0" if the unit does produce electrical or steam load.
 

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4.1 Unit Capacity Data March 07, 2012September 19, 2012 

4.1 UNIT CAPACITY DATA 

Figure 8 

UNIT CAPACITY DATA XML Elements
 

Description of Data 

Report a UNIT CAPACITY DATA record for each unit defined in a UNIT DATA record of the 

monitoring plan. This record is used to specify the maximum hourly heat input capacity for each 

unit. Update this record only if the maximum hourly heat input capacity changes based on the 

design of the unit or its observed data over the past five years. 

For more information on derated, combined cycle, and Low Mass Emission (LME) units for this 

record see the "Specific Considerations" section below. 

Dependencies for UNIT CAPACITY DATA 

The UNIT CAPACITY DATA record is dependent on the UNIT DATA record. 

No other records are dependent upon the UNIT CAPACITY DATA record. 

UNIT CAPACITY DATA Elements 

Instructions for completing each element of the UNIT CAPACITY DATA section are provided 

below: 

Maximum Hourly Heat Input Capacity 

Element Name: MaximumHourlyHeatInputCapacity 

Report the design heat input capacity (in mmBtu/hr) for the unit or the highest hourly heat input 

rate observed in the past five years, whichever is greater. 

Begin Date 

Element Name: BeginDate 

Report the date on which the reported maximum hourly heat input capacity for a unit became 

effective. 

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March 07, 2012September 19, 2012	 4.1 Unit Capacity Data 

End Date 

Element Name: EndDate 

Report the last date on which the reported maximum hourly heat input capacity for a unit was
 

valid. This value should be left blank for active records. 

Specific Considerations 

Derated Units 

●	 If a unit has been derated, report the derated maximum heat input capacity. 

Combined Cycle Units 

●	 For combined cycle units without duct burners, report the maximum heat input of the unit 

combustion turbine. For combined cycle units with duct burners, report the combined 

maximum heat input for the combustion turbine and duct burner, unless, in agreement 

with EPA, the duct burner has been defined as a separate unit. 

Low Mass Emission (LME) Units 

●	 Enter the maximum rated hourly heat input for units using the LME methodology as 

defined in §72.2 or modified according to §75.19(c)(2)(i). 

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4.2 Unit Control Data March 07, 2012September 19, 2012 

4.2 UNIT CONTROL DATA 

Figure 9 

UNIT CONTROL DATA XML Elements
 

Description of Data 

The UNIT CONTROL DATA record is used to identify emissions controls that are utilized or 

planned for the specified unit. Submit a UNIT CONTROL DATA record for each type of NOx, SO2, 

or particulate control equipment in place or planned for each unit defined in the monitoring plan. 

These data include information describing the parameter emitted and the corresponding control 

type. For controls with co-benefits (e.g., flue gas desulfurization systems (FGD)), just list the 

control once using the parameter code that corresponds to the primary pollutant controlled. 

Do not report UNIT CONTROL DATA for any parameter (NOX, SO2, or PART) for which the unit 

is uncontrolled. Similarly, do not report unit control data for a parameter if emissions of that 

parameter are controlled only by limiting production or by switching fuels. 

Dependencies for UNIT CONTROL DATA 

The UNIT CONTROL DATA record is dependent on the UNIT DATA record. 

No other records are dependent upon the UNIT CONTROL DATA record. 

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March 07, 2012September 19, 2012 4.2 Unit Control Data 

UNIT CONTROL DATA Elements 

Instructions for completing each element of the UNIT CONTROL DATA section are provided 

below:
 

Parameter Code 

Element Name: ParameterCode 

Report the parameter being controlled by using one of the following uppercase codes as shown
 

in Table 2:
 

Table 2 

Parameter Codes and Descriptions
 

Code Description 

NOX Nitrogen Oxides 

SO2 Sulfur Dioxide 

PART Particulates (opacity) 

Control Code 

Element Name: ControlCode 

Report the code for the corresponding control device by reporting the uppercase control code as 

shown in Table 3: 

Table 3 

Control Codes and Descriptions
 

Parameter 

Control 

Code Description 

NOX CM Combustion Modification/Fuel Reburning 

DLNB Dry Low NOx Premixed Technology (turbines only) 

H2O 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 wallfired boilers, dry bottom turbo-fired boilers, or process heaters only) 

(cont.) 

Monitoring Plan Reporting Instructions -- Page 22 Environmental Protection Agency 
 

 

4.2 Unit Control Data March 07, 2012September 19, 2012 

Table 3 

Control Codes and Descriptions (cont.)
 

Parameter 

Control 

Code Description 

NOX (cont.) LNC1 Low NOx Burner Technology with Close-Coupled Overfire Air 

(OFA) (tangentially fired units only) 

LNC2 Low NOx Burner Technology with Separated OFA (tangentially 

fired units only) 

LNC3 Low NOx Burner Technology with Close-Coupled and Separated 

OFA (tangentially fired units only) 

LNCB Low NOx Burner Technology for Cell Burners 

NH3 Ammonia Injection 

O Other 

OFA Overfire Air 

SCR Selective Catalytic Reduction 

SNCR Selective Non-Catalytic Reduction 

STM Steam Injection 

SO2 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 

PART B Baghouse(s) 

ESP Electrostatic Precipitator 

HESP Hybrid Electrostatic Precipitator 

WESP Wet Electrostatic Precipitator 

WS Wet Scrubber 

O Other 

C Cyclone 

Environmental Protection Agency Monitoring Plan Reporting Instructions -- Page 23 
 

 

 

 

 

 

 

 

 

March 07, 2012September 19, 2012 4.2 Unit Control Data 

Original Code 

Element Name: OriginalCode 

For each record, indicate whether or not the control equipment was installed and operational as
 

part of the original unit design. The number "1" indicates the equipment was a part of the 

original unit, and "0" indicates that it was not.
 

Install Date 

Element Name: InstallDate 

Report the approximate date on which controls were installed or will be installed at the unit, if 

the control equipment was not part of the original installation. If the equipment was part of the
 

original installation, leave this field blank. 

Optimization Date 

Element Name: OptimizationDate 

Report the approximate date on which optimization of the control equipment was completed and 

the equipment was fully operational at the unit, if the control equipment was not part of the 

original installation. If the equipment was part of the original installation, leave this field blank. 

Seasonal Controls Indicator 

Element Name: SeasonalControlsIndicator 

Report a "1" in the Seasonal Control Indicator field for NOx Budget Program units if the NOx
 

control equipment is used only during the ozone season. If not, report "0" (zero).
 

Retire Date 

Element Name: RetireDate 

Report the date on which the control equipment was removed or retired from the unit. This value 

should be left blank if the control equipment is still in use. 

Monitoring Plan Reporting Instructions -- Page 24 Environmental Protection Agency 
 

 

 

 

4.3 Unit Fuel Data 

4.3 UNIT FUEL DATA 

March 07, 2012September 19, 2012 

Figure 10 

UNIT FUEL DATA XML Elements 

Description of Data 

For each unit identified in the UNIT DATA record of the monitoring plan, submit a UNIT FUEL 

DATA record for each type of fuel combusted by the unit. The UNIT FUEL DATA 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. 

Dependencies for UNIT FUEL DATA 

The UNIT FUEL DATA record is dependent on the UNIT DATA record. 

No other records are dependent upon the UNIT FUEL DATA record. 

Environmental Protection Agency Monitoring Plan Reporting Instructions -- Page 25 
 

 

 

 

 

March 07, 2012September 19, 2012 4.3 Unit Fuel Data 

UNIT FUEL DATA Elements 

Instructions for completing each element of the UNIT FUEL DATA section are provided below: 

Fuel Code 

Element Name: FuelCode 

Report one of the following uppercase codes to indicate the types of fuel combusted by a unit as 

shown in Table 4: 

Table 4 

Unit Fuel Codes and Descriptions
 

Code Description 

C Coal 

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 

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 and 

ultra-low sulfur diesel fuel (ULSD) are considered subsets of diesel oil and therefore should be identified 

with the code DSL. If a fuel does not qualify as one of these types, do not report the code DSL. 

Monitoring Plan Reporting Instructions -- Page 26 Environmental Protection Agency 
 

 

 

 

 

 

4.3 Unit Fuel Data March 07, 2012September 19, 2012 

Indicator Code 

Element Name: IndicatorCode 

Report whether the fuel type listed is the primary fuel (as defined in §72.2), a backup 

(secondary) fuel, a startup fuel, or an emergency fuel for this unit by using one of the uppercase 

codes shown in Table 5: 

Table 5 

Unit Fuel Indicator Codes and Descriptions
 

Code Description 

E Emergency 

I Ignition (startup) 

P Primary 

S Backup (secondary) 

Ozone Season Indicator 

Element Name: OzoneSeasonIndicator 

Report "1" in the Ozone Season Indicator for the secondary fuel(s) record(s) if fuel switching (to 

a secondary fuel or fuels) is used for seasonal control of ozone. If not, report "0" (zero). 

Demonstration Method to Qualify for Monthly Fuel Sampling for GCV 

Element Name: DemGCV 

If applicable, 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) by using one of the following 

uppercase codes as shown in Table 6: 

Table 6 

Demonstration Method to Qualify for Monthly Fuel Sampling for GCV Codes and 

Descriptions
 

Code Description 

GHS 720 Hours of Data Using Hourly 

Sampling 

GGC 720 Hours of Data Using an Online 

Gas Chromatograph 

GOC 720 Hours of Data Using an Online 

Calorimeter 

Environmental Protection Agency Monitoring Plan Reporting Instructions -- Page 27 
 

 

 

 

 

 

March 07, 2012September 19, 2012 4.3 Unit Fuel Data 

Demonstration Method to Qualify for Daily or Annual Fuel Sampling for %S (ARP) 

Element Name: DemSO2 

If applicable, report the method used to demonstrate that an Acid Rain unit using Appendix D 

qualifies for daily or annual percent sulfur sampling (see Section 2.3.6 of Appendix D) using one 

of the uppercase codes shown in Table 7: 

Table 7 

Demonstration Method to Qualify for Daily or Annual Fuel Sampling 

for %S (ARP) Codes and Descriptions
 

Code Description 

SHS 720 Hours of Data Using Manual 

Hourly Sampling 

SGC 720 Hours of Data Using Online Gas 

Chromatograph 

Begin Date 

Element Name: BeginDate 

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 Begin Date must precede or coincide with the date of 

any monitoring system certifications while combusting the fuel. 

End Date 

Element Name: EndDate 

Report the last date on which a given fuel type was combusted at the unit if the combustion of 

this fuel type has been permanently discontinued at this unit. This value should be left blank for 

fuels that are still being used. 

Monitoring Plan Reporting Instructions -- Page 28 Environmental Protection Agency 
 

 

 

 

 

 

5.0 Monitoring Location Attribute Data March 07, 2012September 19, 2012 

5.0 MONITORING LOCATION ATTRIBUTE DATA 

Figure 11 

MONITORING LOCATION ATTRIBUTE DATA XML Elements
 

Description of Data 

The MONITORING LOCATION ATTRIBUTE DATA record provides a description of the physical 

characteristics of a specified monitoring location. Submit a MONITORING LOCATION ATTRIBUTE 

DATA record for each multiple or common stack defined in a monitoring plan. Also report a 

MONITORING LOCATION ATTRIBUTE DATA record for each unit in the monitoring plan if 

emissions are monitored or determined there. Do not report this record for pipes. 

For multiple stack (MS) configurations, if the monitors are located on the stacks, report the 

height, elevation and inside cross-sectional area (CSA) information for each stack (i.e., stack exit 

CSA and, if applicable, the CSA at the flow monitor location). If the monitors are located at 

breechings or ducts rather than on the stack, in the MONITORING LOCATION ATTRIBUTE record for 

each multiple stack report the stack exit height, base elevation and inside CSA information for 

the exhaust stack, and report the CSA at the stack exit and, if applicable, the inside CSA at the 

flow monitor location in the ductwork. 

For units that are part of a common pipe (CP) or multiple (MP) configuration and use Appendix 

D estimation procedures for heat input, CO2, or SO2, report (using the appropriate Unit ID or 

Stack ID) 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 a 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. 

Environmental Protection Agency Monitoring Plan Reporting Instructions -- Page 29 
 

 

 

 

 

 

 

 

 

March 07, 2012September 19, 2012 5.0 Monitoring Location Attribute Data 

Dependencies for MONITORING LOCATION ATTRIBUTE DATA 

The MONITORING LOCATION ATTRIBUTE DATA record is dependent on the UNIT DATA record or 

the STACK PIPE DATA record.
 

No other records are dependent upon the MONITORING LOCATION ATTRIBUTE DATA record. 

MONITORING LOCATION ATTRIBUTE DATA Elements 

Instructions for completing each element of the MONITORING LOCATION ATTRIBUTE DATA
 

section are provided below:
 

Duct Indicator 

Element Name: DuctIndicator 

Report a "1" or a "0" indicating whether the monitoring location is a duct, with "1" meaning yes 

and "0" meaning no. 

Bypass Indicator 

Element Name: BypassIndicator 

Report a "1" or a "0" indicating whether the monitoring location is a bypass stack, with "1" 

meaning yes and "0" meaning no.
 

Ground Elevation 

Element Name: GroundElevation 

Report the elevation of the ground level, in feet above sea level, at the base of a stack or unit. 

Stack Height 

Element Name: StackHeight 

Report the height of the stack exit, in feet above ground level. 

Monitoring Plan Reporting Instructions -- Page 30 Environmental Protection Agency 
 

 

 

 

 

5.0 Monitoring Location Attribute Data March 07, 2012September 19, 2012 

Material Code 

Element Name: MaterialCode 

If applicable (i.e., there is a stack flow monitor at this location), report a code from Table 8 that 

most accurately describes the material from which the inner wall of the duct or stack is
 

constructed at the flow monitoring location:
 

Table 8 

Duct/Stack Material Codes and Description
 

Code Description 

BRICK Brick and mortar 

OTHER Any material other than brick and 

mortar 

Shape Code 

Element Name: ShapeCode 

If applicable (i.e., there is a stack flow monitor at this location), report a code from Table 9 that 

most accurately describes the shape of a duct or stack at the flow monitoring location: 

Table 9 

Duct/Stack Shape Codes and Descriptions
 

Code Description 

RECT Rectangular 

ROUND Round 

Cross Area Flow 

Element Name: CrossAreaFlow 

If applicable (i.e., there is a stack flow monitor at this location), report the inside cross-sectional 

area, in square feet, of the stack at the flow monitoring location. 

Cross Area Stack Exit 

Element Name: CrossAreaStackExit 

Report the inside cross-sectional area, in square feet, of the stack at the flue exit. 

Environmental Protection Agency Monitoring Plan Reporting Instructions -- Page 31 
 

 

 

 

 

 

 

 

 

March 07, 2012September 19, 2012 5.0 Monitoring Location Attribute Data 

Begin Date 

Element Name: BeginDate 

Report the date on which these physical characteristics first applied to the location. If this is the 

first or only MONITORING LOCATION ATTRIBUTE DATA record for the location, this date should 

equal the Active Date in the STACK PIPE DATA record (for common or multiple stacks), or the 

date that a unit first became subject to any applicable program (for units). If this is an updated 

MONITORING LOCATION ATTRIBUTE DATA record showing a change in one or more attribute 

value(s), this date should be the date on which the change took place. 

End Date 

Element Name: EndDate 

Report the last date on which these physical characteristics applied to the location. This value 

should be left blank for active attribute information. 

Monitoring Plan Reporting Instructions -- Page 32 Environmental Protection Agency 
 

 

 

 

6.0 Monitoring Method Data March 07, 2012September 19, 2012 

6.0 MONITORING METHOD DATA 

Figure 12 

MONITORING METHOD DATA XML Elements
 

Description of Data 

The MONITORING METHOD DATA record describes the emissions monitoring methodologies used 

at each monitoring location identified in the monitoring plan. A separate MONITORING METHOD 

DATA record must be included for each parameter (NOX, SO2, CO2, etc.) monitored or 

calculated at each identified monitoring location. Note that when heat input is not monitored at 

the unit level, a MONITORING METHOD DATA record for heat input must be included for both the 

monitoring location and at the unit level. 

For example, if all emissions are monitored at a common stack for Units 1 and 2, report one set 

of monitor method records for the common stack location, which includes a single record for 

each parameter monitored, and (if heat input monitoring is required) two additional records (i.e., 

one each for Units 1 and 2) indicating the method by which heat input is determined at the unit 

level. 

Report only one active method for each parameter monitored at the location. For locations with 

an unmonitored bypass stack, use the Bypass Approach Code field in the applicable method 

record(s) to report whether or not a fuel-specific default value will be used for bypass hours. For 

information on particular usages of this record for moisture, heat input, ARP units, NBP units, 

LME units and Alternative Monitoring System (AMS), refer to "Specific Considerations" below. 

Also, for information on how to update this record, refer to the "Updating the MONITORING 

METHOD DATA Record" section below. 

Environmental Protection Agency Monitoring Plan Reporting Instructions -- Page 33 
 

 

 

 

March 07, 2012September 19, 2012 6.0 Monitoring Method Data 

Dependencies for MONITORING METHOD DATA 

The MONITORING METHOD DATA record is dependent on the UNIT DATA record or the STACK
 

PIPE DATA record.
 

No other records are dependent upon the MONITORING METHOD DATA record. 

MONITORING METHOD DATA Elements 

Instructions for completing each element of the MONITORING METHOD DATA section are 

provided below:
 

Parameter Code 

Element Name: ParameterCode 

Report the appropriate Parameter Code as shown in Table 10: 

Table 10 

Parameter Codes and Descriptions for Monitoring Methods
 

Code Description (Units) 

CO2 CO2 Mass Emissions Rate (tons/hr) 

CO2M CO2 Mass Emissions (tons) 

H2O Moisture (%H2O) 

HI Heat Input Rate (mmBtu/hr) 

HIT Heat Input Total (mmBtu) (LME only) 

NOX NOx Mass Emissions Rate (lb/hr) 

NOXM NOx Mass Emissions (lb) (LME only) 

NOXR NOx Emissions Rate (lb/mmBtu) 

OP Opacity (percent) 

SO2 SO2 Mass Emissions Rate (lb/hr) 

SO2M SO2 Mass Emissions (lb) (LME only) 

Monitoring Plan Reporting Instructions -- Page 34 Environmental Protection Agency 
 

 

 

 

6.0 Monitoring Method Data March 07, 2012September 19, 2012 

Monitoring Method Code 

Element Name: MonitoringMethodCode 

Report the Monitoring Method Code that identifies the methodology employed to monitor the 

specified parameters at the specified monitoring location. Report the appropriate uppercase code 

as shown in Table 11: 

Table 11 

Measured Parameters and Applicable Monitoring Methods
 

Parameter Method Code Description 

CO2 AD Appendix D Gas and/or Oil Flow System(s) (Formula G-4) 

AMS Alternative Monitoring System* 

CEM CO2 Continuous Emission Monitor 

CO2M FSA Fuel Sampling and Analysis (Formula G-1) 

LME Low Mass Emissions (§75.19) 

H2O MMS Continuous Moisture Sensor 

MDF Moisture Default 

MTB Moisture Lookup Table 

MWD H2O System with Wet and Dry O2 Analyzers 

HI AD Appendix D Gas and/or Oil Flow System(s) 

ADCALC Appendix D Gas and/or Oil Flow System at location (unit) 

and different Oil or Gas Measured at Common Pipe. (Heat 

Input at the unit is determined by adding the appropriate value 

apportioned from the Common Pipe to the unit value) 

AMS Alternative Monitoring System* 

CALC Calculated from Values Measured at Other Locations. 

(Used for three situations: (1) this is the method at a unit 

when heat input is determined at a common stack or common 

pipe and then apportioned to the constituent units; or (2) this 

is the method at a unit when heat input is determined at 

multiple stacks and then summed to the unit; or (3) this is the 

method at a common stack if heat input is determined at the 

units and then summed to the common stack in order to 

calculate NOx mass) 

CEM Flow and O2 or CO2 Continuous Emission Monitors 

EXP Exempt from Heat Input monitoring 

HIT LTFF Long-Term Fuel Flow (Low Mass Emissions -- §75.19) 

(cont.) 

Environmental Protection Agency Monitoring Plan Reporting Instructions -- Page 35 
 

 

 

 

 

March 07, 2012September 19, 2012 6.0 Monitoring Method Data 

Table 11 

Measured Parameters and Applicable Monitoring Methods (cont.)
 

Parameter Method Code Description 

HIT (cont.) LTFCALC Long-Term Fuel Flow (Low Mass Emissions -- §75.19) at the 

unit and different Long Term Fuel Flow at the common pipe. 

(Heat Input at the unit is determined by adding the appropriate 

value apportioned from the Common Pipe to the unit value) 

MHHI Maximum Rated Hourly Heat Input (Low Mass Emissions) 

CALC Calculated from values measured at the common pipe. (This 

is the method at a unit when heat input is determined at a 

common pipe and apportioned to the constituent units) 

NOX AMS Alternative Monitoring System* 

CEM NOx Concentration times Stack Flow rate 

CEMNOXR NOx Concentration times Stack Flow rate and NOx Emission 

Rate times Heat Input Rate (one as a primary method and the 

other as secondary). This method is not permitted after 

December 31, 2007 

NOXR NOx Emission Rate times Heat Input Rate 

NOXM LME Low Mass Emissions (§75.19) 

NOXR AMS Alternative Monitoring System* 

AE Appendix E 

CEM NOx Emission Rate CEMS 

PEM Predictive Emissions Monitoring System (as approved by 

petition) 

OP COM Continuous Opacity or Particulate Matter Monitor 

EXP Exempted 

SO2 AD Appendix D Gas and/or Oil Flow System(s) 

AMS Alternative Monitoring System* 

CEM SO2 Continuous Emission Monitor 

CEMF23 SO2 Continuous Emission Monitor, and Use of F-23 Equation 

during hours when only very low sulfur fuel is burned per 

§§75.11(e) and 75.11(e)(4) 

F23 Use of F-23 Equation if only very low sulfur fuel is burned 

per §§75.11(e) and 75.11(e)(4) 

SO2M LME Low Mass Emissions (§75.19) 

* Use of this method requires EPA approval 

Monitoring Plan Reporting Instructions -- Page 36 Environmental Protection Agency 
 

 

 

 

 

6.0 Monitoring Method Data March 07, 2012September 19, 2012 

Substitute Data Code 

Element Name: SubstituteDataCode 

Report the Substitute Data Code that designates the methodology used to determine substitute 

values during periods of missing data. Leave this field blank when NOX Mass is calculated 

from NOX Rate and HI (Method Code NOXR and Parameter Code NOX). Also, leave this field 

blank for parameter code OP and all LME methods, with the following exception. When using 

long-term fuel flow as the heat input methodology for an LME unit, report a Substitute Data 

Code of MHHI only if it will ever be necessary to report the unit's maximum rated hourly heat 

input rate as the heat input rate for any hour. This may be necessary for either of two reasons: 

(1) for any hour when burning a secondary fuel that is not measured by a long-term fuel flow
 

system, or (2) 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 reporting period. Report the appropriate
 

uppercase code as shown in Table 12:
 

Table 12 

Substitute Data Codes and Descriptions
 

Code Description Appropriate For Parameter Codes 

SPTS Standard Part 75 NOXR, NOX, SO2, CO2, H2O, and HI 

FSP75 Fuel-Specific Part 75 NOXR, NOX, SO2, CO2, H2O, and HI 

FSP75C Fuel-Specific Part 75 with separate 

co-fired database 

NOXR, NOX, SO2, CO2, H2O, and HI 

OZN75 Ozone vs. Non-Ozone Season NOX, NOXR 

NLB Non-Load Based NOXR, NOX, and HI 

NLBOP Non-Load Based with Operational 

Bins 

NOXR, NOX, and HI 

REV75 Reverse of Standard Part 75 H2O 

MHHI Maximum Rated Hourly Heat 

Input Rate for LME Units using 

Long Term Fuel Flow 

methodology 

HIT 

Environmental Protection Agency Monitoring Plan Reporting Instructions -- Page 37 
 

 

 

 

 

 

 

 

 

March 07, 2012September 19, 2012 6.0 Monitoring Method Data 

Bypass Approach Code 

Element Name: BypassApproachCode 

Report the Bypass Approach Code used to calculate emissions for an unmonitored bypass stack 

whose method of determining emissions is based on a default value. The Bypass Approach Code 

is not required if a bypass stack is directly monitored or valid data are calculated from monitors 

at other locations (e.g., at a control device inlet). This code is only applicable for parameters 

SO2, NOX, and NOXR with CEM, CEMF23, and NOXR method codes. Report the appropriate 

uppercase codes as shown in Table 13: 

Table 13 

Bypass Approach Codes and Descriptions
 

Code Description 

BYMAX MPC or MER* for Highest Emitting 

Fuel 

BYMAXFS Fuel-Specific MPC or MER* 

* Note that MEC or MCR may be used for documented controlled hours. 

Begin Date 

Element Name: BeginDate 

Report the date on which the methodology was first used to determine emissions or heat input 

rate for the monitoring location. For opacity, report the same starting date as for emission 

reporting, whether the applicable units are exempted from opacity monitoring or not. 

For new units, report the first date on which the methodology is expected to be used to determine 

emissions or heat input rate. Correct as needed when the actual begin date is known. 

Begin Hour 

Element Name: BeginHour 

Report the hour in which the methodology was first used to determine emissions or heat input 

rate for the monitoring location. 

End Date 

Element Name: EndDate 

Report the date on which the methodology was last used to determine emissions or heat input 

rate for the monitoring location. This value should be left blank for active records. 

Monitoring Plan Reporting Instructions -- Page 38 Environmental Protection Agency 
 

 

 

 

 

 

 

 

 

6.0 Monitoring Method Data March 07, 2012September 19, 2012 

End Hour 

Element Name: EndHour 

Report the hour in which the methodology was last used to determine emissions or heat input
 

rate for the monitoring location. This value should be left blank for active records. 

Specific Considerations 

Moisture 

●	 If required to correct for moisture (H2O) when calculating emissions or heat input at a 

monitoring location, report a separate monitor method record for the H2O parameter. Do 

this for each location at which moisture is needed, defining the methodology used to 

determine hourly moisture for emissions calculations. 

Heat Input 

●	 If heat input monitoring is required, there must be a separate monitor method record for 

heat input (HI) data for each unit, even if the monitor location is not at the unit level. For 

example, if SO2, CO2, NOx, and Flow monitors are installed at CS001, which serves Unit 

1, 2, and 3, there will be a full set of monitor method records for CS001 and only one 

monitor method record for HI at each unit. The unit records for monitor method should 

indicate that the heat input is calculated for the unit, using the "CALC" monitoring 

method code. 

Acid Rain Program Units 

●	 If a location which has an SO2 monitor combusts both high sulfur fuel (e.g., coal or oil) 

and a low sulfur fuel, and uses a default SO2 emission rate in conjunction with Equation 

F-23 for hours in which very low sulfur fuel is combusted (see §75.11(e)(1)), report one 

monitor method record for parameter SO2 with a monitoring methodology code 

CEMF23. If only low-sulfur fuel is combusted and the F-23 calculation is used for every 

hour, report the SO2 monitoring method as F23. 

●	 If a unit or stack is exempt from opacity monitoring, report a monitor method record for 

the unit or stack defining the parameter OP with a monitor method code of EXP. 

●	 If opacity is monitored at a common stack or multiple stacks, but no other parameters are 

monitored at that location, do not define the stack(s). Instead, report the opacity method 

and system data at the unit level. 

●	 If a unit is also subject to Subpart H, be sure to include the appropriate method record(s) 

indicating how NOx mass is determined. 

Environmental Protection Agency	 Monitoring Plan Reporting Instructions -- Page 39 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

March 07, 2012September 19, 2012	 6.0 Monitoring Method Data 

NOx Budget Program Units 

●	 Report a monitor methodology record for parameter NOX at each applicable location. 

●	 Report the method code as NOXR if NOx mass emissions are calculated by determining 

NOx emission rate and heat input rate. Report method code CEM if NOx mass is 

calculated as the product of NOx concentration and stack gas flow rate. 

●	 If applicable, report methodology records for NOx emission rate and/or heat input. 

Low Mass Emissions (LME) Units 

For all LME units as under the methodology in §75.19: 

●	 For Acid Rain Program LME units: Submit separate monitor methodology records for 

parameters SO2M, NOXM, CO2M, HIT, and, if applicable OP. 

●	 For Non-Acid Rain, NOx Budget Program LME Units: Submit monitor method records 

to describe the methodologies for both NOx mass (NOXM) and heat input (HIT). 

Part 75 Alternative Monitoring System (AMS) 

●	 The use of method code AMS for determining average hourly emissions for parameters 

CO2, HI, NOX, NOXR, or SO2 is granted through petition based on meeting the 

requirements of Subpart E of Part 75. 

Updating the MONITORING METHOD DATA Record 

When changing monitoring methodologies for a parameter, report both the old and new 

MONITORING METHOD DATA records. First, close out the existing monitoring methodology 

record by entering the date and hour that the methodology was discontinued (EndDate, 

EndHour). Second, create a new monitoring method record for that parameter indicating the date 

and hour during which use of the replacement methodology began (BeginDate, BeginHour). For 

the new method, leave the values for End Date and End Hour blank. 

In order to correct a previously submitted record that contains erroneous information, resubmit 

that MONITORING METHOD DATA record with the corrected information. For example, if the SO2 

Monitoring Method Code was previously submitted as "CEM" and the correct code should have 

been "CEMF23," the record should be updated and resubmitted. Note that the BeginDate and 

BeginHour elements should not be updated, unless the BeginDate and/or BeginHour are the 

elements to be corrected. 

Monitoring Plan Reporting Instructions -- Page 40	 Environmental Protection Agency 
 

 

 

 

7.0 Component Data 

7.0 COMPONENT DATA 

March 07, 2012September 19, 2012 

Figure 13 

COMPONENT DATA XML Elements 

Description of Data 

The COMPONENT DATA record describes each of the components used to make up the monitoring 

systems defined in the monitoring plan. A component can be either a hardware component, such 

as a NOx analyzer, or a software component, such as a DAHS. Under most circumstances, only 

one COMPONENT DATA record is required for components that are shared by multiple monitoring 

systems defined at that location. For example, an O2 monitor that is used in both the NOx 

emissions rate system and the moisture monitoring system needs only to be identified in one 

COMPONENT DATA record. The exception exists for a combined cycle combustion unit using a 

"time-share" CEMS configuration to monitor emissions from both the main and bypass stacks. 

Please refer to "Specific Considerations" below for more information. 

Information describing the monitoring system of which the component is a part is not needed for 

this record. The relationship between components and monitoring systems is defined by the 

MONITORING SYSTEM COMPONENT DATA record. 

For information on defining DAHS components, how to report fuel flowmeter data when using 

flowmeter rotation, and how to represent manufacturer and serial number information, refer to 

"Specific Considerations" below. 

Environmental Protection Agency Monitoring Plan Reporting Instructions -- Page 41 
 

 

 

 

 

 

 

 

 

March 07, 2012September 19, 2012 7.0 Component Data 

Dependencies for COMPONENT DATA 

The COMPONENT DATA record is dependent on the UNIT DATA record or the STACK PIPE DATA
 

record.
 

The following records are dependent upon the COMPONENT DATA record: 

● ANALYZER RANGE DATA 

● MONITORING SYSTEM COMPONENT DATA 

COMPONENT DATA Elements 

Instructions for completing each element of the COMPONENT DATA section are provided below: 

Component ID 

Element Name: ComponentID 

Report the three-character ID assigned to the component. This ID is assigned by a source and 

must be unique to a stack, pipe, or unit. For example, two different monitored units or stacks, 

e.g., CS1 and CS2, could each have an O2 monitor with the same assigned Component ID of 123. 

However, no two components at the same monitored location (in this case, either CS1 or CS2) 

are allowed to have the same Component ID. For temporary like-kind analyzer replacements 

under §75.20(d), the component ID of the like-kind analyzer must begin with the prefix "LK" 

(e.g., "LK1," "LK2," etc.). 

Note that components are linked to each system that the component serves using the 

MONITORING SYSTEM COMPONENT record. The MONITORING SYSTEM COMPONENT record 

includes a begin date and hour to track when a particular component is placed into service as part 

of the system, and an end date and hour to indicate when the component is removed or is 

replaced. 

Do not close out primary monitoring components that are temporarily removed from service for 

maintenance, e.g., when a like-kind monitoring component is placed into service while the 

primary component is being repaired. 

Also, do not close out temporary like-kind replacement analyzer ("LK") components unless a
 

particular like-kind analyzer will never be used again at the unit or stack location. You may
 

represent the "LK" analyzer in the monitoring plan as an active component of the primary
 

monitoring system, for the entire useful life of the LK analyzer.
 

Monitoring Plan Reporting Instructions -- Page 42 Environmental Protection Agency 
 

 

 

7.0 Component Data March 07, 2012September 19, 2012 

Component Type Code 

Element Name: ComponentTypeCode 

Report the code indicating the function of the component. The code does not necessarily 

correspond to the function of the monitoring system as a whole in which a component is 

included. Report the Component Type Code by using the appropriate uppercase code as shown 

in Table 14: 

Table 14 

Component Type Codes and 

Descriptions
 

Code Description 

BGFF Billing Gas Fuel Flowmeter 

BOFF Billing Oil Fuel Flowmeter 

CALR Calorimeter 

CO2 Carbon Dioxide Concentration 

Analyzer 

DAHS Data Acquisition and Handling System 

DL Data Logger or Recorder 

DP Differential Pressure 

Transmitter/Transducer 

FLC Flow Computer 

FLOW Stack Flow Monitor 

GCH Gas Chromatograph 

GFFM Gas Fuel Flowmeter 

H2O Percent Moisture (Continuous 

Moisture System only) 

NOX Nitrogen Oxide Concentration 

Analyzer 

O2 Oxygen Concentration Analyzer 

OFFM Oil Fuel Flowmeter 

OP Opacity Measurement 

PLC Programmable Logic Controller 

PM Particulate Matter Measurement 

PRB Probe 

(cont.) 

Environmental Protection Agency Monitoring Plan Reporting Instructions -- Page 43 
 

March 07, 2012September 19, 2012 7.0 Component Data 

Table 14 

Component Type Codes and 

Descriptions (cont.)
 

Code Description 

PRES Pressure Transmitter/Transducer 

SO2 Sulfur Dioxide Concentration 

Analyzer 

TANK Oil Supply Tank 

TEMP Temperature Transmitter/Transducer 

Sample Acquisition Method Code 

Element Name: SampleAcquisitionMethodCode 

Report the appropriate concentration/diluent codes, operational principle (volumetric flow 

codes), or type of fuel flowmeter (fuel flowmeter type codes). Leave this field blank if a sample 

acquisition method is not applicable to the component type (e.g., for a DAHS component). For 

LME long-term fuel flow components, leave this field blank unless using a certified fuel 

flowmeter to quantify heat input. Report the Sample Acquisition Method Code by using the 

appropriate uppercase codes as shown in Table 15: 

Table 15 

Sample Acquisition Method Codes for Components
 

Component Code Description 

For CEMS DIL Dilution 

DIN Dilution In-Stack 

DOD Dry Out-of-Stack Dilution 

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 

(cont.) 

Monitoring Plan Reporting Instructions -- Page 44 Environmental Protection Agency 
 

7.0 Component Data March 07, 2012September 19, 2012 

Table 15 

Sample Acquisition Method Codes (cont.)
 

Component Code Description 

For Volumetric Stack Flow Monitor 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 

VCON V-Cone 

VEN Venturi 

VTX Vortex 

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March 07, 2012September 19, 2012 7.0 Component Data 

Basis Code 

Element Name: BasisCode 

For CEM analyzer components, report a code indicating whether the applicable components
 

sample on a wet or dry basis or use both wet and dry methods. Use the appropriate uppercase 

codes as shown in Table 16:
 

Table 16 

Basis Codes and Descriptions for CEM Analyzer Components
 

Code Description 

W Wet 

D Dry 

B Both wet and dry (O2 only) 

* For sample acquisition method (SAM) codes IS, ISP, ISC, DIN, DOU, DIL, and WXT = wet extractive; 

EXT = dry extractive, located under Component. Exceptions are possible. For all stack flow monitors -­

wet basis. Check with vendor if uncertain. 

Manufacturer 

Element Name: Manufacturer 

Report the name or commonly used acronym for the manufacturer or developer of the 

component. Do not use this field to identify the unit or location of the component. For LME 

long-term fuel flow components, leave this field blank unless using a certified fuel flowmeter to 

quantify heat input. 

Model Version 

Element Name: ModelVersion 

Report the manufacturer designated model name or number of any hardware component or the 

version number of a software component. For LME units using long-term fuel flow, leave this 

field blank unless using a certified fuel flowmeter to quantify heat input. 

Serial Number 

Element Name: SerialNumber 

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. 

For flow monitors, provide a single component serial number that represents the control unit of 

the monitor. Leave this field blank for LME long-term fuel flow components, unless using a 

certified fuel flowmeter to quantify heat input. 

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7.0 Component Data March 07, 2012September 19, 2012 

Specific Considerations 

Essential DAHS Components (Software and Hardware) 

●	 Identify the software component(s) of the Data Acquisition and Handling System 

(DAHS) as individual components. Any software program that calculates emissions or 

heat input rate, or implements missing data substitution algorithms or quarterly reporting 

functions should be defined as a component. Identify the programmable logic controller 

(PLC) or automated data logger (DL) as a system component if it performs any of those 

functions. 

Non-Essential Software or Hardware Components 

●	 Software or hardware components that perform the following functions do not have to be 

identified as part of the DAHS and therefore do not need component definitions1

: 

-- Calculation of RATA results; 

-- Calculation of flow-to-load results (that are merged with the final quarterly report); or 

-- Recording of operating parameters (that are merged with the final quarterly report), 

e.g., unit load. 

Rotating Fuel Flowmeters 

When fuel flowmeters are rotated among different units to facilitate the removal of meters for 

accuracy testing (e.g., three fuel flowmeters rotated between two units), submit a new 

MONITORING SYSTEM COMPONENT DATA record each time that a fuel flowmeter is being placed 

into service, and update the end date and hour of the MONITORING SYSTEM COMPONENT DATA 

record for the fuel flowmeter that is being removed. Use the reinstallation date and hour in the 

FUEL FLOWMETER ACCURACY DATA record as the begin date and hour in the new MONITORING 

SYSTEM COMPONENT DATA record, and use the hour prior to the reinstallation date and hour as the 

end date and hour in the MONITORING SYSTEM COMPONENT DATA record for the fuel flowmeter 

that is being removed. If the fuel flowmeter that is being placed into service had previously been 

installed, you may report its previously assigned component ID in the MONITORING SYSTEM 

COMPONENT DATA record or you may assign a new component ID. 

The rotation of dilution probes should be reported in the same manner as fuel flowmeters. 

1 While these components do not have to be identified in the monitoring plan, identify them in the data flow 

diagram under § 75.53(c)(5)(iii) and/or the quality assurance plan under Appendix B to Part 75. 

Environmental Protection Agency	 Monitoring Plan Reporting Instructions -- Page 47 
 

 

 

 

 

 

 

March 07, 2012September 19, 2012	 7.0 Component Data 

Manufacturer and Serial Number Data for DAHS Components 

●	 Use an abbreviation that clearly identifies the utility or operating company responsible 

for the software development if software has been developed in-house. Use the same 

abbreviation or name in the Manufacturer field for all units and sources using the 

software. 

●	 Serial numbers are optional for DAHS software components and billing fuel flowmeters. 

If choosing to assign one, it must be unique to the software installation. 

Time-Share CEMS on Single Unit 

When using a "time-share" CEMS configuration to monitor emissions from both the main stack 

and bypass stack for a combined cycle combustion unit using a single monitoring location, 

define separate systems with unique Monitoring System IDs for each effluent point, and define 

separate component records with unique Component IDs for each system. Defining separate 

components for each system will allow for the tracking of component specific tests (e.g., 

linearity, seven day cal, online offline cal, and cycle time) where the test cannot be otherwise 

uniquely identified. (This is a distinct change from the previous EDR format, where it was 

acceptable to include the same component in both systems, since the Monitoring System ID used 

to be included in the test record.) If the same component was previously reported in both 

systems, EPA recommends that affected units define new component records only for the system 

that represents the monitoring of the bypass stack, so as to minimize the amount of data that 

would need to be resubmitted. The most recent component specific QA test data (previously 

submitted under the old format) will need to be resubmitted under the new Component IDs. 

Monitoring Plan Reporting Instructions -- Page 48	 Environmental Protection Agency 
 

 

 

 

 

 

 

7.1 Analyzer Range Data March 07, 2012September 19, 2012 

7.1 ANALYZER RANGE DATA 

Figure 14 

ANALYZER RANGE DATA XML Elements
 

Description of Data 

Submit an ANALYZER RANGE DATA record for each gas analyzer component (NOx, SO2, CO2, 

and O2) identified in a COMPONENT DATA record of the monitoring plan. This record specifies 

for each component whether that component is a high scale, low scale, or autoranging 

component, and whether it is a dual range analyzer. 

Dependencies for ANALYZER RANGE DATA 

The ANALYZER RANGE DATA record is dependent on the COMPONENT DATA record. 

No other records are dependent upon the ANALYZER RANGE DATA record. 

ANALYZER RANGE DATA Elements 

Instructions for completing each element of the ANALYZER RANGE DATA section are provided 

below: 

Analyzer Range Code 

Element Name: AnalyzerRangeCode 

Report the code specifying the range by using the appropriate uppercase code as shown in Table 

17. If using a default high range value for SO2 or NOx, the correct range code for the analyzer is 

L. 

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March 07, 2012September 19, 2012	 7.1 Analyzer Range Data 

Table 17 

Analyzer Range Codes and Descriptions
 

Code Description 

H High Range 

L Low Range 

A Auto Ranging 

Dual Range Indicator 

Element Name: DualRangeIndicator 

Report a Dual Range Indicator code equal to "1" whenever a single analyzer is used to satisfy a 

dual range monitoring requirement. There are two possible ways to represent this in the 

component data: 

●	 As two separate components in the monitoring plan (i.e., when the Analyzer Range Code 

is reported as "H" for the analyzer under one component ID and as "L" for the same 

analyzer under another unique component ID); or 

●	 As a single auto-ranging component in the monitoring plan (i.e., Analyzer Range Code 

equal to "A"). 

Note that reporting dual range analyzers as a single auto-ranging component is recommended. 

If more than one analyzer is used to satisfy a dual range monitoring requirement (i.e., when two 

separate analyzers are used, one for the low-range and another for the high-range), report each 

analyzer component separately in the monitoring plan and report "0" as the Dual Range 

Indicator. 

Also report "0" if the component represents a single range analyzer that is not part of a dual 

range monitoring configuration. 

Begin Date 

Element Name: BeginDate 

Report the date on which the range information reported in this record became effective. In most 

cases, this date will be the same as the earliest begin date in the MONITOR SYSTEM COMPONENT 

DATA record. However, if the analyzer range changes (e.g., from a single scale to dual range), be 

sure to put the proper End Date and End Hour in the existing ANALYZER RANGE DATA record and 

enter another ANALYZER RANGE DATA record for the new range code using the appropriate Begin 

Date and Hour. 

Begin Hour 

Element Name: BeginHour 

Report the hour during which the range information reported in this record became effective. 

Monitoring Plan Reporting Instructions -- Page 50	 Environmental Protection Agency 
 

 

 

7.1 Analyzer Range Data March 07, 2012September 19, 2012 

End Date 

Element Name: EndDate 

Report the last date on which the range information reported in this record was effective. This
 

value should be left blank for active records.
 

End Hour 

Element Name: EndHour 

Report the last hour in which the range information reported in this record was effective. This
 

value should be left blank for active records.
 

Environmental Protection Agency Monitoring Plan Reporting Instructions -- Page 51 
 

March 07, 2012September 19, 2012 7.1 Analyzer Range Data 

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8.0 Monitoring System Data March 07, 2012September 19, 2012 

8.0 MONITORING SYSTEM DATA 

Figure 15 

MONITORING SYSTEM DATA XML Elements
 

Description of Data 

Submit a MONITORING SYSTEM DATA record to define each monitoring system that is installed 

(or will be installed) at each monitoring location in the monitoring plan. For CEMS 

methodologies, a monitoring system is any combination of analytical components, sensors, and 

data software components for which a relative accuracy test is required (e.g., SO2 

concentration system, flow rate system, NOx diluent system, NOx concentration system, O2 

concentration system, CO2 concentration system, or moisture system). For monitoring 

methodologies based on fuel flowmetering, 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. See the "Specific Considerations" section 

below for more detailed information about system types. 

Information describing the monitoring system's individual components is not needed for this 

record. The relationship between COMPONENT DATA and MONITORING SYSTEM DATA is 

defined in the MONITORING SYSTEM COMPONENT DATA record. 

Environmental Protection Agency Monitoring Plan Reporting Instructions -- Page 53 
 

 

 

 

 

March 07, 2012September 19, 2012 8.0 Monitoring System Data 

Dependencies for MONITORING SYSTEM DATA 

The MONITORING SYSTEM DATA record is dependent on the UNIT DATA record or the STACK
 

PIPE DATA record.
 

The following records are dependent upon the MONITORING SYSTEM DATA record: 

● MONITORING SYSTEM COMPONENT DATA 

● MONITORING SYSTEM FUEL FLOW DATA
 

MONITORING SYSTEM DATA Elements
 

Instructions for completing each element of the MONITORING SYSTEM DATA section are 

provided below:
 

Monitoring System ID 

Element Name: MonitoringSystemID 

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, and do not re-use the ID 

number of a system that has been permanently removed from service. However, the same 

system numbering scheme may be used for different units, stacks, or pipes at the same facility. 

System Type Code 

Element Name: SystemTypeCode 

Report the code that indicates the type of system by using the appropriate uppercase codes as
 

shown in Table 18:
 

Table 18 

System Type Codes and Descriptions
 

Code Description 

CO2 CO2 Concentration System 

FLOW Stack Flow System 

GAS Gas Fuel Flow System 

H2O Moisture System that uses wet and dry 

O2 analyzers 

H2OM Moisture System that uses a 

continuous moisture sensor 

H2OT Moisture System that uses a 

temperature sensor and a table of 

lookup values 

(cont.) 

Monitoring Plan Reporting Instructions -- Page 54 Environmental Protection Agency 
 

 

8.0 Monitoring System Data March 07, 2012September 19, 2012 

Table 18
 

System Type Codes and Descriptions
 

(cont.)
 

Code Description 

LTGS Long Term Gas Fuel Flow System 

(LME) 

LTOL Long Term Oil Fuel Flow System 

(LME) 

NOX NOx Emission Rate System 

NOXE Appendix E NOx System 

NOXC NOx Concentration System 

NOXP NOx Emission Rate PEMS System 

O2 O2 Concentration System 

OILV Volumetric Oil Fuel Flow System 

OILM Mass of Oil Fuel Flow System 

OP Opacity (ARP only) 

PM Particulate Matter Monitoring System 

SO2 SO2 Concentration System 

System Designation Code 

Element Name: SystemDesignationCode 

Report one of the following uppercase codes indicating the designation of the monitoring 

system. 

Environmental Protection Agency Monitoring Plan Reporting Instructions -- Page 55 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

March 07, 2012September 19, 2012	 8.0 Monitoring System Data 

Table 19 

System Designation Code and Descriptions
 

Code Description 

P Primary. 

PB Primary Bypass. A primary bypass 

(PB) describes a monitoring system 

located on a bypass stack before a heat 

recovery steam generator (HRSG). 

1 

RB Redundant Backup. A redundant 

backup (RB) monitoring system is 

operated and maintained by meeting 

all of the same program QA/QC 

requirements as a primary system. 

B Non-Redundant Backup. A nonredundant 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. 

RM Reference Method Backup. A 

reference method (RM) monitoring 

system is a monitoring system that is 

operated as a reference method 

pursuant to the requirements of 

Appendix A to Part 60. 

CI2 Certified Monitoring System at the 

Inlet to an Emission Control Device. 

1	 Use code "P" for the monitoring system located on the main HRSG stack. 

2	 Use code "CI" only for units with add-on SO2 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 SO2 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 SO2 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 SO2 or NOx monitor at the 

control device inlet in lieu of reporting MPC or MER values. 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 the Component record. 

Monitoring Plan Reporting Instructions -- Page 56	 Environmental Protection Agency 
 

 

 

8.0 Monitoring System Data March 07, 2012September 19, 2012 

Fuel Code 

Element Name: FuelCode 

For Appendix D fuel flowmeter systems and Appendix E NOx systems, report the type of fuel 

measured by the system by using the appropriate uppercase codes as shown in Table 20. For 

all other systems, report the Fuel Code as "NFS" (Non Fuel-Specific). 

Table 20 

Monitoring System Fuel Codes and Descriptions
 

Code Description 

BFG Blast Furnace Gas 

BUT Butane 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) 

MIX Mixture of oil/gas fuel types (for 

NOXE system for co-fired curve 

only) 

NFS Non-Fuel-Specific for CEM 

(including H2O) and Opacity Systems 

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 Gas 

RFG Refinery Gas 

SRG Unrefined Sour Gas 

Environmental Protection Agency Monitoring Plan Reporting Instructions -- Page 57 
 

 

 

 

 

 

March 07, 2012September 19, 2012	 8.0 Monitoring System Data 

Begin Date 

Element Name: BeginDate 

Report the date on which the system became responsible for reporting emissions data. Under
 

most circumstances, this date should be the actual date when the system first reported
 

emissions data. However, if this is a primary monitoring system associated with the use of a
 

new methodology, this date should be the same as the BeginDate of the associated Monitor
 

Method record.
 

This date may be later than the dates of any initial certification tests performed on the system 

or related components.
 

Begin Hour 

Element Name: BeginHour 

Report the hour on which the system became responsible for reporting emissions data. 

End Date 

Element Name: EndDate 

Report the date the system was last used if a system is retired or permanently deactivated. Do 

not submit emissions data using this monitoring system ID after this date. This value should be 

left blank for active records. 

End Hour 

Element Name: EndHour 

If the system is retired or permanently deactivated, report the hour during which the system
 

was last used. Do not submit emissions data using this monitoring system ID after this time.
 

This value should be left blank for active records.
 

Specific Considerations 

Characteristics of Monitoring Systems 

●	 Monitoring systems are generally 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. 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, or 

mass oil flow). A monitoring system can include both hardware and software 

components. 

●	 CEM Systems must include the probe component in addition to the analyzer(s) and 

DAHS software. 

Monitoring Plan Reporting Instructions -- Page 58	 Environmental Protection Agency 
 

 

 

 

 

 

 

 

 

 

 

 

 

8.0 Monitoring System Data March 07, 2012September 19, 2012 

Types of Systems Which May Be Defined and Used 

●	 CO2 or O2 System. A CO2 monitoring system may be used to: (1) measure percent 

CO2 to determine CO2 mass emissions; or (2) determine hourly heat input rate (in 

conjunction with a flow monitoring system). O2 monitoring systems are only used for 

determining hourly heat input rate. A CO2 or O2 system is comprised of a CO2 or O2 

analyzer and a DAHS software component. When using Equation F-14A or F-14B to 

convert a measured O2 value to CO2 for purposes of determining hourly CO2 mass 

emissions, define a CO2 monitoring system containing an O2 component and DAHS 

software. A probe component must be added to the system when the sample 

acquisition method of the CO2 or O2 System is either dilution (DIL), dilution in-stack 

(DIN), dilution out-of-stack (DOU), dry extractive (EXT), or wet extractive (WXT). 

●	 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 SO2, CO2, 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 flow monitoring system. 

●	 Gas Fuel Flow System. This monitoring system measures gas flow rate in 100 standard 

cubic feet per hour. Gas flow rate is used to calculate SO2 and CO2 mass emissions 

and/or heat input rate. At a minimum, this system is comprised of a gas fuel flowmeter 

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, CO2 

mass emissions, or SO2 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 below. For units with saturated gas 

streams (e.g., following a wet scrubber, it is also possible to 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). 

●	 Long Term Gas or Oil Fuel Flow System. These monitoring systems are for low mass 

emissions (LME) units only. They measure fuel flow on a long term (non-hourly) 

basis, for the purpose of quantifying unit heat input. The systems are comprised of 

DAHS software components and, depending on the methodology selected, may also 

include Appendix D or billing fuel flowmeters or other relevant components. These 

systems are used in conjunction with default or unit-specific, fuel-specific emission 

rates to determine SO2, NOx, and CO2 mass emissions for LME units (see 

§75.19(c)(3)(ii)). 

Environmental Protection Agency	 Monitoring Plan Reporting Instructions -- Page 59 
 

 

 

 

 

 

 

 

 

 

 

 

 

March 07, 2012September 19, 2012	 8.0 Monitoring System Data 

●	 NOx-Diluent System. This monitoring system is used to determine NOx emission rate in 

lb/mmBtu. It is comprised of a NOx concentration monitor, a CO2 or O2 diluent 

monitor, and DAHS software. A probe component must be added to the system when 

the sample acquisition method of the NOx-Diluent System is either dilution (DIL), 

dilution in-stack (DIN), dilution out-of-stack (DOU), dry extractive (EXT), or wet 

extractive (WXT). 

●	 Appendix E NOx System (NOXE). 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. Each NOXE system represents a single correlation curve (either 

for a single fuel or for a consistent mixture of fuels) and is comprised of the DAHS 

software component. Appendix E systems are associated with a unit, not with multiple 

or common stacks. 

●	 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 emission rate (lb/hr). It is comprised of a NOx 

concentration monitor and DAHS software. 

●	 NOx Predictive Emissions Monitoring System. This type of monitoring system must be 

approved by petition under §75.66 and Subpart E of Part 75. It is used to determine 

NOx emission rate for a gas or oil-fired turbine or boiler and is comprised only of a 

DAHS software component (or components). 

●	 Volumetric Oil Fuel Flow System. This monitoring system measures hourly volumetric 

oil flow rate. Oil flow rate is used to calculate SO2 and CO2 mass emissions and/or 

heat input rate. At a minimum, it is comprised of an oil fuel flowmeter and DAHS 

software. 

●	 Mass Oil Fuel Flow System. This monitoring system measures hourly mass of oil 

combusted in pounds per hour. Oil flow rate is used to calculate SO2 or CO2 mass 

emissions and/or heat input rate. At a minimum, it is comprised of an oil fuel 

flowmeter and DAHS software. 

●	 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. 

●	 Particulate Matter Monitoring System. This monitoring system is used to continuously 

monitor particulate emissions. Affected units with a particulate monitoring system are 

exempt from opacity monitoring under Part 75. 

●	 SO2 Concentration System. This monitoring system is used to measure SO2 

concentration. It is used in conjunction with a flow monitoring system to determine 

hourly SO2 mass emission rates in lb/hr. The system consists of an SO2 concentration 

monitor and a DAHS software component. A probe component must be added to the 

system when the sample acquisition method of the SO2 Concentration System is either 

dilution (DIL), dilution in-stack (DIN), dilution out-of-stack (DOU), dry extractive 

(EXT), or wet extractive (WXT). 

Monitoring Plan Reporting Instructions -- Page 60	 Environmental Protection Agency 
 

 

 

 

 

 

 

 

 

 

 

8.0 Monitoring System Data March 07, 2012September 19, 2012 

OILM, OILV, and GAS Systems 

●	 If different types of oil or gas are burned in one unit, define a separate oil or gas system 

for each type of fuel combusted in the unit. 

●	 Each oil or gas system must include at least one fuel flowmeter hardware component. 

Each oil and gas system must also include a DAHS component to record and calculate 

fuel flow and heat input and to perform missing data substitutions. 

●	 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), all the flowmeters measuring that one fuel are considered separate 

components of the same system. 

Low Mass Emissions Units (LMEs) 

●	 For low mass emissions units reporting under §75.19, do not define monitoring 

systems, and do not report this record unless long term fuel flow monitoring systems 

are used to measure fuel flow and heat input. 

●	 For a group of oil or gas-fired LME units served by a common pipe (or supply tank), 

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, define a separate LTOL or LTGS system for each pipe or tank. If 

two or more pipes or tanks supply the same type of fuel to a group of LME units, define 

a single LTOL or LTGS system. 

MONITORING SYSTEM DATA UPDATES 

If changes must be made to key data fields and/or a system must be redefined after that system 

has been certified and used to report emissions, recertification testing may be required. If it is 

necessary to make such changes and it is unclear what testing or other requirements may be 

associated with that change, consult with EPA or the applicable state agency. 

Environmental Protection Agency	 Monitoring Plan Reporting Instructions -- Page 61 
 

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8.1 Monitoring System Fuel Flow Data March 07, 2012September 19, 2012 

8.1 MONITORING SYSTEM FUEL FLOW DATA 

Figure 16 

MONITORING SYSTEM FUEL FLOW DATA XML Elements
 

Description of Data 

The MONITORING SYSTEM FUEL FLOW DATA record provides the maximum fuel flow rate for the 

system for use in missing data substitution routines. Report one MONITORING SYSTEM FUEL 

FLOW DATA record for each GAS, OILV, OILM, LTOL, or LTGS system defined in 

MONITORING SYSTEM DATA. 

Dependencies for MONITORING SYSTEM FUEL FLOW DATA 

The MONITORING SYSTEM FUEL FLOW DATA record is dependent on the SYSTEM DATA record. 

No other records are dependent upon the MONITORING SYSTEM FUEL FLOW DATA record. 

MONITORING SYSTEM FUEL FLOW DATA Elements 

Instructions for completing each element of the MONITORING SYSTEM FUEL FLOW DATA section 

are provided below: 

Maximum Fuel Flow Rate 

Element Name: MaximumFuelFlowRate 

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. 

Environmental Protection Agency Monitoring Plan Reporting Instructions -- Page 63 
 

 

 

 

 

 

 

 

 

 

March 07, 2012September 19, 2012 8.1 Monitoring System Fuel Flow Data 

System Fuel Flow UOM Code 

Element Name: SystemFuelFlowUOMCode 

Report the units of measure for fuel flow rate provided by the system using the appropriate
 

uppercase codes as shown in Table 21:
 

Table 21 

Units of Measure for Maximum Fuel Flow Rate Codes and Descriptions
 

Parameter Code Description 

Volumetric Flow of Oil SCFH Standard cubic feet per hour 

GALHR Gallons per hour 

BBLHR Barrels per hour 

M3HR Cubic meters per hour 

Mass of Oil LBHR Pounds per hour 

Gas Flow HSCF 100 standard cubic feet per hour 

Maximum Fuel Flow Rate Source Code 

Element Name: MaximumFuelFlowRateSourceCode 

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. 

Begin Date 

Element Name: BeginDate 

Report the date on which the monitoring system fuel flow data became effective. This will 

usually be the same as the begin date for the monitoring system. If there was a change to the 

maximum fuel flow rate, in the record for the new information report the date that the change 

took place. 

Begin Hour 

Element Name: BeginHour 

Report the hour in which the monitoring system fuel flow data became effective. 

End Date 

Element Name: EndDate 

If applicable, report the last date on which the fuel flow record was in effect. This value should 

be left blank for active records. 

Monitoring Plan Reporting Instructions -- Page 64 Environmental Protection Agency 
 

 

 

8.1 Monitoring System Fuel Flow Data March 07, 2012September 19, 2012 

End Hour 

Element Name: EndHour 

If applicable, report the last hour in which the fuel flow record was in effect. This value should 

be left blank for active records.
 

Environmental Protection Agency Monitoring Plan Reporting Instructions -- Page 65 
 

March 07, 2012September 19, 2012 8.1 Monitoring System Fuel Flow Data 

[This page intentionally left blank.] 

Monitoring Plan Reporting Instructions -- Page 66 Environmental Protection Agency 
 

 

 

8.2 Monitoring System Component Data March 07, 2012September 19, 2012 

8.2 MONITORING SYSTEM COMPONENT DATA 

Figure 17 

MONITORING SYSTEM COMPONENT DATA XML Elements
 

Description of Data 

This record links individual monitoring components to each monitoring system in which they 

serve and defines the time frame for that relationship. Report a MONITORING SYSTEM 

COMPONENT DATA record for each system-component relationship. See the descriptions for each 

type of monitoring system in the instructions for the MONITORING SYSTEM DATA record for 

general information about what components to include in each system. 

Except for primary monitoring systems containing like-kind replacement ("LK") components, a 

system should not contain any active components that are not in service 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 SO2 system 101, 

consisting of a SO2 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 separate Data Backup (DB) SO2 monitoring system. 

Dependencies for MONITORING SYSTEM COMPONENT DATA 

The MONITORING SYSTEM COMPONENT DATA record is dependent on the MONITORING SYSTEM 

DATA record. 

No other records are dependent upon the MONITORING SYSTEM COMPONENT DATA record. 

Environmental Protection Agency Monitoring Plan Reporting Instructions -- Page 67 
 

 

 

 

 

 

 

 

March 07, 2012September 19, 2012 8.2 Monitoring System Component Data 

MONITORING SYSTEM COMPONENT DATA Elements 

Instructions for completing each element of the MONITORING SYSTEM COMPONENT DATA section 

are provided below: 

Component ID 

Element Name: ComponentID 

Report the three-character alphanumeric ID for the component. 

Begin Date 

Element Name: BeginDate 

Report the date on which the component became an active part of the system. If this component 

is an original part of the system, this date will be the same as the System Begin Date. 

Begin Hour 

Element Name: BeginHour 

Report the hour in which the component became an active part of the system. 

End Date 

Element Name: EndDate 

Report the last date that the component was an active part of the system. This value should be
 

left blank for active system-component relationships. 

End Hour 

Element Name: EndHour 

Report the last hour that the component was an active part of the system. This value should be
 

left blank for active system-component relationships. 

Monitoring Plan Reporting Instructions -- Page 68 Environmental Protection Agency 
 

 

 

 

 

 

 

 

9.0 Monitoring Formula Data March 07, 2012September 19, 2012 

9.0 MONITORING FORMULA DATA 

Figure 18 

MONITORING FORMULA DATA XML Elements
 

Description of Data 

The MONITORING FORMULA DATA record is used to identify the formulas that will be used to 

calculate required data from the monitoring systems defined in the MONITORING SYSTEM DATA 

record. It is not necessary to define formulas referencing backup monitoring systems unless the 

backup monitoring systems use different formulas than the primary system. 

MONITORING FORMULA DATA are used for three primary purposes: 

●	 To verify 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 verify hourly calculations in quarterly reports. 

Dependencies for MONITORING FORMULA DATA 

The MONITORING FORMULA DATA record is dependent on the UNIT DATA record or the STACK 

PIPE DATA record. 

No other records are dependent upon the MONITORING FORMULA DATA record. 

Environmental Protection Agency	 Monitoring Plan Reporting Instructions -- Page 69 
 

 

 

 

March 07, 2012September 19, 2012 9.0 Monitoring Formula Data 

MONITORING FORMULA DATA Elements 

Instructions for completing each element of the MONITORING FORMULA DATA section are 

provided below:
 

Formula ID 

Element Name: FormulaID 

Assign a unique three-character Formula ID for each formula defined at a unit, stack, or pipe. 

Assign unique formula IDs across all related units and stacks, if a facility includes a common 

stack, pipe header, or multiple stack. Do not reuse formula IDs if changing component types 

(e.g., from dry extractive to wet dilution systems) and therefore changing the type of formula in 

use. 

Parameter Code 

Element Name: ParameterCode 

Report the parameter representing the pollutant or parameter calculated by the formula by using 

the appropriate uppercase codes as shown in Table 22. 

Table 22 

Parameter Codes and Descriptions
 

for Monitoring Formula 

Code Description 

CO2 CO2 Hourly Mass Emission Rate 

(tons/hr) 

CO2C CO2 Concentration (%CO2) 

CO2M CO2 Daily Mass (tons) 

FC F-Factor Carbon-Based 

FD F-Factor Dry-Basis 

FGAS Gas Hourly Flow Rate (hscf) 

FLOW Net Stack Gas Volumetric Flow Rate 

FOIL Net Oil Flow Rate to Unit/Pipe 

FW F-Factor Wet-Basis 

H2O Moisture (%H2O) 

HI Heat Input Rate (mmBtu/hr) 

HIT Heat Input Total (mmBtu) 

NOX NOx Hourly Mass Emission Rate 

(lb/hr) 

(cont.) 

Monitoring Plan Reporting Instructions -- Page 70 Environmental Protection Agency 
 

 

 

 

 

9.0 Monitoring Formula Data March 07, 2012September 19, 2012 

Table 22
 

Parameter Codes and Descriptions
 

for Monitoring Formula (cont.)
 

Code Description 

NOXR NOx Emission Rate (lb/mmBtu) 

OILM Oil Mass Flow Rate (lb/hr) 

SO2 SO2 Hourly Mass Emission Rate (lb/hr) 

SO2R SO2 Emission Rate (lb/mmBtu) When 

Equation D-1h Is Used 

Formula Code 

Element Name: FormulaCode 

Report the formula code of the formula that appears in the tables below 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. EPA relies on the accuracy 

of the formula code to verify hourly emissions calculations. Tables 23 through 34 provide 

summaries of the primary formulas used to calculate SO2, NOx emissions, and CO2; moisture and 

heat input rate using CEMS; and fuel flowmeter methodologies. For moisture monitoring 

systems comprised of wet and dry oxygen analyzers, see Table 28, Equations F-31 and M-1K. 

For net fuel flow and average stack flow formulas, see Table 35. All formula codes must be 

entered exactly as they are presented in Tables 23 through 34. This includes the use of dashes 

and capital letters. 

For example, report "F-1" (from Table 25) if using the equation for converting measurements of 

SO2 concentration and flow rate on a wet basis to SO2 in lb/hr. Report "F-5" (from Table 27) if 

using the equation from Method 19, Appendix A, 40 CFR Part 60 for converting measurements 

of NOx concentration and O2 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. 

For custom or non-standard intermediate equations that are not listed in Tables 23 – 34 below, 

leave the Formula Code blank. 

Environmental Protection Agency Monitoring Plan Reporting Instructions -- Page 71 
 

 

March 07, 2012September 19, 2012 9.0 Monitoring Formula Data 

Table 23 

F-Factor* Reference Table
 

Option 1: Fuel-Based Constants 

Fuel 

F-Factor 

(dscf/ 

mmBtu) 

Fc -Factor 

(scf CO2/ 

mmBtu) 

Fw-Factor 

(wscf/mmBtu) 

Coal Anthracite 10,100 1,970 10,540 

Bituminous 9,780 1,800 10,640 

Sub-bituminous 9,820 1,840 -----­

Lignite 9,860 1,910 11,950 

Petroleum Coke 9,830 1,850 -----­

Tire-Derived Fuel 10,260 1,800 -----­

Gas Natural Gas 8,710 1,040 10,610 

Propane 8,710 1,190 10,200 

Butane 8,710 1,250 10,390 

Oil Oil 9,190 1,420 10,320 

Waste Municipal Solid Waste 9,570 1,820 -----­

Wood Bark 9,600 1,920 -----­

Wood Residue 9,240 1,830 -----­

(cont.) 

Monitoring Plan Reporting Instructions -- Page 72 Environmental Protection Agency 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

9.0 Monitoring Formula Data	 March 07, 2012September 19, 2012 

Table 23
 

F-Factor* Reference Table (cont.)
 

Option 2: Calculated F-Factors 

Code 

Parameter Formula Where: 

F-7A FD x 10

GCV 

3.64(%H)+1.53(%C)+0.57(%S)+0.14(%N) 0.46(%O) - F = 6 F = Dry-basis F-factor 

(dscf/mmBtu) 

Fc = Carbon-based F-factor (scf 

CO2/mmBtu) 

Fw = Wet-basis F-factor 

(wscf/mmBtu) 

%H,%N, = Content of element, percent 

%S, %C, by weight, as determined 

%O,%H2O on the same 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 

F-7B FC 

GCV 

321 x 10 x (%C) F =

3 

c 

19-14 FW 

x 10 

GCV 

5.57(%H)+1.53(%C)+0.57(%S)+0.14(%N)- 0.46(%O)+0.21(% H O) F = 6 

w 

2 

w 

(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-8** FD, 

FC, or 

FW 

F = X Fii 

n 

i=1 

∑

F = Dry-basis F-factor 

(dscf/mmBtu) 

Fc = Carbon-based F-factor (scf 

CO2/mmBtu) 

n = Number of fuels being 

combusted 

Fi,(Fc)i, = Applicable F, Fc, or Fw 

(Fw)i factor for each fuel type 

Xi = Fraction of total heat input 

derived from each type of 

fossil fuel 

F = X ( F ) ci i

n 

i=1 

c ∑

F = X ( F ) wi i

n 

i=1 

w ∑

*	 F-factor is the ratio of the gas volume of all the products of combustion (less water) to the heat content of the 

fuel. Fc-factor is the ratio of the gas volume of the CO2 generated to the heat content of the fuel (see Part 75, 

Appendix F, Section 3.3). Fw-factor is the ratio of the quantity of wet effluent gas generated by the combustion 

to the heat content of the fuel including free water in the fuel. 

** 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. 

Environmental Protection Agency	 Monitoring Plan Reporting Instructions -- Page 73 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

March 07, 2012September 19, 2012 9.0 Monitoring Formula Data 

Table 24 

SO2 Formula References
 

Usage Moisture Basis* 

Appropriate Hourly Formulas (Part 

75, Appendices D&F) 

SO2 CEMS WET F-1 

DRY F-2 

Default SO2 emission rate when low 

sulfur fuels are burned (e.g., natural 

gas) 

F-23 (and D-1H) 

Oil Fuel Flowmeter D-2 

Gas Fuel Flowmeter D-4 or D-5 (and D-1H) 

Overall values for multiple fuel 

flowmeter systems 

D-12 

* For sample acquisition method (SAM) codes IS, ISP, ISC, DIN, DOU, DIL, and WXT = wet extractive; 

for EXT = dry extractive, located under component. Exceptions are possible. Check with vendor if 

uncertain. 

Table 25 

SO2 Emission Formulas
 

Code Parameters Formula Where: 

F-1 SO2 E h = K x Ch x QhEh 

K 

Chp 

Ch 

Qh and 

Qhs 

%H2O 

= 

= 

= 

= 

= 

= 

Hourly SO2 mass emission rate (lb/hr) 

1.660 x 10-7 for SO2 ((lb/scf)/ppm) 

Hourly average SO2 concentration (ppm 

(dry)) 

Hourly average SO2 concentration (ppm 

(stack moisture basis)) 

Hourly average volumetric flow rate 

(scfh (stack moisture basis)) 

Hourly average stack moisture content 

(percent by volume) 

F-2 SO2 

100 

100 ­% H O

E = K x C Q xx 

2 

h hp hs

D-1H SO2R 

GCV 

S 10 xx 

7000 

2.0 ER = 6 total 

ER 

Stotal 

GCV 

= 

= 

= 

Default SO2 emission rate for natural 

gas (or "other" gaseous fuel) 

combustion (lb/mmBtu) 

Total sulfur content of gaseous fuel 

(grains/100 scf) 

Gross calorific value of the gas 

(Btu/100 scf) 

2.0 

7000 

106 

= 

= 

= 

Ratio of lb SO2/lb S 

Conversion of grains/100 scf to lb/ 

100 scf 

Conversion of Btu to mmBtu 

(cont.) 

Monitoring Plan Reporting Instructions -- Page 74 Environmental Protection Agency 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

9.0 Monitoring Formula Data March 07, 2012September 19, 2012 

Table 25
 

SO2 Emission Formulas (cont.)
 

Code Parameters Formula Where: 

D-2 SO2 

100.0 

% S SO 2 = 2.0 x OIL x oil 

rate-oil rate 

SO2rate-oil 

OILrate 

%Soil 

2.0 

= 

= 

= 

= 

Hourly mass emission rate of SO2 

emitted from combustion of oil (lb/hr) 

Mass rate of oil consumed per hour 

during combustion (lb/hr) 

Percent sulfur by weight measured in 

oil sample 

Ratio of lb SO2 to lb S 

D-4 SO2 

2 rate =SO x GAS rate x S gas (2.0 / 7000) 

SO2rate 

GASrate 

Sgas 

2.0 

7000 

= 

= 

= 

= 

= 

Hourly mass rate of SO2 from 

combustion of gaseous fuel (lb/hr) 

Hourly metered flow rate of gaseous 

fuel combusted (100 scf/hr) 

Sulfur content of gaseous fuel 

(grains/100 scf) 

Ratio of lb SO2/lb S 

Conversion of grains/100 scf to lb/ 

100 scf 

D-5 SO2 

SO 2 rate = ER x HI rate 

SO2rate 

ER 

HIrate 

= 

= 

= 

Hourly mass emission rate of SO2 from 

combustion of gaseous fuel (lb/hr) 

SO2 emission rate from Appendix D, 

Section 2.3.1.1 or Appendix D, Section 

2.3.2.1.1 to Part 75 (lb/mmBtu) 

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 SO2 

Eh = ER x HI

Eh 

ER 

HI 

= 

= 

= 

Hourly SO2 mass emission rate (lb/hr) 

Applicable SO2 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) 

Hourly heat input rate, determined 

using a certified flow monitor and 

diluent monitor, according to Appendix 

F, Section 5.2 (mmBtu/hr) 

D-12* SO2 

u 

rate-i i

all- fuels 

rate 

t 

tSO 

2 =SO 

∑ 2

SO2rate 

SO2rate-i 

ti 

tu 

= 

= 

= 

= 

Hourly mass emission rate of SO2 from 

combustion of all fuels (lb/hr) 

SO2 mass emission rate for each type of 

gas or oil fuel combusted during the 

hour (lb/hr) 

Time each gas or oil fuel was 

combusted for the hour (fraction of an 

hour) 

Operating time of the unit 

* This equation is a modified form of Equation D-12 as described in Appendix D, Section 3.5.1, and must be used 

when reporting in the XML format. 

Environmental Protection Agency Monitoring Plan Reporting Instructions -- Page 75 
 

March 07, 2012September 19, 2012 9.0 Monitoring Formula Data 

Table 26 

NOx Emission Rate Formula Reference Table
 

Usage 

Moisture Basis Appropriate Hourly 

NOx CO2 O2 Formulas 

NOx CEMS (CO2 Diluent) DRY DRY 19-6 

DRY WET 19-9 

WET DRY 19-8 

WET WET 19-7 or F-6 

NOx CEMS (O2 Diluent) DRY DRY 19-1 or F-5 

DRY WET 19-5 or 19-5D 

WET DRY 19-4 

WET WET 19-2, 19-3, or 19-3D 

Overall Value from Multiple 

Appendix E Systems 

E-2 

Monitoring Plan Reporting Instructions -- Page 76 Environmental Protection Agency 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

9.0 Monitoring Formula Data March 07, 2012September 19, 2012 

Table 27 

NOx Emission Rate Formulas (lb/mmBtu)
 

Code Parameter Formula Where: 

19-1 

(F-5) 

NOXR 

20.9 ­% O

20.9 E = K x C F xx 

2 

d d

d 

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) 

Cw = (Pollutant concentration ppm, wet 

basis) 

Fd = Dry-basis F-factor (dscf/mmBtu) 

Fc = Carbon-based F-factor (scf 

CO2/mmBtu) 

Fw = Wet-basis F-factor (wscf/mmBtu) 

Bwa = Moisture fraction of ambient air 

(default value 0.027) 

%H2O = Moisture content of effluent gas 

O2d = Oxygen diluent concentration 

(percent of effluent gas, dry basis) 

O2w = Oxygen diluent concentration 

(percent of effluent gas, wet basis) 

O2def = Default diluent cap O2 value (14.0 

percent for boilers, 19.0 percent 

for combustion turbines) 

CO2d = Carbon dioxide diluent 

concentration (percent of effluent 

gas, dry basis) 

CO2w = Carbon dioxide diluent 

concentration (percent of effluent 

gas, wet basis) 

Ef = NOx emission rate for the unit for 

a given fuel at heat input rate HIf, 

lb/mmBtu 

HIf = Heat input rate for the hour for a 

given fuel, during the fuel usage 

time, as determined using 

Equation F-19 or F-20 in Section 

5.5 of Appendix F to this part, 

mmBtu/hr 

HT = Total heat input for all fuels for 

the hour from Equation E-1 

tf = Fuel usage time for each fuel 

(rounded to the nearest fraction of 

an hour (in equal increments that 

can range from one hundredth to 

one quarter of an hour, at the 

option of the owner or operator)) 

19-2 NOXR 

20.9 (1 B -)- % O

20.9 E = K x C F xx wa 2

w w

w 

19-3* NOXR 

-% O 100 

% H O-100 20.9 x 

20.9 E = K x C F xx 

2 

2 

w d

 w



 





19­3D* NOXR 





 



 



 





100 

100 -% H O 

O x-% 

100 

100 -% H O 20.9 x 

20.9 E = K x C F xx 2 

2 

2 

w d

def 

19-4* NOXR 

(20.9 ­ O )% 

20.9 

x

(100 ­% H O) 100

C x F )( = K xE 

2 2

w d

d ÷

19-5* NOXR 





 



 



 



 ÷

100 

100 ­% H O 20.9 ­ % O

20.9 x K x C x F E = 

2 

2 

d d

w 

19-5D NOXR 

20.9 ­% O

20.9 E = K x C F xx 

2 

d d

def 

19-6 NOXR 

% CO 

100 E = K x C F xx 

2 

d c

d 

19-7 

(F-6) 

NOXR 

% CO 

100 E = K x C F xx 

2 

w c

w 

19-8* NOXR 

% CO 

100 

x

(100 ­% H O) 100

C x F )( E = K x 

2 2

w c

d ÷

19-9* NOXR 

% CO 

100 

F xx 

100 

100 ­% H O E C x= K x 

2 

c 

2 

d 

w 





 





E-2 NOXR 

H 

( E x HI t )

E = T 

ff f

all fuels 

f =1 

h 

∑

* 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. 

Environmental Protection Agency Monitoring Plan Reporting Instructions -- Page 77 
 

 

 

 

 

 

March 07, 2012September 19, 2012 9.0 Monitoring Formula Data 

Table 28 

Moisture Formulas*
 

Code Parameter Formula Where: 

F-31 H2O 

x 100 

O 

O -( O ) H O =% 

2 

22 

2 

d 

d w

%H2O = 

O2d = 

O2w = 

Percent moisture 

Oxygen diluent concentration 

(percent of effluent gas, dry 

basis) 

Oxygen diluent concentration 

(percent of effluent gas, wet 

basis) 

M-1K H2O ( ) %H O 

O O 

O 

d w 

d 

2 

2 2 

2 

= 100 − ×

, as adjusted1 

* 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 29 

CO2 Formula Reference Table
 

Usage Moisture Basis 

Appropriate Formulas 

(Part 75, Appendices F, G) 

CO2 CEMS 

(O2 Analyzer) 

WET F-14B and F-11 

DRY F-14A and F-2 

CO2 CEM 

(CO2 Analyzer) 

WET F-11 

DRY F-2 

Fuel Sampling G-1 (and possibly G-2, G-3, G-5, G-6 and 

G-8) 

Gas or Oil Flowmeter G-4 

Overall Value from Multiple 

Flowmeter Systems 

G-4A 

Monitoring Plan Reporting Instructions -- Page 78 Environmental Protection Agency 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

9.0 Monitoring Formula Data March 07, 2012September 19, 2012 

Table 30 

CO2 Concentration and Mass Emission Rate Formulas
 

Code Parameter Formula Where: 

F-2 CO2 

E K C Q 

H O 

h hp hs = × × ×

100 −

100 

% 2

Eh = 

K = 

Chp = 

Qhs = 

%H2O = 

Hourly CO2 mass emissions (tons/hr) 

5.7 x 10-7 for CO2 

((tons/scf)/percent CO2) 

Hourly average, CO2 concentration 

(percent CO2, dry basis) 

Hourly average volumetric flow rate 

(scfh, wet basis) 

Hourly average stack moisture 

content (percent by volume) 

F-11 CO2 

E K C Q h h h = × ×

Eh = 

K = 

Ch = 

Qh = 

Hourly CO2 mass emission rate 

(tons/hr) 

5.7x10-7 for CO2 

((tons/scf)/percent CO2) 

Hourly average CO2 concentration 

(percent CO2, wet basis) 

Hourly average volumetric flow rate 

(scfh, wet basis) 

F-14A CO2C 

CO 

F 

F 

O 

d 

c d 

2 

2 100 

20 9 

20 9 = × × . −

. 

CO2d = 

F = 

Fc = 

20.9 = 

O2d = 

Hourly average CO2 concentration 

(percent by volume, dry basis) 

Dry-basis F-factor (dscf/mmBtu) 

Carbon-based F-factor 

(scf CO2/mmBtu) 

Percentage of O2 in ambient air 

Hourly average O2 concentration 

(percent by volume, dry basis) 

F-14B CO2C 

CO 

F 

F 

H O 

w O c 2 W

2 

2 

100 

20 9 

20 9 

100 

100 = × ×  −



 



 − 



 



 . . % 

CO2w = 

F = 

Fc = 

20.9 = 

O2W = 

%H2O = 

Hourly average CO2 concentration 

(percent by volume, wet basis) 

Dry-basis F-factor (dscf/mmBtu) 

Carbon-based F-factor 

(scf CO2/mmBtu) 

Percentage of O2 in ambient air 

Hourly average O2 concentration 

(percent by volume, wet basis) 

Moisture content of gas in the stack 

(percent) 

G-1 CO2M 

( ) W 

MW MW W 

MW CO 

c O c 

c 2 

2 

2000 = + ×

WCO2 = 

MWc = 

MWO2 = 

Wc = 

CO2 emitted from combustion 

(tons/day) 

Molecular weight of carbon (12.0) 

Molecular weight of oxygen (32.0) 

Carbon burned (lb/day) determined 

using fuel sampling and analysis and 

fuel feed rates* 

(cont.) 

Environmental Protection Agency Monitoring Plan Reporting Instructions -- Page 79 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

March 07, 2012September 19, 2012 9.0 Monitoring Formula Data 

Table 30
 

CO2 Concentration and Mass Emission Rate Formulas (cont.)
 

Code Parameter Formula Where: 

G-2 CO2M 

W W 

MW 

MW 

A C 

NCO CO W CO 

c 

2 2 COAL 

2 

100 100 = − × 



 



 × 



 



 × % % 

WNCO2 

WCO2 

MWCO2 

MWc 

= Net CO2 mass emissions discharged 

to the atmosphere (tons/day) 

= Daily CO2 mass emissions calculated 

by Equation G-1 (tons/day) 

= Molecular weight of carbon dioxide 

(44.0) 

= Molecular weight of carbon (12.0) 

A% 

C% 

WCOAL 

= Ash content of the coal sample 

(percent by weight) 

= Carbon content of ash (percent by 

weight) 

= Feed rate of coal from company 

records (tons/day) 

G-3 CO2M 

W W NCO 2 = 99 × CO2 . 

WNCO2 

.99 

WCO2 

= Net CO2 mass emissions from the 

combustion of coal discharged to the 

atmosphere (tons/day) 

= Average fraction of coal converted 

into CO2 upon combustion 

= Daily CO2 mass emissions from the 

combustion of coal calculated by 

Equation G-1 (tons/day) 

G-4 CO2 

W 

F H U MW 

CO 

c f CO 

2 

2 

2000 = × × ×

WCO2 

Fc 

= CO2 emitted from combustion 

(tons/hr) 

= 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 

Uf 

MWCO2 

= Hourly heat input rate (mmBtu/hr) 

= 1/385 scf CO2/lb-mole at 14.7 psi and 

68ΕF 

= Molecular weight of carbon dioxide 

(44.0) 

G-4A CO2 

CO 

CO t 

t unit 

fuel fuel 

all fuels 

unit 

2 

2 

= −

∑

CO2unit 

CO2fuel 

tfuel 

tunit 

= Unit CO2 mass emission rate 

(tons/hr) 

= CO2 mass emission rate calculated 

using Equation G-4 for a single fuel 

(tons/hr) 

= Fuel usage time 

= Unit operating time 

(cont.) 

Monitoring Plan Reporting Instructions -- Page 80 Environmental Protection Agency 
 

 

 

 

 

 

 

 

 

 

 

9.0 Monitoring Formula Data March 07, 2012September 19, 2012 

Table 30
 

CO2 Concentration and Mass Emission Rate Formulas (cont.)
 

Code Parameter Formula Where: 

G-5 CO2M 

SE W F 

MW 

MW CO CaCO u 

CO 

CaCO 2 3 

2 

3 

= × ×

SECO2 = CO2 emitted from sorbent (tons/day) 

WCaCO3 = Calcium carbonate used (tons/day) 

Fu = 1.00, the calcium to sulfur 

stoichiometric ratio 

MWCO2 = Molecular weight of carbon dioxide 

(44.0) 

MWCaCO3 = Molecular weight of calcium 

carbonate (100.0) 

G-6 CO2M 

SE F 

W MW 

MW CO u 

SO CO 

SO 2 

2 

2 2000 

2 =

SECO2 = CO2 emitted from sorbent (tons/day) 

MWCO2 = Molecular weight of carbon dioxide 

(44.0) 

MWSO2 = Molecular weight of sulfur dioxide 

(64.0) 

WSO2 = Sulfur dioxide removed (lb/day) 

based on applicable procedures, 

methods, and equations in § 75.15 

Fu = 1.00, the calcium to sulfur 

stoichiometric ratio 

G-8 CO2M 

CO2 CO2 t += SEWW 

Wt = Estimated total CO2 mass emissions 

(tons/day) 

WCO2 = CO2 emitted from fuel combustion 

(tons/day) 

SECO2 = CO2 emitted from sorbent (tons/day) 

* See Appendix G, sections 2.1.1 through 2.1.3 

** For a unit linked to a common pipe with one additional fuel flowmeter system defined at the unit, report a G-4A 

formula to calculate the unit hourly CO2 rate, even though there is only a single fuel flowmeter defined at the unit. 

Because the fuel usage time may not be equal to the unit operating time, the hourly CO2 rate for the fuel may be 

different from the hourly CO2 rate for the unit. Use formula G-4A to calculate the unit hourly CO2 rate. 

Table 31 

Heat Input Formula Reference Table
 

Usage Moisture Basis* 

Appropriate Hourly Formulas (Part 

75, Appendices D and F) 

CEMS (O2 Analyzer) WET F-17 

DRY F-18 

CEMS (CO2 Analyzer) WET F-15 

DRY F-16 

Gas Fuel Flowmeter System D-6 (F-20) 

(cont.) 

Environmental Protection Agency Monitoring Plan Reporting Instructions -- Page 81 
 

 

 

 

March 07, 2012September 19, 2012 9.0 Monitoring Formula Data 

Table 31
 

Heat Input Formula Reference Table (cont.)
 

Usage Moisture Basis* 

Appropriate Hourly Formulas (Part 

75, Appendices D and F) 

Oil Fuel Flowmeter System 

(Mass) 

D-8 (F-19) 

Oil Fuel Flowmeter System 

(Volumetric) 

D-3 and D-8 (F-19) or F-19V 

Overall Value from Multiple Fuel 

Flowmeter Systems 

D-15A 

Apportioned Value from Common 

Stack or Common Pipe 

F-21A, F-21B, or F-21 

Summed Value from Multiple 

Stacks 

F-21C 

Summed Value from Unit F-25 

* For sample acquisition method (SAM) codes IS, ISP, ISC, DIN, DOU, DIL, and WXT = wet extractive; for 

EXT = dry extractive, locate under the component. Exceptions are possible. Check with vendor if 

uncertain. 

Monitoring Plan Reporting Instructions -- Page 82 Environmental Protection Agency 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

9.0 Monitoring Formula Data March 07, 2012September 19, 2012 

Table 32 

Heat Input Formulas
 

Code Parameter Formula Where: 

D-15A HI 

HI t

HI =

rate-i i

all- fuels 

rate-hr 

∑

HIrate-hr = 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) 

tu ti = Time each gas or oil fuel was 

combusted for the hour (fuel 

usage time) (fraction of an 

hour) 

tu = Operating time of the unit 

F-15 HI 

100 

% CO

x 

F 

1 HI = Q x 2w 

c 

w 

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) 

%CO2w = Hourly concentration of CO2 

(percent CO2, wet basis) 

%CO2d = Hourly concentration of CO2 

(percent CO2 , dry basis) 

%O2w = Hourly concentration of O2 

(percent O2, wet basis) 

%O2d = Hourly concentration of O2 

(percent O2, dry basis) 

%H2O = Hourly average moisture of gas 

in the stack (percent) 

F-16 HI 





 









 





100 

% CO 

100 F 

100 ­% H O HI = Q x 2d 

c 

2 

h 

F-17 HI 

20.9 

[(20.9/100)(100 ­ H O)-% O ]% 

x

F 

1 HI = Q x 2 2w

W 

F-18 HI 





 









 





20.9 

(20.9 ­ O )% 

100F 

(100 ­% H O) HI = Q x

2 2d

w 

D-3 OILM 

OIL rate =V -rate oil x Doil 

OILrate = Mass rate of oil consumed per hr 

(lb/hr) 

Voil-rate = Volume rate of oil consumed 

per hr, measured (scf/hr, gal/hr, 

barrels/hr, or m3/hr) 

Doil = Density of oil, measured 

(lb/scf, lb/gal, lb/barrel, or 

lb/m3) 

D-8** HI HIrate-oil = Hourly heat input rate from 

(F-19V) combustion of oil (mmBtu/hr) 

OILrate = Rate of oil consumed (lb/hr for 

10 

GCV HI = OIL x 6 

oil 

rate-oil rate 

Equation D-8 or gal/hr for 

Equation F-19V) 

GCVoil = Gross calorific value of oil 

(Btu/lb for Equation D-8 or 

Btu/gal for Equation F-19V) 

106 = Conversion of Btu to mmBtu 

(cont.) 

Environmental Protection Agency Monitoring Plan Reporting Instructions -- Page 83 
 

 

 

 

 

 

 

 

 

 

 

March 07, 2012September 19, 2012 9.0 Monitoring Formula Data 

Table 32
 

Heat Input Formulas (cont.)
 

Code Parameter Formula Where: 

F-19 HI 

10 

GCV HI M x= 6 

o 

oo 

HIo = 

Mo = 

GCVo = 

106 = 

Hourly heat input rate from 

combustion of oil (mmBtu/hr) 

Mass rate of oil consumed per 

hour (lb/hr) 

Gross calorific value of oil 

(Btu/lb) 

Conversion of Btu to mmBtu 

D-6 HI 

10 

GAS x GCV 

HI = 6 

rate gas

rate­gas

HIrate-gas,= 

HIg 

GASrate,= 

Qg 

GCVgas,= 

GCVg 

106 = 

Hourly heat input rate from 

combustion of gaseous fuel 

(mmBtu/hr) 

Average volumetric flow 

rate of fuel (100 scfh) 

Gross calorific value of 

gaseous fuel (Btu/100 scf) 

Conversion of Btu to mmBtu 

F-20 HI 

10 

( Q GCV )x 

HI = 6 

g g

g 

** For units required to monitor NOx mass emissions but not SO2 mass emissions, if there is a volumetric oil 

flowmeter, it is possible to use Equation D-8 on a volumetric basis, rather than a mass basis. If using this option, 

represent the Equation as F-19V in the monitoring plan. 

Monitoring Plan Reporting Instructions -- Page 84 Environmental Protection Agency 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

9.0 Monitoring Formula Data March 07, 2012September 19, 2012 

Table 33 

Apportionment and Summation Formulas
 

Code Parameter Formula Where: 

F-21A HI 











 

















 







∑ tMW 

MW t 

t 

t

= HIHI 

ii 

n 

i=1 

ii 

i 

CS 

i CS

HIi 

HICS 

MWi 

ti 

tCS 

n 

i 

= 

= 

= 

= 

= 

= 

= 

Heat input rate for a unit 

(mmBtu/hr) 

Heat input rate at the common 

stack or pipe (mmBtu/hr) 

Gross electrical output (MWe) 

Operating time at a particular 

unit 

Operating time at common 

stack or pipe 

Total number of units using the 

common stack or pipe 

Designation of a particular unit 

F-21B HI 











 

















 







∑SF t 

SF t 

t 

t

= HIHI 

ii 

n 

i=1 

ii 

i 

CS 

i CS

HIi 

HICS 

n 

SFi 

ti 

tCS 

= 

= 

= 

= 

= 

= 

Heat input rate for a unit 

(mmBtu/hr) 

Heat input rate at the common 

stack or pipe (mmBtu/hr) 

Number of stacks or pipes 

Gross steam load (flow) (lb/hr) 

Operating time at a particular 

unit 

Operating time at common 

stack or pipe 

n 

i 

= 

= 

Total number of units using the 

common stack or pipe 

Designation of a particular unit 

F-21C HI 

t 

HI t

HI =

Unit 

s s

n 

s=1 

Unit 

∑

HIUnit 

HIs 

tUnit 

ts 

s 

n 

= 

= 

= 

= 

= 

= 

Heat input rate for a unit 

(mmBtu/hr) 

Heat input rate for each stack 

or duct (mmBtu/hr) 

Operating time for the unit 

Operating time for a particular 

stack or duct 

Designation of a particular 

stack or duct 

Total number stacks, ducts 

(cont.) 

Environmental Protection Agency Monitoring Plan Reporting Instructions -- Page 85 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

March 07, 2012September 19, 2012 9.0 Monitoring Formula Data 

Table 33
 

Apportionment and Summation Formulas (cont.)
 

Code Parameter Formula Where: 

F-21D HI 











 

















 







∑FF t 

FF t 

t 

t

= HIHI 

i i

n 

i=1 

i i

i 

CP 

i CP

HIi 

HICP 

FFi 

ti 

tCP 

= 

= 

= 

= 

= 

Heat input rate for a unit 

(mmBtu/hr) 

Heat input rate at the common 

pipe (mmBtu/hr) 

Fuel flow rate to a particular 

unit (appropriate units) 

Operating time at a particular 

unit (hr) 

Operating time at common pipe 

(hr) 

n 

i 

= 

= 

Total number of units using the 

common pipe 

Designation of a particular unit 

F-25 HI 

HI t

HI =

u u

p 

u=1 

CS

∑

HICS 

HIu 

p 

tu 

= 

= 

= 

= 

Hourly average heat input rate 

at the common stack 

(mmBtu/hr) 

Hourly average heat input rate 

for a unit (mmBtu/hr) 

Number of units 

Operating time at a particular 

tCS 

tCS 

u 

= 

= 

unit 

Operating time at common 

stack 

Designation of a particular unit 

Table 34 

NOx Mass Emissions Formulas (lbs/hr)
 

Code Parameter Formula Where: 

F-24A NOX 

E ( NOx)h = ER(NOx)h x HI h

E(NOx)h = 

K = 

Chd = 

Chw = 

Qh = 

%H2O = 

HIh = 

ER(NOx)h = 

Hourly NOx mass emissions 

rate in lb/hr 

1.194 x 10-7 for NOx 

((lb/scf)/ppm) 

Hourly average, NOx 

concentration (ppm (dry)) 

Hourly average, NOx 

concentration, stack moisture 

basis (ppm (wet)) 

Hourly average volumetric 

flow rate (scfh) 

Hourly average stack moisture 

content (percent by volume) 

Hourly average heat input rate 

(mmBtu/hr) 

Hourly average NOx emission 

rate (lb/mmBtu) 

F-26A NOX 

NOx )( h ××= QCKE hhw

F-26B NOX 

100 

(100 ­% H O) E = K x C Q xx 

2 

NOx )( h hd h

Monitoring Plan Reporting Instructions -- Page 86 Environmental Protection Agency 
 

 

 

 

 

 

 

 

 

 

9.0 Monitoring Formula Data	 March 07, 2012September 19, 2012 

Table 35 

Miscellaneous Formula Codes
 

Code Parameter Description 

N-GAS FGAS Net or total gas fuel flow rate (100 scfh) 

N-OIL FOIL Net or total oil fuel flow rate (scf/hr, gal/hr, barrels/hr, m3/hr, or lb/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) 

T-FL FLOW Total stack flow rate (scfh) 

SS-1A SO2 Total hourly SO2 mass emissions from the affected unit(s) in a subtractive 

stack configuration (lb/hr) 

SS-1B SO2 Hourly SO2 mass emissions from a particular affected unit in a subtractive 

stack configuration (lb/hr) 

SS-2A NOX Total hourly NOx mass emissions from the affected unit(s) in a 

subtractive stack configuration (lb/hr) 

SS-2B NOX Hourly NOx mass emissions from a particular affected unit in a 

subtractive stack configuration (lb/hr). (Apportioned by gross load) 

SS-2C NOX Hourly NOx mass emissions from a particular affected unit in a 

subtractive stack configuration (lb/hr). (Apportioned by steam load) 

SS-3A HIT 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 NOXR Hourly NOx apportionment for NOx affected units in a subtractive stack 

configuration (lb/mmBtu) 

NS-2 NOXR Hourly NOx apportionment for NOx affected units using simple NOx 

apportionment (lb/mmBtu) 

Formula Text 

Element Name: FormulaText 

When using a standard formula from Tables 23 through 34, above, leave the Formula Text field 

blank. The Formula Text element is required only when a non-standard or custom equation is 

used, i.e., either: (1) one of the equations in Table 35; or (2) another site-specific equation not 

listed in Table 37. Use the following guidelines to construct formula text: 

●	 Variables. In non-standard and custom equations, use recognizable symbols in 

conjunction with the operators and other representations shown in Table 38. To the 

extent possible, use symbols and nomenclature consistent with Tables 23 – 34. Use 

parentheses and square brackets as needed, for added clarity. 

●	 Formula References. Wherever another formula in the monitoring plan is part of a nonstandard or custom equation, you may refer to the other formulas as "F#(XYZ)" where 

Environmental Protection Agency	 Monitoring Plan Reporting Instructions -- Page 87 
 

 

 

 

 

March 07, 2012September 19, 2012	 9.0 Monitoring Formula Data 

XYZ is the Formula ID, rather than rewriting the entire text of the formula in the nonstandard or custom equation. 

●	 Constants. Appropriate constants must also be included in each non-standard or custom 

equation, such as unit conversion factors, fuel factors, etc., that are required for the 

calculation. 

Table 36 

Representations for Electronic Reporting of Formulas
 

Operation 

Recommended 

Representation Example 

Addition + MW_1 + MW_2 

Subtraction - (100 - %H2O) 

Multiplication * Cd * Fd 

Division / %CO2/100 

Exponential Power ** 1.66 x 10-7 = 1.66 * 10 ** -7 

Subscript Underscore MW1 = MW_1 

Fraction of Heat Input from Fuel X_<fuel> X_oil 

Gross Electrical Output MW_<unit> MW_1 

Gross Steam Load (Flow) SF_<unit> SF_1 

Hourly Emissions E_h E_h 

Operating Time T_<unit/stack> T_CS1 

Begin Date 

Element Name: BeginDate 

Report the date on which the formula was first applied to calculate the data. This date should 

correspond to the earliest date of the Begin Dates for the systems used in the calculation. 

Begin Hour 

Element Name: BeginHour 

Report the hour in which the formula was first applied to calculate the data. 

End Date 

Element Name: EndDate 

For formulas that are discontinued due to a change in monitoring, report the last date on which 

the formula was used to calculate the data. This value should be left blank for active records. 

Monitoring Plan Reporting Instructions -- Page 88	 Environmental Protection Agency 
 

 

 

 

 

 

 

 

 

9.0 Monitoring Formula Data March 07, 2012September 19, 2012 

End Hour 

Element Name: EndHour 

Report the last hour in which the formula was used to calculate the data. This value should be
 

left blank for active records. 

Specific Considerations 

Required Formulas 

●	 Depending on the monitoring methodologies and component types in use, include in the 

monitoring plan one or more of the following formulas: 

●	 For CEMS Based Methodologies 

-- SO2 mass emission rate 

-- NOx emission rate 

-- NOx mass emission rate 

-- CO2 concentration 

-- CO2 mass emission rate 

-- 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 O2 wet and dry readings 

-- Flow formulas for all flow systems containing two flow monitors 

●	 For Fuel Flow Based Methodologies 

-- SO2 mass emission rate (ARP) 

-- CO2 mass emission rate (ARP) 

-- NOx emission rate for the unit where separate Appendix E single fuel curves were 

used (Equation E-2)
 

-- Heat input rate
 

-- Mass of oil formulas for OILV measurements (ARP)
 

Environmental Protection Agency	 Monitoring Plan Reporting Instructions -- Page 89 
 

 

 

 

March 07, 2012September 19, 2012	 9.0 Monitoring Formula Data 

-- Net fuel flow formulas for systems with more than one flowmeter
 

-- F-factor proration calculation for mixed fuels (if elected)
 

F-Factors and F-Factor Formulas 

●	 Heat input rate, NOx emission rate, and CO2 emission rate formulas based on CEMS 

require the inclusion of a specific F-factor based on the fuel being combusted. 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 prorated Ffactor. Calculate prorated F-factors using Equation F-8 in 40 CFR Part 75, Appendix F. 

If a pro-rated F-factor formula is used, include it in this data set. 

Situations That Do Not Require Formulas 

●	 Appendix E units do not need formulas for the NOx emission rate. 

●	 Units using LME methodology in §75.19 do not need formulas. 

●	 Do not include formulas for cumulative quarterly or annual emissions or heat input. 

●	 Do not provide formulas representing the default heat input rate or default NOx emission 

rate for the unit or stack. 

Monitoring Plan Reporting Instructions -- Page 90	 Environmental Protection Agency 
 

 

 

 

10.0 Monitoring Default Data	 March 07, 2012September 19, 2012 

10.0 MONITORING DEFAULT DATA 

Figure 19 

MONITORING DEFAULT DATA XML Elements
 

Description of Data 

MONITORING DEFAULT DATA records define Maximum Values, Minimum Values, Defaults, and 

Constants that are used in the Part 75 calculations or in the missing data routines. Report 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 at a monitoring location, as 

described below. 

MONITORING DEFAULT DATA records are required for the following situations: 

Missing Data Defaults (DefaultPurposeCode "MD") 

●	 Maximum NOx emission rate (MER) for any location using a NOx-diluent monitoring 

CEM system. 

●	 Maximum controlled NOx emission rate (MCR) for bypass stacks or missing data 

substitution for hours in which the add-on controls are documented to be operating 

properly (see §§75.17(d), 75.31(c)(3), and 75.34(a)(5)). 

Environmental Protection Agency	 Monitoring Plan Reporting Instructions -- Page 91 
 

 

 

 

March 07, 2012September 19, 2012	 10.0 Monitoring Default Data 

●	 Fuel-specific maximum potential SO2 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 SO2 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 and the add-on controls are either bypassed or not documented 

to be operating properly (see §§75.16 (c)(3) and 75.17 (d)). 

●	 Fuel-specific maximum controlled NOx concentrations or maximum controlled NOx 

emission rates (MCR), for units with add-on emission controls and unmonitored bypass 

stacks, if the fuel-specific MEC or MCR is reported during hours when the flue gases are 

routed through the bypass stack when the add-on emissions controls are not bypassed, are 

in use, and are documented to be operating properly (see §75.17 (d)). 

●	 Generic NOx emission rate defaults for low mass emissions units. Use this value when 

NOx controls are not operating or when default has expired. 

●	 Maximum potential NOx concentration and emission rate for Appendix E units. Use 

maximum emissions rate when NOx controls are not operating, when burning emergency 

fuels, or when Appendix E curve has been invalidated or has expired. 

●	 Maximum or minimum potential moisture percentage (required only if monitoring 

moisture continuously or using a moisture look-up table). Used for missing data 

purposes. 

●	 Minimum emission values for subtractive stack situations, if approved by petition. 

●	 Minimum potential O2 used for missing data purposes. 

●	 Maximum potential CO2 concentration for missing data purposes for unit/stacks using an 

O2 monitor to determine CO2. 

Low Mass Emissions Defaults (DefaultPurposeCode "LM") 

●	 Defaults for NOx, SO2, and CO2 emission rates for low mass emissions (LME) units 

under §75.19. 

●	 Default maximum rated hourly heat input rate (mmBtu/hr) for low mass emissions units. 

Use this value if the heat input monitoring method is MHHI or if the substitute data code 

for a LTFF unit is MHHI. 

Monitoring Plan Reporting Instructions -- Page 92	 Environmental Protection Agency 
 

 

 

10.0 Monitoring Default Data March 07, 2012September 19, 2012 

Primary Monitoring Methodology Default (DefaultPurposeCode "PM") 

●	 Default moisture values from §75.11(b) or §75.12(b), used to estimate stack moisture 

content for specific fuels. 

●	 Site-specific default moisture percentages, approved by petition under §75.66. 

● Moisture Fraction in Ambient Air for use with equation 19-2. 

Diluent Cap Default (DefaultPurposeCode "DC")
 

● CO2 or O2 diluent cap for NOx emission rate calculations. 

Default for Use with Equation F-23 (DefaultPurposeCode "F23")
 

●	 Default SO2 emission rates for units which use Equation F-23 to determine SO2 mass 

emissions (see §75.11(e)(1)). 

Minimum Fuel Flow Rate Default (DefaultPurposeCode "DM") 

●	 Default minimum fuel flow rate (refer to the Part 75 Emissions Monitoring Policy 

Manual). 

See "Specific Considerations" section about when not to report this record. 

Dependencies for MONITORING DEFAULT DATA 

The MONITORING DEFAULT DATA record is dependent on the UNIT DATA record or the STACK
 

PIPE DATA record.
 

No other records are dependent upon the MONITORING DEFAULT DATA record. 

Environmental Protection Agency	 Monitoring Plan Reporting Instructions -- Page 93 
 

 

 

 

March 07, 2012September 19, 2012 10.0 Monitoring Default Data 

MONITORING DEFAULT DATA Elements 

Instructions for completing each element of the MONITORING DEFAULT DATA section are 

provided below:
 

Parameter Code 

Element Name: ParameterCode 

Report the parameter for which a default value is defined by using the appropriate uppercase 

codes as shown in Table 37:
 

Table 37 

Parameter Codes and Descriptions for Monitoring Default
 

Category 

Parameter 

Code Description 

Diluent Cap CO2N CO2 Diluent Cap. 

O2X O2 Diluent Cap. 

Low Mass Emissions Parameters 

(§§75.19 and 75.81(b)) 

CO2R CO2 Default Emission Factor, from Table 43 or Fuel 

and Unit-Specific CO2 Default Emission Factor, for 

Combustion of "Other" Gaseous Fuel (tons/mmBtu). 

NOXR NOx Default Emission Factor, from Table 41 or Fuel 

and Unit-Specific NOx Emission Rate1 (lb/mmBtu). 

SO2R SO2 Default Emission Factor, from Table 42 or Fuel and 

Unit-Specific SO2 Default Emission Factor Calculated 

Using Equation D-1h, either (1) for combustion of 

"other" gaseous fuel; or (2) for fuel oil combustion, 

based on the maximum weight percent sulfur in the 

operating permit (lb/mmBtu). 

MHHI Maximum Rated Hourly Heat Input Rate (mmBtu/hr). 

(cont.) 

Monitoring Plan Reporting Instructions -- Page 94 Environmental Protection Agency 
 

 

 

 

 

 

 

 

10.0 Monitoring Default Data	 March 07, 2012September 19, 2012 

Table 37
 

Parameter Codes and Descriptions for Monitoring Default (cont.)
 

Category 

Parameter 

Code Description 

Missing Data Values 

or 

Maximum Values for 

Unmonitored Bypass Stack and 

Emergency Fuels 

H2ON Minimum Potential Percent Moisture. 

H2OX Maximum Potential Percent Moisture. 

CO2X Maximum Percent CO2. 

O2N Minimum Potential Percent Oxygen. 

SO2X Fuel-Specific Maximum Potential SO2 Concentration 

(ppm). 

NOCX Fuel-Specific Maximum Potential (MPC) or Maximum 

Expected NOx Concentration (ppm) for all hours or 

controlled hours. For Appendix E missing data 

purposes, report the MPC used to calculate the 

Maximum NOx Emission Rate for each fuel curve and, 

if applicable, for Emergency fuel. 

NORX Maximum NOx Emission Rate (MER), MCR, or and 

Fuel-Specific Maximum Potential or Maximum 

Expected Controlled NOx Emission Rate (lb/mmBtu) 

for all hours or controlled hours. For Appendix E 

missing data purposes, an MER must be determined for 

each fuel curve and, if applicable, for Emergency fuel. 

FLOX Fuel-Specific Maximum Potential Flow Rate (scfh). 

Moisture Default Parameter H2O Hourly Percent Moisture Content (%H2O). 

BWA Moisture Fraction in Ambient Air. 

SO2 Emission Rate Parameter 

for Use in Formula F-23 

SO2R SO2 Generic Default Emission Factor for Pipeline 

Natural Gas; or 

Fuel and Unit-Specific Default Emission Factor 

Calculated Using Equation D-1h for combustion of 

"other" gaseous fuel; or 

Emission Factor approved by petition for a very low 

sulfur solid or liquid fuel (or combination of fuels) per 

§75.11 (e). 

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. 

1	 Report "NOXR" 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)). 

Environmental Protection Agency	 Monitoring Plan Reporting Instructions -- Page 95 
 

 

 

 

 

 

 

 

 

 

March 07, 2012September 19, 2012 10.0 Monitoring Default Data 

Default Value 

Element Name: DefaultValue 

Report the Maximum, Minimum, Default, or Constant Value to be used to the number of decimal 

places consistent with the corresponding hourly data record. 

Table 38 

Rounding Rules for Default Values
 

Round to 0 Round to 1 Round to 2 Round to 3 Round to 4 Round to 

Decimal Decimal Decimal Decimal Decimal Nearest 

Places Place Places Places Places 1000 

Parameter CO2N, CO2X, BWA, CO2R, SO2R FLOX 

Codes H2O, H2ON, 

H2OX, MHHI, 

MNNX, 

NORX, NOXR 

MNGF, 

MNHI, 

MNOF, 

NOCX, O2X, 

O2N, SO2X 

NOx Maximum Emission Rate (MER) 

For a NOx-diluent monitoring system (lb/mmBtu), calculate and report a maximum potential 

NOx emission rate (MER), based on the MPC value (reported in the Monitoring Span record) for 

use with missing data procedures. 

Calculate NOx MER on a unit or stack basis by using one of the following formulas and values: 

20.9 E = K x Cd x Fd x 

20.9 -%O2d 

(Equation F-5) 

Where: 

E = Pollutant emissions during unit operation, lb/mmBtu;
 

K = 1.194 x 10-7 (lb/dscf)/ppm NOx;
 

Cd = NOx concentration (dry) (use MPC value);
 

Fd (dscf/mmBtu) = Dry basis F-factor used for the unit in Monitoring Formula; and
 

%O2d = Maximum oxygen concentration during normal operating conditions, 

or use the diluent cap value of 14.0 percent O2 for boilers and 19.0 

percent O2 for turbines or if MPC is derived from historical data, the 

O2 reading recorded at the hour of the MPC may be used. 

Monitoring Plan Reporting Instructions -- Page 96 Environmental Protection Agency 
 

 

 

 

 

 

 

 

 

 

 

 

 

10.0 Monitoring Default Data March 07, 2012September 19, 2012 

100 E = K x Cw x Fc x 

%CO2w 

(Equation F-6) 

Where: 

E = Pollutant emissions during unit operation, lb/mmBtu; 

K = 1.194 x 10-7 (lb/dscf)/ppm NOx; 

Cw = NOx concentration (wet) (use MPC value); 

Fc (scf CO2/mmBtu) = Carbon-based F-factor used for the unit in Monitoring Formula 20; 

and 

%CO2w = Minimum CO2 concentration during normal operating conditions, 

or use the diluent cap value of 5.0 percent CO2 for boilers and 1.0 

percent CO2 for turbines or if MPC is derived from historical data, 

the CO2 reading recorded at the hour of the MPC may be used. 

Diluent Cap Values 

For a CO2 diluent cap value, report 5.0 percent for a boiler or 1.0 percent for a combustion 

turbine. For an O2 diluent cap value, report 14.0 percent for a boiler or 19.0 percent for a 

turbine. 

Moisture Defaults 

If using a default value to determine moisture, report fuel-specific moisture default values. 

Tables 39 and 40 provide the fuel-specific moisture default values for coal-fired and woodburning units and natural gas-fired boilers. Table 39 provides minimum default moisture values 

that are used in all emission (SO2, NOx, CO2) 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-7 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 40. 

If using a monitoring system to determine moisture, report either the maximum or minimum 

potential moisture percentage, depending on whether you use the standard or inverse missing 

data procedure from Part 75. For the minimum potential moisture percentage, report either a 

default value of 3.0 percent H2O or a site-specific value obtained from 720 or more hours of 

historical data. For the maximum potential moisture percentage, report either a default value of 

15.0 percent H2O or a site-specific value derived from 720 or more hours of historical data. 

Environmental Protection Agency Monitoring Plan Reporting Instructions -- Page 97 
 

 

 

 

March 07, 2012September 19, 2012 10.0 Monitoring Default Data 

Table 39 

Fuel-Specific Minimum Default Moisture Values
 

for SO2, NOx, CO2, and Heat Input Rate Calculations
 

Minimum Moisture 

Fuel Default Value 

Anthracite Coal 3.0% 

Bituminous Coal 6.0% 

Sub-bituminous Coal 8.0% 

Lignite Coal 11.0% 

Wood 13.0% 

Natural Gas (boilers 

only) 

14.0% 

Table 40 

Fuel-Specific Maximum Default Moisture Values
 

for NOx Emission Rate Calculations
 

Maximum Moisture 

Fuel Default Value 

Anthracite Coal 5.0% 

Bituminous Coal 8.0% 

Sub-bituminous Coal 12.0% 

Lignite Coal 13.0% 

Wood 15.0% 

Natural Gas (boilers 

only) 

18.0% 

LME Defaults 

Table 41 contains the "generic" default NOx emission factors for qualifying oil and gas-fired low 

mass emissions units under §75.19, which are based on the unit type and the type of 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 41. For fuel oil 

combustion, in lieu of using the default values in Table 42, fuel and unit-specific default SO2 

emission rates may be determined based on the maximum allowable weight percentage of sulfur 

in the fuel, as specified in the operating permit (see §75.19(c)(1)(i)). For gaseous fuels other 

than natural gas, there are no generic default values available. Therefore, fuel and unit-specific 

emission rates must be determined for all emission parameters. 

Monitoring Plan Reporting Instructions -- Page 98 Environmental Protection Agency 
 

10.0 Monitoring Default Data March 07, 2012September 19, 2012 

Table 41 

NOx Emission Factors (lb/mmBtu) for Low Mass Emissions Units
 

Boiler Type Fuel Type NOx Emission Factors 

Turbine Natural Gas 0.7 

Oil 1.2 

Boiler Natural Gas 1.5 

Oil 2.0 

Table 42 contains the Part 75 SO2 emission factors for low mass emissions units, which are 

based on the type of fuel combusted. 

Table 42 

SO2 Emission Factors (lb/mmBtu) for Low Mass Emissions Units 

Fuel Type SO2 Emission Factors 

Pipeline Natural Gas 

(as defined in §72.2) 

0.0006 

Natural Gas 0.06 

Residual Oil 

or Other Oil 

2.10 

Diesel Fuel 0.50 

Table 43 contains fuel-specific CO2 emission factors for low mass emissions units. 

Table 43 

CO2 Emission Factors (ton/mmBtu) for Low Mass Emissions Units 

Fuel Type CO2 Emission Factors 

Natural Gas 0.059 

Oil 0.081 

Environmental Protection Agency Monitoring Plan Reporting Instructions -- Page 99 
 

 

March 07, 2012September 19, 2012 10.0 Monitoring Default Data 

Default Units of Measure Code 

Element Name: DefaultUnitsOfMeasureCode 

Report the appropriate measurement units using the appropriate uppercase codes as shown in 

Table 44. For Parameter BWA, leave this field blank. 

Table 44 

Units of Measure Codes by Parameter
 

Units of 

Measure Code Description Parameter Code 

PCT Percent CO2N, CO2X, H2O, H2ON, 

H2OX, O2N, O2X 

LBMMBTU Pounds per Million Btu MNNX, NOXR, SO2R, NORX 

MMBTUHR Million Btu per Hour MNHI, MHHI 

TNMMBTU Tons per Million Btu CO2R 

SCFH Standard Cubic Feet per Hour MNOF, FLOX, 

PPM Parts per million SO2X, 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 

Monitoring Plan Reporting Instructions -- Page 100 Environmental Protection Agency 
 

 

 

 

10.0 Monitoring Default Data March 07, 2012September 19, 2012 

Default Purpose Code 

Element Name: DefaultPurposeCode 

Identify the purpose or intended use of the Default Value for reporting and emissions
 

measurement by using the appropriate uppercase codes as shown in Table 45:
 

Table 45 

Default Purpose Codes and Descriptions
 

Code Description Parameter Code 

DC Diluent Cap CO2N, O2X 

DM Default Minimum Fuel Flow Rate MNGF, MNOF 

F23 SO2 Emission Rate Default for Use in Equation F-23 SO2R 

LM Low Mass Emissions Unit Default (§§75.19 and 

75.81(b)) 

CO2R, SO2R, NOXR, MHHI 

MD Missing Data, Unmonitored Bypass Stack, or 

Emergency Fuel 

CO2X, FLOX, H2ON, H2OX, 

MNHI, MNNX, NOCX, 

NORX, O2N, SO2X 

PM Primary Measurement Methodology BWA, H2O 

Fuel Code 

Element Name: FuelCode 

Report the type of fuel associated with the default by using the appropriate uppercase codes as 

shown in Table 46. For maximum NOx emission rate that is not fuel-specific or for maximum or 

minimum potential moisture or O2/CO2 values, report a Non-Fuel Specific code, or "NFS." 

Table 46 

Monitoring Default Fuel Codes and Descriptions
 

Type Code Description 

LME Defaults 

(§75.19) 

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 

(cont.) 

Environmental Protection Agency Monitoring Plan Reporting Instructions -- Page 101 
 

 

 

 

March 07, 2012September 19, 2012 10.0 Monitoring Default Data 

Table 46
 

Monitoring Default Fuel Codes and Descriptions (cont.)
 

Type Code Description 

LME Defaults 

(§75.19) (cont.) 

LPG Liquefied Petroleum Gas (if measured as a gas) 

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 

Moisture ANT Anthracite Coal 

BT Bituminous Coal 

CRF Coal Refuse (culm or gob) 

LIG Lignite 

NNG Natural Gas (including Pipeline Natural Gas) 

PNG Pipeline Natural Gas 

SUB Sub-bituminous Coal 

W Wood 

SO2 Emission Rate Default 

for Use in Equation F-23 

NNG Natural Gas 

PNG Pipeline Natural Gas 

OGS Other Gas 

* or MIX *With an approved petition, any liquid or solid fuel type that 

qualifies as very low sulfur fuel, or a mixture of such fuels. 

See fuel code list in UNIT FUEL DATA 

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 

(cont.) 

Monitoring Plan Reporting Instructions -- Page 102 Environmental Protection Agency 
 

10.0 Monitoring Default Data March 07, 2012September 19, 2012 

Table 46
 

Monitoring Default Fuel Codes and Descriptions (cont.)
 

Type Code Description 

Fuel-Specific CEMS Missing 

Data (cont.) 

CRF Coal Refuse (culm or gob) 

DGG Digester Gas 

DSL Diesel Oil 

LFG Landfill Gas 

LPG Liquefied Petroleum Gas (if measured as a gas) 

MIX Co-Fired Fuels 

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 

Fuel-Specific MPC/MER or 

MEC/MCR Reporting During 

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 

(cont.) 

Environmental Protection Agency Monitoring Plan Reporting Instructions -- Page 103 
 

March 07, 2012September 19, 2012 10.0 Monitoring Default Data 

Table 46
 

Monitoring Default Fuel Codes and Descriptions (cont.)
 

Type Code Description 

Fuel-Specific MPC/MER or 

MEC/MCR Reporting During 

Bypass Stack Operating 

Hours (cont.) 

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 

Monitoring Plan Reporting Instructions -- Page 104 Environmental Protection Agency 
 

 

 

 

 

 

 

10.0 Monitoring Default Data March 07, 2012September 19, 2012 

Operating Condition Code 

Element Name: OperatingConditionCode 

If the value is used only for controlled or uncontrolled hours, indicate this using a "C" or "U," as 

appropriate (for example, if using separate NORX codes for controlled and uncontrolled 

operating conditions, use the “C” code for the MCR rate value and “U” code for the MER rate 

value). If this is a unit-specific default NOx emission rate for an LME combustion turbine that 

has base and peak rates, report "B" or "P" to indicate the operating condition to which this rate 

applies. Report "A" if the use of the value is not related to the control status of the unit or base 

versus peak operation, such as for diluent cap records. Table 47 summarizes operating condition 

codes and descriptions. 

Table 47 

Monitoring Default Operating Condition Codes and Descriptions
 

Operating Condition Code Description 

A Any Hour 

C Controlled Hour 

B Base Load Hour (LME units) 

P Peak Load Hour (LME units) 

U Uncontrolled Hour 

Default Source Code 

Element Name: DefaultSourceCode 

Report the means of selecting or determining the Maximum, Minimum, or Constant value by 

using the appropriate uppercase codes for the parameters reported as shown in Table 48: 

Table 48 

Default Source Codes and Descriptions
 

Default 

Source Code Source of Value Description Parameter 

APP* Approved (Petition) MNNX, SO2R, MNHI, H2O, 

MHHI 

DATA** Historical or Other Relevant Data O2N, O2X, CO2X, H2ON, 

H2OX, FLOX, SO2X, NOCX, 

NORX, NOXR, MNOF, MNGF, 

BWA 

PERM Maximum Weight Percent Sulfur in Fuel Oil, as 

Specified by Operating Permit (for LME) 

SO2R, NORX, NOCX 

TEST Unit/Stack Testing NOXR, FLOX, SO2X, NOCX, 

Environmental Protection Agency Monitoring Plan Reporting Instructions -- Page 105 
 

 

 

 

 

 

 

 

 

 

 

March 07, 2012September 19, 2012	 10.0 Monitoring Default Data 

NORX 

(cont.) 

Table 48 

Default Source Codes and Descriptions (cont.) 

Default 

Source Code Source of Value Description Parameter 

SAMP Fuel Sampling SO2R, CO2R, SO2X 

CONT Contract Maximum SO2R 

DEF Default Value from Part 75 CO2R, NOXR, CO2N, O2X, 

SO2R, H2ON, H2OX, SO2X, 

NOCX, NORX, H2O 

MAXD Maximum Value Based on Design or Nameplate 

Capacity 

MHHI, NORX, NOCX 

*	 Report "APP" if you have an approved petition to use a site-specific SO2 emission factor for very low 

sulfur solid or liquid fuels.
 

** Report code "DATA" in this field if reporting 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)). 

Group ID 

Element Name: GroupID 

Report data in this field only if the unit is included in a group of identical low mass emissions 

(LME) units under §75.19. Otherwise, leave this field blank. 

Report the Group ID that has been assigned by the Designated Representative, if the default 

value reported in this MONITORING DATA DEFAULT record is a currently-applicable (i.e., active) 

fuel-and-unit-specific default NOx emission rate for this unit and for the other units in a group of 

identical LME units under §75.19. 

The default value for the group of identical units must be updated each time that a subset of the 

group is tested to establish the new default NOx emission rate (for LME units). The minimum 

retest frequency for LME units is once every five years (20 calendar quarters). 

Begin Date 

Element Name: BeginDate 

Report the date on which the default became effective for purposes of reporting emissions data. 

Monitoring Plan Reporting Instructions -- Page 106	 Environmental Protection Agency 
 

 

 

 

 

 

 

 

 

10.0 Monitoring Default Data	 March 07, 2012September 19, 2012 

Begin Hour 

Element Name: BeginHour 

Report the hour on which the default became effective for purposes of reporting emissions data. 

End Date 

Element Name: EndDate 

Report the date after which the value will no longer be used. Submit a second Monitor Default
 

record with an effective date to report a new value. This value should be left blank for active 

records.
 

End Hour 

Element Name: EndHour 

Report the hour after which the value will no longer be used. Submit a second Monitor Default
 

record with an effective hour to report a new value. This value should be left blank for active
 

records.
 

Specific Considerations
 

Situations Not Requiring Monitoring Default Data Submission 

●	 Values for CO2 or O2 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 

calculations in hardcopy with the initial monitoring plan (and store on site). Do not 

report this information electronically in the EDR. 

●	 Maximum oil and gas fuel flow rate. These values are defined in SYSTEM FUEL FLOW 

DATA. 

●	 Maximum potential (or maximum expected) SO2, NOx, CO2, or flow rate values, for units 

using the standard (non-fuel-specific (NSF)) CEMS missing data routines in §75.33. 

(These maximum potential and expected values are defined in Monitor Span Data.) 

●	 Default high range value for SO2 or NOx (already defined in monitor span). 

●	 Default SO2 emission rates for Acid Rain Program units that use Appendix D to account 

for SO2 mass emissions from the combustion of gaseous fuel. For these units, report the 

default SO2 emission rates in the PARAMETER FUEL FLOW DATA record. 

●	 Appendix D density and GCV values for oil and gas. These values are defined in the 

FUEL FLOW DATA record. 

Environmental Protection Agency	 Monitoring Plan Reporting Instructions -- Page 107 
 

 

 

March 07, 2012September 19, 2012	 10.0 Monitoring Default Data 

Specific Considerations for Units Using Equation F-23 

●	 For pipeline natural gas combustion, report 0.0006 lb/mmBtu. 

●	 For other natural gas combustion, report the default SO2 emission rate (lb/mmBtu) 

calculated using Equation D-1h. 

●	 For gaseous fuels other than natural gas that qualify under Section 2.3.6 of Appendix D 

to use a default SO2 emission rate, report the emission rate (lb/mmBtu), calculated using 

Equation D-1h. 

●	 For very low sulfur solid or liquid fuels or mixtures of these fuels with gaseous fuel, 

report the custom default SO2 emission rate(s) approved by petition. 

Monitoring Plan Reporting Instructions -- Page 108	 Environmental Protection Agency 
 

 

 

 

11.0 Monitoring Span Data March 07, 2012September 19, 2012 

11.0 MONITORING SPAN DATA 

Figure 20 

MONITORING SPAN DATA XML Elements
 

Description of Data 

MONITORING SPAN DATA contains information concerning the span and range values associated 

with the continuous emission monitors installed at unit or stack and the time period in which 

these values are effective. It also contains information regarding the Maximum Potential and 

Maximum controlled values for each parameter monitored. 

Environmental Protection Agency Monitoring Plan Reporting Instructions -- Page 109 
 

 

 

 

 

March 07, 2012September 19, 2012 11.0 Monitoring Span Data 

Dependencies for MONITORING SPAN DATA 

The MONITORING SPAN DATA record is dependent on the UNIT DATA record or the STACK PIPE
 

DATA record.
 

No other records are dependent upon the MONITORING SPAN DATA record. 

MONITORING SPAN DATA Elements 

Instructions for completing each element of the MONITORING SPAN DATA section are provided 

below:
 

Component Type Code 

Element Name: ComponentTypeCode 

Identify the component type (parameter) of the monitor using the following uppercase codes: 

Table 49 

Component Type Codes and Descriptions for Monitor Span
 

Code Description 

CO2 CO2 Concentration (percent) 

FLOW Stack Flow 

NOX NOx Concentration (ppm) 

O2 O2 Concentration (percent) 

SO2 SO2 Concentration (ppm) 

Span Scale Code 

Element Name: SpanScaleCode 

Report either "H" to indicate high scale or "L" to indicate low scale for SO2, NOx, CO2, or O2. 

For FLOW leave this field blank. 

Monitoring Plan Reporting Instructions -- Page 110 Environmental Protection Agency 
 

 

 

 

 

11.0 Monitoring Span Data	 March 07, 2012September 19, 2012 

Span Method Code 

Element Name: SpanMethodCode 

Report the method used to determine the maximum potential (or expected) concentration (MPC 

or MEC) or flow rate (MPF) by using the appropriate uppercase codes as shown in Table 50: 

Table 50 

Provision for Calculating MPC/MEC/MPF Codes and Descriptions
 

Code Description 

F Formula (low and high-scale SO2, 

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 SO2 for Gas 

Units 

PL NOx MEC Based on Permit Limit 

ME NOx MPC Based on Manufacturer's 

Estimate of Uncontrolled Emissions 

Table 51 summarizes the recommended methods for determining MPC/MEC/MPF. 

●	 Submit documentation with the original hardcopy monitoring plan submission and retain 

files of the supporting information concerning a unit for recordkeeping purposes if using 

Equations A-1a or A-1b from Appendix A to Part 75 or historical data to determine 

maximum potential flow (MPF). 

●	 Leave this field blank for O2 records. 

●	 For CO2, enter a default MPC value of 14.0 percent CO2 for boilers and 6.0 percent CO2 

for turbines. For turbines, an alternative default MPC value below 6.0 percent CO2 may 

be used if a technical justification is provided in the hard copy monitoring plan. Report a 

Span Method Code of "TB" if the default value is reported. The MPC may also be 

determined based on historical data. If historical data are used (720 hours, minimum), 

report the highest %CO2 value observed in the historical look-back period as the MPC. 

Environmental Protection Agency	 Monitoring Plan Reporting Instructions -- Page 111 
 

 

 

 

March 07, 2012September 19, 2012 11.0 Monitoring Span Data 

Table 51 

Criteria for MPC/MEC/MPF Determinations
 

Parameter Scale 

Method Used to Determine 

MPC/MEC/MPF Selection Criteria 

Method 

Code 

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 

Appendix 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 Sections 2.1.2.2(c) 

and 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 %CO2 F 

Equation A-3b and Equation of 

Continuity* 

Based on %O2 F 

Historical data For changes in MPF, as described in 

Section 2.1.4.3 of Appendix A 

HD 

Test results If available TR 

(cont.) 

Monitoring Plan Reporting Instructions -- Page 112 Environmental Protection Agency 
 

 

 

 

 

 

 

 

 

 

11.0 Monitoring Span Data	 March 07, 2012September 19, 2012 

Table 51
 

Criteria for MPC/MEC/MPF Determinations (cont.)
 

Parameter Scale 

Method Used to Determine 

MPC/MEC/MPF Selection Criteria 

Method 

Code 

SO2 High Equation A-1a Based on %CO2 F 

Equation A-1b Based on %O2 F 

Historical CEM data For initial determination or for changes in 

MPC as described in Section 2.1.1.5 of 

Appendix A 

HD 

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. 

MEC Value 

Element Name: MECValue 

If required to determine MEC per Part 75, Appendix A, report the Maximum Expected 

Concentration (MEC) value for the location in the SO2 and NOx span records. Report MEC for 

SO2 and NOx to one decimal place. Report this value in the high-scale record and, if a low scale 

is defined, also in the low-scale record. Leave this field blank for other parameters. 

MPC Value 

Element Name: MPCValue 

In the high scale record for NOx, SO2, or CO2, report the Maximum Potential Concentration 

(MPC) value for the location. Report MPC for NOx or SO2 to one decimal place. For O2, leave 

this field blank. 

Environmental Protection Agency	 Monitoring Plan Reporting Instructions -- Page 113 
 

 

 

 

 

 

 

 

 

 

 

March 07, 2012September 19, 2012 11.0 Monitoring Span Data 

MPF Value 

Element Name: MPFValue 

If the span record is for parameter FLOW, report the Maximum Potential Flow (MPF) value for 

the monitoring location in standard cubic feet per hour (scfh) on a wet basis. 

Span Value 

Element Name: SpanValue 

Report the Span Value determined according to the requirements of Part 75. If using a default
 

high range value for SO2 or NOx, leave this field blank in the high scale record. 

For SO2 and NOx, high-scale span values must be between 100 percent and 125 percent of the 

maximum potential concentration, rounded up to the next highest multiple of 100 ppm (or, 

alternatively, rounded up to the next 10 ppm if 125 percent of MPC is less than 500 ppm). Lowscale span values must be between 100 percent and 125 percent of MEC, rounded upward to the 

next highest multiple of 10 ppm. 

For flow rate, the span value 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 H2O, 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 flow monitors calibrated in inches of water, report the calibration span 

value to two decimal places. 

For CO2 and O2, report the appropriate percentage (see Part 75, Appendix A, §2.1.3), to the
 

nearest one percent CO2 or O2, not ppm.
 

Full Scale Range 

Element Name: FullScaleRange 

Report the full-scale range in the units used for daily calibrations for SO2, NOx, CO2, O2, and 

flow rate. As a general guideline, select the range such that, to the extent practicable, 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 allowable exceptions to this 

guideline. The full-scale range must be greater than or equal to the span value. Leave this field 

blank in the high scale Monitoring Span record if using a default high range value for SO2 or 

NOx. 

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11.0 Monitoring Span Data March 07, 2012September 19, 2012 

Span Units of Measure Code 

Element Name: SpanUnitsOfMeasureCode 

For SO2 and NOx, report PPM. For O2 and CO2, report PCT. 

For a flow span record, report one of the following uppercase codes to indicate the units used to 

report and perform daily calibrations based on span: 

Table 52 

Flow Span Calibration Units of Measure
 

Code Description 

ACFH Actual Cubic Feet of Stack Flow per Hour 

ACFM Actual Cubic Feet of Stack Flow per 

Minute 

AFPM Actual Feet of Stack Flow per Minute 

AMSEC Actual Meters of Stack Flow per Second 

AFSEC Actual Feet of Stack Flow per Second 

INH2O Inches of Water 

KACFH Thousand Actual Cubic Feet of Stack Flow 

per Hour 

KACFM Thousand Actual Cubic Feet of Stack Flow 

per Minute 

KAFPM Thousand Actual Feet of Stack Flow per 

Minute 

KSCFH Thousand Standard Cubic Feet of Stack 

Flow per Hour 

KSCFM Thousand Standard Cubic Feet of Stack 

Flow per Minute 

KSFPM Thousand Standard Feet of Stack Flow per 

Minute 

MACFH Million Actual Cubic Feet of Stack Flow 

per Hour 

MSCFH Million Standard Cubic Feet of Stack Flow 

per Hour 

SCFH Standard Cubic Feet of Stack Flow per 

Hour 

SCFM Standard Cubic Feet of Stack Flow per 

Minute 

SFPM Standard Feet of Stack Flow per Minute 

SMSEC Standard Meters of Stack Flow per Second 

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March 07, 2012September 19, 2012 11.0 Monitoring Span Data 

Scale Transition Point 

Element Name: ScaleTransitionPoint 

If a dual range analyzer is installed for NOx, SO2 or CO2 (see Analyzer range data), report the 

concentration value at which the DAHS switches from recording on the normal range to 

recording on the secondary range (usually low to high). Report this value in both the low and 

high scale records. Scale transition point is not reported for FLOW span.
 

Default High Range 

Element Name: DefaultHighRange 

For parameter SO2 or NOx, if using a default high range, report the actual default value in this 

field in the high scale record. The default high range value must be 200 percent of the maximum 

potential concentration. Report this value only in the high scale record for the parameter. 

For the parameters CO2, O2, or FLOW, leave this field blank. 

Flow Span Value 

Element Name: FlowSpanValue 

For the parameter FLOW, report the flow rate span value in scfh, which is the product of the 

MPF 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 Full Scale Range 

Element Name: FlowFullScaleRange 

Report the actual full-scale range value expressed in units of scfh for the parameter FLOW. The 

flow rate full-scale range value must be greater than or equal to the flow rate span value. 

Begin Date 

Element Name: BeginDate 

Report the date that the current span value became effective for reporting emissions data. 

If you have elected to use a default high range value for SO2 or NOx, report the date on which the 

default high range was implemented in the DAHS. 

Begin Hour 

Element Name: BeginHour 

Report the hour that the current span value became effective for reporting emissions data. 

If you have elected to use a default high range value for SO2 or NOx, report the hour on which 

the default high range was implemented in the DAHS. 

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11.0 Monitoring Span Data	 March 07, 2012September 19, 2012 

End Date 

Element Name: EndDate 

Report the last date on which the span record was in effect. Leave this field blank for active span 

records. If a span change was made, report both the original span record with the appropriate 

end date and the new span record with the appropriate begin date. 

End Hour 

Element Name: EndHour 

Report the last hour in which the span record was in effect. Leave this field blank for active span 

records. 

Specific Considerations 

CEMS Methodology 

●	 If you are using a CEMS methodology, MONITORING SPAN DATA must be included for 

each parameter (e.g., NOX, SO2, CO2, O2, or FLOW) that is measured with CEMS. 

Note that for units that combust more than one type of fuel, the maximum potential 

concentration (MPC) values reported in MONITORING SPAN DATA 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), in addition to reporting the "conventional" MPC or MER values in 

MONITORING SPAN DATA, you must report a fuel-specific maximum potential value for 

each of the other fuels, using MONITORING DEFAULT DATA. 

Dual Ranges and Separate MONITORING SPAN DATA Records 

●	 If SO2, NOx, CO2, or O2 emission concentrations vary such that dual ranges are required 

(e.g., due to fuel switching or emission controls), provide separate Monitoring Span Data 

records for the low scale and high scale values. 

High Scale and Low Scale Span Records 

●	 If you elect to use a default high range value (200 percent of MPC for SO2 or NOx) 

instead of calibrating and maintaining a high monitor range for hours in which emissions 

exceed the full-scale of the low range, submit both high scale and low scale span records, 

but in the high scale record, only report values for the following elements: the MPC, 

Begin Date and Begin Hour, the activation date and hour of the default high range value, 

and Default High Range (the default high range value of 200 percent of MPC). 

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March 07, 2012September 19, 2012	 11.0 Monitoring Span Data 

DP-Type Flow Monitors Calibrated in Units of Inches of H2O 

●	 For DP-type flow monitors that are calibrated in units of inches of H2O, select a value 

between 100 percent and 125 percent of the MPV. Then convert that value from units of 

wet, standard feet per minute (wsfpm) to units of wet actual feet per second (wafps). 

Then use Equation 2-7 in EPA Reference Method 2 (40 CFR 60, Appendix A-1) to 

convert the actual velocity to an equivalent delta-P value in inches of H2O. 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. 

Updating the MONITORING SPAN DATA Record 

When any value in a MONITORING SPAN DATA record changes, update the information by
 

reporting both the original span record with the appropriate end date and the new span record 

with the appropriate begin date.
 

If you have discontinued the use of a default high range value for SO2 or NOx in favor of using a 

span value, report in the old record the last date and hour on which the default high range was in 

use. In the new record, report the date and hour on which the new span value became effective. 

If changing from a span value to a default high range value for SO2 or NOx, report the date on 

which the default high range was implemented in the DAHS. 

In order to correct a previously submitted record that contains erroneous information, resubmit
 

the MONITORING SPAN DATA record with the corrected information. 

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12.0 Rectangular Duct WAF Data	 March 07, 2012September 19, 2012 

12.0 RECTANGULAR DUCT WAF DATA 

Figure 21 

RECTANGULAR DUCT WAF DATA XML Elements
 

Description of Data 

Submit a RECTANGULAR DUCT WAF DATA record for rectangular ducts or stacks with installed 

flow monitors, in which a wall effects adjustment factor (WAF) was determined using 

Conditional Test Method CTM-041 and applied to the hourly flow rate data. Conditional Test 

Method CTM-041 is used 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, it may be entered into the 

programming of the 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 

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March 07, 2012September 19, 2012 12.0 Rectangular Duct WAF Data 

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 a RECTANGULAR DUCT WAF DATA record in each quarterly submission. For 

units not presently applying a wall effects correction, if you intend to begin using a WAF, report 

this record after the WAF has been determined and prior to the next quarterly file that uses that 

WAF. 

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 RECTANGULAR DUCT WAF DATA records: one 

that ends the record that is no longer effective, and one that reports the new wall effects 

adjustment factor data. 

Dependencies for RECTANGULAR DUCT WAF DATA 

The RECTANGULAR DUCT WAF DATA record is dependent on the UNIT DATA record or the 

STACK PIPE DATA record.
 

No other records are dependent upon the RECTANGULAR DUCT WAF DATA record. 

RECTANGULAR DUCT WAF DATA Elements 

Instructions for completing each element of the MONITORING LOCATION ATTRIBUTE DATA
 

section are provided below:
 

WAF Determination Date 

Element Name: WAFDeterminationDate 

Report the date the WAF was determined. Unless you are a first time user of CTM-041, this date 

must be on or prior to the WAF Begin Date. 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, unless the flow profile changed significantly during that period. 

Therefore, for first-time users, the WAF Begin Date may be earlier than the WAF Determination 

Date. 

WAF Begin Date 

Element Name: WAFBeginDate 

Report the date on which the WAF was first applied to the flow rate data. 

WAF Begin Hour 

Element Name: WAFBeginHour 

Report the hour in which the WAF was first applied to the flow rate data. 

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12.0 Rectangular Duct WAF Data March 07, 2012September 19, 2012 

WAF Method Code 

Element Name: WAFMethodCode 

Report the appropriate WAF Method Code displayed in Table 53 to indicate the WAF
 

calculation approach.
 

Table 53 

WAF Method Code and Descriptions
 

Code Description 

FT Full Test (CTM-041 §§8.1 and 8.2) 

AT Abbreviated Test (CTM-041 §8.4.1) 

DF Default Value (CTM-041 §8.4.2) 

WAF Value 

Element Name: WAFValue 

Report the WAF applied to the flow rate data, to four decimal places, with a leading zero (e.g., 

0.9750). 

Number of Test Runs 

Element Name: NumberOfTestRuns 

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 Traverse Points WAF 

Element Name: NumberOfTraversePointsWAF 

Report the number of Method 1 traverse points in the WAF test runs. 

Number of Test Ports 

Element Name: NumberOfTestPorts 

Report the number of test ports at which measurements were made during the WAF test runs. 

Number of Traverse Points Reference 

Element Name: NumberOfTraversePointsRef 

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 this data element for the 

"reference" flow RATA and for all subsequent flow RATAs must equal the Number of Traverse 

Points WAF data element, for the WAF test run(s). If you wish to increase the number of 

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March 07, 2012September 19, 2012 12.0 Rectangular Duct WAF Data 

Method 1 traverse points used in a subsequent flow RATA, you must re-determine the WAF
 

using an equal number of Method 1 traverse points. 

Duct Width 

Element Name: DuctWidth 

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 

Element Name: DuctDepth 

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 End Date 

Element Name: WAFEndDate 

Report the date on which the WAF was last applied to the flow rate data. Leave this field blank 

if this WAF is still being applied. 

WAF End Hour 

Element Name: WAFEndHour 

Report the hour in which the WAF was last applied to the flow rate data. Leave this field blank 

if this WAF is still being applied. 

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13.0 Monitoring Load Data March 07, 2012September 19, 2012 

13.0 MONITORING LOAD DATA 

Figure 22 

MONITORING LOAD DATA XML Elements
 

Description of Data 

The MONITORING LOAD DATA record identifies the maximum load, the lower and upper 

boundaries of the range of operation and, if applicable, the normal load level(s) for a unit or 

other monitoring location. Report this record for every unit, stack, and pipe in the monitoring 

plan. 

Dependencies for MONITORING LOAD DATA 

The MONITORING LOAD DATA record is dependent on the UNIT DATA record or the STACK PIPE 

DATA record. 

No other records are dependent upon the MONITORING LOAD DATA record. 

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March 07, 2012September 19, 2012	 13.0 Monitoring Load Data 

MONITORING LOAD DATA Elements 

Instructions for completing each element of the MONITORING LOAD DATA section are provided 

below:
 

Maximum Load Value 

Element Name: MaximumLoadValue 

This value is required for all units and all additional monitoring locations with the exception of 

non-load based units. Define the maximum hourly gross load associated with the unit, stack, or 

pipe at full capacity: 

●	 For boilers and simple cycle turbines (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). 

●	 For multiple stacks, report the maximum hourly gross load for the associated unit. 

●	 Determine the total maximum hourly gross load according to the guidelines in the Part 75 

Emissions Monitoring Policy Manual for combined cycle (CC) combustion turbine units. 

For combined cycle combustion turbines where the HRSG produces steam, the equivalent 

load for the HRSG must be included in the maximum hourly gross load determination. 

Express the total unit load on a consistent basis, i.e., either in terms of electrical or steam 

load. 

●	 Leave this field blank for units that do not produce electrical or steam load. 

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13.0 Monitoring Load Data March 07, 2012September 19, 2012 

Maximum Load Units of Measure Code 

Element Name: MaximumLoadUnitsOfMeasureCode 

Identify the type of load information reported in this record by using the appropriate uppercase 

codes as shown in Table 54. Note that you must use the same units of measure as will be used to 

report hourly load. 

Table 54 

Maximum Load Value Codes and Descriptions
 

Code Description 

MW Electrical Capacity (in megawatts) 

KLBHR Steam (load) Mass Rate (in units of 

1000 lbs/hr) 

MMBTUHR BTUs of Steam Produced (in 

mmBtu/hr) 

Note: Leave this field blank for units that do not produce electrical or steam load. 

Lower Operation Boundary 

Element Name: LowerOperationBoundary 

This value is required for all units and all additional monitoring locations where load-based 

missing data are used. Report the lower boundary of the range of operation for units that 

produce electrical or steam load, in units of megawatts, 1000 lb/hr of steam or mmBtu/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), the sum of the 

minimum safe, stable loads of the units serving the common stack (or pipe) may be reported as 

the lower boundary of the operating range. 

For multiple stacks, report, the minimum safe, stable load for the associated unit. 

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. 

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March 07, 2012September 19, 2012 13.0 Monitoring Load Data 

Upper Operation Boundary 

Element Name: UpperOperationBoundary 

This value is required for all units and all additional monitoring locations where load-based
 

missing data are used. Report the upper boundary of the range of operation for units that
 

produce electrical or steam load, in units of megawatts, 1000 lb/hr of steam, or mmBtu/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 the Maximum Load Value. 

Report the maximum sustainable load for single units (including units that have a multiple stack 

exhaust configuration), to either: (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. 

Report the sum of the maximum sustainable loads of all units using the stack (or pipe) for a 

common 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 multiple stacks, report the maximum sustainable load for the associated unit. 

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. 

Normal Level Code 

Element Name: NormalLevelCode 

This value is required for all units and all additional monitoring locations where load-based 

missing data are used, except for peaking units or stacks linked to peaking units. Designate and 

report the most frequently used load level ("L," "M," or "H") as the "normal" load level 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. For all SO2, 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. 

Second Level Code 

Element Name: SecondLevelCode 

This value is required for all units and all additional monitoring locations where load-based 

missing data are used, except for peaking units or stacks linked to peaking units. Report the 

second most frequently used level 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). 

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13.0 Monitoring Load Data March 07, 2012September 19, 2012 

Second Normal Indicator 

Element Name: SecondNormalIndicator 

This value is required for all units and all additional monitoring locations where load-based 

missing data are used, except for peaking units or stacks linked to peaking units. For units that 

produce electrical or steam load, based upon the results of the historical load data analysis, the 

second most frequently used load level may be elected to be designated as an additional normal 

load level. If you wish to designate the second most frequently used operating level as a second 

normal level, report "1" for this element. Otherwise, report "0". Note that if you designate the 

second level as a normal level, you must perform a bias test for all SO2, NOx, and flow RATAs 

conducted at this load level. 

For non load-based units, a second normal operating level may be designated, based on 

knowledge of the unit and operating experience with the industrial process. 

Load Analysis Date 

Element Name: LoadAnalysisDate 

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 two most frequently used load levels, and the normal load 

level(s) for units that produce electrical or steam load.
 

Leave this field blank for new units since no load analysis has yet been completed. 

Leave this field blank for non load-based units. 

Begin Date 

Element Name: BeginDate 

Report the date on which the load information became effective. For the initial load analysis at a 

particular unit or stack, report the Begin Date as the first day of the quarter in which the data 

analysis was performed (i.e., 2005-01-01 or 2005-04-01, etc.), rather than the actual date of the 

analysis unless the two dates are the same. For records created to indicate a change to the load 

information, this date should equal the load analysis date if the change is based on a new load 

analysis. But, if you are simply electing to add a second normal load or to make minor 

adjustments to the boundaries of the operating range, or updating other information that is not 

dependent on the load analysis, the Begin Date may be later than the load analysis date. 

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.
 

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.
 

Begin Hour 

Element Name: BeginHour 

Report the hour in which the load information became effective. 

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March 07, 2012September 19, 2012	 13.0 Monitoring Load Data 

End Date 

Element Name: EndDate 

Report the last date on which the load information was in effect. Report an end date only when 

another MONITORING LOAD DATA record will be reported to provide a change to one or more 

data elements, either because a new historical load data analysis was performed which indicated 

a change, or because you elect to change the second normal load designation or the range of 

operation. When this occurs, submit one MONITORING LOAD DATA record with the results of the 

previous load data analysis and report the end date in this field. Submit a second MONITORING 

LOAD DATA record with the results of the new load data analysis or choice, leaving this field 

blank (see "Specific Considerations" below). 

For non load-based units, report an end 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 

MONITORING LOAD DATA records, one to deactivate the old information, and one to activate the 

new information, as described immediately above for load-based units. 

End Hour 

Element Name: EndHour 

Report the last date on which the load information was in effect. This value should be left blank 

for active records. 

Specific Considerations 

Range of Operation for Electrical or Steam Load Units and Non Load-Based Units 

●	 MONITORING LOAD DATA 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. 

Purpose of Historical Load Data Analysis 

●	 MONITORING LOAD DATA 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 two-load flow RATAs; (3) 

determining, for multi-load flow RATAs, 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. 

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13.0 Monitoring Load Data	 March 07, 2012September 19, 2012 

Historical Load Data Analysis for Non Load-Based Units 

● 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. 

Upper and Lower Boundaries for New or Newly-Affected Units 

●	 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) in the Begin Date field. 

Updating the MONITORING LOAD DATA Record 

When the manner of operating the unit(s) changes significantly, update the information in 

MONITORING LOAD DATA by submitting two MONITORING LOAD DATA records. First, close out 

the existing monitor load record by entering an end date and hour. Next, create a new monitor 

load record indicating the Begin Date and Hour for the new record. 

In order to correct a previously submitted record that contains erroneous information, resubmit 

the MONITORING LOAD DATA record with the corrected information. For example, if the Normal 

Level Code was previously submitted as "H" (for high-load) when the normal load level should 

have be "M" (for mid-load), the record should be updated and resubmitted. Note that the 

BeginDate and BeginHour elements should not be updated, unless the BeginDate and/or 

BeginHour are the elements to be corrected. 

Once the operating range and normal load level(s) have been established, Part 75 does not 

require repeating 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 such a change has been determined, establish the new load information by creating a new 

MONITORING LOAD DATA record with the new information, and report the old record with the 

appropriate End Date and End Hour (which must be just prior to the Begin Date and Begin Hour 

of the new record). 

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 (this is good practice, even though this is not
 

required by the regulation), do not change the Begin 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.
 

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March 07, 2012September 19, 2012 13.0 Monitoring Load Data 

For peaking units, if peaking status is lost at the end of a year or ozone season, the MONITORING 

LOAD DATA record information must be deactivated 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 MONITORING LOAD DATA record, as 

described in the Load Analysis data element instructions above. 

When transitioning from non-peaking status to peaking unit status at the beginning of a new 

calendar year or ozone season, deactivate the existing MONITORING LOAD DATA record, 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 MONITORING LOAD DATA record, 

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 MONITORING 

LOAD DATA record, leave Normal Level Code through Second Level Indicator data elements 

blank. A MONITORING QUALIFICATION PERCENT DATA record must also be submitted, to claim 

peaking unit status. 

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14.0 Monitoring Qualification Data March 07, 2012September 19, 2012 

14.0 MONITORING QUALIFICATION DATA 

Figure 23 

MONITORING QUALIFICATION DATA XML Elements
 

Description of Data 

Report a MONITORING QUALIFICATION DATA record for a unit for which qualification is sought 

as a gas-fired unit or a peaking unit, or to use the low mass emissions (LME) monitoring and 

reporting provisions in §75.19. A separate record must be submitted for each type of 

qualification sought. For example, two separate record sets must be submitted for a single unit to 

indicate both gas-fired and peaking unit status. Also include the appropriate Monitoring 

Qualification records providing the historical or projected information to demonstrate peaking, 

gas-fired, or LME status. See instructions for MONITORING QUAL LME DATA and MONITORING 

QUAL PERCENT DATA for more information. 

To indicate that a unit or stack has an approved petition to perform flow RATAs at only a single 

load or two loads, report this record with applicable Qual Type Code (PRATA1 or PRATA2). 

Dependencies for MONITORING QUALIFICATION DATA 

The MONITORING QUALIFICATION DATA record is dependent on the UNIT DATA record or the 

STACK PIPE DATA record. 

The following complex elements specify additional qualification data and are dependent on the 

MONITORING QUALIFICATION DATA record: 

● MONITORING QUAL LME DATA 

● MONITORING QUAL PERCENT DATA 

The complex elements cannot be submitted for a monitoring plan unless an applicable 

MONITORING QUALIFICATION DATA record is included. 

Environmental Protection Agency Monitoring Plan Reporting Instructions -- Page 131 
 

 

 

 

 

 

 

 

March 07, 2012September 19, 2012 14.0 Monitoring Qualification Data 

MONITORING QUALIFICATION DATA Elements 

Instructions for completing each element of the MONITORING QUALIFICATION DATA section are 

provided below:
 

Qualification Type Code 

Element Name: QualificationTypeCode 

Report a code from the Table 55 specifying the type of qualification being sought: 

Table 55 

Qualification Type Codes and Descriptions
 

Category Code Description 

Gas-Fired GF Gas-Fired Qualification 

Low Mass Emitter LMEA Low Mass Emitter Qualification (Annual) -- Required 

when reporting on a year-round basis 

LMES Low Mass Emitter Qualification (Ozone Season) -­

Required when subject to an Ozone-Season NOx program 

Peaking PK Peaking Unit Qualification (Annual) 

SK Peaking Unit Qualification for Ozone Season (applies 

exclusively to sources that report on an ozone season-only 

basis) 

QA Test Exemption PRATA1 Single Load RATA Qualification by petition approval 

PRATA2 Two Load RATA Qualification by petition approval 

COMPLEX Exemption from Flow-to-Load Testing Due to Complex 

Configuration 

LOWSULF SO2 RATA Exemption for a Source Combusting Only 

Very Low Sulfur Fuel 

Begin Date 

Element Name: BeginDate 

Report the date on which qualification will become effective. 

For gas-fired and peaking unit qualifications and for LME qualifications, this should equal the 

first date on which the qualification is needed for monitoring and reporting purposes. It must be 

no later than the begin date of any MONITORING METHOD DATA record that depends on the 

qualification. 

For Flow RATA qualifications, this date should be equal to or earlier than the first RATA which 

relies on the petition provisions. 

Monitoring Plan Reporting Instructions -- Page 132 Environmental Protection Agency 
 

 

14.0 Monitoring Qualification Data March 07, 2012September 19, 2012 

For Flow-to-Load exemptions, this date should be equal to the completion date of the first flow
 

RATA that qualifies for the exemption. 

End Date 

Element Name: EndDate 

If applicable, report the date on which the qualification ended. 

For gas-fired and peaking unit qualifications and for LME qualifications, this would be the last 

day of the calendar year (or ozone season) in which the qualification was lost. This date triggers 

the requirement to meet new monitoring and reporting requirements within the specified time 

allowed by Part 75. 

Environmental Protection Agency Monitoring Plan Reporting Instructions -- Page 133 
 

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14.1 Monitoring Qual LME Data March 07, 2012September 19, 2012 

14.1 MONITORING QUAL LME DATA 

Figure 24 

MONITORING QUAL LME DATA XML Elements
 

Description of Data 

Report MONITORING QUALIFICATION DATA records to provide the initial evidence that a unit 

qualifies for low mass emissions (LME) status. If the unit reports on a year-round basis, report a 

MONITORING QUALIFICATION DATA record with a QualificationTypeCode of "LMEA" and three 

supporting MONITORING QUAL LME DATA records (one for each required 

QualificationDataYear). If the unit is subject to an ozone-season NOx program (e.g., CAIROS, 

NBP, etc.), report a MONITORING QUALIFICATION DATA record with a 

QualificationTypeCode of "LMES" and three supporting MONITORING QUAL LME DATA 

records (one for each required QualificationDataYear). 

If the unit reports on a year-round basis, and is also subject to an ozone-season NOx program, the 

unit must report both sets of records and meet both the annual and ozone-season emissions limits 

to qualify for LME status. 

See Table 56 for more information about which MONITORING QUALIFICATION DATA records to 

report and which elements must be filled out in the associated MONITORING QUAL LME DATA 

records. 

Environmental Protection Agency Monitoring Plan Reporting Instructions -- Page 135 
 

March 07, 2012September 19, 2012 14.1 Monitoring Qual LME Data 

Table 56 

Data Requirements for Monitoring Qual LME
 

Reporting 

Frequency Program Applicability 

Linked to MONITORING QUALIFICATION DATA 

Record with QualificationTypeCode: 

LMEA LMES 

SO2 

Tons 

NOx 

Tons 

SO2 

Tons 

NOx 

Tons 

Annual Subject to Acid Rain 

Program (or CAIRSO2 plus 

CAIRNOX), but not subject 

to Ozone Season NOx 

Program 

 

Do not report LMES 

record 

Subject to Acid Rain 

Program (or CAIRSO2 plus 

CAIRNOX), and also subject 

to Ozone Season NOx 

Program 

  -­ 

Subject to CAIRSO2, but not 

subject to any NOx Program 

 -­ Do not report LMES 

record 

Subject to Ozone Season 

NOx program and reporting 

year-round, but not subject to 

CAIRSO2 

-­  -­ 

Subject to CAIRNOX, but 

not subject to CAIRSO2 or 

Ozone Season NOx program 

-­ 

Do not report LMES 

record 

Ozone Season 

Only 

Subject to Ozone Season 

NOx program and reporting 

during Ozone Season only 

Do not report LMEA 

record 

-­ 

Dependencies for MONITORING QUAL LME DATA 

The MONITORING QUAL LME DATA record is dependent on the MONITORING QUALIFICATION 

DATA record. 

No other records are dependent upon the MONITORING QUAL LME DATA record. 

Monitoring Plan Reporting Instructions -- Page 136 Environmental Protection Agency 
 

 

 

 

 

 

 

14.1 Monitoring Qual LME Data March 07, 2012September 19, 2012 

MONITORING QUAL LME DATA Elements 

Instructions for completing each element of the MONITORING QUAL LME DATA section are 

provided below:
 

Qualification Data Year 

Element Name: QualificationDataYear 

Report the calendar year used for the measured, estimated, or projected SO2 and/or NOx mass 

emissions.
 

Operating Hours 

Element Name: OperatingHours 

Report the number of unit operating hours (as defined in §72.2) for the Qualification Data Period 

(i.e., full year or ozone season) in the Qualification Data Year. 

SO2 Tons 

Element Name: SO2Tons 

If this record is linked to a MONITORING QUALIFICATION DATA record with a 

QualificationTypeCode of "LMEA", and the unit is subject to an SO2 program, report the SO2 

mass emissions for the Qualification Data Year based on either measured or estimated SO2 mass 

emissions or projected SO2 mass emissions, as appropriate according to § 75.19. Round and 

report this value to one decimal place. 

Otherwise, leave this field blank. 

NOx Tons 

Element Name: NOxTons 

If this record is linked to a MONITORING QUALIFICATION DATA record with a
 

QualificationTypeCode of "LMEA", and the unit is subject to a NOx program and is reporting
 

year-round, report the annual NOx mass emissions for the Qualification Data Year based on 

either measured or estimated NOx mass emissions or projected NOx mass emissions, as 

appropriate according to §75.19. Round and report this value to one decimal place.
 

If this record is linked to a MONITORING QUALIFICATION DATA record with a
 

QualificationTypeCode of "LMES", and the unit is subject to an ozone-season NOx program, 

report the seasonal NOx mass emissions for the Qualification Data Year based on either
 

measured or estimated NOx mass emissions or projected NOx mass emissions, as appropriate
 

according to §75.19. Round and report this value to one decimal place.
 

Otherwise, leave this field blank. 

Environmental Protection Agency Monitoring Plan Reporting Instructions -- Page 137 
 

 

 

 

 

 

 

 

 

 

March 07, 2012September 19, 2012	 14.1 Monitoring Qual LME Data 

Specific Considerations 

SO2 Mass Emissions Reduction Program 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 SO2 per year. 

NOx Mass Emissions Reduction Program Units 

●	 For a unit subject to a program with a seasonal NOx emission cap, 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 per ozone season. 

●	 For a unit that reports NOx mass emission data year-round, use this record to qualify as a 

low mass emissions unit by demonstrating that the unit emits < 100 tons of NOx per year. 

Data Projections 

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); 

●	 One or more of the past three years is not representative of current unit operation (e.g., if 

controls were recently installed); or 

●	 The owner or operator takes a federally enforceable permit restriction on unit operating 

hours. 

Historical Data 

●	 If only historical data are being used to qualify, Year 1 would be three years before the 

Qualification Data Year (i.e., the year of the LME application (see §75.19(a)(2)). 

●	 If only projected data are being used, Year 1 would be the calendar year of the
 

Qualification Data Year (i.e., the year of the LME application). 

●	 If only historical data are being used, Year 3 would be one year before the Qualification 

Data Year or if only projected data were being used, Year 3 would be two years after the 

Qualification Data Year (i.e., the year of the LME application). 

●	 The appropriate calendar years for Ozone Seasons 1, 2, and 3 are determined in a similar 

manner. 

Monitoring Plan Reporting Instructions -- Page 138	 Environmental Protection Agency 
 

 

 

 

 

14.1 Monitoring Qual LME Data	 March 07, 2012September 19, 2012 

LME Attainment Failure 

●	 If a qualifying LME unit emits more than the allowable number of tons of SO2 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(b)(2). 

●	 If LME status is lost, update the MONITORING QUALIFICATION DATA record by 

completing the end date. Also submit a MONITORING METHOD DATA record indicating 

changes in monitoring methodologies with the appropriate effective dates. 

LME Emission Testing 

●	 For information on emission testing of a group of identical LME units, refer to the UNIT 

DEFAULT TEST SUMMARY DATA record instructions in the QA Certification Data section 

of the reporting instructions. 

Updating the MONITORING QUAL LME DATA Record 

This record is not designed to be updated from year to year. Rather, ongoing LME status is 

demonstrated by the cumulative SO2 and NOx mass emissions reported in the hourly emissions
 

records. Changes to this data should only be necessary if the unit loses its LME status or needs
 

additional qualification records based on a change in program applicability or a change in 

reporting frequency.
 

Environmental Protection Agency	 Monitoring Plan Reporting Instructions -- Page 139 
 

March 07, 2012September 19, 2012 14.1 Monitoring Qual LME Data 

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14.2 Monitoring Qual Percent Data March 07, 2012September 19, 2012 

14.2 MONITORING QUAL PERCENT DATA 

Figure 25 

MONITORING QUAL PERCENT DATA XML Elements
 

Description of Data 

Report this record in conjunction with the MONITORING QUALIFICATION DATA record to support 

the qualifications of a peaking unit or gas-fired unit. For any year or ozone season in which a 

unit qualifies as a peaking or gas-fired unit, submit a MONITORING QUAL PERCENT DATA record 

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)(11) 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). 

Dependencies for MONITORING QUAL PERCENT DATA 

The MONITORING QUAL PERCENT DATA record is dependent on the MONITORING QUALIFICATION 

DATA record. 

No other records are dependent upon the MONITORING QUAL PERCENT DATA record. 

Environmental Protection Agency Monitoring Plan Reporting Instructions -- Page 141 
 

 

 

 

 

 

 

 

 

 

 

 

March 07, 2012September 19, 2012 14.2 Monitoring Qual Percent Data 

MONITORING QUAL PERCENT DATA Elements 

Instructions for completing each element of the MONITORING QUAL PERCENT DATA section are 

provided below:
 

Qualification Year 

Element Name: QualificationYear 

Report the year for which qualification is sought. 

Average Percentage Value 

Element Name: AveragePercentageValue 

Report the average of the three years' Percentage Values. 

Year 1 Qualification Data Year 

Element Name: Yr1QualificationDataYear 

Report the calendar year or season represented by Year 1. 

Year 1 Qualification Data Type Code 

Element Name: Yr1QualificationDataTypeCode 

Report one of the following codes that describe the type of percent data for Year 1 supporting
 

qualification as a peaking unit or gas-fired unit:
 

Table 57 

Qualification Data Type Code and Descriptions
 

Code Description 

A Actual Percent Capacity Factor or Fuel 

Usage 

P Projected Capacity Factor or Fuel 

Usage 

D 720 Hours of Unit Operating Data 

(gas-fired only) 

Year 1 Percentage Value 

Element Name: Yr1PercentageValue 

Report the percent capacity factor or the percent of heat input from gaseous fuel for Year 1. 

Monitoring Plan Reporting Instructions -- Page 142 Environmental Protection Agency 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

14.2 Monitoring Qual Percent Data March 07, 2012September 19, 2012 

Year 2 Qualification Data Year 

Element Name: Yr2QualificationDataYear 

Report the calendar year or season represented by Year 2. 

Year 2 Qualification Data Type Code 

Element Name: Yr2QualificationDataTypeCode 

Report one of the codes from Table 57, above, that describes the type of percent data for Year 2 

supporting qualification as a peaking unit or gas-fired unit: 

Year 2 Percentage Value 

Element Name: Yr2PercentageValue 

Report the percent capacity factor or the percent of heat input from gaseous fuel for Year 2. 

Year 3 Qualification Data Year 

Element Name: Yr3QualificationDataYear 

Report the calendar year or season represented by Year 3. 

Year 3 Qualification Data Type Code 

Element Name: Yr3QualificationDataTypeCode 

Report one of the codes from Table 57, above, that describes the type of percent data for Year 3 

supporting qualification as a peaking unit or gas-fired unit: 

Year 3 Percentage Value 

Element Name: Yr3PercentageValue 

Report the percent capacity factor or the percent of heat input from gaseous fuel for Year 3. 

Environmental Protection Agency Monitoring Plan Reporting Instructions -- Page 143 
 

 

 

 

 

 

 

 

 

 

March 07, 2012September 19, 2012	 14.2 Monitoring Qual Percent Data 

Specific Considerations 

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 unit in a NOx mass emissions reduction program reporting on an ozone season-only 

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 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 percent, 10.0 percent, and 12.0 percent annual 

capacity factor, report each of these values as a Percentage Value element. 

Table 58 

Example Data for Qualification Based on
 

Historical and Projected Data
 

Initial 

Qualifying 

Methodology 

Data Reported in MONITORING QUAL PERCENT DATA Record 

Current 

Year Year 1 Type* Year 2 Type* Year 3 Type* 

Actual Historical 

Data 

2000 1997 A 1998 A 1999 A 

2001 1998 A 1999 A 2000 A 

2002 1999 A 2000 A 2001 A 

Projected Data 2000 2000 P 2001 P 2002 P 

2001 2000 A 2001 P 2002 P 

2002 2000 A 2001 A 2002 P 

2003 2000 A 2001 A 2002 A 

Combination of 

Actual Historical 

Data and Projected 

Data 

2001 2000 A 2001 P 2002 P 

2002 2000 A 2001 A 2002 P 

2003 2000 A 2001 A 2002 A 

* A = Actual historical data; P = Projected data 

Monitoring Plan Reporting Instructions -- Page 144	 Environmental Protection Agency 
 

 

 

 

 

 

 

14.2 Monitoring Qual Percent Data	 March 07, 2012September 19, 2012 

Peaking and Gas-Fired Unit Qualification 

●	 If reporting to qualify both as a peaking unit and as a gas-fired unit, submit two 

MONITORING QUALIFICATION DATA records, one with QualificationTypeCode of GF 

(gas-fired) and one with QualificationTypeCode of PK or SK. With each, report the 

appropriate MONITORING QUAL PERCENT DATA record to demonstrate that the unit meets 

the gas-fired or peaking unit criteria. 

Qualifications for Gas-Fired Units 

●	 In accordance with paragraph (3)(ii)(B) of the "gas-fired" definition in §72.2, 720 hours 

of unit operating data may be provided 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 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 the results of the demonstration are submitted until the end of that same 

calendar year. 

●	 For the next year, actual, historical fuel usage data must be submitted from the previous 

year (beginning with the date on which gas-fired qualification was first met) to verify that 

fuel usage requirements were met for the first reporting year. 

●	 For example, if qualified based on the 720 hour demonstration as of June 30, 2000, then, 

in 2001, historical data must be submitted for the time interval from June 30, 2000 

through December 31, 2000 (labeled as Year 1). In 2002, historical data would be 

submitted for 2000 (labeled as Year 1) and 2001 (labeled as Year 2). In 2003, historical 

data would be submitted for 2000, 2001, and 2002, labeled as Year 1, Year 2, and Year 3, 

respectively (see Table 59, below). 

Table 59 

Example of Gas-Fired Qualification Based on Unit Operating Data
 

Initial 

Qualifying 

Methodology 

Data Reported in MONITORING QUAL PERCENT DATA Record 

Current 

Year Year 1 Type Year 2 Type Year 3 Type 

Qualifying Based 

on 720 Hours of 

Unit Operating 

2000 2000 D** 2001 P 2002 P 

2001 2000 A 2001 P 2002 P 

Data 2002 2000 A 2001 A 2002 P 

After the first 

year, available 

historical data 

must be provided. 

2003 2000 A 2001 A 2002 A 

** Initial qualification based on 720 hours of unit operating data 

Environmental Protection Agency	 Monitoring Plan Reporting Instructions -- Page 145 
 

 

 

 

 

 

March 07, 2012September 19, 2012	 14.2 Monitoring Qual Percent Data 

Initial and Subsequent Qualification 

●	 It is possible a unit may initially qualify as a gas-fired or peaking unit by using historical 

data or projected data. A combination of historical and projected data may be used. 

However, to maintain peaking unit or gas-fired unit status, actual capacity factor or fuel 

usage data for each subsequent year must be reported. Thus, if the basis for qualifying in 

the first reporting year is on three years of projections, it is not possible to re-qualify 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. 

Loss of Status 

●	 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, update the MONITORING QUAL 

DATA record by reporting the appropriate End Date, to indicate that the peaking or gasfired unit status has been lost. 

●	 If a unit has previously qualified as a peaking or gas-fired unit but has lost that status and 

re-establishing peaking or gas-fired status is wished, the unit may only re-qualify 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). 

Updating the MONITORING QUAL PERCENT DATA Record 

For each unit, as applicable, add another MONITORING QUAL PERCENT DATA record at the 

beginning of each calendar year (for year-round reporters) or at the start of the ozone season (for 

ozone season-only reporters) to demonstrate on-going qualification, based on the previous year 

(or ozone season) of historical data. 

Monitoring Plan Reporting Instructions -- Page 146	 Environmental Protection Agency