Component 2 Form Approved 03/28/2011 

OMB Control No. 2060-0657 

Approval Expires 03/31/2014 

1 

Petroleum Refinery 

Emissions Information Collection 

PART VI. EMISSIONS INVENTORY DATA 

The U.S. EPA is working to fulfill its obligations under CAA section 112(f)(2) to review residual 

risk from the petroleum refinery NESHAP subparts CC and UUU, CAA section 112(d)(6) to 

perform technology reviews of the petroleum refinery NESHAP subparts CC and UUU, and 

CAA sections 111(b) to review the petroleum refinery NSPS subpart J. Emission data sets 

provided by the individual refineries will be used for these reviews. 

Please provide emission estimates (tons/yr) for the 2010 calendar year for individual HAP and 

criteria pollutants for all emission sources located at the facility using the Refinery ICR 

Component 2 Reporting Tool available on the ICR website (https://refineryicr.rti.org). You may 

report emissions by emissions point rather than by unit, but you should identify which units are 

associated with each emissions point. (Note: You do not have to report emissions a single way 

throughout the entire inventory. For example, you may report equipment leak emissions by 

process unit for the major process units and by geographical area for other areas of your 

refinery.) Emission sources include, but are not limited to: 

• Each processing unit for which you provided an ID in Part I, Question 16 

• Each electricity generating, steam generating, or combined heat and power unit 

listed in Table 1-2 of Part II 

• Each process heater listed in Table 2-1 of Part II 

• Each fuel gas and natural gas system for which you provided equipment leaks 

data in Table 3-2 of Part II 

• Each storage tank regardless of size or partial pressure of material stored 

• Each “other atmospheric vent” listed in Table 11-1 of Part II (except for vents 

controlled by a flare) 

• Each flare listed in Table 12-1 of Part II, including those controlling emissions 

from “other atmospheric vents” listed in Table 11-1 of Part II 

Except as noted below, provide emission estimates following the methods provided in the 

Emission Estimation Protocol for Petroleum Refineries (Version 2.1 – Final ICR Draft). As 

noted in the Emission Estimation Protocol for Petroleum Refineries, for each unit for which 

there are multiple methodologies for estimating emissions, you must use the highest 

Methodology Rank in the Emission Estimation Protocol for Petroleum Refineries for which you 

have available 2010 data. For example, if Methodology Rank 1 for NOX is estimating emissions 

using a continuous emissions monitoring system (CEMS), and you have a NOX CEMS on that 

unit, you must use the CEMS results to estimate NOX emissions from that unit. However, if you 

did not have a NOX CEMS installed on that unit during 2010, you do not have available data to 
Component 2 Form Approved 03/28/2011 

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Approval Expires 03/31/2014 

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use Methodology Rank 1 for NOX; you must then consider whether you have available data to 

use Methodology Rank 2 for NOX from that unit. Similarly, if a particular methodology requires 

speciation of a stream and you do not have speciation data available, you are not required to 

conduct additional sampling and analysis (but if you do have speciation data available and no 

higher ranking methodology can be used, you must use the methodology that calls for 

speciation). 

For units and other emissions points not addressed in the Emission Estimation Protocol for 

Petroleum Refineries, you should provide the emissions estimates as your TRI or State inventory 

or use engineering estimates and process knowledge for pollutants not required to be reported for 

TRI or State inventory. Also provide a brief explanation of the methodology you used in the 

“Comments” column of the emissions template provided. 

For wastewater treatment systems, also please provide a copy of the Refinery Wastewater 

Emissions Tool spreadsheet (provided as part of the Emission Estimation Protocol for Petroleum 

Refineries) completed for your refinery. 

Instructions for completing the emissions template are provided below. 

1. Emissions point ID: Provide the identification number or code for the location at which 

emissions are released into the environment. If this is an emissions point for one 

particular process unit or a flare, you may use the Unit ID as your Emissions point ID. If 

you choose to report fugitive emissions by process unit, the Emissions point ID should be 

“FUG-” plus the Unit ID (e.g., if you are reporting equipment leak emissions for a FCCU 

with a Unit ID of FCCU01, the Emissions point ID is “FUG- FCCU01”). 

2. Emissions point description: Provide a description of the emissions point for easy 

reference (e.g., FCCU regenerator vent stack; catalytic reforming unit depressurization 

vent; crude heater vent; facility-wide start-up and shutdown emissions). 

3. Unit ID(s): Provide the identification number or code for the unit(s) associated with this 

emissions point. Use the same identification number that you provided in Component 1. 

For sulfur recovery, enter the SRU ID. For an emissions point that covers the entire 

facility, enter “All Units.” (Note that for flares, you are not required to identify the 

process units and/or vents routed to each flare; the response to this question is the Flare 

ID). For units not included in Component 1, use a unique ID for each process unit. 

When possible, use the same identifier from your permit or emissions inventory. 

4. SCC: The ICR website (https://refineryicr.rti.org) provides source classification codes 

(SCC) extracted from EPA’s 2005 National Scale Air Toxics Assessment (NATA) 

National Emissions Inventory (NEI) database lookup tables. There have been updates 

(both additions and deletions) to the SCC over the years, and the list on the ICR website 

contains the current list of SCC that EPA would like you to use for this inventory. If a 

code that you have used in the past no longer appears in the applicable lookup table, 

please select the most appropriate code from those listed. 

5. Type of Release (Point or Fugitive): Point releases are the emissions released from a 

facility unit that is included in the facility inventory through one or more stacks or vents. 
Component 2 Form Approved 03/28/2011 

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Fugitive releases are air pollutants released to the air other than those from stacks or 

vents, including small releases from leaking plant equipment such as valves, pump seals, 

flanges, or sampling connections, and large open area releases such as from landfills, 

waste ponds, coke drum cutting, coke transport and storage, or unpaved roads. 

6. Point Sources: Complete the columns listed below if you answered “Point” in Number 5. 

Release Height (ft): Enter the height of the stack or vent from the ground. 

Internal Vent Diameter (ft): Enter the diameter of the stack or vent at the release height. 

Exit Temperature (°F): Enter the temperature of the exit gas stream 

Gas Flow Rate (acfm): Enter the flow rate of the exit gas stream. 

7. Fugitive Sources: Complete the columns listed below if you answered “Fugitive” in 

Number 5. 

Length (ft): Enter the dimension of the source in the east-west (x-) direction 

Width (ft): Enter the dimension of the source in the north-south (y-) direction 

Angle: The release angle is the orientation of the y-dimension relative to true North, 

measured positive for clockwise starting at 0 degrees (maximum less than 90 degrees). 

EPA will assume 0 degrees if it is not provided. 

8. Longitude and Latitude: Pay particular attention when entering emission release point 

stack parameters and locations. EPA requires latitude/longitude for each emissions point 

provided in North American Datum (NAD) 83 and prefers six digits to the right of the 

decimal point. (If currently available coordinates have five digits to the right of the 

decimal point instead of six, those coordinates are acceptable.) These data are critical 

inputs to the modeling files that EPA will use to determine the risk profile for the residual 

risk review process.1

9. Pollutant name: Enter the name of the pollutant for which you are estimating emissions. 

You will need to enter only one pollutant per row; for most units, it will take multiple 

rows to provide emissions estimates for all pollutants. 

10. Pollutant CAS No. or Pollutant Code: See Table 1-1 of the Emission Estimation Protocol 

for Petroleum Refineries for a list of CAS numbers and Pollutant Codes for selected 

 

1

Latitude measure in decimal degrees of the angular distance on a meridian north or south of the equator. Positive 

(+) data point for North America. Example: +78.123456. For point sources, this represents the center of the source; 

for fugitive sources, this is the southwest corner if the fugitive angle is zero or the western most corner if the fugitive 

angle is greater than zero. Longitude measure in decimal degrees of the angular distance on a meridian east or west 

of the prime meridian. Negative (-) data point for North America. Example: -123.234561. For point sources this 

represents the center of the source; for fugitive sources, this is the southwest corner if the fugitive angle is zero, or 

the western most corner if the fugitive angle is greater than zero. 
Component 2 Form Approved 03/28/2011 

OMB Control No. 2060-0657 

Approval Expires 03/31/2014 

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pollutants. The same list is also included in the Refinery ICR Component 2 Reporting 

Tool. 

11. 2010 routine emissions (tons): All emissions reported in this column should reflect the 

ACTUAL emissions during normal operation for the reported calendar year. If you use a 

CEMS/CMS to monitor emissions of a particular pollutant, report in this column the 

emissions measured during all periods when readings were within the calibrated span of 

the CEMS/CMS. 

12. Methodology used for routine emissions: Indicate whether the emissions are based on 

direct measurements, stack testing, engineering calculations, or another method. 

13. 2010 non-routine emissions (tons): All emissions reported in this column should reflect 

the ACTUAL emissions during any non-routine operation for the reported calendar year, 

including startups, shutdowns, and other events. If you use a CEMS/CMS to monitor 

emissions of a particular pollutant and the readings for certain periods of the year were 

not within the calibrated span of the CEMS/CMS, estimate emissions of that pollutant 

from the process unit during those periods and report the value here. Enter 0 if there 

were not non-routine operations for this source during 2010 or if non-routine emissions 

are not applicable for the source type (e.g., equipment leaks). You may use an emissions 

point ID representing “All Units” to report the non-routine emissions (see descriptions for 

Number 1 and Number 3). 

14. Maximum hourly emissions (lb/hr): Enter the maximum actual emissions from the unit 

during normal operation in any one hour of 2010. See the Emission Estimation Protocol 

for Petroleum Refineries for additional information on how to determine hourly 

emissions. 

15. Annual emissions allowed by NESHAP for emissions points subject to emission limits

(tons/yr): Enter the annual emissions during normal operation allowed by the NESHAP 

to which this unit is subject. (Note that if the NESHAP limit is on a concentration basis, 

you will need to use process data at maximum capacity to convert the limit to tons/yr. 

Similarly, if the NESHAP limit is on a percent reduction basis, you may need to use 

information about the inlet to the control device to estimate the allowable emissions.) If 

this unit is not subject to any NESHAP for this pollutant, enter “N/A.” 

As an example, if you comply with the 1 lb per 1,000 lb coke burn-off limit for PM for an 

FCCU, determine and report the allowed annual PM emissions based on the annual 

quantity of coke burned in 2010 when reporting the allowed PM emissions and enter 

“N/A” when reporting the allowed nickel emissions. Alternatively, if you comply with 

the 0.029 lb/hr nickel emissions limit for an FCCU, enter “N/A” when reporting the 

allowed PM emissions and determine and report the allowed annual nickel emissions 

based on the operating hours of the unit in 2010 when reporting the allowed nickel 

emissions. 

16. Hourly emissions allowed by NESHAP for emissions points subject to emission limits

(lb/hr): Enter the maximum hourly emissions during normal operation allowed by the 
Component 2 Form Approved 03/28/2011 

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Approval Expires 03/31/2014 

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NESHAP to which this unit is subject. For example, when reporting nickel emissions 

from an FCCU, enter “N/A” if you comply with a PM emissions limit but report the 

allowed hourly emissions rate if you comply with the nickel emission rate alternative. 

(Note that if the NESHAP limit is on a concentration basis, you will need to use process 

data at maximum capacity to convert the limit to lb/hr. Similarly, if the NESHAP limit is 

on a percent reduction basis, you may need to use information about the inlet to the 

control device to estimate the allowable emissions.) If this unit is not subject to any 

NESHAP for this pollutant, enter “N/A.” 

As an example, if you comply with the 1 lb per 1,000 lb coke burn-off limit for PM for an 

FCCU, determine and report the allowed hourly PM emissions based on the maximum 

quantity of coke burned in an hour during 2010 when reporting the allowed PM 

emissions and enter “N/A” when reporting the allowed nickel emissions. Alternatively, if 

you comply with the 0.029 lb/hr nickel emissions limit for an FCCU, enter “N/A” when 

reporting the allowed PM emissions and enter “0.029” (lb/hr) when reporting the allowed 

nickel emissions. 

17. Annual emissions allowed by permit (tons/yr): Enter the annual emissions during normal 

operation allowed by your operating permit (may be more stringent than the emissions 

limit under the applicable NESHAP). (Note that if the permit limit is on a concentration 

basis, you will need to use process data at maximum capacity to convert the limit to 

tons/yr.) If your permit does not have a numerical limit for emissions of this pollutant 

from this unit, enter “N/A” (see example for Number 15). 

18. Hourly emissions allowed by permit (lb/hr): Enter the maximum hourly emissions during 

normal operation allowed by your operating permit (may be more stringent than the 

emissions limit under the applicable NESHAP). (Note that if the permit limit is on a 

concentration basis, you will need to use process data at maximum capacity to convert 

the limit to lb/hr.) If your permit does not have a numerical limit for emissions of this 

pollutant from this unit, enter “N/A” (see example for Number 16). 

19. Comments: Provide any comments that you feel are necessary to qualify or explain any 

of your answers to the previous questions.