Instructions for filling in the Emission Test Template

This Information Collection Request (ICR) spreadsheet is intended to collect information about emission data fro

fuel burning power plants and which test methods were used to do so for cases where the test methods are not 

supported by the Electronic Reporting Tool (ERT). This spreadsheet should only be used if the method is not in t

if you do not have access to a lab which performs methods that are in the ERT. You must complete at least 3 se

runs or sampling events for each of the requested constituents. This spreadsheet is intended to be used for one 

one facility. Data for multiple boilers should be handled by using separate copies of this spreadsheet.

yellow are required. All cells that are shaded in green are populated using drop-down lists. You do not need to 

cells shaded in gray, as they are automatically populated from the Boiler Information worksheet. 

resulting spreadsheet with the following naming convention: [FacilityID]_Unit_[BoilerID]_EmisTestMethods.xls 

(example: 8100_Unit_2_EmisTestMethods.xls).

Please refer to the following steps when using these spreadsheets.

Boiler Information Worksheet

1. Please enter the EIA Facility Code, Facility Name and Boiler ID of your boiler on the Boiler Information worksh

2. Please enter the control device configuration.

Emission Data Worksheets

The emission data worksheets are provided for each constituent or constituent family required for this analysis. 

spreadsheet, you must enter boiler operating information during sampling, fuel input information, and emission 

results. There are generally 1 to 3 emission test results records to be entered depending on the constituent or c

family. For example, CO only requires 1 record with 3 sample events, while Mercury requires that you enter bot

Hg+2, or if the Ontario-Hydro Method was used, you would need to enter Hg0, HgP, and Hg

Volatile Organic HAP and Speciated Semi-Volatile Organic HAP worksheets allow you to use a drop

Constituent field to define as many records as needed to record each HAP that you have results for. General ins

follow for these worksheets:

Boiler Operation Information

1. Please provide the values of all requested parameters for each of test run/sample.

2. Please provide any other supporting information or comments in the Other Supporting Information field.

Fuel Information

1. Please enter what types of fuel are being used in your boiler using the drop-downs in the Fuel Type Selection 

You may enter up to 4 fuel types. If you are not burning one or more of the fuel types entered in one or more sa

then enter an input rate of zero. 

2. Please enter the unit of measure using the drop down provided.

3. Please enter the test method used to determine the fuel input rate.

4. Please provide any other information that you feel may be important in the Other Supporting Information fie

Emission Data
1. Some constituents ask for the emission rate results of each run in two different units of measure, while other

If emission rate results are requested in two different units of measure (ex. lb/MMBtu (Pounds per million BTU) 

ppmvd @ 7% O2(parts per million by volume dry basis at 7 percent oxygen)), you are required to provide both.

2. Please provide the test method used. This may or may not match the example given in the Test Method Used 

Please ensure that the name includes the owning organization of the test method (ex. U.S. EPA Method 0010).

3. Please provide any other information that you feel may be important in the Other Supporting Information fie

4. If data sheets and QA/QC documentation tables are provided for the test method you are entering data for p

enter these data.
nformation about emission data from fossil 

ses where the test methods are not currently 

nly be used if the method is not in the ERT or 

T. You must complete at least 3 separate 

sheet is intended to be used for one boiler of 

copies of this spreadsheet. Fields shaded in 

down lists. You do not need to populate 

rmation worksheet. Please name each 

nit_[BoilerID]_EmisTestMethods.xls 

ler on the Boiler Information worksheet. 

ent family required for this analysis. On each 

fuel input information, and emission test 

d depending on the constituent or constituent 

Mercury requires that you enter both Hg0 and 

, HgP, and Hg+2. However, both the Speciated 

low you to use a drop-down provided in the 

at you have results for. General instructions 

er Supporting Information field.

downs in the Fuel Type Selection field. 

fuel types entered in one or more samples, 

he Other Supporting Information field.
erent units of measure, while others do not. 

b/MMBtu (Pounds per million BTU) and 

, you are required to provide both.

mple given in the Test Method Used field. 

ethod (ex. U.S. EPA Method 0010).

he Other Supporting Information field.

 method you are entering data for please also 
EIA Facility Code Facility Name Boiler ID

50951 Sunnyside Cogeneration Associates Unit 1
Control Device Configuraton

Listed (by boiler) in the Configuration Order Section of the Facility Unit Configurations Section of the Electronic ICR
lectronic ICR
EIA Facility Code Facility Name Boiler ID

50951 Sunnyside Cogeneration Associates Unit 1

Run Number Test Start Date Test Start Time
Measured Value (ppm)

Test End Date Test End Time
Basis (Wet or Dry) Test Method Used Data Flag (ADL, BDL, DDL)

CO Emission Test Results
Test Method Comments lb/mmBtu ppmdv @ 7% O2

Calculated Emission Rate
Steam Output (1000 lb/hr) Total Heat Input 

(mmBtu/hr) Flue Gas Moisture (%)
Flue Gas Flow Rate 

(dscfm) Flue Gas CO2

 (%) Flue Gas O

2

 (%)
Fuel Input Rate Fuel Type

Flue Gas Temperature (F)

Fuel #1
Units of Measure Measurement Method Fuel Input Rate

Fuel #1
Fuel Type Units of Measure Measurement Method

Fuel #2
Fuel Input Rate Fuel Type Units of Measure

Fuel #3
Measurement Method Fuel Input Rate Fuel Type

Fuel #4
Units of Measure Measurement Method

Fuel #4

Other Supporting 

Information
EIA Facility Code Facility Name Boiler ID

50951 Sunnyside Cogeneration Associates Unit 1

1 6/22/2010 10:25 6/22/2010

2 6/22/2010 13:12 6/22/2010

3 6/22/2010 15:52 6/22/2010

Run Number Test Start Date Test Start Time Test End Date
Measured Value 

(ppm) Basis (Wet or Dry) Test Method Used Data Flag (ADL, BDL, DDL)

12:37 <0.00160 Dry U.S. EPA Method 316 BDL

15:30 <0.00199 Dry U.S. EPA Method 316 BDL

18:02 0.00949 Dry U.S. EPA Method 316 ADL

Test End Time

Formaldehyde Emission Test Results
Test Method 

Comments lb/mmBtu ppmdv @ 7% O2

<1.66E-06 <0.00137 473.96 10.006

<2.07E-06 <0.00170 473.96 10.006

9.82E-06 0.00809 473.96 10.006

Steam Output (1000 

lb/hr)

Total Heat Input 

(mmBtu/hr)

Calculated Emission Rate
Fuel Input 

Rate Fuel Type Units of Measure

11.8 15 4.68 146040 313

10.3 14.7 4.68 145919 313

11 14.9 4.6 145257 313

Flue Gas 

Temperature 

(F)

Fuel #1 Flue Gas 

Moisture (%)

Flue Gas 

CO2 (%)

Flue Gas 

O2 (%)

Flue Gas Flow 

Rate (dscfm)
Measurement 

Method

Fuel Input 

Rate Fuel Type Units of Measure

Measurement 

Method

Fuel Input 

Rate Fuel Type Units of Measure

Fuel #2 Fuel #3
Measurement 

Method

Fuel Input 

Rate Fuel Type Units of Measure

Measurement 

Method

Fuel #4

Other Supporting Information
EIA Facility Code Facility Name Boiler ID

50951 Sunnyside Cogeneration Associates Unit 1

1 6/22/2010 10:25

2 6/22/2010 13:12

3 6/22/2010 15:52

Run Number Test Start Date Test Start Time
Measured Value (ppm) Basis (Wet or Dry)

6/22/2010 12:37 <3.55 Dry

6/22/2010 15:30 <3.55 Dry

6/22/2010 18:02 <3.55 Dry

Test End Date Test End Time

Methane Emission T
Test Method Used Data Flag (ADL, 

BDL, DDL)

Test Method 

Comments lb/mmBtu

U.S. EPA Method 18 BDL <0.00197

U.S. EPA Method 18 BDL <0.00197

U.S. EPA Method 18 BDL <0.00196

Methane Emission Test Results Calculated Emission Rate
ppmdv @ 7% O2

<3.05 473.96 10.006 11.8 15 4.68 146040

<3.04 473.96 10.006 10.3 14.7 4.68 145919

<3.03 473.96 10.006 11 14.9 4.6 145257

Flue Gas 

O2 (%)

Flue Gas 

Flow Rate 

(dscfm)

lated Emission Rate

Steam Output 

(1000 lb/hr)

Total Heat 

Input 

(mmBtu/hr)

Flue Gas 

Moisture 

(%)

Flue Gas 

CO2 (%)
Fuel 

Input 

Rate

Fuel Type Units of 

Measure

Measurement 

Method

Fuel 

Input 

Rate

Fuel Type Units of 

Measure

313

313

313

Flue Gas 

Temperat

ure (F)

Fuel #1 Fuel #2
Measurement 

Method

Fuel 

Input 

Rate

Fuel Type Units of 

Measure

Measurement 

Method

Fuel 

Input 

Rate

Fuel Type Units of 

Measure

Fuel #3 Fuel #4
Measurement 

Method

Other Supporting 

Information
EIA Facility Code Facility Name Boiler ID

50951 Sunnyside Cogeneration Associates Unit 1

Run Number Test Start Date Test Start Time Test End Date
Measured Value 

(ppm) Basis (Wet or Dry) Test Method Used Test End Time

SO2 Emission Test Results
Data Flag (ADL, 

BDL, DDL)

Test Method 

Comments lb/mmBtu ppmdv @ 7% O

2

Calculated Emission Rate Steam Output 

(1000 lb/hr)
Fuel Input 

Rate Fuel Type

Flue Gas 

O2 (%)

Flue Gas 

Flow Rate 

(dscfm)

Total Heat 

Input 

(mmBtu/hr)

Flue Gas 

Moisture 

(%)

Flue Gas 

CO2 (%)

Flue Gas 

Temperature 

(F)

Fuel #1
Units of 

Measure

Measurement 

Method

Fuel Input 

Rate Fuel Type Units of Measure

Measurement 

Method

Fuel Input 

Rate Fuel Type

Fuel #1 Fuel #2 Fuel #3
Units of 

Measure

Measurement 

Method

Fuel Input 

Rate Fuel Type Units of Measure

Measurement 

Method

Fuel #3 Fuel #4
Other Supporting Information
EIA Facility Code Facility Name Boiler ID

50951 Sunnyside Cogeneration Associates Unit 1

1 6/21/2010 16:56

2 6/23/2010 12:11

3 6/24/2010 8:55

Run Number Test Start Date Test Start Time
Please note QA/QC documentation starting in Column "AI"

Measured Value 

(μg/dscm) Basis (Wet or Dry)

6/21/2010 18:56 0.0545 Dry

6/23/2010 14:11 0.0806 Dry

6/24/2010 10:55 0.102 Dry

Test End Date Test End Time

Total Vapor Phase Mercury Em
 starting in Column "AI"

Test Method Used Data Flag (ADL, 

BDL, DDL)

Test Method 

Comments (lb/mmBtu)

U.S. EPA Method 30B ADL 3.68E-08 475.18

U.S. EPA Method 30B ADL 5.41E-08 475.35

U.S. EPA Method 30B ADL 6.87E-08 469.98

Steam Output 

(1000 lb/hr)

Total Vapor Phase Mercury Emission Test Results
Fuel Input Rate

11.417 8.87 15.3 4.3 151955 315

11.201 11.9 15.6 4.3 153420 316

10.883 11.6 14.9 4.5 152310 315

Flue Gas 

Flow Rate 

(dscfm)

Flue Gas 

Temperature (F)

Flue Gas 

O2 (%)

Total Heat 

Input 

(mmBtu/hr)

Flue Gas 

CO2 (%)

Flue Gas 

Moisture 

(%)
Fuel Type Units of 

Measure

Measurement 

Method

Fuel Input 

Rate Fuel Type Units of Measure

Measurement 

Method

Fuel Input 

Rate

Fuel #1 Fuel #2
Fuel Type Units of 

Measure

Measurement 

Method

Fuel Input 

Rate Fuel Type Units of Measure

Measurement 

Method

Fuel #3 Fuel #4
 QA/QC Documentation

Trap ID Section 1 

Mass (ng)

Section 2 

Mass (ng)

Total 

Mass (ng)

Initial 

Spike 

(ng)

Total NonSpike (ng)

67583 4.96 0.135 5.1 0 5.1

67598 6.68 0.356 7.03 0 7.03

72725 9.6 0.669 10.27 0 10.27

Other Supporting Information
Sample 

Volume 

(dscm)

Volume 

Difference (%)

Volume Diff. 

Limit

Breaktrough 

(%)

Breaktrough 

Limit

Concentration 

(μg/dscm) Trap ID

0.09203 2.21 2.721774194 0.055416712 68634

0.09245 2.66 5.329341317 0.076041103 68665

0.09218 2.37 6.96875 0.111412454 59713

#DIV/0! #DIV/0!

#DIV/0! #DIV/0!

#DIV/0! #DIV/0!

≤ 10% of 

Section 1 Hg 

mass for Hg 

conc. >1 

μg/dscm: or ≤ 

20% of Section 

Trap #1

≤20% of field 

recovery test
Section 1 

Mass

Section 2 

Mass

Total 

Mass

Initial 

Spike

Total NonSpikeSample 

Volume

Volume 

Difference (%)

Volume Diff. 

Limit

24.1 0.775 24.9 20 4.9 0.09089 0.99

27.2 0.443 27.7 20 7.7 0.0899 0.11

37.8 0.578 38.4 30 8.4 0.09128 1.39 ≤20% of field 

recovery test

Trap #2
Breaktrough (%) Breaktrough 

Limit

Concentration 

(μg/dscm) Abs. diff. RD (%) Limit Crec

3.215767635 0.053911321 0.001505 1.376948 0.218

1.628676471 0.085650723 0.00961 5.94317 0.232

1.529100529 0.09202454 0.019388 9.530181 0.309

#DIV/0! #DIV/0! #DIV/0! #DIV/0!

#DIV/0! #DIV/0! #DIV/0! #DIV/0!

#DIV/0! #DIV/0! #DIV/0! #DIV/0!

Paired Trap Agreement (RD) Measured Spik

≥10 % RD mass 

for Hg conc. >1 

μg/dscm: or 

≤20% RD or ≤0.2 

μg/dscm abs.diff. 

for Hg conc. ≤1 

≤ 10% of Section 

1 Hg mass for 

Hg conc. >1 

μg/dscm: or ≤ 

20% of Section 1 

for Hg conc.≤1 
R (%) by 

Run Ravg (%) Limit

99.2

104.1

94.1

Average 

Recovery, 

between 85 and 

115%

Measured Spike Recovery ( R )

99.13333333
EIA Facility Code Facility Name Boiler ID

50951 Sunnyside Cogeneration Associates Unit 1

Run Number Test Start Date Test Start Time
Measured Hg

0

 Value 

(μg/dscm)

Measured Hg+2 Value 

(μg/dscm)

Test End Date Test End Time
Measured HgP

 Value 

(μg/dscm)

Basis (Wet or Dry) Test Method Used Data Flag (ADL, BDL, DDL)

Total Vapor Phase Mercury Emission Test Results
Test Method 

Comments

Total Mercury 

(lb/mmBtu)

Steam Output 

(1000 lb/hr)

Total Heat 

Input 

(mmBtu/hr)

Flue Gas 

Moisture (%)

Flue Gas 

CO

2

 (%)
Fuel Input Rate Fuel Type Units of 

Measure

Measurement 

Method

Fuel #1 Flue Gas 

O2 (%)

Flue Gas 

Flow Rate 

(dscfm)

Flue Gas 

Temperature 

(F)
Fuel Input Rate Fuel Type Units of 

Measure

Measurement 

Method

Fuel Input 

Rate Fuel Type Units of Measure

Measurement 

Method

Fuel #2 Fuel #3
Fuel Input 

Rate Fuel Type Units of Measure

Measurement 

Method

Other Supporting Information

Fuel #4
EIA Facility Code Facility Name Boiler ID

50951 Sunnyside Cogeneration Associates Unit 1

Speciated Volatile Organic HAP Emission Data

Methyl chloride 1 5/1/2010

Methyl chloride 2 5/1/2010

Methyl chloride 3 5/2/2010

Acetaldehyde 1 5/3/2010

Acetaldehyde 2 5/3/2010

Acetaldehyde 3 5/4/2010

Compound 

(use drop down to define for as many rows as 

needed)

Run Number Test Start Date







Measured Value 

(μg/m3)

10:00 AM 5/1/2010 12:00 PM

2:00 PM 5/1/2010 5:00 PM

10:00 AM 5/2/2010 12:00 PM

10:00 AM 5/1/2010 12:00 PM

2:00 PM 5/1/2010 5:00 PM

10:00 AM 5/2/2010 12:00 PM

Test Start Time Test End Date Test End Time







Footnotes:

* Front half fraction contains filter, cyclone, and cartridge

** Back half fraction contains condensate, solvent, impingers

Basis Test Method Used Data Flag (ADL, BDL, 

DDL) Front Half Mass (ng)







Back Half Mass (ng) Total Mass (ng) Test Method Comments lb/mmBtu

Calculated Emission Rate







ug/dscm @ 7% O2

alculated Emission Rate

Steam Output (1000 

lb/hr)

Total Heat Input 

(mmBtu/hr) Flue Gas Moisture (%)







Flue Gas O

2

 (%) Flue Gas Flow Rate 

(scfm)

Flue Gas Temperature 

(F) Flue Gas CO2

 (%)







Fuel Input Rate Fuel Type Units of Measure Measurement Method

Fuel #1







Fuel Input Rate Fuel Type Units of Measure Measurement Method

Fuel #2







Fuel Input Rate Fuel Type Units of Measure Measurement Method

Fuel #3







Fuel Input Rate Fuel Type Units of Measure Measurement Method

Fuel #4







Other Supporting 

Information







EIA Facility Code Facility Name

50951 Sunnyside Cogeneration Associates

Speciated Semi-Volatile Organic HAP Emission Data

Anthracene 1

Anthracene 2

Anthracene 3

Pyrene 1

Pyrene 2

Pyrene 3

Compound 

(use drop down to define for as many rows as 

needed)

Run Number







Boiler ID

Unit 1

5/1/2010 10:00 AM 5/1/2010

5/1/2010 2:00 PM 5/1/2010

5/2/2010 10:00 AM 5/2/2010

5/3/2010 10:00 AM 5/1/2010

5/3/2010 2:00 PM 5/1/2010

5/4/2010 10:00 AM 5/2/2010

Test Start Date Test Start Time Test End Date







Footnotes:

* Front Half Composite contains particulate filter, front half of the 

** Back Half Composite contains XAD-2 resin tube, back half of t

*** Condensate Composite contains condensate and Impinger con

Measured Value (μg/m3) Basis (Wet or Dry)

12:00 PM

5:00 PM

12:00 PM

12:00 PM

5:00 PM

12:00 PM

Test End Time







posite contains particulate filter, front half of the filter holder, and probe solvent rinses

posite contains XAD-2 resin tube, back half of the filter holder, and coil condenser solvent rinses

omposite contains condensate and Impinger contents and the glassware solvent rinses

Test Method Used Data Flag (ADL, BDL, DDL) Front Half mass* (ng)

Semi-Volatile Organic HAP Emission Test Results







Back Half mass* (ng) Condensate Mass*** (ng) Total Composite (ng)

Emission Test Results







Test Method Comments lb/mmBtu ug/dscm @ 7% O2

Calculated Emission Rate







Steam Output (1000 lb/hr) Total Heat Input 

(mmBtu/hr) Flue Gas Moisture (%)







Flue Gas O2 Flue Gas CO2

 (%) (%) Flue Gas Flow Rate (scfm)







Fuel Input Rate Fuel Type Flue Gas Temperature (F)

Fuel #1







Units of Measure Measurement Method Fuel Input Rate

Fuel #1







Fuel Type Units of Measure Measurement Method

Fuel #2







Fuel Input Rate Fuel Type Units of Measure

Fuel #3







Measurement Method Fuel Input Rate Fuel Type

Fuel #4







Units of Measure Measurement Method

Fuel #4 Other Supporting 

Information







EIA Facility Code Facility Name Boiler ID

50951 Sunnyside Cogeneration Associates Unit 1

1 6/21/2010 13:09 6/21/2010

2 6/22/2010 10:25 6/22/2010

3 6/22/2010 13:53 6/22/2010

Run Number Test Start Date Test Start Time Test End Date
Measured Value 

(ppm) Basis (Wet or Dry) Test Method Used 

16:32 <0.00385 Dry U.S. EPA Conditional Test Method 033 (CTM-033)

13:40 <0.00399 Dry U.S. EPA Conditional Test Method 033 (CTM-033)

17:08 <0.00403 Dry U.S. EPA Conditional Test Method 033 (CTM-033)

Hydrogen Cyanide Emission Test Results

Test End Time
Data Flag (ADL, 

BDL, DDL)

Test Method 

Comments

BDL <3.75E-06 475.18 11.417 10.5 13.7

BDL <3.67E-06 473.96 10.006 11.8 15

BDL <3.75E-06 473.96 10.006 11.6 14.8

Steam Output 

(1000 lb/hr)

Total Heat 

Input 

(mmBtu/hr)

Calculated 

Emission Rate 

(lb/mmBtu)

Flue Gas 

Moisture 

(%)

Flue Gas 

CO2 (%)
Fuel Input 

Rate Fuel Type Units of Measure

Measurement 

Method

Fuel Input 

Rate

5.4 159590 315

4.4 152671 313

4.6 149447 314

Flue Gas 

Flow Rate 

(dscfm)

Flue Gas 

Temperature 

(F)

Fuel #1 Flue Gas 

O2 (%)
Fuel Type Units of 

Measure

Measurement 

Method Fuel Input Rate Fuel Type Units of Measure

Measurement 

Method

Fuel Input 

Rate

Fuel #2 Fuel #3
Fuel Type Units of 

Measure

Measurement 

Method

Fuel #4

Other Supporting Information
EIA Facility Code Facility Name Boiler ID

50951 Sunnyside Cogeneration Associates Unit 1

Run Number Test Start Date Test Start Time Test End Date
Measured Value 

(ppm) Basis (Wet or Dry) Test Method Used Test End Time

Hydrogen Chloride Emission Test Results
Data Flag (ADL, 

BDL, DDL)

Test Method 

Comments

Calculated 

Emission Rate 

(lb/mmBtu)

Flue Gas 

Moisture 

(%)

Flue Gas 

CO2 (%)

 Test Results

Steam Output 

(1000 lb/hr)

Total Heat 

Input 

(mmBtu/hr)
Fuel Input 

Rate Fuel Type Units of Measure

Measurement 

Method

Fuel Input 

Rate

Flue Gas 

Temperature 

(F)

Fuel #1 Flue Gas 

O2 (%)

Flue Gas 

Flow Rate 

(dscfm)
Fuel Type Units of 

Measure

Measurement 

Method Fuel Input Rate Fuel Type Units of Measure

Measurement 

Method

Fuel Input 

Rate

Fuel #2 Fuel #3
Fuel Type Units of 

Measure

Measurement 

Method

Fuel #4

Other Supporting Information
EIA Facility Code Facility Name Boiler ID

50951 Sunnyside Cogeneration Associates Unit 1

Run Number Test Start Date Test Start Time Test End Date
Measured Value 

(ppm) Basis (Wet or Dry) Test Method Used 

Hydrogen Flouride Emission Test Results

Test End Time
Data Flag (ADL, 

BDL, DDL)

Test Method 

Comments

Test Results

Steam Output 

(1000 lb/hr)

Total Heat 

Input 

(mmBtu/hr)

Calculated 

Emission Rate 

(lb/mmBtu)

Flue Gas 

Moisture (%)
Fuel Input 

Rate Fuel Type Units of Measure

Measurement 

Method

Flue Gas 

Flow Rate 

(dscfm)

Flue Gas 

Temperature 

(F)

Fuel #1 Flue Gas 

CO2 (%)

Flue Gas 

O2 (%)
Fuel Input 

Rate Fuel Type Units of Measure

Measurement 

Method Fuel Input Rate Fuel Type Units of Measure

Measurement 

Method

Fuel #2 Fuel #3
Fuel Input 

Rate Fuel Type Units of Measure

Measurement 

Method

Fuel #4

Other Supporting Information
EIA Facility Code Facility Name Boiler ID

50951 Sunnyside Cogeneration Associates Unit 1

Run Number Test Start Date Test Start Time
Measured NO (ppm) Test End Date Test End Time
Measured NO2

 (ppm) Basis (Wet or Dry) Test Method Used 

NOX Emission Test Results
Data Flag (ADL, BDL, DDL) Test Method Comments (lb/mmBtu)

Total NOX Calculated Emission Rate
ppmdv @ 7% O2

Flue Gas 

O2 (%)

 Calculated Emission Rate Steam Output 

(1000 lb/hr)

Total Heat Input 

(mmBtu/hr)

Flue Gas 

Moisture (%)

Flue Gas 

CO2 (%)
Fuel Input 

Rate Fuel Type Units of Measure

Measurement 

Method

Fuel Input 

Rate

Flue Gas 

Flow Rate 

(dscfm)

Flue Gas 

Temperature 

(F)

Fuel #1
Fuel Type Units of 

Measure

Measurement 

Method

Fuel Input 

Rate Fuel Type Units of Measure

Measurement 

Method

Fuel Input 

Rate

Fuel #2 Fuel #3
Fuel Type Units of 

Measure

Measurement 

Method

Fuel #4

Other Supporting Information
EIA Facility Code Facility Name Boiler ID

50951 Sunnyside Cogeneration Associates Unit 1

Run Number Test Start Date Test Start Time
Total Dissolved Solids 

(mg solids/liter)

Total Suspended Solids 

(mg solids/liter)

Test End Date Test End Time
Test Method Used Data Flag (ADL, 

BDL, DDL)

Constisuent Emission Test Results
Test Method Comments Fuel Input Rate

Flue Gas 

Temperat

ure (F)

Flue Gas 

Flow Rate 

(dscfm)

Steam Output 

(1000 lb/hr)

Total Heat Input 

(mmBtu/hr)
Fuel Type Units of 

Measure

Measurement 

Method Fuel Input Rate Fuel Type Units of Measure

Measurement 

Method Fuel Input Rate

Fuel #1 Fuel #2
Fuel Type Units of 

Measure

Measurement 

Method

Fuel Input 

Rate Fuel Type Units of Measure

Measurement 

Method

Fuel #3 Fuel #4
Other Supporting Information