### Name: Richard Carter

Title: Plant Manager Company: Sunnyside Cogeneration Associates Sign Date: 9/7/2010 Name: Chet Gutwein Title: Engineer Company:Airtech Environmental Services Inc. Sign Date: 9/7/2010 Permitted Facility Representative / Date Testing Company Representative / Date 

## Sunnyside Cogeneration Associates Unit 1

Final Test Report for

/ / Based on information and belief formed after reasonable inquiry, I certify that the statements and information in this test report are true, accurate, and complete. I have reviewed all testing details and results in this test report and hereby certify that the test report is authentic and accurate.

Friday, February 18, 2011 Page 1 of 31

### Sunnyside Cogeneration Associates Unit 1
9/7/2010 Facility Information: Sunnyside Cogeneration Associates
1 Power Plant Road

Sunnyside UT84539 Contact:Rusty Netz Phone: (435)888-4476 ext. 107 Fax: Email: rusnetz@hotmail.com Testing Company:
Airtech Environmental Services Inc.
5776 Lamar Street

Arvada CO80002 Contact:Jeff Johnson Phone:(303) 670-0530 Fax: (303) 670-4130 Email:jjohnson@airtechenv.com

Air Permit Number: 50951 Permitted Source ID/Name: Unit 1 1 Permitted Maximum Process Rate: N/A Max. Normal Operation Process Rate: N/A Target Process Test Rate N/A

Description of the source (including control equipment). Please see the attachments for source or process flow diagram: The Sunnyside Cogeneration Facility is a steam-electric generating power plant located in Sunnyside, Carbon County, Utah (approximately 25 miles southeast of Price). The plant consists of a circulating fluidized bed combustion boiler, an emergency backup diesel fire pump, diesel storage tanks, coal handling equipment, ash handling equipment, and limestone handling equipment. The boiler is fueled by coal refuse from the Sunnyside and Star Point Refuse Piles. The fly/bottom ash generated from the coal combustion is disposed of in an on site landfill and/or for beneficial use. Sunnyside is classified as a major source of air pollution with respect to PM10, sulfur dioxide (SO2), nitrogen oxide (NOx) and carbon monoxide (CO) emissions. Sunnyside is subject to 40 CFR 64 and 40 CFR 60, Subpart A, Subpart Kb (40 CFR 60.116b (a) and (b)), Subpart Db (40 CFR 60.40b), and Subpart Y (40 CFR 60.250). Industry/SCC/NAIS221112

Sampling Location Information:

Test Parameter Information: AFS #:4900700030 FRS #:110000470008

SCC / Description10100202 External Combustion Boilers - Electric Generation - Bituminous/Subbituminous Coal - Pulverized Coal: Dry Bottom (Bituminous Coal)

The following state and federal regulations that apply to the proposed testing:

Location Round

Duct Diam. Distance from upstream dist. Distance from

downstream dist. Number of

Traverse Ports Equiv. Diam Min.Travers Points Rect. Duct Length /Width Stack Exit 102 8 2 3 102 12 0 0

Target Parameter Test Method Number of

Test Runs Test Run

Duration Sample

Points Comments Location % H2O Method 1 - 4 3 180 0 Stack Exit Carbon Monoxide Method 10 3 120 0 Stack Exit



### Friday, February 18, 2011 Page 2 of 31

### Sunnyside Cogeneration Associates Unit 1
9/7/2010

The following describes any modifications and/or deviations to the applicable test methods. If alternative methods were requested, see the attachments for documentation of request AND approval, including dates. The following is a list of the test methods that are to be used for this test program and their respective promulgation dates:
Methods 1 through 29 – August 1997 Method 30B – January 2008 Other Test Methods 27 and 28 – April 2009

Total organic compounds (TOC) as Propane Method 25A 3 120 0 Stack Exit

Chlorine Method 26A 3 180 0 Stack Exit Hydrogen Chloride Method 26A 3 180 0 Stack Exit Hydrogen Fluoride Method 26A 3 180 0 Stack Exit Total Particulate OTM - 27/28 3 240 0 Use only for dry stacks. Delete Method 5/OTM28 tests. Stack Exit

Filterable Particulate OTM - 27/28 3 240 0 Use only for dry stacks. Delete Method 5/OTM28 tests. Stack Exit

Filterable PM2.5 OTM - 27/28 3 240 0 Use only for dry stacks. Delete Method 5/OTM28 tests. Stack Exit

Inorganic (Aqueous)

Condensible Part. OTM - 27/28 3 240 0 Use only for dry stacks. Delete Method 5/OTM28 tests. Stack Exit

Total PM2.5 OTM - 27/28 3 240 0 Use only for dry stacks. Delete Method 5/OTM28 tests. Stack Exit

Organic Condensible

Particulate OTM - 27/28 3 240 0 Use only for dry stacks. Delete Method 5/OTM28 tests. Stack Exit

Phosphorus (yellow or white)Method 29 3 240 0 Stack Exit Antimony Method 29 3 240 0 Stack Exit Arsenic Method 29 3 240 0 Stack Exit Beryllium Method 29 3 240 0 Stack Exit Cadmium Method 29 3 240 0 Stack Exit Chromium Method 29 3 240 0 Stack Exit Lead Method 29 3 240 0 Stack Exit Manganese Method 29 3 240 0 Stack Exit Nickel Method 29 3 240 0 Stack Exit Filterable Particulate Method 29 3 240 0 Stack Exit Cobalt Method 29 3 240 0 Stack Exit Selenium Method 29 3 240 0 Stack Exit O2 Method 3A O2 3 240 0 Stack Exit Co2 Method 3A CO2 3 240 0 Stack Exit Co2 Method 3A CO2 3 120 0 Stack Exit O2 Method 3A O2 3 120 0 Stack Exit O2 Method 3A O2 3 480 0 Stack Exit Co2 Method 3A CO2 3 480 0 Stack Exit Sulfur Dioxide Method 6C 3 180 0 Stack Exit Nitrogen oxides (NOx) Method 7E 3 180 0 Stack Exit



### Friday, February 18, 2011 Page 3 of 31

### Sunnyside Cogeneration Associates Unit 1
9/7/2010 Sampling / Stack Data Results Summary



### Location Stack Exit - Method 1 - 4 Average Run Number 1 2 3
Test Date 6/22/2010 6/22/2010 6/22/2010 Run Start Time 10:25:00 AM1:12:00 PM 3:52:00 PM Run Finish Time 12:37:00 PM3:30:00 PM 6:02:00 PM Net Run Time, minutes 120 120 120 Dry Gas Meter Volume Sampled, dscf 63.625 63.150 59.717 62.164 Moisture Content of Stack Gas, % 11.80 10.27 10.92 10.997 Moisture Saturation at Stack Gas Temperature, % 100.00 100.00 100.00 100.000 Carbon Dioxide, % 15 14.7 14.9 14.867 Oxygen, % 4.68 4.68 4.6 4.653 Average Stack Gas Temperature, °F 313.08 312.75 313.42 313.083 Dry Volumetric Flow Rate, dry scfm 146,051.3 145,955.0 145,365.8 145,790.700 Actual Wet Volumetric Flue Gas Flow Rate, acfm 304,414.2 298,898.6 300,124.3 301,145.700 Percent Isokinetic of Sampling Rate, % 104.6 103.9 98.7 102.400 F-Factor, dscfm/MMBtu @ %O2 10355 10355 10355 10,355.000
Fw 0 0 0 0.000
Fc 0 0 0 0.000



### Location Stack Exit - Method 10 Average Run Number NDF1 NDF2 NDF3
Test Date 6/22/2010 6/22/2010 6/22/2010 Run Start Time 11:57:00 AM1:44:00 PM 3:56:00 PM Run Finish Time 1:27:00 PM3:07:00 PM 5:50:00 PM Carbon Dioxide, % 14.7 14.7 14.9 14.767 Oxygen, % 4.68 4.68 4.6 4.653 Dry Volumetric Flow Rate, dry scfm 146100 145900 145300 145,766.667 F-Factor, dscfm/MMBtu @ %O2 10355 10355 10355 10,355.000 Moisture, % 11.8 10.3 11 11.033 Fuel Type Override Override Override
Fw 0 0 0 0.000
Fc 0 0 0 0.000



### Friday, February 18, 2011 Page 4 of 31

### Sunnyside Cogeneration Associates Unit 1
9/7/2010
Location Stack Exit - Method 25A Average Run Number NDF1 NDF2 NDF3
Test Date 6/22/2010 6/22/2010 6/22/2010 Run Start Time 11:57:00 AM1:44:00 PM 3:56:00 PM
Run Finish Time 1:27:00 PM3:07:00 PM 5:50:00 PM Carbon Dioxide, % 14.7 14.7 14.9 14.767 Oxygen, % 4.68 4.68 4.6 4.653 Dry Volumetric Flow Rate, dry scfm 146100 145900 145300 145,766.667 F-Factor, dscfm/MMBtu @ %O2 10355 10355 10355 10,355.000 Moisture, % 11.8 10.3 11 11.033 Fuel Type Override Override Override
Fw 0 0 0 0.000
Fc 0 0 0 0.000



### Location Stack Exit - Method 26A Average Run Number 1 2 3
Test Date 6/21/2010 6/22/2010 6/22/2010 Run Start Time 1:09:00 PM 10:25:00 AM 1:53:00 PM

Run Finish Time 4:32:00 PM1:40:00 PM 5:08:00 PM Net Run Time, minutes 180 180 180 Dry Gas Meter Volume Sampled, dscf 106.158 102.498 101.322 103.326 Moisture Content of Stack Gas, % 10.46 11.78 11.56 11.267 Moisture Saturation at Stack Gas Temperature, % 100.00 100.00 100.00 100.000 Carbon Dioxide, % 13.7 15 14.8 14.500 Oxygen, % 5.4 4.4 4.6 4.800 Average Stack Gas Temperature, °F 315.17 312.67 313.83 313.890 Dry Volumetric Flow Rate, dry scfm 159,596.2 152,684.6 149,497.7 153,926.167 Actual Wet Volumetric Flue Gas Flow Rate, acfm 328,553.6 317,999.0 311,053.4 319,202.000 Percent Isokinetic of Sampling Rate, % 106.5 107.5 108.5 107.500 F-Factor, dscfm/MMBtu @ %O2 10284 10355 10355 10,331.333
Fw 0 0 0 0.000
Fc 0 0 0 0.000



### Friday, February 18, 2011 Page 5 of 31

### Sunnyside Cogeneration Associates Unit 1
9/7/2010
Location Stack Exit - Method 29 Average Run Number 1 2 3
Test Date 6/21/2010 6/23/2010 6/24/2010 Run Start Time 1:11:00 AM 9:55:00 AM 8:00:00 AM

Run Finish Time 5:35:00 PM2:15:00 PM12:38:00 PM Net Run Time, minutes 240 240 240 Dry Gas Meter Volume Sampled, dscf 127.407 132.376 135.283 131.689 Moisture Content of Stack Gas, % 8.85 11.92 11.55 10.773 Moisture Saturation at Stack Gas Temperature, % 100.00 100.00 100.00 100.000 Carbon Dioxide, % 15.3 15.6 14.9 15.267 Oxygen, % 4.3 4.3 4.52 4.373 Average Stack Gas Temperature, °F 314.58 315.58 314.67 314.943 Dry Volumetric Flow Rate, dry scfm 151,975.0 153,435.2 152,346.5 152,585.567 Actual Wet Volumetric Flue Gas Flow Rate, acfm 307,103.9 322,765.6 320,109.9 316,659.800 Percent Isokinetic of Sampling Rate, % 100.7 103.6 106.6 103.633 F-Factor, dscfm/MMBtu @ %O2 10284 10233 10308 10,275.000
Fw 0 0 0 0.000
Fc 0 0 0 0.000



### Location Stack Exit - Method 3A CO2 Average Run Number A1 A2 A3
Test Date 6/21/2010 6/22/2010 6/22/2010 Run Start Time 12:48:00 PM 10:02:00 AM 2:47:00 PM

Run Finish Time 4:13:00 PM2:36:00 PM 5:50:00 PM Carbon Dioxide, % 13.7 15 14.8 14.500 Oxygen, % 5.4 4.4 4.6 4.800 Dry Volumetric Flow Rate, dry scfm 159590 152671 149447 153,902.667 F-Factor, dscfm/MMBtu @ %O2 10284 10355 10355 10,331.333 Moisture, % 10.5 11.8 11.6 11.300 Fuel Type Override Override Override
Fw 0 0 0 0.000
Fc 0 0 0 0.000



### Friday, February 18, 2011 Page 6 of 31

### Sunnyside Cogeneration Associates Unit 1
9/7/2010
Location Stack Exit - Method 3A CO2 3 Average Run Number M1 M2 M33
Test Date 6/21/2010 6/23/2010 6/24/2010 Run Start Time 12:48:00 PM 9:36:00 AM 7:56:00 AM

Run Finish Time 8:36:00 PM5:17:00 PM 4:01:00 PM Carbon Dioxide, % 15.3 15.6 14.9 15.267 Oxygen, % 4.26 4.33 4.52 4.370 Dry Volumetric Flow Rate, dry scfm 151955 153009 152310 152,424.667 F-Factor, dscfm/MMBtu @ %O2 10284 10233 10308 10,275.000 Moisture, % 8.87 12.2 11.6 10.890 Fuel Type Override Override Override
Fw 0 0 0 0.000
Fc 0 0 0 0.000



### Location Stack Exit - Method 3A CO2 3 6 Average Run Number NDF1 NDF2 NDF3
Test Date 6/22/2010 6/22/2010 6/22/2010 Run Start Time 11:57:00 AM1:44:00 PM 3:56:00 PM Run Finish Time 1:27:00 PM3:07:00 PM 5:50:00 PM Carbon Dioxide, % 14.7 14.7 14.9 14.767 Oxygen, % 4.68 4.68 4.6 4.653 Dry Volumetric Flow Rate, dry scfm 146100 145900 145300 145,766.667 F-Factor, dscfm/MMBtu @ %O2 10355 10355 10355 10,355.000 Moisture, % 11.8 10.3 11 11.033 Fuel Type Override Override Override
Fw 0 0 0 0.000
Fc 0 0 0 0.000



### Friday, February 18, 2011 Page 7 of 31

### Sunnyside Cogeneration Associates Unit 1
9/7/2010
Location Stack Exit - Method 3A O2 Average Run Number A1 A2 A3
Test Date 6/21/2010 6/22/2010 6/22/2010 Run Start Time 12:48:00 PM 10:02:00 AM 2:47:00 PM

Run Finish Time 4:13:00 PM2:36:00 PM 5:50:00 PM Carbon Dioxide, % 13.7 15 14.8 14.500 Oxygen, % 5.4 4.4 4.6 4.800 Dry Volumetric Flow Rate, dry scfm 159590 152671 149447 153,902.667 F-Factor, dscfm/MMBtu @ %O2 10284 10355 10355 10,331.333 Moisture, % 10.5 11.8 11.6 11.300 Fuel Type Override Override Override
Fw 0 0 0 0.000
Fc 0 0 0 0.000



### Location Stack Exit - Method 3A O2 3 Average Run Number M1 M2 M3
Test Date 6/21/2010 6/23/2010 6/24/2010 Run Start Time 12:48:00 PM 9:36:00 AM 7:56:00 AM

Run Finish Time 8:36:00 PM5:17:00 PM 4:01:00 PM Carbon Dioxide, % 15.3 15.6 14.9 15.267 Oxygen, % 4.26 4.33 4.52 4.370 Dry Volumetric Flow Rate, dry scfm 151955 153009 152310 152,424.667 F-Factor, dscfm/MMBtu @ %O2 10284 10233 10308 10,275.000 Moisture, % 8.87 12.2 11.6 10.890 Fuel Type Override Override Override
Fw 0 0 0 0.000
Fc 0 0 0 0.000



### Friday, February 18, 2011 Page 8 of 31

### Sunnyside Cogeneration Associates Unit 1
9/7/2010
Location Stack Exit - Method 3A O2 3 6 Average Run Number NDF1 NDF2 NDF3
Test Date 6/22/2010 6/22/2010 6/22/2010 Run Start Time 11:57:00 AM1:44:00 PM 3:56:00 PM
Run Finish Time 1:27:00 PM3:07:00 PM 5:50:00 PM Carbon Dioxide, % 14.7 14.7 14.9 14.767 Oxygen, % 4.68 4.68 4.6 4.653 Dry Volumetric Flow Rate, dry scfm 146100 145900 145300 145,766.667 F-Factor, dscfm/MMBtu @ %O2 10355 10355 10355 10,355.000 Moisture, % 11.8 10.3 11 11.033 Fuel Type Override Override Override
Fw 0 0 0 0.000
Fc 0 0 0 0.000



### Location Stack Exit - Method 6C Average Run Number A1 A2 A3
Test Date 6/21/2010 6/22/2010 6/22/2010 Run Start Time 12:48:00 PM 10:02:00 AM 2:47:00 PM

Run Finish Time 4:13:00 PM2:36:00 PM 5:50:00 PM Carbon Dioxide, % 13.7 15 14.8 14.500 Oxygen, % 5.4 4.4 4.6 4.800 Dry Volumetric Flow Rate, dry scfm 159590 152671 149447 153,902.667 F-Factor, dscfm/MMBtu @ %O2 10284 10355 10355 10,331.333 Moisture, % 10.5 11.8 11.6 11.300 Fuel Type Override Override Override
Fw 0 0 0.000
Fc 0 0 1420 473.333



### Friday, February 18, 2011 Page 9 of 31

### Sunnyside Cogeneration Associates Unit 1
9/7/2010
Location Stack Exit - Method 7E Average Run Number A1 A2 A3
Test Date 6/21/2010 6/22/2010 6/22/2010 Run Start Time 12:48:00 PM 10:02:00 AM 2:47:00 PM

Run Finish Time 4:13:00 PM2:36:00 PM 5:50:00 PM Carbon Dioxide, % 13.7 15 14.8 14.500 Oxygen, % 5.4 4.4 4.6 4.800 Dry Volumetric Flow Rate, dry scfm 159.59 152671 149447 100,759.197 F-Factor, dscfm/MMBtu @ %O2 10284 10355 10355 10,331.333 Moisture, % 10.5 11.8 11.6 11.300 Fuel Type Override Override Override
Fw 0 0 0 0.000
Fc 0 0 0 0.000



### Location Stack Exit - OTM - 27/28 Average Run Number 1 2 3
Test Date 6/21/2010 6/23/2010 6/24/2010 Run Start Time 12:58:00 PM 9:38:00 AM 8:20:00 AM

Run Finish Time 7:49:00 PM5:21:00 PM 4:15:00 PM Net Run Time, minutes 450 450 450 Dry Gas Meter Volume Sampled, dscf 139.233 145.189 141.794 142.072 Moisture Content of Stack Gas, % 8.98 11.62 11.31 10.637 Moisture Saturation at Stack Gas Temperature, % 100.00 100.00 100.00 100.000 Carbon Dioxide, % 15.3 15.6 14.9 15.267 Oxygen, % 4.3 4.3 4.52 4.373 Average Stack Gas Temperature, °F 314.58 315.08 316.17 315.277 Dry Volumetric Flow Rate, dry scfm 159,009.7 149,360.6 153,372.7 153,914.333 Actual Wet Volumetric Flue Gas Flow Rate, acfm 321,778.2 312,926.0 322,016.5 318,906.900 Percent Isokinetic of Sampling Rate, % 96.3 106.9 101.7 101.633 F-Factor, dscfm/MMBtu @ %O2 10284 10233 10308 10,275.000
Fw 0 0 0 0.000
Fc 0 0 0 0.000



### Friday, February 18, 2011 Page 10 of 31

### Sunnyside Cogeneration Associates Unit 1
9/7/2010 Emissions Summary



### Location: Stack Exit - Method 1 - 4 Compound: % H2O Average RunNumber 1 2 3 Mass_mg 180700 159600 155600 165,300.000



### Location: Stack Exit - Method 10 

### Compound: Carbon Monoxide Average Run NDF1 NDF2 NDF3 lb/mmBtuO2 3.42E-02 3.18E-02 3.18E-02 0.033 ppm 3.52E+01 3.28E+01 3.30E+01 33.667 ppm@7%O2 3.02E+01 2.81E+01 2.81E+01 28.800



### Location: Stack Exit - Method 25A 

### Compound: Total organic compounds (TOC) as Average Run NDF1 NDF2 NDF3 lb/mmBtuO2 7.64E-04 7.64E-04 7.60E-04 0.001 ppm 5.00E-01 5.00E-01 5.00E-01 0.500 ppm@7%O2 4.28E-01 4.28E-01 4.26E-01 0.427



### Location: Stack Exit - Method 26A Compound: Chlorine Average RunNumber 1 2 3 Mass_mg 52.36 54.245 56.73 54.445 Elb/hr 1.04E+01 1.07E+01 1.11E+01 10.733 lb/mmBtuO2 1.51E-02 1.53E-02 1.64E-02 0.016 mg/dscm 1.74E+01 1.87E+01 1.98E+01 18.633 mg/dscm@7%O2 1.56E+01 1.58E+01 1.69E+01 16.100 

### Compound: Hydrogen Chloride Average RunNumber 1 2 3 Mass_mg 53.8 55.8 58.3 55.967 Elb/hr 1.07E+01 1.10E+01 1.14E+01 11.033 lb/mmBtuO2 1.55E-02 1.57E-02 1.68E-02 0.016 mg/dscm 1.79E+01 1.92E+01 2.03E+01 19.133 mg/dscm@7%O2 1.61E+01 1.62E+01 1.73E+01 16.533 

### Compound: Hydrogen Fluoride Average RunNumber 1 2 3 Mass_mg 0.419 0.367 0.399 0.395 Elb/hr 8.33E-02 7.23E-02 7.79E-02 0.078 lb/mmBtuO2 1.21E-04 1.04E-04 1.15E-04 0.000 mg/dscm 1.39E-01 1.26E-01 1.39E-01 0.135 mg/dscm@7%O2 1.25E-01 1.06E-01 1.19E-01 0.117



### Friday, February 18, 2011 Page 11 of 31

### Sunnyside Cogeneration Associates Unit 1
9/7/2010 Location: Stack Exit - Method 29 

### Compound: Antimony Average RunNumber 1 2 3 Mass_mg 0.000346 0.000229 0.000727 0.000 Elb/hr 5.46E-05 3.51E-05 1.08E-04 0.000 lb/mmBtuO2 7.75E-08 4.91E-08 1.56E-07 0.000 mg/dscm 9.59E-05 6.11E-05 1.90E-04 0.000 mg/dscm@7%O2 8.03E-05 5.12E-05 1.61E-04 0.000 

### Compound: Arsenic Average RunNumber 1 2 3 Mass_mg 0.000425 0.000474 0.000487 0.000 Elb/hr 6.71E-05 7.27E-05 7.25E-05 0.000 lb/mmBtuO2 9.52E-08 1.02E-07 1.04E-07 0.000 mg/dscm 1.18E-04 1.26E-04 1.27E-04 0.000 mg/dscm@7%O2 9.88E-05 1.06E-04 1.08E-04 0.000 

### Compound: Beryllium Average RunNumber 1 2 3 Mass_mg 0.000086 0.00014 0.000115 0.000 Elb/hr 1.36E-05 2.15E-05 1.71E-05 0.000 lb/mmBtuO2 1.93E-08 3.00E-08 2.46E-08 0.000 mg/dscm 2.38E-05 3.74E-05 3.00E-05 0.000 mg/dscm@7%O2 1.99E-05 3.13E-05 2.55E-05 0.000 

### Compound: Cadmium Average RunNumber 1 2 3 Mass_mg 0.0036 0.00555 0.00338 0.004 Elb/hr 5.68E-04 8.51E-04 5.03E-04 0.001 lb/mmBtuO2 8.07E-07 1.19E-06 7.24E-07 0.000 mg/dscm 9.98E-04 1.48E-03 8.82E-04 0.001 mg/dscm@7%O2 8.36E-04 1.24E-03 7.48E-04 0.001 

### Compound: Chromium Average RunNumber 1 2 3 Mass_mg 0.00339 0.0145 0.00249 0.007 Elb/hr 5.35E-04 2.22E-03 3.71E-04 0.001 lb/mmBtuO2 7.60E-07 3.11E-06 5.34E-07 0.000 mg/dscm 9.40E-04 3.87E-03 6.50E-04 0.002 mg/dscm@7%O2 7.87E-04 3.24E-03 5.52E-04 0.002 

### Compound: Cobalt Average RunNumber 1 2 3 Mass_mg 0.000334 0.000531 0.000394 0.000 Elb/hr 5.27E-05 8.14E-05 5.87E-05 0.000 lb/mmBtuO2 7.48E-08 1.14E-07 8.44E-08 0.000 mg/dscm 9.26E-05 1.42E-04 1.03E-04 0.000



### Friday, February 18, 2011 Page 12 of 31

### Sunnyside Cogeneration Associates Unit 1
9/7/2010 mg/dscm@7%O2 7.75E-05 1.19E-04 8.74E-05 0.000 

### Compound: Filterable Particulate Average RunNumber 1 2 3 Mass_mg 16.6 21.4 26 21.333 Elb/hr 2.62E+00 3.28E+00 3.87E+00 3.257 lb/mmBtuO2 3.72E-03 4.59E-03 5.57E-03 0.005 mg/dscm 4.60E+00 5.71E+00 6.79E+00 5.700 mg/dscm@7%O2 3.85E+00 4.78E+00 5.76E+00 4.797 

### Compound: Lead Average RunNumber 1 2 3 Mass_mg 0.00173 0.00132 0.00131 0.001 Elb/hr 2.73E-04 2.02E-04 1.95E-04 0.000 lb/mmBtuO2 3.88E-07 2.83E-07 2.81E-07 0.000 mg/dscm 4.80E-04 3.52E-04 3.42E-04 0.000 mg/dscm@7%O2 4.02E-04 2.95E-04 2.90E-04 0.000 

### Compound: Manganese Average RunNumber 1 2 3 Mass_mg 0.00313 0.00509 0.00352 0.004 Elb/hr 4.94E-04 7.80E-04 5.24E-04 0.001 lb/mmBtuO2 7.01E-07 1.09E-06 7.54E-07 0.000 mg/dscm 8.68E-04 1.36E-03 9.19E-04 0.001 mg/dscm@7%O2 7.27E-04 1.14E-03 7.80E-04 0.001 

### Compound: Nickel Average RunNumber 1 2 3 Mass_mg 0.00175 0.00371 0.00224 0.003 Elb/hr 2.76E-04 5.69E-04 3.34E-04 0.000 lb/mmBtuO2 3.92E-07 7.96E-07 4.80E-07 0.000 mg/dscm 4.85E-04 9.90E-04 5.85E-04 0.001 mg/dscm@7%O2 4.06E-04 8.29E-04 4.96E-04 0.001 

### Compound: Phosphorus (yellow or white) Average RunNumber 1 2 3 Mass_mg 0.238 0.257 0.24 0.245 Elb/hr 3.76E-02 3.94E-02 3.58E-02 0.038 lb/mmBtuO2 5.33E-05 5.51E-05 5.14E-05 0.000 mg/dscm 6.60E-02 6.86E-02 6.27E-02 0.066 mg/dscm@7%O2 5.53E-02 5.74E-02 5.32E-02 0.055 

### Compound: Selenium Average RunNumber 1 2 3 Mass_mg 0.0002 0.000216 0.000229 0.000 Elb/hr 3.16E-05 3.31E-05 3.41E-05 0.000 lb/mmBtuO2 4.48E-08 4.63E-08 4.91E-08 0.000 mg/dscm 5.54E-05 5.76E-05 5.98E-05 0.000


### Friday, February 18, 2011 Page 13 of 31

### Sunnyside Cogeneration Associates Unit 1
9/7/2010 mg/dscm@7%O2 4.64E-05 4.82E-05 5.07E-05 0.000



### Location: Stack Exit - Method 6C Compound: Sulfur Dioxide Average Run A1 A2 A3 Elb/hr 1.22E+02 1.29E+02 1.23E+02 124.667 lb/mmBtuO2 1.77E-01 1.85E-01 1.83E-01 0.182 mg/dscm 2.04E+02 2.26E+02 2.21E+02 217.000 mg/dscm@7%O2 1.83E+02 1.90E+02 1.88E+02 187.000 ppm 7.66E+01 8.48E+01 8.28E+01 81.400 ppm@7%O2 6.87E+01 7.14E+01 7.06E+01 70.233



### Location: Stack Exit - Method 7E 

### Compound: Nitrogen oxides (NOx) Average Run A1 A2 A3 Elb/hr 1.17E-01 1.23E+02 1.27E+02 83.372 lb/mmBtuO2 1.70E-01 1.77E-01 1.88E-01 0.178 mg/dscm 1.96E+02 2.16E+02 2.27E+02 213.000 mg/dscm@7%O2 1.76E+02 1.82E+02 1.94E+02 184.000 ppm 1.03E+02 1.13E+02 1.19E+02 111.667 ppm@7%O2 9.24E+01 9.52E+01 1.01E+02 96.200



### Location: Stack Exit - OTM - 27/28 Compound: Filterable Particulate Average RunNumber 1 2 3 Mass_mg 8.9 15.8 12.5 12.400 lb/mmBtuO2 1.82E-03 3.09E-03 2.56E-03 0.002 

### Compound: Filterable PM2.5 Average RunNumber 1 2 3 Mass_mg 0.2 0 0 0.067 lb/mmBtuO2 4.10E-05 0.00E+00 0.00E+00 0.000 

### Compound: Inorganic (Aqueous) Condensible Pa Average RunNumber 1 2 3 Mass_mg 6.9 9.1 10.5 8.833 lb/mmBtuO2 1.41E-03 1.78E-03 2.15E-03 0.002 

### Compound: Organic Condensible Particulate Average RunNumber 1 2 3 Mass_mg 4.6 3.5 4.4 4.167 lb/mmBtuO2 9.43E-04 6.85E-04 9.00E-04 0.001 

### Compound: Total Particulate Average RunNumber 1 2 3



### Friday, February 18, 2011 Page 14 of 31

### Sunnyside Cogeneration Associates Unit 1
9/7/2010

Process Run Data Mass_mg 20.4 28.4 27.4 25.400 lb/mmBtuO2 4.18E-03 5.56E-03 5.60E-03 0.005 

### Compound: Total PM2.5 Average RunNumber 1 2 3 Mass_mg 11.7 12.6 14.9 13.067 lb/mmBtuO2 2.40E-03 2.46E-03 3.05E-03 0.003



### Friday, February 18, 2011 Page 15 of 31

### Sunnyside Cogeneration Associates Unit 1
9/7/2010 Process Run Data

APCD Run Data 

### Run Name Value UOM Comments Target Value 1 Coal Firing Rate 51.04 tons/hr 50


### 2 Coal Firing Rate 49.5 tons/hr 50
3 Coal Firing Rate 49.52 tons/hr 50
4 Coal Firing Rate 51.2 tons/hr 50


### 1 Average Heat Input 9.014 MMBtu/hr 9
2 Average Heat Input 10.006 MMBtu/hr 9
3 Average Heat Input 11.201 MMBtu/hr 9


### 4 Average Heat Input 10.883 MMBtu/hr 9
1 Steam Output 4601000 lb steam/hr 480
2 Steam Output 473.961000 lb steam/hr 480


### 3 Steam Output 475.351000 lb steam/hr 480
4 Steam Output 469.981000 lb steam/hr 480
1 Flue Gas Oxygen Content 4.45 % 4.5


### 2 Flue Gas Oxygen Content 4.58 % 4.5
3 Flue Gas Oxygen Content 4.5 % 4.5
4 Flue Gas Oxygen Content 4.48 % 4.5


### 1 Unit Gross Electrical Output 58 MW 58
2 Unit Gross Electrical Output 58.32 MW 58
3 Unit Gross Electrical Output 58.24 MW 58


### 4 Unit Gross Electrical Output 58.32 MW 58
1 Unit Net Electric Generation 51.3 MWh 51
2 Unit Net Electric Generation 51.86 MWh 51


### 3 Unit Net Electric Generation 51.8 MWh 51
4 Unit Net Electric Generation 51.85 MWh 51


### 1 Sorbent Injection Rate 3.68 tons/hr 4
2 Sorbent Injection Rate 4.21 tons/hr 4
3 Sorbent Injection Rate 4.71 tons/hr 4


### 4 Sorbent Injection Rate 4.43 tons/hr 4

Run Name Value UOM Comments Target Value 1 List all emissions control devices in order of process flow. Choose from 0 0



### Friday, February 18, 2011 Page 16 of 31

### Sunnyside Cogeneration Associates Unit 1
9/7/2010

Process Lab Run Data 1 drop down lists. If not on list add description and provide detailed 0 0



### 1 desription in section 5a. 0 0

Run Name Value UOM Comments 1 See 4b Comments. 0



### Friday, February 18, 2011 Page 17 of 31

### Sunnyside Cogeneration Associates Unit 1
9/7/2010 Sampling / Stack Data Results Detail



### Location Stack Exit - Method 1 - 4 Average Run Number 1 2 3 Test Date 6/22/2010 6/22/2010 6/22/2010 Run Start Time 10:25:00 AM 1:12:00 PM 3:52:00 PM Run Finish Time 12:37:00 PM 3:30:00 PM 6:02:00 PM Net Traversing Points 12 12 12 Net Run Time, minutes 120 120 120 Nozzle Diameter, inches 0.19 0.19 0.19 0.190 Pitot Tube Coefficient 0.84 0.84 0.84 0.840 Dry Gas Meter Calibration Factor 0.9888 0.9888 0.9888 0.989 Barometric Pressure, inches of Mercury 23.89 23.89 23.89 23.890 Average Orifice Meter Differential, inches H2O 1.13 1.09 1.09 1.103 Dry Gas Meter Volume Sampled, cubic feet 81.150 82.630 78.300 80.693 Average Dry Gas Meter Temperature, °F 73.54 87.29 88.42 83.083 Dry Gas Meter Volume Sampled, dscf 63.625 63.150 59.717 62.164 Total Moisture Liquid collected, g 180.7 153.6 155.6 163.300 Volume of Water Vapor, standard cubic feet 8.51 7.23 7.32 7.687 Moisture Content of Stack Gas, % 11.80 10.27 10.92 10.997 Moisture Saturation at Stack Gas Temperature, % 100.00 100.00 100.00 100.000 Dry Mole Fraction 0.882 0.8973 0.8908 0.890 Carbon Dioxide, % 15 14.7 14.9 14.867 Oxygen, % 4.68 4.68 4.6 4.653 Carbon Monoxide & Nitrogen, % 80.32 80.62 80.5 80.480 Fuel Factor 1.08 1.10 1.09 Dry Molecular Weight, lb/lb-Mole 30.59 30.54 30.57 30.567 Wet Molecular weight, lb/lb-Mole 29.10 29.25 29.20 29.183 Flue Gas Static Pressure, inches of H2O -0.8 -0.8 -0.8 -0.800 Absolute Flue Gas Pressure, inches of Mercury 23.83 23.83 23.83 23.830 Average Stack Gas Temperature, °F 313.08 312.75 313.42 313.083 Average Velocity Head, inches of H2O 1.3906337263 64871.348221166

106661.355690518

7627 1.365
Average Stack Gas Velocity, feet/second 89.41 87.79 88.15 88.450 Stack Cross-Sectional Area, square feet 56.745 56.745 56.745 56.745 Dry Volumetric Flow Rate, dry scfm 146,051.3 145,955.0 145,365.8145,790.700 Actual Wet Volumetric Flue Gas Flow Rate, acfm 304,414.2 298,898.6 300,124.3301,145.700 Percent Isokinetic of Sampling Rate, % 104.6 103.9 98.7 102.400 Percent Excess Air, % 28.3 28.2 27.6 28.033 F-Factor, dscfm/MMBtu @ %O2 10355 10355 1035510,355.000 Round Duct Diameter, inches 102 102 102 Rectangular Duct Width, inches 0 0 0 Rectangular Duct Length, inches 0 0 0 Fw 0 0 0 0.000 Fc 0 0 0 0.000



### Friday, February 18, 2011 Page 18 of 31

### Sunnyside Cogeneration Associates Unit 1
9/7/2010
Location Stack Exit - Method 10 Average Run Number NDF1 NDF2 NDF3 Test Date 6/22/2010 6/22/2010 6/22/2010 Run Start Time 11:57:00 AM 1:44:00 PM 3:56:00 PM Run Finish Time 1:27:00 PM 3:07:00 PM 5:50:00 PM Carbon Dioxide, % 14.7 14.7 14.9 14.767 Oxygen, % 4.68 4.68 4.6 4.653 Fuel Factor 1.1 1.1 1.09 Dry Volumetric Flow Rate, dry scfm 146100 145900 145300145,766.667 F-Factor, dscfm/MMBtu @ %O2 10355 10355 1035510,355.000 Moisture, % 11.8 10.3 11 11.033 Analyzer Make Analyzer Model Analyzer Serial Number Operating Range 1000 1000 1000 1,000.000 Operating Units ppm ppm ppm No. Readings/Avg. 60 60 60 60.000 Calibration Set 100 100 100 100.000 Calibration Pre Zero Cylinder ID 00-Zero 00-Zero 00-Zero Calibration Pre Zero Cylinder Instrument Response 0.3 -0.2 -0.4 -0.100 Calibration Pre Zero Cylinder Bias 0.3 -0.2 -0.39 -0.097 Calibration Pre Zero Cylinder Drift 0 0 0 0.000 Calibration Pre High Cylinder ID XC030124BCOXC030124BCOXC030124BCO Calibration Pre High Cylinder Instrument Response 48.6 48.3 48 48.300 Calibration Pre High Cylinder Bias -0.39 -0.69 -0.99 -0.690 Calibration Pre High Cylinder Drift 0 0 0 0.000 Calibration Post Zero Cylinder ID 00-Zero 00-Zero 00-Zero Calibration Post Zero Cylinder Instrument Response -0.2 -0.4 -0.4 -0.333 Calibration Post Zero Cylinder Bias -0.2 -0.39 -0.39 -0.327 Calibration Post Zero Cylinder Drift 0.5 0.19 0 0.230 Calibration Post High Cylinder ID XC030124BCOXC030124BCOXC030124BCO Calibration Post High Cylinder Instrument Response 48.3 48 47.6 47.967 Calibration Post High Cylinder Bias -0.69 -0.99 -1.38 -1.020 Calibration Post High Cylinder Drift 0.3 0.3 0.39 0.330 Cavg 34.6 31.9 31.8 32.767 Cavg Units ppmvd ppmvd ppmvd Cgas 35.2496 32.8181 32.9883 33.685 Cgas Units ppmvd ppmvd ppmvd Fuel Type Override Override Override Fw 0 0 0 0.000 Fc 0 0 0 0.000 Cgasw 0 0 0 0.000 Cgasw Units



### Friday, February 18, 2011 Page 19 of 31

### Sunnyside Cogeneration Associates Unit 1
9/7/2010
Location Stack Exit - Method 25A Average Run Number NDF1 NDF2 NDF3 Test Date 6/22/2010 6/22/2010 6/22/2010 Run Start Time 11:57:00 AM 1:44:00 PM 3:56:00 PM Run Finish Time 1:27:00 PM 3:07:00 PM 5:50:00 PM Carbon Dioxide, % 14.7 14.7 14.9 14.767 Oxygen, % 4.68 4.68 4.6 4.653 Fuel Factor 1.1 1.1 1.09 Dry Volumetric Flow Rate, dry scfm 146100 145900 145300145,766.667 F-Factor, dscfm/MMBtu @ %O2 10355 10355 1035510,355.000 Moisture, % 11.8 10.3 11 11.033 Analyzer Make Analyzer Model Analyzer Serial Number Operating Range 1000 1000 1000 1,000.000 Operating Units ppm ppm ppm No. Readings/Avg. 60 60 60 60.000 Calibration Set 25 25 25 25.000 Calibration Pre Zero Cylinder ID 00-Zero 00-Zero 00-Zero Calibration Pre Zero Cylinder Instrument Response 0 0 0 0.000 Calibration Pre Zero Cylinder Bias -0.3 0 0 -0.100 Calibration Pre Zero Cylinder Drift 0 0 0 0.000 Calibration Pre High Cylinder ID CC52193- Propane CC52193-

Propane CC52193-

Propane Calibration Pre High Cylinder Instrument Response 30.15 30.15 30.15 30.150 Calibration Pre High Cylinder Bias 0.65 0 0 0.217 Calibration Pre High Cylinder Drift 0 0 0 0.000 Calibration Post Zero Cylinder ID 00-Zero 00-Zero 00-Zero Calibration Post Zero Cylinder Instrument Response 0 0 0 0.000 Calibration Post Zero Cylinder Bias -0.3 0 0 -0.100 Calibration Post Zero Cylinder Drift 0 0 0 0.000 Calibration Post High Cylinder ID CC52193- Propane CC52193-

Propane CC52193-

Propane Calibration Post High Cylinder Instrument Response 30.15 30.15 30.15 30.150 Calibration Post High Cylinder Bias 0.65 0 0 0.217 Calibration Post High Cylinder Drift 0 0 0 0.000 Cavg 0.5 0.5 0.5 0.500 Cavg Units ppmvd ppmvd ppmvd Cgas 0.5 0.5 0.5 0.500 Cgas Units ppmvd ppmvd ppmvd Fuel Type Override Override Override Fw 0 0 0 0.000 Fc 0 0 0 0.000 Cgasw 0 0 0 0.000 Cgasw Units ppmvw



### Friday, February 18, 2011 Page 20 of 31

### Sunnyside Cogeneration Associates Unit 1
9/7/2010
Location Stack Exit - Method 26A Average Run Number 1 2 3 Test Date 6/21/2010 6/22/2010 6/22/2010 Run Start Time 1:09:00 PM10:25:00 AM 1:53:00 PM Run Finish Time 4:32:00 PM 1:40:00 PM 5:08:00 PM Net Traversing Points 12 12 12 Net Run Time, minutes 180 180 180 Nozzle Diameter, inches 0.19 0.19 0.19 0.190 Pitot Tube Coefficient 0.84 0.84 0.84 0.840 Dry Gas Meter Calibration Factor 1.0163 1.0163 1.0163 1.016 Barometric Pressure, inches of Mercury 23.89 23.89 23.89 23.890 Average Orifice Meter Differential, inches H2O 1.32 1.27 1.21 1.267 Dry Gas Meter Volume Sampled, cubic feet 135.340 128.600 129.640 131.193 Average Dry Gas Meter Temperature, °F 88.46 79.67 90.25 86.127 Dry Gas Meter Volume Sampled, dscf 106.158 102.498 101.322 103.326 Total Moisture Liquid collected, g 263.4 290.6 281.6 278.533 Volume of Water Vapor, standard cubic feet 12.40 13.68 13.25 13.110 Moisture Content of Stack Gas, % 10.46 11.78 11.56 11.267 Moisture Saturation at Stack Gas Temperature, % 100.00 100.00 100.00 100.000 Dry Mole Fraction 0.8954 0.8822 0.8844 0.887 Carbon Dioxide, % 13.7 15 14.8 14.500 Oxygen, % 5.4 4.4 4.6 4.800 Carbon Monoxide & Nitrogen, % 80.9 80.6 80.6 80.700 Fuel Factor 1.13 1.10 1.10 Dry Molecular Weight, lb/lb-Mole 30.41 30.58 30.55 30.513 Wet Molecular weight, lb/lb-Mole 29.11 29.10 29.10 29.103 Flue Gas Static Pressure, inches of H2O -0.8 -0.8 -0.8 -0.800 Absolute Flue Gas Pressure, inches of Mercury 23.83 23.83 23.83 23.830 Average Stack Gas Temperature, °F 315.17 312.67 313.83 313.890 Average Velocity Head, inches of H2O 1.6159320778 5921.518264484

215291.450410579

15667 1.528
Average Stack Gas Velocity, feet/second 96.50 93.40 91.36 93.753 Stack Cross-Sectional Area, square feet 56.745 56.745 56.745 56.745 Dry Volumetric Flow Rate, dry scfm 159,596.2 152,684.6 149,497.7153,926.167 Actual Wet Volumetric Flue Gas Flow Rate, acfm 328,553.6 317,999.0 311,053.4319,202.000 Percent Isokinetic of Sampling Rate, % 106.5 107.5 108.5 107.500 Percent Excess Air, % 33.8 26.1 27.6 29.167 F-Factor, dscfm/MMBtu @ %O2 10284 10355 1035510,331.333 Round Duct Diameter, inches 102 102 102 Rectangular Duct Width, inches 0 0 0 Rectangular Duct Length, inches 0 0 0 Fw 0 0 0 0.000 Fc 0 0 0 0.000



### Friday, February 18, 2011 Page 21 of 31

### Sunnyside Cogeneration Associates Unit 1
9/7/2010
Location Stack Exit - Method 29 Average Run Number 1 2 3 Test Date 6/21/2010 6/23/2010 6/24/2010 Run Start Time 1:11:00 AM9:55:00 AM 8:00:00 AM Run Finish Time 5:35:00 PM2:15:00 PM12:38:00 PM Net Traversing Points 12 12 12 Net Run Time, minutes 240 240 240 Nozzle Diameter, inches 0.19 0.19 0.19 0.190 Pitot Tube Coefficient 0.84 0.84 0.84 0.840 Dry Gas Meter Calibration Factor 0.9888 1.0163 1.0163 1.007 Barometric Pressure, inches of Mercury 23.89 23.78 23.68 23.783 Average Orifice Meter Differential, inches H2O 1.13 1.28 1.25 1.220 Dry Gas Meter Volume Sampled, cubic feet 164.660 168.030 171.770 168.153 Average Dry Gas Meter Temperature, °F 80.63 83.50 81.33 81.820 Dry Gas Meter Volume Sampled, dscf 127.407 132.376 135.283 131.689 Total Moisture Liquid collected, g 262.9 380.5 375.3 339.567 Volume of Water Vapor, standard cubic feet 12.37 17.91 17.67 15.983 Moisture Content of Stack Gas, % 8.85 11.92 11.55 10.773 Moisture Saturation at Stack Gas Temperature, % 100.00 100.00 100.00 100.000 Dry Mole Fraction 0.9115 0.8808 0.8845 0.892 Carbon Dioxide, % 15.3 15.6 14.9 15.267 Oxygen, % 4.3 4.3 4.52 4.373 Carbon Monoxide & Nitrogen, % 80.4 80.1 80.58 80.360 Fuel Factor 1.08 1.06 1.10 Dry Molecular Weight, lb/lb-Mole 30.62 30.67 30.56 30.617 Wet Molecular weight, lb/lb-Mole 29.50 29.16 29.11 29.257 Flue Gas Static Pressure, inches of H2O -0.8 -0.8 -0.8 -0.800 Absolute Flue Gas Pressure, inches of Mercury 23.83 23.72 23.62 23.723 Average Stack Gas Temperature, °F 314.58 315.58 314.67 314.943 Average Velocity Head, inches of H2O 1.4317440019 45291.554327040

780971.521293974

38933 1.502
Average Stack Gas Velocity, feet/second 90.20 94.80 94.02 93.007 Stack Cross-Sectional Area, square feet 56.745 56.745 56.745 56.745 Dry Volumetric Flow Rate, dry scfm 151,975.0 153,435.2 152,346.5152,585.567 Actual Wet Volumetric Flue Gas Flow Rate, acfm 307,103.9 322,765.6 320,109.9316,659.800 Percent Isokinetic of Sampling Rate, % 100.7 103.6 106.6 103.633 Percent Excess Air, % 25.4 25.5 27.0 25.967 F-Factor, dscfm/MMBtu @ %O2 10284 10233 1030810,275.000 Round Duct Diameter, inches 102 102 102 Rectangular Duct Width, inches 0 0 0 Rectangular Duct Length, inches 0 0 0 Fw 0 0 0 0.000 Fc 0 0 0 0.000



### Friday, February 18, 2011 Page 22 of 31

### Sunnyside Cogeneration Associates Unit 1
9/7/2010
Location Stack Exit - Method 3A CO2 Average Run Number A1 A2 A3 Test Date 6/21/2010 6/22/2010 6/22/2010 Run Start Time 12:48:00 PM10:02:00 AM 2:47:00 PM Run Finish Time 4:13:00 PM2:36:00 PM 5:50:00 PM Carbon Dioxide, % 13.7 15 14.8 14.500 Oxygen, % 5.4 4.4 4.6 4.800 Fuel Factor 1.13 1.1 1.1 Dry Volumetric Flow Rate, dry scfm 159590 152671 149447153,902.667 F-Factor, dscfm/MMBtu @ %O2 10284 10355 1035510,331.333 Moisture, % 10.5 11.8 11.6 11.300 Analyzer Make Analyzer Model Analyzer Serial Number Operating Range 25 25 25 25.000 Operating Units % % % No. Readings/Avg. 60 60 60 60.000 Calibration Set 30 31 31 30.667 Calibration Pre Zero Cylinder ID 00-Zero 00-Zero 00-Zero Calibration Pre Zero Cylinder Instrument Response 0 0.5 0.5 0.333 Calibration Pre Zero Cylinder Bias 0 4.3 4.3 2.867 Calibration Pre Zero Cylinder Drift 0 0 0 0.000 Calibration Pre High Cylinder ID CC152301- CO2 CC152301-

CO2 CC152301-

CO2 Calibration Pre High Cylinder Instrument Response 14 13.8 13.9 13.900 Calibration Pre High Cylinder Bias 1.22 0.22 0.93 0.790 Calibration Pre High Cylinder Drift 0 0 0 0.000 Calibration Post Zero Cylinder ID 00-Zero 00-Zero 00-Zero Calibration Post Zero Cylinder Instrument Response -0.4 0.5 0.4 0.167 Calibration Post Zero Cylinder Bias -2.87 4.3 3.58 1.670 Calibration Post Zero Cylinder Drift 2.87 0 0.72 1.197 Calibration Post High Cylinder ID CC152301- CO2 CC152301-

CO2 CC152301-

CO2 Calibration Post High Cylinder Instrument Response 14 13.9 14 13.967 Calibration Post High Cylinder Bias 1.22 0.93 1.65 1.267 Calibration Post High Cylinder Drift 0 0.71 0.72 0.477 Cavg 13.7 14.9 14.8 14.467 Cavg Units %vd %vd %vd Cgas 13.6553 15.0472 14.8283 14.510 Cgas Units %vd %vd %vd Fuel Type Override Override Override Fw 0 0 0 0.000 Fc 0 0 0 0.000 Cgasw 0 0 0 0.000 Cgasw Units



### Friday, February 18, 2011 Page 23 of 31

### Sunnyside Cogeneration Associates Unit 1
9/7/2010
Location Stack Exit - Method 3A CO2 3 Average Run Number M1 M2 M33 Test Date 6/21/2010 6/23/2010 6/24/2010 Run Start Time 12:48:00 PM9:36:00 AM 7:56:00 AM Run Finish Time 8:36:00 PM 5:17:00 PM 4:01:00 PM Carbon Dioxide, % 15.3 15.6 14.9 15.267 Oxygen, % 4.26 4.33 4.52 4.370 Fuel Factor 1.09 1.06 1.1 Dry Volumetric Flow Rate, dry scfm 151955 153009 152310152,424.667 F-Factor, dscfm/MMBtu @ %O2 10284 10233 1030810,275.000 Moisture, % 8.87 12.2 11.6 10.890 Analyzer Make Analyzer Model Analyzer Serial Number Operating Range 25 25 25 25.000 Operating Units % % % No. Readings/Avg. 60 60 60 60.000 Calibration Set 30 32 33 31.667 Calibration Pre Zero Cylinder ID 00-Zero 00-Zero 00-Zero Calibration Pre Zero Cylinder Instrument Response 0 0 0 0.000 Calibration Pre Zero Cylinder Bias 0 0.72 -0.72 0.000 Calibration Pre Zero Cylinder Drift 0 0 0 0.000 Calibration Pre High Cylinder ID CC152301- CO2 CC152301-

CO2 CC152301-

CO2 Calibration Pre High Cylinder Instrument Response 13.6 14 14 13.867 Calibration Pre High Cylinder Bias -1.65 0.72 0 -0.310 Calibration Pre High Cylinder Drift 0 0 0 0.000 Calibration Post Zero Cylinder ID 00-Zero 00-Zero 00-Zero Calibration Post Zero Cylinder Instrument Response -0.5 0.2 0 -0.100 Calibration Post Zero Cylinder Bias -3.58 2.15 -0.72 -0.717 Calibration Post Zero Cylinder Drift 3.58 1.43 0 1.670 Calibration Post High Cylinder ID CC152301- CO2 CC152301-

CO2 CC152301-

CO2 Calibration Post High Cylinder Instrument Response 13.3 13.8 14 13.700 Calibration Post High Cylinder Bias -3.8 -0.72 0 -1.507 Calibration Post High Cylinder Drift 2.15 1.44 0 1.197 Cavg 14.7 15.2 14.8 14.900 Cavg Units %vd %vd %vd Cgas 15.2228 15.2641 14.7471 15.078 Cgas Units %vd %vd %vd Fuel Type Override Override Override Fw 0 0 0 0.000 Fc 0 0 0 0.000 Cgasw 0 0 0 0.000 Cgasw Units



### Friday, February 18, 2011 Page 24 of 31

### Sunnyside Cogeneration Associates Unit 1
9/7/2010
Location Stack Exit - Method 3A CO2 3 6 Average Run Number NDF1 NDF2 NDF3 Test Date 6/22/2010 6/22/2010 6/22/2010 Run Start Time 11:57:00 AM 1:44:00 PM 3:56:00 PM Run Finish Time 1:27:00 PM 3:07:00 PM 5:50:00 PM Carbon Dioxide, % 14.7 14.7 14.9 14.767 Oxygen, % 4.68 4.68 4.6 4.653 Fuel Factor 1.1 1.1 1.09 Dry Volumetric Flow Rate, dry scfm 146100 145900 145300145,766.667 F-Factor, dscfm/MMBtu @ %O2 10355 10355 1035510,355.000 Moisture, % 11.8 10.3 11 11.033 Analyzer Make Analyzer Model Analyzer Serial Number Operating Range 25 25 25 25.000 Operating Units % % % No. Readings/Avg. 60 60 60 60.000 Calibration Set 31 31 31 31.000 Calibration Pre Zero Cylinder ID 00-Zero 00-Zero 00-Zero Calibration Pre Zero Cylinder Instrument Response 0.5 0.1 0.2 0.267 Calibration Pre Zero Cylinder Bias 4.3 1.43 2.15 2.627 Calibration Pre Zero Cylinder Drift 0 0 0 0.000 Calibration Pre High Cylinder ID CC152301- CO2 CC152301-

CO2 CC152301-

CO2 Calibration Pre High Cylinder Instrument Response 13.8 14 13.8 13.867 Calibration Pre High Cylinder Bias 0.22 1.65 0.22 0.697 Calibration Pre High Cylinder Drift 0 0 0 0.000 Calibration Post Zero Cylinder ID 00-Zero 00-Zero 00-Zero Calibration Post Zero Cylinder Instrument Response 0.1 0.2 -0.1 0.067 Calibration Post Zero Cylinder Bias 1.43 2.15 0 1.193 Calibration Post Zero Cylinder Drift 2.87 0.72 2.15 1.913 Calibration Post High Cylinder ID CC152301- CO2 CC152301-

CO2 CC152301-

CO2 Calibration Post High Cylinder Instrument Response 14 13.8 14 13.933 Calibration Post High Cylinder Bias 1.65 0.22 1.65 1.173 Calibration Post High Cylinder Drift 1.43 1.43 1.43 1.430 Cavg 14.9 14.7 14.8 14.800 Cavg Units %vd %vd %vd Cgas 14.9757 14.7616 14.8565 14.865 Cgas Units %vd %vd %vd Fuel Type Override Override Override Fw 0 0 0 0.000 Fc 0 0 0 0.000 Cgasw 0 0 0 0.000 Cgasw Units



### Friday, February 18, 2011 Page 25 of 31

### Sunnyside Cogeneration Associates Unit 1
9/7/2010
Location Stack Exit - Method 3A O2 Average Run Number A1 A2 A3 Test Date 6/21/2010 6/22/2010 6/22/2010 Run Start Time 12:48:00 PM10:02:00 AM 2:47:00 PM Run Finish Time 4:13:00 PM2:36:00 PM 5:50:00 PM Carbon Dioxide, % 13.7 15 14.8 14.500 Oxygen, % 5.4 4.4 4.6 4.800 Fuel Factor 1.13 1.1 1.1 Dry Volumetric Flow Rate, dry scfm 159590 152671 149447153,902.667 F-Factor, dscfm/MMBtu @ %O2 10284 10355 1035510,331.333 Moisture, % 10.5 11.8 11.6 11.300 Analyzer Make Analyzer Model Analyzer Serial Number Operating Range 25 25 25 25.000 Operating Units % % % No. Readings/Avg. 60 60 60 60.000 Calibration Set 39 38 38 38.333 Calibration Pre Zero Cylinder ID 00-Zero 00-Zero 00-Zero Calibration Pre Zero Cylinder Instrument Response -0.1 -0.2 0 -0.100 Calibration Pre Zero Cylinder Bias 1.43 -1.43 0 0.000 Calibration Pre Zero Cylinder Drift 0 0 0 0.000 Calibration Pre High Cylinder ID CC152301-O2 CC152301- O2 CC152301-

O2 Calibration Pre High Cylinder Instrument Response 7.1 6.9 7 7.000 Calibration Pre High Cylinder Bias 0 -1.43 -0.72 -0.717 Calibration Pre High Cylinder Drift 0 0 0 0.000 Calibration Post Zero Cylinder ID 00-Zero 00-Zero 00-Zero Calibration Post Zero Cylinder Instrument Response 0.3 0 0 0.100 Calibration Post Zero Cylinder Bias 4.29 0 0 1.430 Calibration Post Zero Cylinder Drift 2.86 1.43 0 1.430 Calibration Post High Cylinder ID CC152301-O2 CC152301- O2 CC152301-

O2 Calibration Post High Cylinder Instrument Response 7 7 7 7.000 Calibration Post High Cylinder Bias -0.72 -0.72 -0.72 -0.720 Calibration Post High Cylinder Drift 0.72 0.71 0 0.477 Cavg 5.4 4.36 4.59 4.783 Cavg Units %vd %vd %vd Cgas 5.3305 4.422 4.5834 4.779 Cgas Units %vd %vd %vd Fuel Type Override Override Override Fw 0 0 0 0.000 Fc 0 0 0 0.000 Cgasw 0 0 0 0.000 Cgasw Units



### Friday, February 18, 2011 Page 26 of 31

### Sunnyside Cogeneration Associates Unit 1
9/7/2010
Location Stack Exit - Method 3A O2 3 Average Run Number M1 M2 M3 Test Date 6/21/2010 6/23/2010 6/24/2010 Run Start Time 12:48:00 PM9:36:00 AM 7:56:00 AM Run Finish Time 8:36:00 PM 5:17:00 PM 4:01:00 PM Carbon Dioxide, % 15.3 15.6 14.9 15.267 Oxygen, % 4.26 4.33 4.52 4.370 Fuel Factor 1.09 1.06 1.1 Dry Volumetric Flow Rate, dry scfm 151955 153009 152310152,424.667 F-Factor, dscfm/MMBtu @ %O2 10284 10233 1030810,275.000 Moisture, % 8.87 12.2 11.6 10.890 Analyzer Make Analyzer Model Analyzer Serial Number Operating Range 25 25 25 25.000 Operating Units % % % No. Readings/Avg. 60 60 60 60.000 Calibration Set 39 37 36 37.333 Calibration Pre Zero Cylinder ID 00-Zero 00-Zero 00-Zero Calibration Pre Zero Cylinder Instrument Response -0.1 0.1 -0.1 -0.033 Calibration Pre Zero Cylinder Bias 1.43 0 0 0.477 Calibration Pre Zero Cylinder Drift 0 0 0 0.000 Calibration Pre High Cylinder ID CC152301-O2 CC152301- O2 CC152301-

O2 Calibration Pre High Cylinder Instrument Response 7.05 7.01 6.84 6.967 Calibration Pre High Cylinder Bias -0.36 -1.07 -2.15 -1.193 Calibration Pre High Cylinder Drift 0 0 0 0.000 Calibration Post Zero Cylinder ID 00-Zero 00-Zero 00-Zero Calibration Post Zero Cylinder Instrument Response 0.3 -0.2 0 0.033 Calibration Post Zero Cylinder Bias 4.29 -2.15 0.72 0.953 Calibration Post Zero Cylinder Drift 2.86 2.15 0.72 1.910 Calibration Post High Cylinder ID CC152301-O2 CC152301- O2 CC152301-

O2 Calibration Post High Cylinder Instrument Response 7.08 7.03 6.98 7.030 Calibration Post High Cylinder Bias -0.14 -0.93 -1.15 -0.740 Calibration Post High Cylinder Drift 0.22 0.14 1 0.453 Cavg 4.33 4.37 4.49 4.397 Cavg Units %vd %vd %vd Cgas 4.2452 4.37 4.5596 4.392 Cgas Units %vd %vd %vd Fuel Type Override Override Override Fw 0 0 0 0.000 Fc 0 0 0 0.000 Cgasw 0 0 0 0.000 Cgasw Units



### Friday, February 18, 2011 Page 27 of 31

### Sunnyside Cogeneration Associates Unit 1
9/7/2010
Location Stack Exit - Method 3A O2 3 6 Average Run Number NDF1 NDF2 NDF3 Test Date 6/22/2010 6/22/2010 6/22/2010 Run Start Time 11:57:00 AM 1:44:00 PM 3:56:00 PM Run Finish Time 1:27:00 PM 3:07:00 PM 5:50:00 PM Carbon Dioxide, % 14.7 14.7 14.9 14.767 Oxygen, % 4.68 4.68 4.6 4.653 Fuel Factor 1.1 1.1 1.09 Dry Volumetric Flow Rate, dry scfm 146100 145900 145300145,766.667 F-Factor, dscfm/MMBtu @ %O2 10355 10355 1035510,355.000 Moisture, % 11.8 10.3 11 11.033 Analyzer Make Analyzer Model Analyzer Serial Number Operating Range 25 25 25 25.000 Operating Units % % % No. Readings/Avg. 60 60 60 60.000 Calibration Set 38 38 38 38.000 Calibration Pre Zero Cylinder ID 00-Zero 00-Zero 00-Zero Calibration Pre Zero Cylinder Instrument Response -0.2 0.2 -0.1 -0.033 Calibration Pre Zero Cylinder Bias -1.43 1.43 -0.72 -0.240 Calibration Pre Zero Cylinder Drift 0 0 0 0.000 Calibration Pre High Cylinder ID CC152301-O2 CC152301- O2 CC152301-

O2 Calibration Pre High Cylinder Instrument Response 6.86 7.02 7.02 6.967 Calibration Pre High Cylinder Bias -1.72 -0.57 -0.57 -0.953 Calibration Pre High Cylinder Drift 0 0 0 0.000 Calibration Post Zero Cylinder ID 00-Zero 00-Zero 00-Zero Calibration Post Zero Cylinder Instrument Response 0.2 -0.1 0 0.033 Calibration Post Zero Cylinder Bias 1.43 -0.72 0 0.237 Calibration Post Zero Cylinder Drift 2.86 2.15 0.72 1.910 Calibration Post High Cylinder ID CC152301-O2 CC152301- O2 CC152301-

O2 Calibration Post High Cylinder Instrument Response 7.02 7.02 6.98 7.007 Calibration Post High Cylinder Bias -0.57 -0.57 -0.86 -0.667 Calibration Post High Cylinder Drift 1.15 0 0.29 0.480 Cavg 4.65 4.72 4.59 4.653 Cavg Units %vd %vd %vd Cgas 4.6835 4.6834 4.6005 4.656 Cgas Units %vd %vd %vd Fuel Type Override Override Override Fw 0 0 0 0.000 Fc 0 0 0 0.000 Cgasw 0 0 0 0.000 Cgasw Units



### Friday, February 18, 2011 Page 28 of 31

### Sunnyside Cogeneration Associates Unit 1
9/7/2010
Location Stack Exit - Method 6C Average Run Number A1 A2 A3 Test Date 6/21/2010 6/22/2010 6/22/2010 Run Start Time 12:48:00 PM10:02:00 AM 2:47:00 PM Run Finish Time 4:13:00 PM2:36:00 PM 5:50:00 PM Carbon Dioxide, % 13.7 15 14.8 14.500 Oxygen, % 5.4 4.4 4.6 4.800 Fuel Factor 1.13 1.1 1.1 Dry Volumetric Flow Rate, dry scfm 159590 152671 149447153,902.667 F-Factor, dscfm/MMBtu @ %O2 10284 10355 1035510,331.333 Moisture, % 10.5 11.8 11.6 11.300 Analyzer Make Analyzer Model Analyzer Serial Number Operating Range 1000 1000 1000 1,000.000 Operating Units ppm ppm ppm No. Readings/Avg. 60 60 60 60.000 Calibration Set 60 61 61 60.667 Calibration Pre Zero Cylinder ID 00-Zero 00-Zero 00-Zero Calibration Pre Zero Cylinder Instrument Response 6.6 1.4 1.6 3.200 Calibration Pre Zero Cylinder Bias 1.62 0.29 0.37 0.760 Calibration Pre Zero Cylinder Drift 0 0 0 0.000 Calibration Pre High Cylinder ID CC154255- SO2 CC154255-

SO2 CC154255-

SO2 Calibration Pre High Cylinder Instrument Response 166.2 164.1 156.7 162.333 Calibration Pre High Cylinder Bias -0.15 -1.62 -4.35 -2.040 Calibration Pre High Cylinder Drift 0 0 0 0.000 Calibration Post Zero Cylinder ID 00-Zero 00-Zero 00-Zero Calibration Post Zero Cylinder Instrument Response 18.7 1.6 1.6 7.300 Calibration Post Zero Cylinder Bias 6.08 0.37 0.37 2.273 Calibration Post Zero Cylinder Drift 4.46 0.08 0 1.513 Calibration Post High Cylinder ID CC154255- SO2 CC154255-

SO2 CC154255-

SO2 Calibration Post High Cylinder Instrument Response 172.8 156.7 153.6 161.033 Calibration Post High Cylinder Bias 2.29 -4.35 -5.49 -2.517 Calibration Post High Cylinder Drift 2.44 2.73 1.14 2.103 Cavg 84.9 82.5 78 81.800 Cavg Units ppmvd ppmvd ppmvd Cgas 76.649 84.8232 82.7936 81.422 Cgas Units ppmvd ppmvd ppmvd Fuel Type Override Override Override Fw 0 0 0.000 Fc 0 0 1420 473.333 Cgasw 0 0 0 0.000 Cgasw Units



### Friday, February 18, 2011 Page 29 of 31

### Sunnyside Cogeneration Associates Unit 1
9/7/2010
Location Stack Exit - Method 7E Average Run Number A1 A2 A3 Test Date 6/21/2010 6/22/2010 6/22/2010 Run Start Time 12:48:00 PM10:02:00 AM 2:47:00 PM Run Finish Time 4:13:00 PM2:36:00 PM 5:50:00 PM Carbon Dioxide, % 13.7 15 14.8 14.500 Oxygen, % 5.4 4.4 4.6 4.800 Fuel Factor 1.13 1.1 1.1 Dry Volumetric Flow Rate, dry scfm 159.59 152671 149447100,759.197 F-Factor, dscfm/MMBtu @ %O2 10284 10355 1035510,331.333 Moisture, % 10.5 11.8 11.6 11.300 Analyzer Make Analyzer Model Analyzer Serial Number Operating Range 1000 1000 1000 1,000.000 Operating Units ppm ppm ppm No. Readings/Avg. 60 60 60 60.000 Calibration Set 70 71 71 70.667 Calibration Pre Zero Cylinder ID 00-Zero 00-Zero 00-Zero Calibration Pre Zero Cylinder Instrument Response -0.2 -1.8 -1.6 -1.200 Calibration Pre Zero Cylinder Bias 0 -0.33 -0.25 -0.193 Calibration Pre Zero Cylinder Drift 0 0 0 0.000 Calibration Pre High Cylinder ID CC154255- NOX CC154255-

NOX CC154255-

NOX Calibration Pre High Cylinder Instrument Response 132.7 128.3 134.5 131.833 Calibration Pre High Cylinder Bias 0.33 -0.96 1.63 0.333 Calibration Pre High Cylinder Drift 0 0 0 0.000 Calibration Post Zero Cylinder ID 00-Zero 00-Zero 00-Zero Calibration Post Zero Cylinder Instrument Response -1 -1.6 -1.3 -1.300 Calibration Post Zero Cylinder Bias -0.33 -0.25 -0.13 -0.237 Calibration Post Zero Cylinder Drift 0.33 0.08 0.12 0.177 Calibration Post High Cylinder ID CC154255- NOX CC154255-

NOX CC154255-

NOX Calibration Post High Cylinder Instrument Response 126.8 134.5 135.2 132.167 Calibration Post High Cylinder Bias -2.13 1.63 1.92 0.473 Calibration Post High Cylinder Drift 2.46 2.59 0.29 1.780 Cavg 99.2 110.4 119.2 109.600 Cavg Units ppmvd ppmvd ppmvd Cgas 102.518 112.7738 118.5256 111.272 Cgas Units ppmvd ppmvd ppmvd Fuel Type Override Override Override Fw 0 0 0 0.000 Fc 0 0 0 0.000 Cgasw 0 0 0 0.000 Cgasw Units



### Friday, February 18, 2011 Page 30 of 31

### Sunnyside Cogeneration Associates Unit 1
9/7/2010
Location Stack Exit - OTM - 27/28 Average Run Number 1 2 3 Test Date 6/21/2010 6/23/2010 6/24/2010 Run Start Time 12:58:00 PM9:38:00 AM 8:20:00 AM Run Finish Time 7:49:00 PM 5:21:00 PM 4:15:00 PM Net Traversing Points 12 12 12 Net Run Time, minutes 450 450 450 Nozzle Diameter, inches 0.145 0.145 0.145 0.145 Pitot Tube Coefficient 0.84 0.84 0.84 0.840 Dry Gas Meter Calibration Factor 1.0045 1.0045 1.0045 1.005 Barometric Pressure, inches of Mercury 23.89 23.78 23.68 23.783 Average Orifice Meter Differential, inches H2O 0.45 0.45 0.45 0.450 Dry Gas Meter Volume Sampled, cubic feet 179.580 185.720 182.830 182.710 Average Dry Gas Meter Temperature, °F 86.96 79.96 82.00 82.973 Dry Gas Meter Volume Sampled, dscf 139.233 145.189 141.794 142.072 Total Moisture Liquid collected, g 291.9 405.6 384.2 360.567 Volume of Water Vapor, standard cubic feet 13.74 19.09 18.08 16.970 Moisture Content of Stack Gas, % 8.98 11.62 11.31 10.637 Moisture Saturation at Stack Gas Temperature, % 100.00 100.00 100.00 100.000 Dry Mole Fraction 0.9102 0.8838 0.8869 0.894 Carbon Dioxide, % 15.3 15.6 14.9 15.267 Oxygen, % 4.3 4.3 4.52 4.373 Carbon Monoxide & Nitrogen, % 80.4 80.1 80.58 80.360 Fuel Factor 1.08 1.06 1.10 Dry Molecular Weight, lb/lb-Mole 30.62 30.67 30.56 30.617 Wet Molecular weight, lb/lb-Mole 29.49 29.20 29.14 29.277 Flue Gas Static Pressure, inches of H2O -0.8 -0.8 -0.8 -0.800 Absolute Flue Gas Pressure, inches of Mercury 23.83 23.72 23.62 23.723 Average Stack Gas Temperature, °F 314.58 315.08 316.17 315.277 Average Velocity Head, inches of H2O 1.5713974384 68791.463963967

343441.538217059

70941 1.525
Average Stack Gas Velocity, feet/second 94.51 91.91 94.58 93.667 Stack Cross-Sectional Area, square feet 56.745 56.745 56.745 56.745 Dry Volumetric Flow Rate, dry scfm 159,009.7 149,360.6 153,372.7153,914.333 Actual Wet Volumetric Flue Gas Flow Rate, acfm 321,778.2 312,926.0 322,016.5318,906.900 Percent Isokinetic of Sampling Rate, % 96.3 106.9 101.7 101.633 Percent Excess Air, % 25.4 25.5 27.0 25.967 F-Factor, dscfm/MMBtu @ %O2 10284 10233 1030810,275.000 Round Duct Diameter, inches 102 102 102 Rectangular Duct Width, inches 0 0 0 Rectangular Duct Length, inches 0 0 0 Fw 0 0 0 0.000 Fc 0 0 0 0.000



### Friday, February 18, 2011 Page 31 of 31