### Name: James V. Locher

Title: Vice President Company: RRI Energy Sign Date: Name: Carl Vineyard Title: P.E., QSTI, Test Engineer Company: Grace Consulting, Inc. Sign Date: Permitted Facility Representative / Date Testing Company Representative / Date 

## RRI ENERGY CONEMAUGH 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.

Monday, February 14, 2011 Page 1 of 13

### RRI ENERGY CONEMAUGH UNIT 1

Facility Information: RRI Energy
1442 Power Plant Road

New Florence PA 15944 Contact: Shaun Stenlake
Phone: 570-897-2140
Fax: 570-897-2110
Email: sstenlake@rrienergy.com Testing Company: Grace Consulting, Inc
510 Dickson Street

Wellington OH 44090 Contact: Carl Vineyard, P.E.
Phone: 440-647-6672
Fax: 440-647-6673
Email: carlvineyard@gcitest.com

Air Permit Number: 32-00059 Permitted Source ID/Name: Conemaugh Unit 1
Permitted Maximum Process Rate: Max. Normal Operation Process Rate: Target Process Test Rate

Description of the source (including control equipment). Please see the attachments for source or process flow diagram: This unit is equipped with LNB-LNCF III, ESP, FGD. All emission testing was conducted downstream of all APCD. An Upstream Downstream diagram is attached. Industry/SCC/NAIS 221112

Sampling Location Information:

Test Parameter Information: AFS #: 4206300011 FRS #: 10000538801

SCC / Description 10100212 External Combustion Boilers - Electric Generation - Bituminous/Subbituminous Coal - Pulverized Coal: Dry Bottom (Tangential) (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
Unit 1 Stack 396 1104 2616 4 0 24 0 0

Target Parameter Test Method Number of

Test Runs Test Run

Duration Sample

Points Comments Location Hydrogen Fluoride Method 26A 3 180 0 Unit 1 Stack Hydrogen Chloride Method 26A 3 180 0 Unit 1 Stack O2 Method 3A O2 3 180 0 Unit 1 Stack Co2 Method 3A CO2 3 180 0 Unit 1 Stack Sulfur Dioxide Method 6C 3 180 0 Unit 1 Stack Nitrogen oxides (NOx) Method 7E 3 180 0 Unit 1 Stack Regulation Description Compound Limit Unit
0



### Monday, February 14, 2011 Page 2 of 13

### RRI ENERGY CONEMAUGH UNIT 1

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 HCN was sampled using CTM 033 with 6 Normal NaOH and an additional impinger for one hour per the clarification given by the USEPA in FAQ Number 10. The preferred method is EPA CTM 033. You may use a modified Method 26A or Method 26 sampling train. The analysis is then with ion chromatography.



### Monday, February 14, 2011 Page 3 of 13

### RRI ENERGY CONEMAUGH UNIT 1

Sampling / Stack Data Results Summary



### Location Unit 1 Stack - Method 26A Average
Run Number 1 2 3
Test Date 3/10/2010 3/10/2010 3/11/2010
Run Start Time 12:20:00 PM 4:03:00 PM 8:17:00 AM
Run Finish Time 3:39:00 PM 7:15:30 PM 11:25:30 AM Net Run Time, minutes 180 180 180 Dry Gas Meter Volume Sampled, dscf 128.040 126.870 125.387 126.766 Moisture Content of Stack Gas, % 13.65 13.62 13.30 13.523 Moisture Saturation at Stack Gas Temperature, % 11.79 11.77 11.69 11.750 Carbon Dioxide, % 12.9 13 13.2 13.033 Oxygen, % 6.8 6.6 6.5 6.633 Average Stack Gas Temperature, °F 119.08 119.00 118.88 118.987 Dry Volumetric Flow Rate, dry scfm 2,111,472.1 2,092,219.5 2,081,462.2 2,095,051.26 7 Actual Wet Volumetric Flue Gas Flow Rate, acfm 2,760,905.2 2,734,733.0 2,709,074.1 2,734,904.10 0 Percent Isokinetic of Sampling Rate, % 100.7 100.7 100.1 100.500 F-Factor, dscfm/MMBtu @ %O2 9772 9782 9811 9,788.333
Fw 10659 1777 10704 7,713.333
Fc 1775 10681 1790 4,748.667



### Location Unit 1 Stack - Method 3A CO2 Average Run Number
Test Date
Run Start Time
Run Finish Time Carbon Dioxide, % Oxygen, % Dry Volumetric Flow Rate, dry scfm F-Factor, dscfm/MMBtu @ %O2 Moisture, % Fuel Type
Fw
Fc



### Monday, February 14, 2011 Page 4 of 13

### RRI ENERGY CONEMAUGH UNIT 1

Location Unit 1 Stack - Method 3A O2 Average Run Number
Test Date
Run Start Time
Run Finish Time Carbon Dioxide, % Oxygen, % Dry Volumetric Flow Rate, dry scfm F-Factor, dscfm/MMBtu @ %O2 Moisture, % Fuel Type
Fw
Fc



### Location Unit 1 Stack - Method 6C Average Run Number
Test Date
Run Start Time
Run Finish Time Carbon Dioxide, % Oxygen, % Dry Volumetric Flow Rate, dry scfm F-Factor, dscfm/MMBtu @ %O2 Moisture, % Fuel Type
Fw
Fc



### Monday, February 14, 2011 Page 5 of 13

### RRI ENERGY CONEMAUGH UNIT 1

Location Unit 1 Stack - Method 7E Average Run Number
Test Date
Run Start Time
Run Finish Time Carbon Dioxide, % Oxygen, % Dry Volumetric Flow Rate, dry scfm F-Factor, dscfm/MMBtu @ %O2 Moisture, % Fuel Type
Fw
Fc



### Monday, February 14, 2011 Page 6 of 13

### RRI ENERGY CONEMAUGH UNIT 1

Emissions Summary

Process Run Data 

### Location: Unit 1 Stack - Method 26A Compound: Hydrogen Chloride Average RunNumber 1 2 3 Mass_mg 1.224 1.191 1.05 1.155 lb/mmBtuO2 3.05E-04 2.96E-04 2.63E-04 0.000


### Compound: Hydrogen Fluoride Average RunNumber 1 2 3 Mass_mg 0.378 0.4 0.359 0.379 lb/mmBtuO2 9.43E-05 9.94E-05 8.99E-05 0.000



### Location: Unit 1 Stack - Method 6C Compound: Sulfur Dioxide Average Run 1 2 3 lb/mmBtuO2 1.43E-01 1.33E-01 1.41E-01 0.139 ppm 5.92E+01 5.62E+01 5.98E+01 58.400 ppm@7%O2 5.84E+01 5.46E+01 5.77E+01 56.900



### Location: Unit 1 Stack - Method 7E Compound: Nitrogen oxides (NOx) Average Run 1 2 3 lb/mmBtuO2 3.49E-01 3.52E-01 3.67E-01 0.356 ppm 2.02E+02 2.06E+02 2.16E+02 208.000 ppm@7%O2 1.99E+02 2.00E+02 2.09E+02 202.667



### Monday, February 14, 2011 Page 7 of 13

### RRI ENERGY CONEMAUGH UNIT 1

Process Run Data

APCD Run Data

Process Lab Run Data 

### Run Name Value UOM Comments Target Value 1 Heat Input 8075.7 MMBtu using O2 8000


### 1 Coal 615.15 Klb/hr 610
1 Steam Flow 6289.5 Klb/hr 6200
1 Gross Megawatts 905.4 GMW 900


### 1 Net Megawatts 845.91 MW 830
2 Heat Input 8015.1 MMBtu using O2 8000
2 Coal 612.54 Klb/hr 610


### 2 Steam Flow 6170.3 Klb/hr 6200
2 Gross Megawatts 905.66 GMW 900
2 Net Megawatts 842.39 MW 830


### 3 Heat Input 7942.1 MMBtu using O2 8000
3 Coal 618.69 Klb/hr 610
3 Steam Flow 6231.4 Klb/hr 6200


### 3 Gross Megawatts 905.3 GMW 900
3 Net Megawatts 838.21 MW 830

Run Name Value UOM Comments Target Value 

### 1 Liquor Flow Rate Module A 100.67 GPM 100
2 Liquor Flow Rate Module A 96.34 GPM 100
3 Liquor Flow Rate Module A 104.68 GPM 100


### 1 Liquor Flow Rate Module B 132.96 GPM 120
2 Liquor Flow Rate Module B 131.8 GPM 120
3 Liquor Flow Rate Module B 117.89 GPM 120


### 1 DP Module A 3.29 H20 3.2
2 DP Module A 3.42 H20 3.2
3 DP Module A 3.37 H20 3.2


### 1 DP Module B 3.68 H20 3.5
2 DP Module B 3.9 H20 3.5
3 DP Module B 3.71 H20 3.5



### Monday, February 14, 2011 Page 8 of 13

### RRI ENERGY CONEMAUGH UNIT 1

Sampling / Stack Data Results Detail



### Location Unit 1 Stack - Method 26A Average Run Number 1 2 3 Test Date 3/10/2010 3/10/2010 3/11/2010 Run Start Time 12:20:00 PM 4:03:00 PM 8:17:00 AM Run Finish Time 3:39:00 PM 7:15:30 PM 11:25:30 AM Net Traversing Points 24 24 24 Net Run Time, minutes 180 180 180 Nozzle Diameter, inches 0.229 0.229 0.229 0.229 Pitot Tube Coefficient 0.84 0.84 0.84 0.840 Dry Gas Meter Calibration Factor 0.996 0.996 0.996 0.996 Barometric Pressure, inches of Mercury 28.41 28.41 28.5 28.440 Average Orifice Meter Differential, inches H2O 1.53 1.50 1.43 1.487 Dry Gas Meter Volume Sampled, cubic feet 143.090 141.773 138.411 141.091 Average Dry Gas Meter Temperature, °F 100.25 100.17 95.00 98.473 Dry Gas Meter Volume Sampled, dscf 128.040 126.870 125.387 126.766 Total Moisture Liquid collected, g 430 425 408.5 421.167 Volume of Water Vapor, standard cubic feet 20.24 20.00 19.23 19.823 Moisture Content of Stack Gas, % 13.65 13.62 13.30 13.523 Moisture Saturation at Stack Gas Temperature, % 11.79 11.77 11.69 11.750 Dry Mole Fraction 0.8821 0.8823 0.8831 0.883 Carbon Dioxide, % 12.9 13 13.2 13.033 Oxygen, % 6.8 6.6 6.5 6.633 Carbon Monoxide & Nitrogen, % 80.3 80.4 80.3 80.333 Fuel Factor 1.09 1.10 1.09 Dry Molecular Weight, lb/lb-Mole 30.34 30.34 30.37 30.350 Wet Molecular weight, lb/lb-Mole 29.22 29.22 29.21 29.217 Flue Gas Static Pressure, inches of H2O 0.52 0.52 0.55 0.530 Absolute Flue Gas Pressure, inches of Mercury 28.45 28.45 28.54 28.480 Average Stack Gas Temperature, °F 119.08 119.00 118.88 118.987 Average Velocity Head, inches of H2O 0.8057630379 19623 0.790764997

752334 0.778223814

975154 0.792

Average Stack Gas Velocity, feet/second 53.80 53.29 52.79 53.293 Stack Cross-Sectional Area, square feet 855.299 855.299 855.299 855.299 Dry Volumetric Flow Rate, dry scfm 2,111,472.1 2,092,219.5 2,081,462.2 2,095,051.2 67 Actual Wet Volumetric Flue Gas Flow Rate, acfm 2,760,905.2 2,734,733.0 2,709,074.1 2,734,904.1 00 Percent Isokinetic of Sampling Rate, % 100.7 100.7 100.1 100.500 Percent Excess Air, % 47.2 45.1 44.2 45.500 F-Factor, dscfm/MMBtu @ %O2 9772 9782 9811 9,788.333 Round Duct Diameter, inches 396 396 396 Rectangular Duct Width, inches 0 0 0 Rectangular Duct Length, inches 0 0 0 Fw 10659 1777 10704 7,713.333 Fc 1775 10681 1790 4,748.667



### Monday, February 14, 2011 Page 9 of 13

### RRI ENERGY CONEMAUGH UNIT 1

Location Unit 1 Stack - Method 3A CO2 Average Run Number Test Date Run Start Time Run Finish Time Carbon Dioxide, % Oxygen, % Fuel Factor Dry Volumetric Flow Rate, dry scfm F-Factor, dscfm/MMBtu @ %O2 Moisture, % Analyzer Make Analyzer Model Analyzer Serial Number Operating Range Operating Units No. Readings/Avg. Calibration Set Calibration Pre Zero Cylinder ID Calibration Pre Zero Cylinder Instrument Response Calibration Pre Zero Cylinder Bias Calibration Pre Zero Cylinder Drift Calibration Pre High Cylinder ID Calibration Pre High Cylinder Instrument Response Calibration Pre High Cylinder Bias Calibration Pre High Cylinder Drift Calibration Post Zero Cylinder ID Calibration Post Zero Cylinder Instrument Response Calibration Post Zero Cylinder Bias Calibration Post Zero Cylinder Drift Calibration Post High Cylinder ID Calibration Post High Cylinder Instrument Response Calibration Post High Cylinder Bias Calibration Post High Cylinder Drift Cavg Cavg Units Cgas Cgas Units Fuel Type Fw Fc Cgasw Cgasw Units



### Monday, February 14, 2011 Page 10 of 13

### RRI ENERGY CONEMAUGH UNIT 1

Location Unit 1 Stack - Method 3A O2 Average Run Number Test Date Run Start Time Run Finish Time Carbon Dioxide, % Oxygen, % Fuel Factor Dry Volumetric Flow Rate, dry scfm F-Factor, dscfm/MMBtu @ %O2 Moisture, % Analyzer Make Analyzer Model Analyzer Serial Number Operating Range Operating Units No. Readings/Avg. Calibration Set Calibration Pre Zero Cylinder ID Calibration Pre Zero Cylinder Instrument Response Calibration Pre Zero Cylinder Bias Calibration Pre Zero Cylinder Drift Calibration Pre High Cylinder ID Calibration Pre High Cylinder Instrument Response Calibration Pre High Cylinder Bias Calibration Pre High Cylinder Drift Calibration Post Zero Cylinder ID Calibration Post Zero Cylinder Instrument Response Calibration Post Zero Cylinder Bias Calibration Post Zero Cylinder Drift Calibration Post High Cylinder ID Calibration Post High Cylinder Instrument Response Calibration Post High Cylinder Bias Calibration Post High Cylinder Drift Cavg Cavg Units Cgas Cgas Units Fuel Type Fw Fc Cgasw Cgasw Units



### Monday, February 14, 2011 Page 11 of 13

### RRI ENERGY CONEMAUGH UNIT 1

Location Unit 1 Stack - Method 6C Average Run Number Test Date Run Start Time Run Finish Time Carbon Dioxide, % Oxygen, % Fuel Factor Dry Volumetric Flow Rate, dry scfm F-Factor, dscfm/MMBtu @ %O2 Moisture, % Analyzer Make Analyzer Model Analyzer Serial Number Operating Range Operating Units No. Readings/Avg. Calibration Set Calibration Pre Zero Cylinder ID Calibration Pre Zero Cylinder Instrument Response Calibration Pre Zero Cylinder Bias Calibration Pre Zero Cylinder Drift Calibration Pre High Cylinder ID Calibration Pre High Cylinder Instrument Response Calibration Pre High Cylinder Bias Calibration Pre High Cylinder Drift Calibration Post Zero Cylinder ID Calibration Post Zero Cylinder Instrument Response Calibration Post Zero Cylinder Bias Calibration Post Zero Cylinder Drift Calibration Post High Cylinder ID Calibration Post High Cylinder Instrument Response Calibration Post High Cylinder Bias Calibration Post High Cylinder Drift Cavg Cavg Units Cgas Cgas Units Fuel Type Fw Fc Cgasw Cgasw Units



### Monday, February 14, 2011 Page 12 of 13

### RRI ENERGY CONEMAUGH UNIT 1

Location Unit 1 Stack - Method 7E Average Run Number Test Date Run Start Time Run Finish Time Carbon Dioxide, % Oxygen, % Fuel Factor Dry Volumetric Flow Rate, dry scfm F-Factor, dscfm/MMBtu @ %O2 Moisture, % Analyzer Make Analyzer Model Analyzer Serial Number Operating Range Operating Units No. Readings/Avg. Calibration Set Calibration Pre Zero Cylinder ID Calibration Pre Zero Cylinder Instrument Response Calibration Pre Zero Cylinder Bias Calibration Pre Zero Cylinder Drift Calibration Pre High Cylinder ID Calibration Pre High Cylinder Instrument Response Calibration Pre High Cylinder Bias Calibration Pre High Cylinder Drift Calibration Post Zero Cylinder ID Calibration Post Zero Cylinder Instrument Response Calibration Post Zero Cylinder Bias Calibration Post Zero Cylinder Drift Calibration Post High Cylinder ID Calibration Post High Cylinder Instrument Response Calibration Post High Cylinder Bias Calibration Post High Cylinder Drift Cavg Cavg Units Cgas Cgas Units Fuel Type Fw Fc Cgasw Cgasw Units



### Monday, February 14, 2011 Page 13 of 13