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:

Unit 1 Conemaugh

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 0 0 0 1104 2616 4 24

Target

Parameter 

Test

Method

Number of

Test Runs

Test Run

Duration

Sample 

Location Points Comments

Unit 1 Stack 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

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 8075.7MMBtu 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 8015.1MMBtu 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 7942.1MMBtu 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