### 7/23/2010 Test Plan 3190 Platte River Power Authority

Facility Information: Rawhide 2700 East County Road 82
Wellington CO Contact: Mike O'Brien Phone: (970) 222-2325 Fax: Email: obrienm@prpa.org Testing Company: Airtech Environmental Services Inc. 5776 Lamar Street

Arvada CO 80002 Contact: Jeff Johnson Phone: (303) 670-0530 Fax: (303) 670-4130 Email: jjohnson@airtechenv.com

Air Permit Number: 6761 Permitted Source ID/Name: Boiler 101 101 Permitted Maximum Process Rate: N/A Max. Normal Operation Process Rate: N/A Target Process Test Rate N/A

1. What is the specific purpose for the proposed t esting? The primary reasons for performing this emissions test is to satisfy the EPA's Section 114 Letter requiring this testing.

3. Will the test results be used for other regulat ory purposes (e.g., emission inventories, permit applications, etc.) beyond that stat ed above? If yes, explain. List any secondary purposes that you will use the d ata from this emissions test to address. If known list those pollutants that are of secondary interest. Some ex amples are: Determine emissions of CO, THC, VOC and condensable PM emissions for use in emissions inventory reporting and determination of fees. Industry NAICS: 221112

4a. Enter the process data to be documented duringtesting. AFS #: 0806900053 FRS #: 110000607148

SCC / Description 10100202 External Combustion Boilers - Electric Generation -Bituminous/Subbituminous Coal - Pulverized Coal: Dry Bottom (Bituminous Coal )

2. List all state and federal regulations that app ly to the proposed testing:

Process Parameter Units Target Value Comments Coal Burned 1000 Tons/hr 0.15 Provide estimated process rate for the test. Unit Net Electric Generation MWh 280 Provide estimated process rate for the test as well as a daily average for a 30 day period encompassing the tests. Flue Gas Sampling Point Temperature Deg F 200 Provide estimated process rate for the test as well as a daily average for a 30 day period encompassing the tests.
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### 7/23/2010 Test Plan 3190 Platte River Power Authority

5a. Please give a brief description of the source (including control equipment) and attach source or process flow diagram: The Rawhide Energy Station is a pulverized coal fir ed steam generating electric utility plant serving Northern Colorado. It has a nominal generating capacity of 305 MW (gross) at 100% load and a heat input rate o f 2,800 mmBtu per hour based on a coal feed rate of 157 ton s per hour (as received). The coal is typically, a s received 8,850 Btu per pound and contains 0.28% sulfur and 5.3% ash. The boiler is tangentially fired and is equippe d with LNC3 concentric firing low-NOx burners with separated ov er fire air dampers. The hot boiler flue gas exitsthe air heater in a common inlet duct to the Spray Dry Absorber (SDA) SO2 emissions control inlet manifold. The SDA emissions control system is designed to control both SO2 and particulate. The process is base d on initial absorption of SO2 onto "atomized" alkaline particle s injected by the three slurry atomizers. The sulf ate-laden flue gas particles, along with existing fly ash, are the n separated from the flue gas in two fabric filter baghouses before passing through the two ID fans and into the common stack breech. The maximum EPA allowable sulfur dio xide emission rate is 0.13 lb/mmBtu with at least an 80%reduction of sulfur dioxide in the flue gas. The unit must also achieve a State-only SO2 emission limit of 0.09 lbs/mmBtu (calendar-year average) and a State-only NOx limit of 0.18 lbs/mmBtu (calendar-year average). 5b. Control Devices:

6. Please enter sampling location information. 4b. Enter the process lab data to be documented du ring testing.

Control Device Name BAGHOUSE OVERFIRE AIR SPRAY DRYER

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 Flue Gas Carbon Dioxide Content % 14 Provide estimated process rate for the test as well as a daily average for a 30 day period encompassing the tests. Flue Gas Oxygen Content % 6 Provide estimated process rate for the test as well as a daily average for a 30 day period encompassing the tests. Flue Gas Flow Rate kscfh 40000 Provide estimated process rate for the test as well as a daily average for a 30 day period encompassing the tests. Steam Output 1000 lb steam/hr 1800 Provide estimated process rate for the test as well as a daily average for a 30 day period encompassing the tests. Average Heat Input MMBtu/hr 2500 Provide estimated process rate for the test as well as a daily average for a 30 day period encompassing the tests.

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### 7/23/2010 Test Plan 3190 Platte River Power Authority

7. Please provide the following information for ea ch test parameter.

7b. Please select the Emissions / Concentrations f or each location. Target Parameter Test

Method Number of

Test Runs Test Run

Duration Sample

Points Comments Location % H2O Method 1 - 4 6 180 0 Stack Exit Carbon Monoxide Method 10 3 120 0 Stack Exit Total organic

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

Hydrogen Fluoride Method 26A 3 180 0 Stack Exit Hydrogen Chloride Method 26A 3 180 0 Stack Exit Filterable PM2.5 OTM - 27/28 3 240 0 Use only for dry st acks. 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

Inorganic

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

(yellow or white) Method 29 0 Stack Exit
Selenium Method 29 3 240 0 Stack Exit Nitrogen oxides

(NOx) Method 7E 3 180 0 Stack Exit Stack Exit 240 480 1920 4 240 12 0 0

Test Method Emissions / Concentrations Corrected Analyte Corrected

Percent Location Method 10 lb/million BTU using O2 0 Stack Exit Method 10 ppm corrected O2 7 Stack Exit Method 25A lb/million BTU using O2 0 Stack Exit Method 25A ppm corrected O2 7 Stack Exit Method 26A lb/million BTU using O2 0 Stack Exit Method 26A mg/dscm 0 Stack Exit Method 26A mg/dscm corrected O2 7 Stack Exit Method 29 lb/hr 0 Stack Exit Method 29 lb/million BTU using O2 0 Stack Exit Method 29 mg/dscm 0 Stack Exit
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### 7/23/2010 Test Plan 3190 Platte River Power Authority

8. Describe below or attach complete documentatio n of all modifications and/or deviations to the applicable test methods. If alternative methods requested, attach documentation of request The following is a list of the test methods that are to be used for this test program and their respec tive promulgation dates: Methods 1 through 29 – August 1997 Method 30B – January 2008 Other Test Methods 27 and 28 – April 2009 SW-846 0010 – September 1986 SW-846 0030 – December 1996 9. Does the proposed sampling location meet the minimum EPA Method 1 criteria for acceptable measurement sites? Please list below or atta ch the supporting documentation.

10. Has absence of cyclonic flow been verified perEPA Method 1 (Section 2.4)? If no, absence of cyclonic flow must be verifiedprior to testing. If yes, please attach supporting documentation. The verification of absence of cyclonic flow was not necessary as per Section 11.4.1 of EPA Method 1.
11. Select the method that will determine the oxyg en concentration : M3B-Orsat

13. Has all testing equipment been calibrated with in the past year? If no, please explain. Yes No

Yes No

Yes No

Yes No

Yes No

14. Will all calibration gases be certified by EPATraceability Protocol procedures? If No, describe certificationprocedure below.

15. Is a dilution system (via EPA Method 205) prop osed? Yes No N/A

Yes No N/A Zero nitrogen and/or zero air was used for zero cal ibrations.

16. If applicable, list the expected calibration g as concentrations for all proposed instrumental test methods. Include as much information a s is known at this time. 12. Do any of the proposed test methods require an alysis of EPA audit samples? If yes, notify Regional Office at least 45 days prior to testing to allow for audit sample preparation and shipment.

Method 29 mg/dscm corrected O2 7 Stack Exit Method 7E lb/million BTU using O2 0 Stack Exit Method 7E ppm 0 Stack Exit Method 7E ppm corrected O2 7 Stack Exit OTM - 27/28 lb/million BTU using O2 0 Stack Exit Method 10 ppm 0 Stack Exit Method 25A ppm 0 Stack Exit

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### 7/23/2010 Test Plan 3190 Platte River Power Authority

17. What is the proposed test schedule? The testing will be performed during the week of Ma y 4th, 2010.

18. Additional comments:

Name: Mike O'Brien Title: Environmental Specialist Company: Platte River Power Authority Sign Date: 7/23/2010 Name: Chet Gutwein Title: Engineer Company: Airtech Environmental Services Inc. Sign Date: 7/22/2010 Permitted Facility Representative Testing Company Re presentative Date Date 19. Required Personal Protection Equipment: Required PPE: hardhat, steel-toed boots, safety gla sses, gloves, hearing protection, and fall protecti on if necessary. Compound (Analyte) Certification

Procedure Cert.

Value Uncertianty

Percent Cylinder Certification Date Expiration

Date Nitrogen NA 0 0 Zero 10/29/2009 10/29/2012

NOX G1 179 1 AAL933 2/17/2010 2/17/2012

NOX G1 852.4 1 sx12373 3/30/2010 3/30/2012

CO G1 49.38 1 XC030124B 9/1/2009 9/1/2012

CO G1 101.5 1 SG9104876BAL 3/3/2009 3/3/2012

Propane G1 30.15 1 CC52193 12/2/2008 12/2/2011

Propane G1 50 0.5 CC78858 9/5/2007 9/4/2010

Propane G1 84.4 0.7 CC115970 9/5/2007 9/4/2010

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