Dereiizo and Associates,_inc. L,ivzronmental Consultants EMISSIONS TEST REPORT Compliance Test Report for the #4 Landfill Gas Fueled Title G3520C Internal Combustion Engine Operated

at the Trail Ridge Energy, L.L. C., Trail Ridge Landfill, Duval County, Florida Report May4, 2009 Test March 25 & 26 2009 Date(s) I ILIlIt) lfllt)1IN 111011 Name Trail Ridge Energy, L.L.C., Trail Ridge Landfill City, County
j Jacksonville, Duval Enchtv Permit ntuniuilion DEP File No.: 0310358-011 -AC fenit No.: PSD-FL-374B Testing Contractor Company Derenzo and Associates, Inc. Mailing 39395 Schoolcraft Road Address Livonia, MI 48150 Phone (734) 464-3880 Project No. 0901014 39395 Schooleraft Road

• Livonia, MI 48150

. (734) 464-3880

• FAX (734) 464-4368 4970 Northwind, Suite 213

• East Lansing, Ml 48823

• (517) 324-1880

• FAX (517) 324-5409Derenzo and Associates, Inc. Trail Ridge Energy, L.L.C. G3520C IC Engine

May 4, 2009 Compliance Test Report

Page

i TABLE OF CONTENTS

Page 1.0 SOURCE INFORMATION 2.0 PLANT AND SAMPLING LOCATION DESCRiPTION

2 2.1 Generat Process Description

2 2.2 Rated Capacities, Type and Quantity of Raw Materials Used

2 2.3 Emission Control System Description

2 2.4 Sampling Locations (USEPA Method

1)

2 3.0 SUMMARY AND DISCUSSION
OF TEST RESULTS

3 3.1 Purpose and Objectives
of the Tests

3 3.2 VariatioHs from Normal Sampling Procedures

or Operating Conditions

3 3.3 Operating Conditions during Compliance Tests

4 3.4 Air Pollutant Sampling Results

4 4.0 SAMPLING AND ANALYTICAL PROCEDURES

5 4.1 Exhaust Gas Velocity and Flowrate Determination (IJSEPA Method
2)

5 4.2 Exhaust Gas Molecular Weight Determination (USEPA Method 3A)

5 4.3 Exhaust Gas Moisture Content Detenninations (Method
4)

6 4.4 NO and CO Concentration Measurements (USEPA Method 7E and 10)

6 4.5 Particulate Matter Concentration Measurements (USEPA 5/USEPA 202)

6 4.6 Volatile Organic Compound Measurement (USEPA Methods 25A!l 8)

7 4.7 Hydrogen Chloride Measurements (USEPA Method 26A)

7 4.8 Visible Emissions Detenninations (USEPA Method
9)

7 5.0 INTERNAL QA/QC ACTIVITIES

7 5.1 NO Converter Efficiency Test

7 5.2 Sampling System Response Time Determination

7 5.3 Determination

of Exhaust Gas Stratification

8 5.4 Instrumental Analyzer Interference Check

8 5.5 Instrument Calibration and System Bias Checks

8 5.6 Meter l3ox Calibrations and Percent Isokinetics

8licreiizo and Associates, Inc. Trail Ridge Energy, L.L.C. G3520C IC Engine

May 4, 2009 Compliance Test Report

Page
ii LIST OF TABLES Table

Page I Particulate Matter less than 10 Microns (PM 10) Emission Rates from the Unit #4 Engine
at the Trail Ridge Energy, L.L.C.— Trail Ridge Landfill

11 2 Hydrogen Chloride Emission Rates from the Unit #4 Engine
at the Trail Ridge Energy, L.L.C.- Trail Ridge Landfill

12 3 Calculation
of HCI Emission Factor Based on Influent Landfill Gas Chlorinated Compounds

to the #4 Caterpillar Model G3520C Engine
at the Trail Ridge Energy, LLC

- Trail Ridge Landfill

13 4 Nitrogen Oxides, Carbon Monoxide, and Volatile Organic Compound Concentrations, Emission Rates, and Emission Factors from the Unit #4 Caterpillar Model G3520C Engine
at the Trail Ridge Energy, L.L.C.- Trail Ridge Landfill

14 5 Six-Minute USEPA Method

9 Opacity Averages for the Caterpillar Model G3520C Engine Unit #4 at the Trail Ridge Energy, LL.C- Trail Ridge Landfill

15 LIST OF PIGURE(S) Figure

1. Trail Ridge Energy Facility Process Flow Diagram Figure
2. Trail Ridge Energy Source Diagram Figure
3. Trail Ridge Energy Exhaust Sampling Location Figure
4. Instrumental Analyzer Sampling Train Diagram (USEPA Methods 3A, 7E, and 10) Figure
5. Isokinetic Sampling Train Diagram (USEPA Methods

5 and 202) Figure
6. Isokinetic Sampling Train Diagram (USEPA Methods 26A) LIST OF APPENDICES Appendix

A Computer Calculated and Field Sampling Data Sheets Appendix

B Equipment Calibration Data and Opacity Certification Appendix

C Laboratory Data Appendix

D Sample Calculations Appendix

E Process Data Appendix

F Detailed Descriptions
of Sampling ProceduresDerenzo and Associates, Inc. Environmental Consultants COMPLIANCE TEST REPORT FOR THE LANDFILL GAS FUELED G3520C INTERNAL COMBUSTION ENGLNE OPERATED AT TRAIL RIDGE ENERGY, LL.C. TRAIL RIDGE LANDFILL DUVAL COUNTY, FLORIDA 1.0 SOURCE INFORMATION Trail Ridge Energy, L.L.C. (Trail Ridge Energy)

is located
at the Trail Ridge Landfill
in Duval County, Florida. The Facility File No. is 0310358-011-AC
and the Permit No. is PSD-FL-374B. At its landfill gas to energy (LFGTE) facility, Trail Ridge Energy
is permitted

to operate emission units 002— 005 which consist of four (4) Caterpillar G3520C Lean Burn Reciprocating Engines and electricity generator sets. These engines are fueled with methane-rich gas, which
is generated

at the Trail Ridge Landfill,
to power base load electricity generator operations. The FDEP pennit requires perIbrinance testing of a representative engine for the cleternunation of specified pollutant emissions while the unit is operated

at near base load conditions. Comnliance testing was performed

to measure nitrogen oxides (NO), carbon monoxide (CU), particulate with diameters equal to or less than 10 microns (PM—

1 0), volatile organic COmpOUfld (VOC), hydrogen chloride (lid), and oxygen (02), concentrations
and emission rates and opacity from the exhaust of the Unit #4 engine pursuant
to the testing requirements specified
in the FDEP Air Construction Permit. The compliance testing was performed
on March 25, 2009 by Derenzo and Associates, Inc., an environmental consulting and testing company from Livonia, Michigan. The exhaust gas sampling and analysis was performed using procedures specified
in the Test Protocol dated February 13, 2009. Questions regarding this emission test report should be directed to: Mr. Michael Brack

Mr. Michael Laframboise Field Services Manager

Sr. Vice President- Operations Derenzo and Associates, Inc. Landfill Energy Systems. 39395 Schoolcraft Road
29261 WaIl Street Livonia, MI 48150 Wixorn, Mi 48393 (734) 464-3880

(248) 380-3920 3P)5 Sclcr.fi Ru:

• L;v L\II 4I5O

. (74 46--3Sfl

• F\.\ (/ 1) 4(- 5 rmiuJ S1Itc 213

•

I iic

-1)erenzo and Associates. Inc. Trail Ridge Energy, L.L.C. G3520C IC Engine

May 4, 2009 Compliance Test Report

Page

2 2.0 PLANT AND SAMPLFNG LOCATION DESCRIPTION 2.1 General Process Description Methane-rich landfill gas (LEG)
is produced
in the Trail Ridge Landfill from the anaerobic decomposition

of disposed waste materials. The methane-rich LFG is collected from both active and capped landfill cells using

a system of wells that are connected

to a central header (gas collection system). The collected LEG is directed
to the Trail Ridge Energy facility where
it is treated and used as fuel for the IC engine generators that produce electricity for transfer
to the local utility. The Trail Ridge Energy facility currently consists of six (6) CAT Model No.G3520C

IC internal combustion engines that are connected

to individual electricity generators. A process flow diagram for the LEG to electricity process

is presented subsequent

to the summary tables in this report. 2.2 Rated Capacities, Type and Quantity of Raw Materials Used The representative CAT (33520C IC engine generator set was operated

at base load conditions (i.e., 100% of the design capachy of 2,233 brake horsepower)

to produce

a peak electricity output of 1,600 kilowatts (kW). Fuel (treated landfill gas) consumption

is regulated

to maintain the required heat input rate to support engine operations and is dependant
on the tPel heat value (methane content). The average engine fuel consumption rate during the test periods was 541.4 scfm based on data recorded from the fuel flow meter installed and operated by Trail Ridge Energy. Appendix

E provides engine generator process data collected during the compliance test. 2.3 Emission Control System Description The engines incorporate state of the art technology

in order to fire lean fuel mixtures and produce low combustion by-product emissions. Emissions from the combustion
of LFG are released uncontrolled into the ambient air through

a stack connected

to the IC engine exhaust manifold and noise control system (noise muffler). 2.4 Sampling Locations (USEPA Method

1) The exhaust stack sawpfrog port for the Model G3520C IC engine satistied the L’SEiA Method

I criteria for a representative sample location. The inner diameter of the engine exhaust stacks
is 15.5 inches. The stack is equipped with two (2) sample ports, opposed 90°, that provide

a sampling location
53 inches (34 duct diameters) downstream and 124 inches (8 duet diameters) upstream from any flow disturbance. Velocity pressure traverse locations for the sampling points were tletermincd

in accordance with I JS EPA Method

I fur thc lepresentative engine.Deieiizo and Associates, Inc. Trail Ridge Energy, L.LC. G3520C IC Engine

May 4, 2009 Compliance Test Report

Page

3 Included, following the summary tables
is a diagram presenting the performance test sampling locations. The relatively small stack diameter (15.5 inches) of the engine exhaust

is obstructed
by the surface area of the isokinetic sampling probe, which tends to bias the exhaust velocity measurements

on the high side. The test results are calculated from pre-test velocity averages. 3.0 SUMMARY AND DISCUSSION
OF TEST RESULTS 3.1 Purpose and Objectives
of the Tests Stack testing
is required for the permitted emission units to demonstrate compliance with the CO, NOx, PM-l0, VOC, HCI, and opacity emission limits by permit conditions. The facility
is required to perform initial, annual and permit renewal testing during

a six-year period. This test event satisfies the 2009 initial pertbrxnance test required by the permit. The PM—i

0 emissions were determined
by combining the total filterable with the total condensable portions of the USEPA Method

5 and USEPA Method 202 sampling trains. The VOC emission rate from the tested engine was determined by subtracting the methane concentration (in—field USEIA Method
18 field analysis) from the total hydrocarbon (THC) concentration detennined
by US EPA Method 25A field analysis. The exhausts from the LFG-fueled
IC engines were momtored for six (6) one-hour test periods during which the 02 and CO 2 exhaust gas concentrations were measured using instrumental analyzers. The engine NON, and CO measurements consisted of triplicate 60-minute measurements using instrumental analyzers, and the PMI 0, and HCI consisted of triplicate 60-minute measurements using isokinetic sampling equipment. Exhaust gas moisture content from the representative engine was determined
by gravimetric analysis of the weight gain in the chilled impingers. Velocity and volumetric flow rates were measured prior to each isokinetic sampling test period and during pre-test and post-test time periods. Opacity observations were made during one of the PM-b tests and were observed

at the point of areatest opacity in the portion of the plume where condensed water vapor is not present, with continuous readings taken every 15 seconds for 60 minutes. The testing was performed while the IC engine was operated
at nonnal base load conditions (1600 kW peak electricity output +1- 5%). 3.2 Variations from Normal Sampling Procedures

or Operating Conditions The testing for all pollutants were performed

in accordance with the Test Protocol dated February 13, 2000 and specified TISEPA test mcthods. Isokinetic s:unpl ag rates were determine(l using pm-test velocity measureincats.Dereiizo and Associates, Inc. Trail Ridge Energy, L.L.C. G3520C IC Engine

May 4, 2009 Compliance Test Report

Page
4 Instrument calibrations and sampling period results satisfied the quality assurance verifications required by USEPA Methods 3A, 7E, 10, 18, and 25A. No variations from the normal operating conditions
of the IC engine occurred during the testing program. 3.3 Operating Conditions during Compliance Tests The representative LFG-fueled

IC engine was operated

at base load (100% capacity +1- 5%) conditions during the compliance testing. The average kilowatt (kW) output value displayed by the engine data management computer (LCD screen) were manually recorded

3 times during each test period. LFG flowrate information was obtained similarly (manually recorded readings) from data displayed by the fuel flow rate meter installed
at the facility. The average LFG consumption rate during the testing was 541.4 standard cubic feet per minute (scfm). The average electrical output rate during the test event was 1,601 kW. 3.4 Air Pollutant Sampling Results The following table presents the engine #4 three-test average emission rates from the initial performance evaluation: Emission Parameter

Unit #1 Emissions Pennit Limit NOx NO emissions (lb/he)
2.09

2.95 NO emissions (g/bhp-hr)

0.43

0.60 CO
CO emissions (lb/hr)
13.13
13.54 CO emissions (g/bhp-hr)

2.70

2.75 VOC VOC emissions (lb/br)

0.0

1.37 VOC emissions (g/bhp-hr)

0.0

0.28 PM 10 PM 10 emissions(lb/hr)

0.57

1.18 PM 10 emissions (g/bhp-hr)

0.12

0.24 HC1 HC1 emissions (lb/hi)
0.02- IICI emissions (Ib/IviMsef)

0.68

10.9 02 Oxygen concentration (%)
8.27 Opair/’ F-Lghesr
10 second average d 6 )
0.0

10 Notes (lb/he) pounds per hour, (g/bhp-hr) grams per brake horsepower hour, (lb/MMscf pounds per million standard cubic foot Tables

1 through

5 present measured gas conditions and io11utant emission rates for the representative Ll’G-fueled
IC engine. Appendix

A provides

c miputel calculated and hold data sheets flr the [C engine tests.Derenzo an(l Associates, Inc. Trail Ridge Energy, L.L.C. G3520C IC Engine

May 4, 2009 Compliance Test Report

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5 Appendix

A provides raw instrumental analyzer response data for each test period. 4.0 SAMPLING AND ANALYTICAL PROCEDURES A test protocol for the compliance testing was prepared by Derenzo and Associates and reviewed by the FDEP. Tins section provides

a summary of the sampling and analytical procedures that were used during the test and presented

in the test plan. Appendix

F presents diagrams for the USEPA Methods sampling trains. 4.1 Exhaust Gas Velocity and Flowrate Determination (USEPA Method
2) In order to determine air pollutant emission rates on a mass basis (e.g., pound per hour), IC engine exhaust stack gas velocities, and volumetric flow rates were determined using USEPA Method

2 prior to conducting tests. An S-type pitot tube connected

to a red-oil manometer was used to determine velocity pressure. Gas temperature was measured using

a K—type thermocouple mounted
to the heated sample probe. The heated sample probe and connective tubing were leak-checked

to verify tire integrity of the measurement system. The absence of cyclonic flow for each sampling location was verified using an S-type Pitot tube and oil manometer. The Pitot tube was positioned

at all of the velocity traverse points with the planes of the face openings of the Pitot tube perpendicular

to the stack cross-sectional plane. The Pitot tube was then rotated
to determine the null angle (rotational angle as measured from the perpendicular,

or reference, position
at which the differential pressure

is equal to zero). Exhaust gas velocity pressure and temperature were measured during each one-hour isokinetic sampling period in accordance with USEPA Method

2. 4.2 Exhaust Gas Molecular Weight Determination (USEPA Method 3A) CO 2 and 02 content
in the IC engine exhaust gas stream was measured continuously throughout each one-hour test period in accordance with USEPA Method 3A. The CO 2 content of the exhaust was monitored using

a non-dispersive infrared (NDIR) gas analyzer. The 02 content of the exhaust was monitored using

a gas analyzer that utilizes

a paramagnetic sensor. During each one-hour sanmpiirig period,

a ontmnuous sample of the IC engine exhaust gas stream was extracted from the stack using

a stainless steel probe connected

to a Teflon® heated sample line. The sampled gas was conditioned
by removing moisture prior to being introduced

to the analyzer; therefore, measurement
of 02 and CO 2 concentrations correspond

to standard dry gas conditions. The instrument was calibrated using appropriate calibration gases to determine accuracy and system bias (described

in Section 5.5 of this document).Derenzo and Associates, Inc. Trail Ridge Energy, L.L.C. G3520C IC Engine

May 4, 2009 Compliance Test Report

Page

6 4.3 Exhaust Gas Moisture Content Determinations (Method
4) Moisture content of the IC engine exhaust gas was determined

in accordance with USEPA Method

4 using

a chilled impinger sampling train as a component
of the USEPA sampling procedures for PM (i.e., not as a separate measurement train), which was performed concurrently with the instrumental analyzer sampling methodologies. Moisture detenninations were measured similarly during each HC1 sampling period. During each sampling period,

a gas sample was extracted

at a predetermined rate from the source where moisture was removed from the sampled gas stream using imnplngers that were submersed

in an ice bath, and then determined gravimetrically.

At the conclusion
of each sampling period, the moisture gain in the impingers was determined gravimetrically

by weighing each impinger
to determine net weight gain. Appendix

F presents detailed gas sampling procedures for the US EPA sampling trains. 4.4 NO and CO Concentration Measurements

(L SEPA Method 7E and 10) NO and CO pollutant concentrations

in the exhaust of the IC engine were detennined using

a chemiluininescence NO analyzer and NDIR CC) analyzer. Three (3) one-hour sampling periods were performed for the IC engine exhaust testing. Throughout each one-hour test period,

a continuous sample of the engine exhaust gas was extracted from the stack using the Teflon® heated sample line and gas conditioning system described

in Section 4.2 of this document, and delivered

to the instrumental analyzers. Instrument response for each analyzer was recorded on a data logging system that monitored the analog output of the instrumental analyzers continuously and logged data as one-minute averages. Prior to, and at the conclusion
of each test, the instruments were calibrated using appropriate upscale calibration and zero gas to determine analyzer calibration error and system bias. Sampling times were recorded on field data sheets. 4.5 Particulate Matter Concentration Measurements (USEPA 5/USEPA 202) An integrated sample of the exhaust gas was withdrawn isokinetically from the IC engine exhaust stack. The filterable PM emissions were measured with the front-half of the sampling system in accordance with US EPA Method

5. The condensible particulate concentrations were measured with the back half of the sampling system in accordance with USEPA Method 202. The combined filterable and condensible emission rates constitute the PM-)O emission rates. Upon completiun
of the reLILLired posttest leak check of the isokmnetic sampling train, the impingers were transported

to the mobile laboratory (trailer) where

a nitrogen purge was conducted. The nitrogen purge consisted of bubbling reagent grade nitrogen through the impinger train at a rate of 20 liter per minute for 60 minutes and was conducted
on all PM-l0 sampling trains. Upon completion
of the nitrogen purge, the samples were recovered

in accordance with the applicable methodologies;
the samples were clearly and uniquely labeled and readied for transport. (lravimetric analysis was conducted by Bureau \ 7 critas, Novi, Michigan. Laboratory data is presented

in Appendix
C.Derenzo and Associates, Inc. Trail Ridge Energy, L.L.C. 0352CC IC Engine

May 4, 2009 Compliance Test Report

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7 4.6 Volatile Organic Compound Measurement (USEPA Methods 25A118) The VOC emission rate from the engine was detenni ied by subtracting the methane concentration from the total hydrocarbon (T1IC) concentration. TI-IC concentrations were measured using

a flame ionization analyzer
in accordance with USEPA Method 25A. Methane concentrations were determined using

a Direct Methane, Non-Methane Analyzer
in accordance with USEPA Method 18. The resultant methane concentrations were subtracted from the THC concentrations giving VOC values. The VOC values were used in calculating VOC emission rates from the engine exhaust. Computer calculated and field data is presented
in Appendix
A. 4.7 Hydrogen Chloride Measurements (USEPA Method 26A) An integrated sample of the exhaust gas was withdrawn isokinetically from the IC engine exhaust stack. The Hydrogen chloride concentrations from the engine were deterrnmed
by ion specific electrode analysis of the ilnpinger contents
in accordance with USEPA Method 26A. The 0.1 N H 2 S0 4 samples were analyzed by Bureau Veritas, Novi, Michigan. Laboratory data is presented

in Appendix

C. 4.8 Visible Emissions Determinations (USEPA Method
9) Opacity determinations were performed using USEPA Method

9 where 15-second readings recorded on an observation report for a total of 60 minutes. 5.0 INTERNAL QAIQC ACTiVITIES 5.1 NO Converter Efficiency Test The NO 2 —NO conversion efficiency of the Model 42c analyzer was verified prior to the testing program.

A mixture of NO calibration gas and hydrocarbon free air gas was added to a Tedlar bag. The bag was attached
to the inlet of the analyzer and the instrument response was monitored

as the bag emptied. As the conversion efficiency test progresses the NO reacts with 02 to form NO 2 . The analyzer’s NO 2— NO converter uses
a catalyst
at high temperatures

to convert the NO 2 to NO for measurement. The conversion efficiency of the analyzer

is deemed acceptable

if the total NO concentration decreases
no more than 2% of the highest observed concentration over

a 30-minute time period. The NO 2 — NO conversion efficiency test satisfied the USEPA Method 7E criteria (measured NO concentration decreased by less than 2% over
a 30-minute time period). 5.2 Sampling System Response Time Determination The response time of the sampline sstn was determined poor to the compliance test piogiam by izmtroclucmu upscale eas and zero mis. in series, into the sampling system using

a Ice connection

at theDereiizo and Associates, Inc. Trail Ridge Energy, L.LC. G3520C IC Engine

May 4, 2009 Compliance Test Report

Page

8 base of the sample probe. The elapsed time for the analyzer
to display

a reading of 95% of the expected concentration was determined using

a stopwatch. 5.3 Dctenriination

of Exhaust Gas Stratification Gaseous sample extraction was performed

at sampling points corresponding

to the predetermined measurement points used for velocity measurements

in accordance with USEPA Method

I. It was determined that no stratification was present in the stack at the sampling location. 5.4 Instrumental Analyzer Interference Check The instrumental analyzers used to measure NOx, CO, 02 and CO 2 have had an interference response test perfonned prior to their use in the field, pursuant
to the interference response test procedures specified
in USEPA Method 7E. The appropriate interference test gases (i.e. gases that would he encountered

in the exhaust gas stream) were introduced into each analyzer, separately and as a mixture with the analyte that each analyzer

is designed
to measure. All of analyzers exhibited

a composite deviation of less than 3.0% of the span for all measured interferent gases. No major analytical components
of the analyzers have been replaced since performing the original interference tests. 5.5 Instrument Calibration and System Bias Checks At the beginning
of each day, initial three-point instrument calibrations were performed
by injecting calibration gas directly into the inlet sample port for each instrument. System bias checks were preformed prior to and at the conclusion
of each sampling period by introducing the appropriate upscale calibration gas and zero gas into the sampling system (at the base of the stainless steel sampling probe prior to the particulate filter and Teflon® heated sample line) and verifying the instrument response against the initial instrument calibration readings. The instruments were calibrated with USEPA Protocol

1 certified concentrations

of C0 2 , 02, NOx, CO, THC and zeroed using pure nitrogen
or hydrocarbon free air. 5.6 Meter Box Calibrations and Percent Isokinetics The isokinetic sampling console, which was used for isokinetic testing, was calibrated prior to and after the testing program. This calibration uses the critical orifice calibration technique presented

in IJSFPA Method

S The metering consol calibration exhibited no data outside the acceptable ranges presented

in US EPA Method

5. All tests were within the required +-l0% isokinetic sampling rate required by USEPA Methods 5/2 02 and 26A. Appendix

13 presents test equipment quality assurance data (i.e., NO 2— NO conversion efficiency test data, instrument cal ibratiori and system bias check records, calibration gas cer 0 ticatmumis, intem-tbrcnc’e test results, mimeter box calibration records. cvcluiiic flow determujtiius sheets, pilotDerenzo and Associates, Inc. Trail Ridge Energy, L.L.C. G3520C IC Engine

May 4, 2009 Compliance Test Report

Page
9 tube and probe assembly calibration records, nozzle calibration data, and opacity observation certification). Equipment calibration and certifications
are presented

in Appendix

B. I hereby certify that the information given in this report
is correct
to the best of my knowledge. This test report has been reviewed and is approved for submittal

to FDEP by the following representatives: Report Prepared By: Michael

J. Brack Field Services Manager Derenzo and Associates, Inc.Dereuzo nut! Associates, Inc. Trail Ridg Energy, L.L.C. G3520C IC Engine

May 4, 2009 Compliance Test Report

Page 10 Report Certification I certify that all data required and provided

to the person conducting the test are true and correct to my knowledge. Report Certified By: Scott Salisbury President Trail Ridge Energy, LL.C.Derento and Associates, Inc.

Table

I Particulate Matter less than 10 Microns (PM 10) Emission Rates from the Unit #4 Caterpillar Model G3520C Engine at Trail Ridge Energy, L.LC. Trail Ridge Landfill- Jacksonville, Duval County, Florida Test Date(s): March 25, 2009 Derenzo and Associates, Inc. Project No.: 0901014 Test Test Times Engine Output Moisture

02 C02 ID (EST) (Kw) (bhp)
(%)
(%)

(%) Unit4-Test

1 8:05- 9:10 1,551 2,167
11.4
8.28
10.9 Unit 4-Test

2 9:48- 10:53 1,581 2,208
11.6
8.29
10.9 Unit 4-Test

3 11:35- 12:40 1,600 2,235
10.4
8.30
11.0 Average 1,577 2,203

1 1.1 8.29
10.9 Particulate Matter (USEPA Method

5 Filterable) Test Flowrate Sample Volume Lab Weight Concentration

PM Emission Rates ID (dscfuii) (dscf) (mg) (mg/dscf) (lb/br) (g/bhp*hr) Unit 4-Test

1 4,591 40.97

8.1 0.20 0.12
0.03 Unit4-Test2 4,573 40.44

8.2 0.20
0.12
0.03 Unit4-Tcst3 4,668 41.18
11.2 0.27
0.17
0.03 Average
4,61

1 40.87

9.2 0.22
0.14
0.03 Particulate Matter (USEPA Method 202 Condensible) Test Flowrate Sample Volume Lab Weight Concentration

PM Emission Rates ID (dscfm) (dscf) (rng) (rng/dscf) (lb/br) (g/bhp*hr) Unit 4-Test

1 4,591 40.97
27.3 0.67
0.41
0.08 Unit 4-Test

2 4,573 40.44 27.6 0.68
0.41
0.08 Unit4-Test3 4,668 41.18
31.9 0.77
0.48
0.10 Average 4,611 40.87 28.9
0.71
0.43
0.09 PM-b (Filterable and Condensible) Test Flowrate Sample Volume Lab Weight Concentration

PM Emission Rates ID (dscfm) (dscf) (mg) (mgldscf) (lb/br) (g/bhp*hr) Unit 4-Test

1 4,591 40.97
35.4 0.86
0.53
0.11 Unit4-Test2 4,573 40.44
35.8 0.89 0.54
0.11 Unit4-Test3 4,668 41.18
43.1
1.05
0.65
0.13 Average 4,611 40.87
38.1
0.93
0.57
0.12 Permit Limit:
1.18
0.24 Definitions: (EST)
= Eastern Standard Time (Kw)
= Killowatt (bhp) brake horse power (dscfn)

= dry standard cubic feet per minute (dscf) =dry standard cubic feet (mg)
= milligrams (mg/dscf)

= milligrams per dry standard cubic foot (lb/br)

= pounds per hour (g/bhp*hr) grams per brake horse power hour Equations: (lb/br)

= (mg*0.0l 543)/dscf*dscfiri*0.00858 (g/hhp*hr)

= ih/hr*453.6 g/ib

* 0.7457 Kw/bhp

/ (Kw

/ 0.96 efficiency)Dci enzo and Associates, Inc.

Table

2 Hydrogen Chloride Emission Rates from the Unit #4 Caterpillar Model G3520C Engine at Trail Ridge Energy, L.L.C. Trail Ridge Landfill- Jacksonville, Duval County, Florida Test Date(s): March 25, 2009 Derenzo and Associates, Inc. Project No.: 0901014 Test Test Times Engine Output Moisture

0,
CO, ID (EST) (Kw) (bhp)
(%)
(%)

(%) Unit 4-Test

1 14:09- 15:14 1,601 2,236
11.7
8.27 10.91 Unit 4-Test

2 16:05- 17:11 1,600 2,235

1 1.1 8.24 10.95 Unit 4-Test

3 17:57- 19:01 1,598 2,233
10.6
8.22 10.98 Average 1,600 2,235
11.1
8.25 10.94 Hydrogen Chloride Test Flowrate Sample Volume Lab Weight Fuel Flow
HCI Emission Rates ID (dscfm) (dscf) (mg) (IvlMscf/hr) (lb/br) (lb/Mlvtscf) Unit 4-Test

1 4,555 38.37

0.5 0.03226
0.01
0.26 Unit 4-Test

2 4,582 72.17

3.4 0.03253
0.03
0.88 Unit 4-Test

3 4,648 72.43

3.5 0.03247
0.03
0.91 Average 4,595 60.99

2.5 0.03242
0.02
0.68 Permit Limit:
10.9 Definitions: (EST)

= Eastern Standard Time (Kw)
= Killowatt (bhp)
= brake horse power (dscfm)

= dry standard cubic feet per minute (dscf) dry standard cubic feet (mg) = milligrams (mg!dscf)

= milligrams per dry standard cubic foot (lb/br) pounds per hour (glbhp*hr)

= grams per brake horse power hour Equations: (lb/br)
= (mg*0.01543)/dscf*dscfm*0.00858 (g!bhp*hr)

= lb/hr*453.6 glIb

* 0.7457 Kw/bhp

/ (Kw

/ 0.96 efficiency)Dercnzo and Associates, Inc.

Table

3 Calculation
of HCL Emission Factor Based on Iniluent Landfill Gas Chlorinated Compounds to the Unit #4 Caterpillar Model G3520C Engine at Trail Ridge Energy, L.L.C. Trail Ridge Landfill- Jacksonville, Duval County, Florida Test Date(s): March 25, 2009 Derenzo and Associates, Inc. Projecl No.: 0901014 Analytical Report

No. FICI LFG Influcnt Chlorine Coumpounds Concentration Molecular Chlorine Emission Faclor (ppm) Formula Atoms (lb./MMcP) Freon 12 (Dichiorodifluoromethane)

0.600 CC1,F 2

2 0.113 Freon 114 (Dichiorotetrafluroethane)

<0.080 C 2 I,F 4

2 0.015 Chloromethane

<0.320 CH 3 I

1 <0.030 Vinyl Chloride

0.097 C 2 HCI

1 0.009 Chloroethane

<0.080 C,H 5 I

1 <0.008 Freon
11 (Fluorotrichloromethane)

<0.080 CFCI 3

3 0.023 Freon 113 (l,1,2-trichloro-1,2,2-trifluoroethane)

<0.080 C 2 1 F 3

2 <0.015 3-Chloropropene

<0.320 C 5 H I

1 <0.030 Methylene Chloride (Dichloromethane)
<0.080 CH 2 I

2 <0.015 I ,2-Dichloroethene

(as cis-

1 ,2-Dichloroethene)

0.320 C 2 H 1 7

2 <0.060 I .2-Dichloroetlsene(as trans-I ,2-Dichloroethene) <0.030 C,H 2 1

2 0.015 1.1-Dichloroethane

<0.080 C 2 F1 4 1,

2 <0.015 1,1-Dichloroethene

<0.080 C,H 2 1

2 <0.015 Chloroform

<0.080 CHCI 3

3 <0.023 1.1,1-Trichloroethane

<0.080 C 2 H 3 1

3 <0.023 Carbon Tetrachloride

<0.080 Cd 4

4 <0.030 1.2-Dichloroethane

<0.080 C,H 4 I,

2 <0.015 Trichloroethene

0.130 C 2 FICI 5

3 <0.037 1,2-dichloropropane

<0.080 C 3 H 6 I,

2 0.015 Bromodichloromethane

<0.080 CBrCI 2

2 <0.015 I ,3-Dichloropropene

(as cis-

1 ,3-Dichloropropene) <0.080 C 3 H 4 1 2

2 <0.015 1,3-Dichloropropene(as trans-1,3-Dichloropropene)
<0.080 C 3 H 4 1 2

2 <0.015 1,1,2-Trichloroethane

<0.080 C,H 3 l

3 <0.023 Tetrachioroethene (Perchloroethene)

0.250 C 2 1 4

4 <0.094 Dibromochloromethane

<0.080 CHBr 2 I

1 0.008 Chlorobenzene

<0.080 C 6 H 5 I

1 <0.008 1,1,2,2-Tetrachloroethane

<0.080 C 2 H,C1 4

4 0.030 l,3-Dichlorobenzene

<0.080 C 6 H 4 1 2

2 <0.02 I ,4-Dichlorobenzene

0,270 C 5 H 4 I,

2 <0.05 aipha-Chlorotoluene

<0.080 C 7 H 1

1 0.008 I ,2-Dichlorobenzene

<0.080 C 6 H 4 I 2

2 <0.02 I ,2,4-Trichlorobenzene

<0.3 20 C 6 H 3 1

3 <0.09 Hexachlorobutadiene

<0.320 C 4 1 6

6 <0.18 Total hydrogen chloride emission factor (lb/MMct)

<1.07 Average fuel flow (scfm)

540.3 Calculated hydrogen chloride emission rate (lb/hr)

<0.03

2 Sample Calculations: 1. E’ample calculation for Freon 12 that assumes complete conversion
of chloride

to 1-ICI (0.600 fi t Freon l2iMMcf LFG) (2 mol FlCl/mol Freon
2) (3646 lb. HClfmol)

I (387 ti’Jniol) 0.113 lb llCFhlMcflF(i 2 Example hydrogen chloride emission rate colculation

as lb/hr (I )7x 03 lb ll(l.ibl\lcl

I Eli

I l.000.Or)0 scl/hiNiset) 5$

3 scf/min. meg. inlet (1os to engines dunii’ sanitilmnma) (nO nunihr 1)03 lb Ily hrDerenzo

a id Assoc

a tes, Inc.

Table

4 Nitrogen Oxides. Ca boo Monoxide. and Volatile Orgasie (‘oinponnd Concentrations, Emission Rates, and Emission Factors from the Unit #4 Caterpillar Model G3520C Engine at Trail Ridge Energy, L.LC. Trail Ridge Landfill- Jacksonville, Duval Coutaty, Florida Test Date(s): March 25, 2009 Derenzo and Associates, Inc. Project No.: 0901014 Test Times Engine Output Moisture

0,
CO. (EST)
(Kw) (bhp)

(%)

(%)

(%) Test

1 805-905
1,551 2,167

11.4

8.3

10.9 Test2 952-1052
1581 2,208

11.6

8.3

10.9 Test3 1135-1235
1598 2,233

10.4

8.3
11.0 Average
1,577 2,203

11.1
8.29

10.9 NOx

NOx Instrumental NOx Corrected NOx Emission NOx Emission Test Flowrate Concentration Concentration
Rate Factor ID (dscfln)’ (ppmv) (ppmv) (lb/br) (glbhp*hr) Test

1 4,591 65.15 63.05
2.08
0.43 Test2 4,573 63.97 61.27
2.01

0.41 Test

3 4,668 68.07 65.21
2.18
044 Average
4,611 65.73 63.18
2.09
0.43 Permit Limits
2.95
0.60 Co

co CO Ittstrunsental (‘otrected
CO Emission CO Emission Test Flowrate Concentration Concentration

Rate Factor ID (dscfm)’ (ppmv) (ppmv) (lb/tsr) (g/bhpThr)— Pest

I 4,591

646

650 13.02
2.73 Test
2 4,573

649

653 13.04
2.68 lest

3 4.668

653

654 13.33

2.71 Average
4.611

649

652 13.13
2.70 Permit Limits 13.54
2.75 voc

THC

VOC Corrected Exhaust Methane Emission
VOC Teat Flowrate Concentration Concentration 2
Rate Emission Factor ID (scfin) t (ppmv) (ppmv) (lb/hr) 1 (glbhp*hr)S Test

I 5,180

562

628

0.0

0.0 Test
2 5,172

636

662

0.0

0.0 Test3 5,210

614

650

0.0

0.0 Average
5,188

604

647

0.0

0.0 Permit Limits
1.37
0.28 Notes:= Flosvrute calculation based on Type

S Pitot measurements (USEPA Methods

1 -4) pee-lest flosvrates 2= Exhaust gas methane concentration (pptsv-svet),

as propane 3= Calculated emission rate derived from in-8etd, methane subtracted from THC as propane Definitions: (Kw) Kittowatt

(EST)— Eastern Standard Time (bhp) brake horseposver

0,= Oxygen (g/bhp 5 hr) grams per brake horsepower hour

CO carbon dioxide (dschu) dry standard cubic feet per ntisute

NOx oxides of nitrogen )scfm) standard cubic feet per inmate (wet)

CO carbon monoxide (lb/br)= pounds per hour

THC total hydrocarbons (ppmv) parts per mitlion by volume-as propane

VOC sotatite organic compounds NOx, CO. and VOC Emission Rate Calculation Formulas: (63 pallistant!lOO

63 gas)

• (lb.niok’385

63 potiutant)
(lb pollutast/lh.nsol pollutant) (exhaust flosvrate 1t3’min) (60 mis/br)= Ensssios Rate (tb/br) (Emission Rite (lb/br)) 453.6 cR6) (blipi I/mission F,irtoi (g/bhphr)Derenzo and Associates, Inc. Table

5 Six-Minute USEPA Method

9 Opacity Averages for the Caterpillar Model G3520C Engine Unit #4 at Trail Ridge Energy, L.L.C. Trail Ridge Landfill- Jacksonville, Duval County, Florida Test Date(s): March 25, 2009 Derenzo and Associates, Inc. Project No.: 0901014 Start Time: 11:30 End Time: 12:30 Page

1 of

1 Minute

Second

6-mm_____________

0

15

30

45 Average 1

0

0

0

0 2

0

0

0

0 3

0

0

0

0 4

0

0

0

0 5

0

0

0

0- 6

0

0

0

0
0.0 7

0

0

0

0
0.0 8

0

0

0

0
0.0 9

0

0

0

0
0.0 10

0

0

0

0
0.0 11

0

0

0

0
0.0 12

0

0

0

0
0.0 13

0

0

0

0
0.0 14

0

0

0

0
0.0 15

0

0

0

0
0.0 16

0

0

0

0
0.0 17

0

0

0

0
0.0 18

0

0

0

0
0.0 19

0

0

0

0
0.0 20

0

0

0

0
0.0 21

0

0

0

0
0.0 22

0

0

0

0
0.0 23

0

0

0

0
0.0 24

0

0

0

0
0.0 25

0

0

0

0
0.0 26

0

0

0

0
0.0 27

0

0

0

0
0.0 28

0

0

0

0
0.0 29

0

0

0

0
0.0 30

0

0

0

0
0.0 6-minute average maximum

0.0

# Trail RidgeEnergy LLC Exhaust Stack

Condensate I / 

# Figure 1. TrailRidgeEnergy LLC LFGElectricityGeneraticn Facility Scale Sheet DerenzoandAssociates 

# None I ofI ProjectNo. 

# 0901014 LFGCollectionHeader Muffler

Air,’Gas Cooler TreatedLFG toEngines

Treatedwithleachate orreturnedto landfill GasTreatment System Engine Coolant Radiator

GeneratorSets

— 

# AdditionalFive (5)

IdenticalEngine0 - — 0 0 oo -t —. -t — -t -t -t (t 

## N ri-i


# N CID 0 0 ,, 0 0 0- tij= 0 — 0 Cu 0

# EngineExhausts

4.5 in. long SamplePorts Velocity sample lotions as measuredfromsampleportopening SamplePort

4 15.41 5 

# 17.74 6 19.46 

# Figure 

# 3. TrailRidgeEnergyLLC ExhaustSampleLocations DerenzoandAssociates ProjectNo. 

# 0901014 ExhaustStack Cross-Section



# Muffler

EngineFacilityRooftop

Scale 

# None Sheet 

# 1 of1

# 4/28/09 

# USEPAMethod3A,7E,1O,18/25A SampleTrain Sheet iDerenzoandAssociates 

# I of1 ProjectNo.

# 0901014 Stainless steel sampleprobe Spring-Ioaded

checkvalve

7-MicronSS ParticulateFilter Heated sampleline
HeatedTeflon line Calibration Sample Pump DataLogger

Gas Divider

Zero Gas 

# (HCFreeAir!

— 

# Nitrogen) Excesssample toatm 

# Figure4.
Calibrationgases Scale 

# None

# GlassFilter Housing GlassImpingers Stainless Steel HeatTracedGlass-LinedSample Probe J-Bar

NutechSamplingand

MeteringConsole Impinger# 1: 100mLofDIH20 Impinger#2: 100mLofDIH20 Impinger#3: lOOmLofDIH2O Impinger#4: DriedSilicaGel PitotTube _________



# TemperatureSensor ____________



# StainlessSteelNozzle /Type-S PitotTube 

# Ice!Water Bath



# fl VacuumGauge

=

# Temperature Measurement (rfct,,r1rri 

# std or ‘mod’

Exhaust Orifice 

# VacuumLine

Air-Tight

Pump 

# Figure 

# 5. USEPAMethod5/202 Scale 

# None Sheet DerenzoandAssociates 1 

# of1 ProjectNo. 0901014

# HeatTracedGlass-LinedSample Probe 

# GlassFilter Housing GlassImpingers 

# J-Bar

ImpingerContents(indicateStandard ‘std’ orModified“mod”)



# Irnpinger# 1: 100mLof0.1NHSO 4 (std) lrnpinger#2: 100mLof0.INH 2 SO 4 (std) Impinger#3: 100mL of0. 1 NNaOH(mod)* Impinger#4: 100mLof0.1 NNaOH(mod)* Impinger#5: DriedSilicaGel(mod)

* 

# DiNNaOHimpingersmaybereplaced

# withempty

knockoutimpingeraschlorideemissionswillnotbe measured.

Scale 

# None DerenzoandAssociates ProjectNo. 

# 0901014 Pitot PitotTube

TemperatureSensor 

# ---( GlassNozzle Type-S PitotTube



# VacuumGauge Ice!Water Bath

Temperature Measurement

Exhaust Bypass Valve
OrIfice Main Valve 

# VacuumLine

Air-Tight

Pump 

# Figure 6. Nutech Samplingand

Metering Console 

# USEPAMethod26ASampleTrain Sheet 

# I ofIAPPENDIXACOMPUTERCALCULATEDANDFIELDDATAEXHAUST GAS VELOCITY, MOISTURE, AND FLOWRATE CALCULATION SHEET Company

Trail Ridge Energy Source Designation
ICE # 4 Pitot Tube Number

5F Test Date 3/25/2009
Pitot Tube Corr. Factor
0.84 Test Number

Pre-1

% CO 2

10.86 Time

7:45

% 02

8.28 Barometric Pressure 30.13

% CO

0.00 Stack Static Pressure
7.70

% N

80.86 Stack Diameter (in.) 15.50

Md

30.07 Traverse points

12

Ms

28.70 Operator TS/DW Moisture Content (%)
11.4 Traverse

Traverse Point Stack Temp. Velocity Pres. Point Stack Temp. Velocity Pres. Number
(°F) (“H20) Number
(°F) (“H20) Side A

Side B 1 881 3.30

1 879
3.20 2
881 3.60

2 880
3.20 3 882 3.60

3 880
3.30 4 884 3.50

4
881
3.50 5 880 3.50

5 882
3.40 6 878 3.40

6
881
3.10 Average

881 3.48

881
3.28 Average Velocity Pressure (“H,O)

3.3 83 Average Velocity Pressure Sqrt (“H 2 0) 1.839 Stack Pressure (“Hg)

30.70 Stack Gas Specific Gravity (Gs)
0.99 Average Stack Temperature (°F)

881 Average Stack Velocity (fps)
162.9 Average Stack Velocity (fpm) 9775.0 Area of Stack (ft 2 )

1.3 10 Flowrate (Actual-CFM)

12,809 Flowrate (Standard Wet-SCFM)
5,175 Flowrate (Standard Dry-DSCFM)
4,586 Derenzo and Associates, Inc.EXHAUST GAS VELOCITY, MOISTURE, AND FLOWRATE CALCULATION SHEET Company

Trail Ridge Energy Source Designation
ICE #4 Pitot Tube Number

5F Test Date 3/25/2009
Pitot Tube Corr. Factor
0.84 Test Number Post-i Pre-2

% CO 2

10.94 Time

9:15

% 02

8.29 Barometric Pressure 30.13

% CO

0.00 Stack Static Pressure
7.50

% N

80.77 Stack Diameter (in.) 15.50
Md

30.08 Traverse points

12

Ms

28.68 Operator TS/DW Moisture Content (%)
11.6 Traverse

Traverse Point Stack Temp. Velocity Pres. Point Stack Temp. Velocity Pres. Number
(°F) (H2O) Number
(°F) (“H20) Side A

Side B 1 879 3.20

1 876
3.00 2 880 3.20

2
878
3.30 3
881 3.40

3 880
3.50 4 879 3.70

4 878
3.40 5 878 3.50

5 876
3.50 6 877 3.50

6 877
3.30 Average
879 3.42

878
3.33 Average Velocity Pressure (“H 2 0)

3.3 75 Average Velocity Pressure Sqrt (“H 2 0) 1.836 Stack Pressure (“Hg)

30.68 Stack Gas Specific Gravity (Gs)
0.99 Average Stack Temperature (°F)

878 Average Stack Velocity (fps)
162.6 Average Stack Velocity (fpm) 9757.8 Area of Stack (ft 2 )

1.310 Flowrate (Actual-CFM)

12,786 Flowrate (Standard Wet-SCFM)
5,173 Flowrate (Standard Dry-DSCFM)
4,574 1)erenzo and Associates, Inc.EXHAUST GAS VELOCITY, MOISTURE, AND FLOWRATE CALCULATION SHEET Company

Trail Ridge Energy Source Designation

ICE #4 Pitot Tube Number

5F Test Date 3/25/2009
Pitot Tube Corr. Factor
0.84 Test Number Post-2 Pre-3

% CO 2

10.96 Time

11:00 %02

8.30 Barometric Pressure 30.13

% CO

0.00 Stack Static Pressure
7.50

% N

80.74 Stack Diameter (in.) 15.50

Md

30.09 Traverse points

12

Ms

28.83 Operator TS/DW Moisture Content (%)
10.4 Traverse

Traverse Point Stack Temp. Velocity Pres. Point Stack Temp. Velocity Pres. Number
(°F) (“H20) Number
(°F) (UH2O) Side A

Side B 1 881 3.20

1 878
3.10 2 879 3.50

2 880
3.30 3 880 3.70

3
883
3.50 4 882 3.40

4 879
3.60 5 880 3.40

5 878
3.50 6 879 3.50

6 877
3.30 Average
880 3.45

879
3.38 Average Velocity Pressure (‘H 2 0)

3.4 17 Average Velocity Pressure Sqrt (“H 2 0) 1.848 Stack Pressure (“Hg)

30.68 Stack Gas Specific Gravity (Gs)

1.00 Average Stack Temperature (°F)

880 Average Stack Velocity (fs)
163.3 Average Stack Velocity (Thm) 9798.7 Area of Stack (ft 2 )

1.310 Flowrate (Actual-CFM)

12,840 Flowrate (Standard Wet-SCFM)
5,189 Flowrate (Standard Dry-DSCFM)
4,650 Derenzo and Associates, Inc.EXHAUST GAS VELOCITY, MOISTURE, AND FLOWRATE CALCULATION SHEET Company

Trail Ridge Energy Source Designation
ICE #4 Pitot Tube Number

5F Test Date 3/25/2009
Pitot Tube Corr. Factor
0.84 Test Number Post-3 Pre-4

% CO 2

10.91 Time

12:50

% 02

8.27 Barometric Pressure 30.13

% CO

0.00 Stack Static Pressure
7.70

% N 2

80.82 Stack Diameter (in.) 15.50

Md

30.08 Traverse points

12

Ms

28.66 Operator TS/DW Moisture Content (%)
11.7 Traverse

Traverse Point Stack Temp. Velocity Pres. Point Stack Temp. Velocity Pres. Number
(°F) (“H20) Number
(°F) (“H20) Side A

Side B 1 877 3.10

1 875
3.00 2 876 3.20

2 880
3.20 3 880 3.30

3
881
3.60 4 879 3.40

4 876
3.50 5 880 3.50

5 878
3.40 6 878 3.40

6 876
3.40 Average
878 3.32

878
3.35 Average Velocity Pressure (“H 2 0) 3.333 Average Velocity Pressure Sqrt (“H 2 0) 1.825 Stack Pressure (“Hg)

30.70 Stack Gas Specific Gravity (Gs)
0.99 Average Stack Temperature (°F)

878 Average Stack Velocity (Ths)
161.6 Average Stack Velocity (fpm) 9697.8 Area of Stack (ft 2 )

1.3 10 Flowrate (Actual-CFM)

12,708 Flowrate (Standard Wet-SCFM)
5,145 Flowrate (Standard Dry-DSCFM)
4,542 Derenzo and Associates, Inc.EXhAUST GAS VELOCITY, MOISTURE, AND FLOWRATE CALCULATION SHEET Company

Trail Ridge Energy Source Designation
ICE #4 Pitot Tube Number

5F Test Date 3/25/2009
Pitot Tube Corr. Factor
0.84 Test Number Post-4 Pre-5

% CO 2

10.95 Time

15:20

% 02

8.24 Barometric Pressure 30.13

% CO

0.00 Stack Static Pressure
7.60

% N 2

80.81 Stack Diameter (in.) 15.50
Md

30.08 Traverse points

12

Ms

28.73 Operator TS/DW Moisture Content (%)

11.1 Traverse

Traverse Point Stack Temp. Velocity Pres. Point Stack Temp. Velocity Pres. Number
(°F) ( 11 H20) Number
(°F) (H2O) Side A

Side B 1 878 3.00

1 872
3.20 2 875 3.30

2 875
3.50 3 876 3.30

3 876
3.50 4 877 3.40

4 877
3.60 5 875 3.20

5 875
3.50 6 874 3.40

6 874
3.30 Average
876 3.27

875
3.43 Average Velocity Pressure (“H 2 0) 3.350 Average Velocity Pressure Sqrt (“H 2 0) 1.830 Stack Pressure (“Hg)

30.69 Stack Gas Specific Gravity (Gs)
0.99 Average Stack Temperature (°F)

875 Average Stack Velocity (Ths)
161.7 Average Stack Velocity (Thm) 9701.6 Area of Stack (ft 2 )

1.310 Flowrate (Actual-CFM)

12,713 Flowrate (Standard Wet-S CFM) 5,156 Flowrate (Standard Dry-DSCFM)
4,581 Dercnzo and Associates, Inc.EXHAUST GAS VELOCITY, MOISTURE, AND FLOWRATE CALCULATION SIIEET Company

Trail Ridge Energy Source Designation
ICE #4 Pitot Tube Number

SF Test Date 3/25/2009
Pitot Tube Corr. Factor
0.84 Test Number Post-5 Pre-6

% CO 2

10.98 Time

17:15 %02

8.22 Barometric Pressure 30.13

% CO

0.00 Stack Static Pressure
7.50

% N

80.80 StackDiameter (in.) 15.50
Md

30.09 Traverse points

12

Ms

28.81 Operator TS/DW Moisture Content (%)
10.6 Traverse

Traverse Point Stack Temp. Velocity Pres. Point Stack Temp. Velocity Pres. Number
(°F) (“H20) Number
(°F) (“H20) Side A

Side B 1 877 3.00

1 873
3.30 2 878 3.30

2 879
3.60 3 877 3.30

3 876
3.70 4 880 3.60

4 875
3.60 5 879 3.30

5
873
3.50 6 878 3.40

6 874
3.40 Average
878 3.32

875
3.52 Average Velocity Pressure (“H 2 0) 3.417 Average Velocity Pressure Sqrt (“H 2 0) 1.848 Stack Pressure (“Hg)

30.68 Stack Gas Specific Gravity (Gs)
0.99 Average Stack Temperature (“F)

877 Average Stack Velocity (Ths)
163.2 Average Stack Velocity (fpm) 9790.2 Area of Stack (ft 2 )

1.310 Flowrate (Actual-.CFM)

12,829 Flowrate (Standard Wet-SCFM)
5,197 Flowrate (Standard Dry-DSCFM)
4,647 Derenzo and Associates, Inc.EXHAUST GAS VELOCITY, MOISTURE, AND FLOWRATE CALCULATION SHEET Company

Trail Ridge Energy Source Designation

ICE #4 Pitot Tube Number

5F Test Date 3/25/2009 Pitot Tube Corr. Factor
0.84 Test Number
Post-6

% CO

10.98 Time

19:05

% 02

8.22 Barometric Pressure 30.13

% CO

0.00 Stack Static Pressure
7.00

% N 2

80.80 Stack Diameter (in.) 15.50
Md

30.09 Traverse points

12

Ms

28.81 Operator TS/DW Moisture Content (%)
10.6 Traverse

Traverse Point Stack Temp. Velocity Pres. Point Stack Temp. Velocity Pres. Number
(°F) (H2O) Number
(°F) (“H20) Side A

Side B 1 878 3.20

1
873
3.00 2 876 3.40

2 878
3.40 3 876 3.60

3 879
3.60 4 873 3.50

4 879
3.60 5 878 3.40

5 876
3.50 6 872 3.50

6
873
3.00 Average
876 3.43

876
3.35 Average Velocity Pressure (‘H 2 0)

3.3 92 Average Velocity Pressure Sqrt (‘H 2 0) 1.841 Stack Pressure (“Hg)

30.64 Stack Gas Specific Gravity (Gs)
0.99 Average Stack Temperature (°F)

876 Average Stack Velocity (fps)
162.6 Average Stack Velocity (Thm) 9756.8 Area of Stack (ft 2 )

1.310 Flowrate (Actual-CFM)

12,785 Flowrate (Standard Wet-SCFM)
5,175 Flowrate (Standard Dry-DSCFM)
4,628 Derenzo and Associates, Inc.

# Derenzo andAssociates, inc.

Company Trail Ridge

# Energy Source Designation ICE #4 

# Exhaust Test Date 3/25/2009 Assumed Moisture (Bws) 13 

# TestNumber TREP-I Condensate Volume (Vie) 100.7 Operator TS’D\V 

# Silica GelWeightGain (Vie) 11.0 Filter Number 124087 Nozzle Diameter

# (in.) 0.19 Barometric Pressure (Pb) 30.13 LeakRate Initial 0.006

# @ 15” 

# StackStatic Pressure (Ps) 7.70 

# LeakRate Final 0.000 @5’ StackDimensions (in.) 5.5 Traverse points 12 PitotTubeNumber SF Pitot Corr. Factor (Cp) 0.84 fvleterNumber Ni MeterCorr. Factor(Y) 1.002I Meter iso. Factor(Kiso) 823.534 Method 3A Results 

# (%) Delta H@ 2.026 CO, 10.86 0, 8.28 Traverse SamplingTime Sampling StackTemp. Velocity Pres. Orifice Sample Volume Dry Gas MeterTemp. Probe FilterBox Last Impinger

Point (Minutes) ClockTime Train Vuc. 

# (nF) (“H,O) Differential (cubic feet) Inlet Outlet Temperature Temperature Temperature Number 

# o (24 hour) (Hg) Ts DeltaP (“H.O) Delta H Vm (°F) Tm (°F)Tm (°F) (°F) (°F)

1 0 8:05:00 

# 3 890 3.30 1.68 307.855 78 77 252 250 60 2 

# 5 8:10:00 

# 3 895 3.60 1.83 311.27 79 78 253 253 61 3 

# [0 8:15:00 3 892 3.60 1.84 3)4.79 81 78 253 252 62 4 15 8:20:00 

# 3 894 3.50 1.79 318.38 83 79 253 251 63 5 20 8:25:00 

# 3 892 3.50 1.80 321.87 85 79 253 250 65 

# 6 25 830:00 

# 3 894 3.40 1.74 325.36 86 79 254 251 64 off 30 835:00

-

-

-

- 

# 328.817

-
-

- 

# -
- 

# I 30 8:40:00 

# 3 880 3.20 1.65 328.817 82 80 253 250 62 2 35 8:45:00 3 882 3.20 1.66 332.18 86 80 253 252 62 3 40 8:50:00 3 885 3.30 1,71 335.55 88 80 252 251 57 4 45 8:55:00 3 883 3.50 1.82 339.02 89 81 254 251 56 5 50 9:00:00 3 886 3.40 1,77 342.52 91 81 254 251 56 6 55 0:05:00 3 885 3.10 1.6! 346,01 91 82 255 251 57 off 60 9:10:00

-

-

-

- 

# 340,388

-

-

-


# -

- 

# ?verage 60 888.2 3.38 1.74 41.533 85 80 253 251 60

# Derciazo and Associates, Inc.

Company TrailRidge Energy 

# Source Designation ICE #4 Exhausl 

# TestDate 3/25)2009 Assumed Moisture (Bsvs) 13 Test Number TREP-2 Condensate Volume

# (Vie) 98.9 Operator TS/DW Silica Gel

# WeightGain (Vie) 13.7 FilterNumber 124088 Nozzle Diameter(in.) 0.19 

# Barometric Pressure (Pb) 30.13 LeakRate Initial 0.000 @ 15” 

# StackStatic Pressure (Ps) 7.50 LeakRate Final 0.000 @7 StackDimensions 

# (in.) 15.5 

# Traversepoints 12 PilotTubeNumber 5F 

# Pitot Corr. Factor(Cp) 0.84 MeterNumber N-i 

# MeterCorr. Factor(Y) 1.0021 Meteriso. Factor(lOso) 1823.534 Method 3A Results 

# (%) Delta H@ 2.026 CO 2 10.94 O 8.29 Traverse SamplingTime Sampling StackTemp. VelocityPres. OrifIce Sample Volume 

# DryGasMeterTemp. Probe FtlterBox LastImpmger

Point (Minutes) ClockTime Train Vac. 

# (°F) (“H.O) Differential (cubic feet) Inlet Outlet Temperature Temperature Temperature Number 

# o (24 hour) (Hg) Ts DeltaP (“HO) Delta H Vm (°F) Tm (°F) Tm (°F) (°F) (°F)

1 0 9:48:00 3 883 3.20 1.65 349.474 82 81 242 252 63 2 5 9:53:00 3 886 3.20 1.06 352.81 87 82 248 251 61 3 tO 9:58:00 3 888 3.40 1.77 356.08 91 83 251 253 63 4 15 10:03:00 4 889 3.70 1.93 359.55 94 83 252 251 62 5 20 10:08:00 3 897 3.50 tOt 363.21 96 84 252 252 63 6 25 10:13:00 3 893 3.50 1.82 366.7t 96 85 253 251 64 off 30 10:18:00

.

-

-

- 

# 370.939

-

.

.

-

- 

# I 30 10:23:00 3 883 3.00 1.57 370.939 90 86 253 250 62 2 35 10:20:00 3 886 3.30 1.73 373.56 95 87 252 252 64 3 40 10:33:00 3 889 3.50 1.83 377.01 96 87 252 252 60 4 

# 45 10:38:00 3 889 3.40 1.78 380.51 97 87 252 252 60 

# 5 50 10:43:00 3 890 3.50 t.84 384.02 98 88 254 252 61 6 55 10.48:00 3 892 3.30 1.73 387.52 99 88 253 251 61 off 60 10:53:00

. -

-

- 

# 391.003

-

-

-

- 

# Average 60 888.8 3.38 1.76 41.53 93 85 251 252 62

# Derenzo and Associates, Inc.

Company Trail Ridge Energy 

# Source Designation ICE#4 Exhaust 

# TestDate 3/25/2009 Assumed Moisture 

# (Bws) 13 

# TestNumber TREP-3 

# CondensateVolume (VIe) 80.3 Operator TS/D\V 

# Silica Gel Weight Gain (VIc) 21.2 

# FilterNumber 124089 

# NozzleDiameter(in.) 0.19 

# BarometricPressure (Pb) 30.13 

# LeakRate Initial 0.000 IS 

# StackStatic Pressure (Ps) 7.50 

# LeakRateFinal 0.000 

# @ 5’ 

# StackDimensions (in.) 5.5 

# Traverse points 12 

# PitotTube Number SF Pitot Corr. Factor(Cp) 0.84 Meter Number N-I 

# MeterCorr. Factor(Y) 1.0021 

# Meteriso. Factor(Kiso) 1823,534 

# Method 3AResults (%) Delta H@ 2.026 

# CO 2 10.96 02 8.30 Traverse Sampling Time Sampling StackTemp. VelocityPres. Orifice Sample Volume Diy Gas MeterTemp. Probe FilterBox Last Impinger

Point (Minutes) ClockTime Train Vac. (nF) (‘ffO) Differential (cubic feet> Inlet Outlet Temperature Temperature Temperature Number n (24 boar) (‘l-Ig) Ts Delta P CHO) Delta H Vm (°F)Tm (°F) Tm (°F) (°F) (°F)

1 0 11:35:00 

# 3 878 3.20 1.67 391.180 86 86 245 250 66 2 S 11:40:00 

# 3 879 3.50 1.83 394.72 90 86 252 251 64 3 10 11:45:00 

# 3 879 3,70 1.95 398,27 94 86 253 252 60 4 15 11:50:00 3 881 3.40 1.79 402,09 92 87 251 252 58 5 20 1 :55:00 3 880 3.40 1.79 405.50 98 87 252 252 57 a 25 12:00:00 3 878 3.50 1,86 408.95 100 88 254 252 57 off 30 12:05:00

-

-

-

- 

# 412.577

-

-

-

-

- 

# I 30 12:10:00 3 883 3.10 1.63 412,577 92 88 252 250 62 2 35 12.15:00 3 878 3.30 1.75 415.900 98 89 255 252 59 3 40 12:20:00 3 872 3.50 1.87 419.40 100 90 253 251 59 4 45 12:25:00 3 875 3.60 1.92 423.02 102 90 254 251 59 5 50 12:30:00 3 886 3.50 1.85 426.64 102 91 253 251 59 Ii 

# 55 12:35:00 3 879 3.30 1.76 430.20 103 91 254 250 60 off 60 240:00

-


# -

-

- 

# 433.701

-

-


# .

- 

# 0 Average 

# 60 879.0 3.42 I 01 42.52 96 88 252 251 60

# Dcrenzo and Associates, Inc.

Company Trail RidgeEnergy Source Designation ICE84 Exhaust TestDate 3/25/2009 Assumed Moisture (Bws) 13 TestNunsber TREHCL-1 CondensateVolume (VIe) 94.9 Operator TS/DW SilicaGel WeightGain (Vie) 13.2 Filter Number N/A Nozzle Diameter(in.) 0.185 BarometricPressure (Pb) 30.13 LeakRateInitial 0.000

# @ 15” StackStatic Pressure(Ps) 7.70 LeakRateFinal 0.000

# @ 15” StackDimensions (in.) 15.5 Traversepoints 12 PitotTubeNumber SF PitotCorr. Factor(Cp) 0.84 MeterNumber N-I MeterCorr. Factor(Y) 1.0021 Meter iso. Factor

# (Kiso) 1823.534 Method 3AResults (°/) DeltaH@ 2.026 (Analyzer) CO 2 10.91 (Analyzer) 02 8.27 Traverse Sampling time Sampling StackTemp. Velocity Pres. Orifice SampleVolume 

# OreGasMeterTemp. FillerBox Probe Iautlmpinger

Point (Minutea) ClockTime Train\‘ac. (°F) (‘H,O) Differential (cubic feet) Inlet Outlet Temperature Temperature Temperature Number 0 

# (24 hour) (“Hg) Ta DeltaP (‘l-LO) DeltaH Vm (°FTm (°FTm (°F) (° 

# 1 0 14:09:00 2 879 3.10 1.47 434.546 91 90 245 253 67 2 5 14:14:00 3 879 3.20 1.52 437.76 94 90 247 253 61 3 10 14:19:00 3 887 3.30 1.56 440.98 98 91 249 253 61 4 15 14:24:00 3 878 3.40 1.62 444.25 100 91 251 252 63 5 20 14:29:00 3 881 3.50 1.67 447.62 102 91 251 252 65 6 25 14:34:00 3 887 3.40 1.62 450.97 103 92 253 251 63 off 30 14:39:00

-

-

-

- 

# 454.335

-

-

-

-

- 

# 1 30 14:44:00 3 879 3.00 1.42 454.335 94 91 252 250 57 2 35 14:49:00 3 877 3.20 1.53 457.58 100 92 253 253 65 3 40 14:54:00 3 883 3.60 1.72 460.99 101 92 253 252 66 4 45 14:59:00 3 881 3.50 167 464.36 102 92 253 251 61 5 50 15:04:00 3 875 3.40 1.63 467.76 103 92 254 250 63 6 55 15:09:00 3 881 3.40 1.62 471.09 102 93 254 251 60 off 60 15:14:00

-


# -

-



# - 

# 474.396

- 

# -

-

-

- 

# Average 60 880.6 3.33 1.59 39.850 99 91 251 252 63

# Dcrenzo and Associates, Inc.

Company 

# Troll RidgeEnergy Source Designation ICE#4Exhaust TestDate 

# 3/25i2009 Assumed Moisture (Bws) 13 TestNumber TREHCL-2 CondensateVolume(VIe) 156.6 Operator TS)DW Silica Gel

# WeightGain (VIe) 35.7 FilterNumber N/A Nozzle Diameter(in.) 0.25 Barometric Pressure (Pb) 30.13 LeakRate Initial 0.000

# @ 15” StackStaticPressure(Ps) 7.60 LeakRate Final 0.000

# @ 5” StackDimensions (in.) 15.5 Traversepoints 12 PilotTubeNumber 5F PilotCorr. Factor(Cp) 0.84 MeterNumber N-I MeterCorr. Factor(Y) 1.0021 Meteriso. Factor(Kiso) 1823.534 Method 3A Results (%) Delta l1@ 2.026 (Analyzer) CO 2 10.95 (Analyzer) 02 8.24 Traverse SamplingTime Sampling SlackTemp. VelocityPres. 

# Orifice SampleVolume DryGasMeterTemp. FilterBox 

# Probe Last

# linpinger

Point (Minutes) ClockTime Train Vac. (“F) (“H,O) Differential (cubic 

# feet) Inlet Outlet Temperature Temperature Temperature Number 0 

# (24 hour) (Hg) Ts DeltaP (“H,O) DellaH Vm (“F) Tm (°F)Tm (“F) (“F) (°F) I 0 

# 16:05:00 6 875 3.00 

# 4.77 475.742 91 89 248 251 

# 63 2 5 16:10:00 7 883 3.30 5.25 481.56 97 90 251 252 63 3 10 16:15:00 7 877 3.30 5.30 487.61 103 90 251 253 62 4 15 16:20:00 7 888 3.40 5.44 493.61 106 92 252 252 64 5 20 16:25:00 8 888 3.20 5.13 499.91 107 92 253 252 62 6 

# 25 16:30:00 7 892 3.40 

# 5.44 505.13 107 93 254 251 61 

# off 30 16:35:00

- -

- 

# 512.439

- - - - 

# I 30 16:41:00 7 879 3.20 5.12 512.439 96 93 255 250 60 2 35 16:46:00 7 884 3.50 5.61 518.53 103 93 253 252 60 3 40 16:51:00 8 891 3.50 5.60 524.81 106 93 253 251 61 4 45 16:56:00 8 883 3.60 5.80 531.19 109 94 254 252 60 5 50 17:01:00 7 887 3.50 5.64 537.57 110 95 254 52 61 6 55 17:06:00 7 890 3.30 5.31 543.89 110 95 255 251 63 off 60 17:11:00

- 

# -

-



# - 

# 550.382

- 

# -

- - 

# Average 60 884.8 3.35 5.37 74.640 104 92 253 235 62

# Dercnzo and Associates, Inc.

Company Trail Ridge Energy 

# SourceDesignation ICE#4 Exhaust Test Date 3/25/2009 AssumedMoisture(lSws) 13 TestNumber TREI-{CL-3 CondensateVolume(VIe) 148.5 Opcrator TS/DW SilicaGel WeightGain(VIe) 33.4 FilterNumber N/A Nozzle Diameter (in.) 0.25 Barometric Pressure (Pb) 30.13 LeakRate Initial 0.000

# @ 15” StackStatic Pressure (Ps) 7.50 LeakRate Final 0.000

# @ 10’ StackDimensions(in.) 15.5 Traversepoints 12 PilotTubeNumber SF PilotCorr. Factor(Cp) 0.84 MeterNumber N-I MeterCorr. Factor(Y) 1.0021 Meteriso.Factor(Kiso) 1823.534 Method 3AResults 

# (%) DeltaH@ 2.026 (Analyzer) CO 1 10.98 (Analyzer) 

# 02 8.22 

# Traverse SamplingTime Sampling StackTemp. VelocityPres. Orifice 

# SampleVolume 

# DryGasMeterTemp. FilterBox Probe 

# LastImpinger

Point (Minutes) ClockTime Train

# Vac. (°F) (“HQ) Differential (cubic feet) Inlet Outlet Temperature Temperature Temperature 

# Number 0 

# (24

# hour) (“Hg) Ts Delta P (“H 2 0) DeltaH Vni (°FTm (°FTm (°F) (°F (°F) I 0 17:57:00 7 881 3.00 4.76 550.665 92 90 252 250 59 2 5 18:02:00 7 888 3.30 5.24 556.48 100 90 254 252 56 3 10 18:07:00 7 884 3.30 5.29 562.49 106 91 254 252 58 4 15 18:12:00 7 887 3.60 5.78 568.76 108 92 254 252 61 5 20 18:17:00 7 885 3.30 5.31 574.98 108 93 254 251 62 5 25 18:22:00 7 896 3.40 5.43 581.22 109 94 255 252 63 

# off 30 18:27:00

-
. .

- 

# 587.533

-
. -

-

- 

# I 30 18:31:00 7 886 3.30 5.25 587.533 97 93 253 250 61 2 35 18:36:00 7 884 3.60 5.77 593.660 104 93 252 252 60 3 40 18:41:00 7 888 3.70 5.93 599.96 106 93 255 252 63 4 45 18:46:00 9 883 3.60 5.80 606.92 107 94 255 251 61 5 50 18:51:00 9 888 3.50 5.62 612.88 108 94 255 251 61 6 55 18:56:00 9 887 3.40 5.48 619.63 108 94 253 251 62 off 

# 60 19:01:00

- 

# . .

- 

# 625.615

. . - .
- 

# Average 

# 60 886.4 3.42 5.47 74.95 104 93 254 251 61

# ON —

— 

# U. 0— U. U. DC



# _so—, U.DCDC 0



# 0

0

0



# 0 .U UJ

- 

# p 0 flP ONONU.DC 

# 0 0 0 0 U. 

# 0

- 

# —4 ‘0Derenzo

& Associates, Inc. EPA Method
10 CO Calculation Summary Company: Trail Ridge Energy Location: Jacksonville,
FL Source: Engine #4 Date: 3/25/2009

Test

1 Test
2 Test

3 Average CO concentration

= 646.1 648.9 653.1 ppmv Average pre-test and post-test instrument zero

= 0.24 0.28 1.26 ppmv Average pre-test and post-test instrument calibration
601.2 600.6 603.6 ppmv Midrange calibration gas concentration

= 604.5 604.5 604.5 ppmv Volumetric flow rate

= 4,593 4,574 4,669 dscfm Average generator kilowatt output

= 1,551 1,581 1,598 kW CO CONCENTRATION CORRECTED FOR CALIBRATION AND ZERO DRIFT Cd(CO conc.-Avg. zero)x(Cal. gas conc.)/(Avg. cal-Avg. zero)

= 649.7 653.1 654.2 ppmv CO EMISSION RATE (Cd) (Qdstd) (60 min!hr) (MW 0

I (V)

13.03 13.04 13.33 lb/hr where: Cd = observed CO concentration,
dry basis (ft 3 CO

/ 106 ft 3 stack gas) Q std stack gas flowrate (dscfm) MW 0 molecular weight CO (28.0 ib/Ib-mol) VM = molar volume of ideal gas at std conditions (385 ft 3 Ilb-mol) Engine Output (bHp)
= (kWavg)/(O.96)/(O.7457 kWfbHp)

= 2167 2208 2233 bHp where: kWavg
= average recorded generator kilowatt output 0.96 = engine to generator efficiency 0.7457

= conversion factor, kilowatts
to brake horsepower (Ec 0 ) (453.6 g/ib) /(bHp)

2.73 2.68 2.71 g/bHp*hr where: E 0 = CO emission rate (lb/hr) 453.6
= conversion factor, grams to pounds bHp = engine brake horsepowerDerenzo

& Associates, Inc. EPA Method 7E NOx Calculation Summary Company Trail Ridge Energy Location Jacksonville,
FL Source Engine #4 Date 3/25/2009

Test

1 Test
2 Test

3 Average NOx concentration

= 65.1 64.0 68.1 ppmv Average pre-test and post-test instrument zero

= 0.66 1.00 0.77 ppmv Average pre-test and post-test instrument calibration

= 99.1 99.9 100.1 ppmv Midrange calibration gas concentration

= 96.3 96.3 96.3 ppmv Volumetric flow rate

= 4,593 4,574 4,669 dscfm Average generator kilowatt output
1,551 1,581 1,598 kW NOx CONCENTRATION CORRECTED FOR CALIBRATION AND ZERO DRIFT Cd = (NOx cone-Avg. zero)x(CaI. gas conc.)/(Avg. cal-Avg. zero)

=

63.1 61.3 65.2 ppmv NOx EMISSION RATE. AS NO., ENOX
= (Cd) (Qdstd) (60 minfbr) (MWN 0 ,)

/ (VM)

= 208 2.01 2.18 lb/hr as NO, where: Cd = observed NOx concentration,
dry basis (ft 3 NOx

/ 106 ft 3 stack gas) Qdstd
= stack gas flowrate (dscfm) MWNOX

= molecular weight NO, (46.0 ib/Ib-mol) VM = molar volume of ideal gas at std conditions (385 fl 3 /lb-mol) Engine Output (bHp)
= (kWavg)/(O.96)/(0.7457 kW/bHp)

= 2167 2208 2233 bHp where: kWavg
= average recorded generator kilowatt output 0.96 = engine to generator efficiency 0.7457

= conversion factor, kilowatts
to brake horsepower (EN0X) (453.6 g/Ib)

/ (bHp)

0.43 0.41 0.44 g/bHp*hr where: ENOX
= NOx emission rate (lb/hr) 453.6
= conversion factor, grams to pounds bHp
= engine brake horsepowerDerenzo

& Associates, Inc. EPA Method 3A CO, Calculation Summary Company Trail Ridge Energy Location: Jacksonville,
FL Source: Engine 4 Date: 3/25/2009
TestiD

1

2

3

4

5

6 Average CO 2 concentration

10.7 10.8 10.9 10.9 11.0 11.0 % Average pre-test and post-test instrument zero= 0.00 0.00 0.00 0.02 0.07 0.10 % Average pre-test and post-test instrument calibration= 13.34 13.37 13.48 13.57 13.57 13.57 % Midrange calibration gas concentration

13.52 13.52 13.52 13.52 13.52 13.52 % CO, CONCENTATION CORRECTED FOR CATJBRATION AND ZERO DRIFT (CO 2 cone-Avg. zero)x(Cal. gas conc.)/(Avg. cal-Avg. zero)

10.9 10.9 11.0 10.9 10.9 11.0 %Derenzo
& Associates, Inc. EPA Method 3A 02 Calculation Summary Company: Trail Ridge Energy Location: Jacksonville,
FL Source: Engine #4 Date: 3/25/2009 TestiD

= Average 02 concentration Average pre-test and post-test instrument zero

= Average pre-test and post-test instrument calibration

= Midrange calibration gas concentration

=

1

2

3

4

5

6 8.29 830 8.30 8.27 8.25 8.24
% 0.01 0.01 0.01 0.01 0.01 0.01

% 8.29 8.30 8.28 8.28 8.29 8.30
% 8.28 8.28 8.28 8.28 8.28 8.28
% 0, CONCENTATION CORRECTED FOR CALIBRATION AND ZERO DRIFT 8.28 8.29 8.30 8.27 8.24 8.22
% (02 conc.-Avg. zero)x(Cal. gas conc.)/(Avg. cal-Avg. zero)

=Average measured THC concentration,

as propane Average pre-test and post-test instrument zero Average pre-test and post-test instniment calibration Midrange calibration gas concentration Methane Concentration
(as methane) THC Concentration Corrected for Calibration and Zero Drift (THC conc.-Avg. zero)x(Cal. gas conc.)/(Avg. cal.-Avg. zero) as propane VOC Concentration (THC with methane subtraction) VOC EMISSION RATE, AS PROPANE = (Cd) (Qdstd) (60 mm/br) (MWvc)

/ (VM) where:

-0.84 -0.33 -0.47 lb/hi, as propane Cd = observed VOC concentration,
dry basis (ft 3 VOC

/ 106 ft 3 stack gas) Qastd
= stack gas flowrate (dscfm) MWvx

= molecular weight methane (16.0 Ib/Ib-mol) VM = molar volume of ideal gas at std conditions (385 ft 3 /lb-mol) Engine Output (bHp) (kWavg)/(0.96)/(0.7457 kWIbHp) where: kWvg

= average recorded generator kilowatt output 0.96
= engine to generator efficiency 0.7457

= conversion factor, kilowatts

to brake horsepower (Evoc) (453.6 g/Ib)

/ (bHp) where:

= 2167 2208 2233 bHp = -0.18 -0.07 -0.10 g/bHp*hr VOC emission rate (lb/br) 453.6
= conversion factor, grams to pounds bHp = engine brake horsepower Derenzo

& Associates, Inc. EPA Method 25A118 VOC Calculation Summary Company Trail Ridge Energy Location Jacksonville,
FL Source Engine #4 Date 3/25/2009

Test

1 = 560.2 0.08 521.40 523.2 = 1,883 Test
2 641.7 0.08 527.86 523.2 1,986 Test

3 623.3 0.08 531.40 523.2 1,951 ppmv (wet) ppmv ppmv ppmv ppmv (wet) = 562.17 636.13 613.71 ppmv (wet) THC- Methane Volumetric tow rate Average generator kilowatt output

= -65 = 5,182 = 1,551 -26 5,174 1,581 -37 5,211 1,598 ppmv wet, as propane scfm kWTrailRidgeEnergyCEM1)ataMarch24,2009DateHourTHCCH4NOXNONO2COC02023/24/200913:000.08-44.010.230.35-0.132.430.0112.413/24/200913:010.08-43.580.230.35-0.132.690.0214.353/24/200913:020.08-43.590.230.35-0.023.480.0220.523/24/200913:030.09-43.560.230.35-0.133.020.0120.943/24/200913:040.09-32.790.230.35-0.13-0.06021.033/24/200913:050.082.580.230.35-0.130.08020.23/24/200913:060.092.550.230.35-0.13026013.53/24/200913:070.082.580.290.39-0.070.79012.563/24/200913:080.082.610.290.4-0.070.44012.473/24/200913:090.082.610.30.4-0.071.05012.443/24/200913:100.082.460.310.41-0.061.720.0112.443/24/200913:110.082.630.30.4-0.071.820.0112.433/24/200913:120.082.660.310.4-0.071.920.0112.363/24/200913:130.092.610.30.4-0.071.840.019.313/24/200913:140.082.620.30.4-0.072.250.018.313/24/200913:150.082.70.320.4-0.072.460.018.243/24/200913:160.092.690.310.41-0.073.160.024.493/24/200913:170.092.680.310.4-0.073.430.020.293/24/200913:180.092.70.320.41-0.063.310.020.013/24/200913:190.082.670.310.41-0.063.80.020.013/24/200913:200.092.720.320.41-0.064.660.0213.033/24/200913:210.092.620.30.4-0.074.710.0220.63/24/200913:220.092.570.30.4-0.075.090.0220.943/24/200913:230.082.640.30.4-0.065.10.0221.023/24/200913:240.092.680.310.4-0.065.640.0321.053/24/200913:250.082.630.310.41-0.065.590.0321.053/24/200913:260.082.640.320.41-0.065.880.0315.983/24/200913:270.092.620.320.41-0.065.810.0312.643/24/200913:280.092.60.310.41-0.066.120.0312.473/24/200913:290.082.650.310.41-0.066.820.0312.433/24/200913:300.082.620.310.41-0.066.890.0412.423/24/200913:310.082.60.310.41-0.067.150.0411.523/24/200913:320.082.60.30.41-0.067.740.048.53/24/200913:330.082.620.30.4-0.067.180.048.263/24/200913:340.092.660.310.41-0.067.670.048.233/24/200913:350.092.660.310.41-0.067.630.045.673/24/200913:360.082.610.310.41-0.068.210.040.413/24/200913:370.082.460.310.41-0.068.420.040.013/24/200913:380.082.570.310.41-0.068.40.040.013/24/200913:390.092.660.310.41-0.068.090.040.013/24/200913:400.082.650.310.41-0.068.610.040.013/24/200913:410.092.670.310.4-0.069.020.040.013/24/200913:420.092.660.320.40.059.430.050.013/24/200913:430.082.630.30.40.029.460.050.53/24/200913:440.082.640.310.4-0.069.440.0517.553/24/200913:450.082.650.310.41-0.069.650.0520.713/24/200913:460.082.630.310.41-0.069.930.0520.943/24/200913:470.082.630.310.41-0.0610.180.0520.993/24/200913:480.092.670.320.41-0.0610.260.0521.013/24/200913:490.092.660.310.41-0.0610.550.0521.033/24/200913:500.082.670.310.41-0.0610.510.0521.033/24/200913:510.092.680.310.41-0.0610.560.0521.033/24/200913:520.082.720.320.41-0.0610.920.0521.033/24/200913:530.092.690.310.41-0.0610.950.0519.83/24/200913:540.082.670.320.41-0.0611.050.0513.17Trail Ridge Energy CEIV1 Data

March 24, 2009 3/24/2009 13:55 0.09 2.06 0.36 0.43 -0.04 10.89 0.05 12.52 3/24/2009 13:56 0.09 1.59 0.39 0.44 -0.03 10.97 0.05 12.43 3/24/2009 13:57 0.09 1.63 0.39 0.44 -0.03 11.48 0.06 12.41 3/24/2009 13:58 0.08 1.77 0.37 0.43 -0.04 11.75 0.06 12.4 3/24/2009 13:59 0.08 1.48 0.39 0.44 -0.03 12.4 0.06 12.39 3/24/2009 14:00 0.08 1.47 0.4 0.44 -0.03 12.18 0.06 9.55 3/24/2009 14:01 0.08 1.46 0.4 0.44 -0.03 11.72 0.06 8.29 3/24/2009 14:02 0.09 1.54 0.39 0.44 -0.03 12.34 0.06 8.23 3/24/2009 14:03 0.09 2.56 0.31 0.41 -0.06 12.3 0.06 8.21 3/24/2009 14:04 0.08 2.41 0.31 0.41 -0.05 12.54 0.06 3.52 3/24/2009 14:05 0.08 2.41 0.32 0.41 -0.07 12.33 0.06 0.18 3/24/2009 14:06 0.09 2.05 0.33 0.42 -0.05 12.37 0.06 0.01 3/24/2009 14:07 0.08 2.52 0.29 0.4 -0.07 637.68 8.55 6.07 3/24/2009 14:08 0.08 1.71 0.36 0.43 -0.04 1023.28 15.29 12.32 3/24/2009 14:09 0.09 2.31 0.31 0.41 -0.06 1024.68 15.35 12.59 3/24/2009 14:10 0.08
2.1 0.32 0.42 -0.05 607.12 9.92 9.28 3/24/2009 14:11 0.08 2.08 0.33 0.42 -0.05 23.23 0.41 0.77 3/24/2009 14:12 0.09 1.53 0.38 0.44 -0.03 13.46 0.14 0.06 3/24/2009 14:13 0.08 1.83 0.37 0.44 -0.04 13.27 0.12 0.01 3/24/2009 14:14 0.07 1.77 0.37 0.43 -0.04 13.56 0.11 0.01 3/24/2009 14:15 0.09 2.31 0.33 0.42 -0.05 13.54
0.1 0.01 3/24/2009 14:16 0.09
1.7 0.29 0.38 -0.11 13.78

0.1 0.01 3/24/2009 14:17 0.09 2.03 0.36 0.43 -0.04 336.03 4.09 2.27 3/24/2009 14:18 0.08 2.56 0.32 0.41 -0.06 1019.48 15.15 11.93 3/24/2009 14:19 0.09 2.65
0.3 0.41 -0.06 1026.12 15.35 12.53 3/24/2009 14:20 0.08 2.66
0.3 0.41 -0.06 1025.42 15.37 12.63 3/24/2009 14:21 0.07 2.64
0.3 0.4 -0.06 372.6 6.42 6.58 3/24/2009 14:22 0.09 2.62 0.29 0.4 -0.06 17.3 0.23 0.41 3/24/2009 14:23 0.09 2.62 0.29 0.4 -0.06 15.24 0.16 0.02 3/24/2009 14:24 0.08 2.63 0.29 0.4 -0.07 15.08 0.14 0.01 3/24/2009 14:25 0.08

2 0.29 0.38 -0.09 49.99
0.4 0.04 3/24/2009 14:26 0.09 1.65 0.37 0.43 -0.04 923.33 13.1 9.45 3/24/2009 14:27 0.08 1.43 0.38 0.43 -0.04 1027.46 15.34 12.44 3/24/2009 14:28 0.08 1.82 0.36 0.42 -0.05 1028.09 15.37 12.61 3/24/2009 14:29 0.08 2.52 0.31 0.4 -0.06 1028.02 15.38 12.65 3/24/2009 14:30 0.09 1.96 0.35 0.42 -0.05 1027.81 15.39 12.66 3/24/2009 14:31 0.08
1.7 0.37 0.43 -0.04 1028.16 15.4 12.67 3/24/2009 14:32 0.08 2.52 0.31 0.41 -0.06 1028.66 15.41 12.67 3/24/2009 14:33 0.09 2.11 0.33 0.41 -0.06 1028.91 15.41 12.67 3/24/2009 14:34 0.09 2.53
0.3 0.4 -0.06 548 9.07 8.62 3/24/2009 14:35 0.08 2.41 0.31 0.4 -0.07 22.09
0.4 0.63 3/24/2009 14:36 0.08 2.29 0.32 0.41 -0.06 16.56 0.22 0.04 3/24/2009 14:37 0.09 2.25 0.32 0.41 -0.06 16.6 0.19 0.01 3/24/2009 14:38 0.08 2.54
0.3 0.4 -0.06 16.64 0.17 0.01 3/24/2009 14:39 0.08 1.54 0.38 0.43 -0.04 404.86 0.29 0.54 3/24/2009 14:40 0.08 2.34 0.31 0.41 -0.06 1048.34 0.16 0.11 3/24/2009 14:41 0.09 2.51 0.28 0.39 -0.08 1033.18 0.14 0.01 3/24/2009 14:42 0.08 1.63 0.34 0.41 -0.06 1015.25 0.13 0.01 3/24/2009 14:43 0.09 1.52 0.35 0.41 -0.05 1015.05 0.12 0.01 3/24/2009 14:44 0.09 2.38 0.28 0.39 -0.08 896.13 0.11 0.01 3/24/2009 14:45 0.08 2.46 0.28 0.39 -0.08 614.96 0.11 0.01 3/24/2009 14:46 0.07 2.12 0.31 0.4 -0.07 609.69 0.11 0.01 3/24/2009 14:47 0.09 1.48 0.36 0.42 -0.05 606.97 0.11 0.01 3/24/2009 14:48 0.08 1.47 0.4 0.45 -0.02 168.09 9.12 0.22 3/24/2009 14:49 0.08 2.15 0.35 0.43 -0.05 15.72 13.93 0.01 3/24/2009 14:50 0.09 231 0.33 0.42 -0.06 15.53 13.59 0.01 2Trail Ridge Energy CEM I)ata

March 24, 2009 3/24/2009 14:51 0.09 2.13 0.33 0.42 -0.05 15.54 13.54 0.01 3/24/2009 14:52 0.09 2.52
0.3 0.41 -0.06 15.76 13.51 0.01 3/24/2009 14:53 0.08 2.52 0.29 0.41 -0.06 15.54 13.46 0.01 3/24/2009 14:54 0.08 2.17 0.32 0.41 -0.06 15.07 9.33 0.01 3/24/2009 14:55 0.08 2.34 0.31 0.41 -0.05 15.18 8.12 0.01 3/24/2009 14:56 0.08 2.45 0.31 0.41 -0.06 15.23 8.11 0.01 3/24/2009 14:57 0.09 1.76 0.36 0.43 -0.04 15.39 5.53 4.52 3/24/2009 14:58 0.09 2.55
0.3 0.41 -0.06 16.87 0.39 19.17 3/24/2009 14:59 0.09 2.55
0.3 0.41 -0.06 16.83 0.17 20.74 3/24/2009 15:00 0.08 2.57
0.3 0.41 -0.06 16.96 0.16 20.91 3/24/2009 15:01 0.08 2.31 0.33 0.42 -0.05 16.89 0.14 20.96 3/24/2009 15:02 0.09 2.59 0.31 0.42 -0.05 17.18 0.14 20.97 3/24/2009 15:03 0.08 2.58
0.3 0.41 -0.06 17.11 0.13 20.97 3/24/2009 15:04 0.09 2.6 0.31 0.41 -0.06 0.75

0 21.01 3/24/2009 15:05 0.09 2.57
0.3 0.41 -0.05 0.05

0 21.01 3/24/2009 15:06 0.08 2.57
0.3 0.41 -0.06
0.1

0 19.43 3/24/2009 15:07 0.08 2.6 0.32 0.42 -0.05 0.08

0 11.48 3/24/2009 15:08 0.09 2.48 0.32 0.42 -0.06 -0.02

0 9.56 3/24/2009 15:09 0.09 1.72 0.37 0.44 -0.04 0.08

0 9.4 3/24/2009 15:10 0.08 2.54
0.3 0.41 -0.06 0.06

0 9.35 3/24/2009 15:11 0.09 2.53
0.3 0.41 -0.06 0.11

0 9.32 3/24/2009 15:12 0.09 2.41 0.31 0.41 -0.06 0.45

0 8.83 3/24/2009 15:13 0.09 2.55 0.29 0.41 -0.06 0.14

0 8.24 3/24/2009 15:14 0.09 2.39 0.31 0.41 -0.06 0.18

0 8.22 3/24/2009 15:15 0.09 1.41 0.55 0.44 0.43 0.16

0 8.22 3/24/2009 15:16 0.09 1.82 0.35 -0.21 0.86 0.39

0 8.55 3/24)2009 15:17 0.08 2.48
0.3 0.41 0.43 0.56

0 8.26 3/24/2009 15:18 0.09 1.65 3.22 1.76 2.12 0.46

0 7.9 3/24/2009 15:19 0.09 1.48 52.6 27.48 25.15 0.45

0 1.15 3/24/2009 15:20 0.09 1.63 199.1 184.21 15.63
0.5

0 0.06 3/24/2009 15:21 0.09 1.39 262.77 258.36 4.73 0.19

0 0.01 3/24/2009 15:22 0.09 1.41 248.21 248.73 -0.19 0.62

0 0.01 3/24/2009 15:23 0.09 1.48 236.53 239.19 -0.21 0.55

0 0.01 3/24/2009 15:24 0.08 2.27 106.55 108.52 0.54 0.99

0 0.01 3/24/2009 15:25 0.09 2.48 98.11 97.24 0.93 0.49

0 0.01 3/24/2009 15:26 0.09 2.27 97.86 97.07 0.92 0.83

0 0.01 3/24/2009 15:27 0.08 2.66 97.85 97.06 0.42 1.05

0 0.01 3/24/2009 15:28 156.5 419.17 50.9 58.62 -4.91 137.81
0.8 6.12 3/24/2009 15:29 13.53 1273.78 11.58

7 4.52 82.44 0.67 18.58 3/24/2009 15:30 14.13 491.79 1.53 0.41 0.91 2.33 0.02 20.69 3/24/2009 15:31 47.96 26.75 1.63 2.28 -0.66 97.55 0.19 20.15 3/24/2009 15:32 0.24 6.21 1.41 1.09 0.44 580.76 0.08 2.89 3/24/2009 15:33 0.09 4.03 0.79 0.41 0.43 593.12

0 0.37 3/24)2009 15:34 0.08 1.84 0.84 0.43 0.45 593.29

0 0.03 3/24/2009 15:35 0.09 2.23 0.82 0.42 0.44 593.7

0 0.01 3/24/2009 15:36 0.09 2.73 0.8 0.41 0.43 650.28

0 0.01 3/24/2009 15:37 0.08 2.69 0.54 0.41 0.43 986.28

0 0.01 3/24/2009 15:38 0.08 2.71 0.31 0.42 0.44 1015.47

0 0.01 3/24/2009 15:39 0.09 2.41 0.32 0.43 0.45 722.58

0 0.01 3/24)2009 15:40 0.09 2.76
0.3 0.41 0.43 606.84

0 0.01 3/24/2009 15:41 0.08 2.73
0.3 0.41 0.44 606.07

0 0.01 3/24/2009 15:42 0.09 2.68 0.31 0.41 0.43 414.49 2.86 0.01 3/24/2009 15:43 0,09 2.79
0.3 0.41 0.43 5.76 12.87 0.01 3/24/2009 15:44 0.09 2.83
0.3 0.41 0.43 2.2 13.14 0.01 3/24/2009 15:45 0.08 2.84
0.3 0.41 0.43 1.92 13.18 0.01 3/24/2009 15:46 0.09 2.82 0.31 0.41 0.43 1.77 13.33 0.01 3Trail Ridge Energy CEM Data

March 24, 2009 3/24/2009 15:47 0.09 2.84
0.3 0.41 0.43
1.9 13.52 0.01 3/24/2009 15:48 0.08 2.39 0.31 0.42 0.44 1.87 13.53 0.01 3/24/2009 15:49 0.94 2.61
0.3 0.41 0.43 1.42 13.18 0.18 3/24/2009 15:50 0.09 2.81 0.29 0.41 0.43
1.8 2.18 6.82 3/24/2009 15:51 0.08 2.86
0.3 0.4 0.43 2.01 0.15 8.12 3/24/2009 15:52 0.08 2.84
0.3 0.4 0.42 1.99 0.09 8.24 3/24/2009 15:53 0.09
2.8 0.28
0.4 0.43 2.09 0.06 8.27 3/24/2009 15:54 0.09 2.81 7.67 6.69 1.52 1.93 0:04 8.05 3/24/2009 15:55 0.08 2.79

89 88.47 0.76 2.09 0.03 1.27 3/24/2009 15:56 0.08 2.41 97.57 99.44 -1.55 2.06 0.01 0.15 3/24/2009 15:57 0.08 1.42 97.93 99.62 -1.53 2.07 0.01 0.01 3/24/2009 15:58 0.09 2.32 97.89 99.6 -1.54 2.21

0 0.01 3/24/2009 15:59 0.08 2.79 63.83 69.07 -1.97 1.92

0 0.01 3/24/2009 16:00 0.09 2.73 1.23 1.05 0.23 2.02

0 0.01 3/24/2009 16:01 0.09 2.54 0.79 0.42 0.44 1.96

0 0.01 3/24/2009 16:02 322.28 2.68 0.3 0.41 0.41 40.01 0.32 0.06 3/24/2009 16:03 543.01 2.79 0.3 0.41 0.2 646.04 9.72 6.35 3/24/2009 16:04 565.37 1448.2 38.35

34 6.78 718.86 11.03
7.9 3/24/2009 16:05 561.04 2007.08 78.67 48.82 29.98 704.12 11.01 8.06 3/24/2009 16:06 560.85 2006.88 84.49 47.11 37.5 713.36 11.04 8.08 3/24/2009 16:07 558.62 2007.55 82.59 41.26 41.18 700.84 11.03 8.12 3/24/2009 16:08 541.07 2007.57 77.63 35.22 42.41 685.99 11.05 8.13 3/24/2009 16:09 554.46 2007.6 80.85 37.29 43.64 706.61 11.11 8.08 3/24/2009 16:10 563.25 2007.59 87.15 39.47 47.8 718.89 11.09 8.08 3/24/2009 16:11 578.77 2007.45 80.65 36.61 44.14 691.91 11.03 8.14 3/24/2009 16:12 578.82 1951.44 77.66 38.57 39.08 677.43 11.01 8.17 3/24/2009 16:13 582.08 1796.87 77.21 36.22 41.2 677.18

11 8.18 3/24/2009 16:14 576.89 1915.46 75.39 34.46 41.17 675.34

11 8.2 3/24/2009 16:15 586.81 2006.68 75.03 37.35 37.87 673.67

11 8.2 3/24/2009 16:16 587.51 2006.6 84.82 57.12 27.81 671.48 10.98 8.22 3/24/2009 16:17 543.84 2006.66 90.83 74.71

16 675.34 10.99 8.21 3/24/2009 16:18 554.2 2006.51 91.95 78.01 14.07 695.93 11.11 8.09 3/24/2009 16:19 582.64 2007.03 96.07 84.98 11.35 705.25 11.05 8.11 3/24/2009 16:20 570.38 2007.5 85.17 74.51 10.85 683.83 10.99 8.19 3/24/2009 16:21 571.69 2007.53 87.56 76.6 11.05 693.56 11.03 8.15 3/24/2009 16:22 582.93 1972.34 84.01 73.86 10.25 687.23 10.98 8.19 3/24/2009 16:23 578.47 1588.52 80.05 68.9 11.2 678.16 10.97 8.21 3/24/2009 16:24 591.24 1749.14 83.08

73 10.21 688.79 10.98 8.21 3/24/2009 16:25 600.02 2006.76 83.68 71.63 12.09 682.25 10.94 8.22 3/24/2009 16:26 587.53 1704.84 81.4 70.57 10.88 680.53 10.93 8.25 3/24/2009 16:27 574.65 1575.47 78.9 66.68 12.4 674.47 10.95 8.24 3/24/2009 16:28 583.26 1487.75 82.66 69.16 13.55 684.88 10.98
8.2 3/24/2009 16:29 573.78 1640.8 80.3 68.13 12.54 680.9 10.97 8.21 3/24/2009 16:30 603.41 2007.43 84.33 71.14 13.56 691.59 10.99 8.18 3/24/2009 16:31 600.09 1751.37 81.05 66.86 14.39 674.91 10.9 8.25 3/24/2009 16:32 595.7 1580.54 80.38 65.15 15.27 676.85 10.92 8.25 3/24/2009 16:33 606.55 1971.99 75.04 61.77 13.47 667.24 10.89 8.28 3/24/2009 16:34 614.78 1925.76 73.37 58.62

15 662.96 10.87
8.3 3/24/2009 16:35 590.5 1632.45 75.17 60.4 14.86 668.36 10.89 8.28 3/24/2009 16:36 609.08 1600.56 76.38 62.23 14.31 671.55 10.93 8.25 3/24/2009 16:37 595.94 1569.82 64.33 56.9 9.65 672.88 10.9 8.27 3/24/2009 16:38 606.31 1614.14 1.77 4.76 -1.69 671.08 10.9 8.27 3/24/2009 16:39 598.11 1617.99 0.42 0.4 0.41 666.82 10.88 8.29 3/24/2009 16:40 587.44 1574.27 8.64 6.46 2.46 661.39 10.92 8.27 3/24/2009 16:41 615.4 1574.58 19.68 19.43 0.42 675.35 10.93 8.25 3/24/2009 16:42 593.65 1574.58 19.81 19.43 0.42 679.2 10.91 8.28 4Trail Ridge Energy CEM Data

March 24, 2009 3/24/2009 16:43 568.08 1891.74 16.57 16.03
0.6 671.28 10.94 8.24 3/24/2009 16:44 608.49 1992.5 30.26 29.15 1.18 678.19 10.99 8.19 3/24/2009 16:45 619.29 1587.41 42.86 43.5 -0.55 673.21 10.91 8.25 3/24/2009 16:46 609.17 1593.27 42.83 43.47 -0.58 668.88 10.9 8.26 3/24/2009 16:47 599.04 1601.55 42.88 43.51 -0.17 664.08 10.89 8.29 3/24/2009 16:48 618.78 1864.74 42.88 43.21 -0.04 661.54 10.88
8.3 3/24/2009 16:49 609.72 2006.44 42.88 43.01 -0.04 664.29 10.88
8.3 3/24/2009 16:50 610.22 1570.34 42.89 43.01 -0.04 657.64 10.86 8.31 3/24/2009 16:51 574.72 1662.16 42.88 43.01 -0.03 653.71 10.9 8,29 3/24/2009 16:52 596.9 2006.45 42.88 43.02 0.42 661.61 10.97 8.23 3/24/2009 16:53 610.08 1881.97 42.88 42.72 0.45 671.79 10.92 8.24 3/24/2009 16:54 606.11 1783.9 42.88 42.51 0.46 661.29 10.89 8.27 3/24/2009 16:55 607.8 1470.25 42.89 42.52 0.46 651.94 10.85 8.32 3/24/2009 16:56 608.99 1452.29 42.89 42.52 0.46 656.18 10.85 8.32 3/24/2009 16:57 585.04 1611.7 39.27 40.76 -1.27 650.04 10.85 8.32 3/24/2009 16:58 578.43 1795.9 41.61 43.13 -1.08 651.32 10.93 8.27 3/24/2009 16:59 605.71 2006.81 43.87 43.3 0.94 668.47 10.92 8.25 3/24/2009 17:00 606.22 2006.75 43.95 43.01 0.94 662.38 10.88 8.29 3/24/2009 17:01 597.03 1959.18 43.83 42.99 0.97 662.34 10.89 8.27 3/24/2009 17:02 606.82 1429.6 43.86

43 1.27 658.28 10.87 8.29 3/24/2009 17:03 601.54 1651.49 43.83 42.97 1.41 660.21 10.87 8.29 3/24/2009 17:04 613.71 2007.58 43.82 42.59 1.41 657.33 10.86
8.3 3/24/2009 17:05 582.71 1680.2 43.83 42.47 1.41 651.86 10,85 8.33 3/24/2009 17:06 582.77 1528.19 43.84 42.48 1.42 650.36 10.93 8.26 3/24/2009 17:07 614,01 2006.59 43.89 42.52 1.67 670.8 10.92 8.24 3/24/2009 17:08 546.43 1867.9 43.88 42.46 1.89 657.07 10.87 8.28 3/24/2009 17:09 5.13 1542.46 43.97 42.47 1.92 309.22 5.78 5.26 3/24/2009 17:10 1.89 595.47 44.32 42.25 1.92 5.04
0.2 0.37 3/24/2009 17:11 1.06 6.8 44.32 41.97 1.92 3.44 0.12 0.04 3/24/2009 17:12 0.76 3.49

44 42.02 1.96 3.28 0.09 0.01 3/24/2009 17:13 0.09 3.59 43.86

42 2.41 2.83 0.07 0.01 3/24/2009 17:14 0.08 2.88 43.82 41.73 2.41 2.62 0.05 0.01 3/24/2009 17:15 0.08 2.88 43.82 41.46 2.42 2.84 0.04 0.01 3/24/2009 17:16 0.08 2.87 43.82 41.46 2.41 2.79 0.03 0.01 3/24/2009 17:17 0.09
2.9 43.82 41.46 2.42 2.86 0.02 0.01 3/24/2009 17:18 0.08 2.86 43.82 41.24 2.72 2.79 0.01 0.01 3/24/2009 17:19 0.08 2.87 43.82 40.96 2.91 2.93 0.01 0.01 3/24/2009 17:20 0.08 2.85 43.82 40.96 2.91 2.82

0 0.01 3/24/2009 17:21 0.09 2.86 43.82 40.96 2.91 2.87

0 0.01 3/24/2009 17:22 0.08 2.84 43.82 40.96 2.91 2.97

0 0.01 3/24/2009 17:23 0.09 2.88 43.82 40.57 2.91 2.76

0 0.01 3/24/2009 17:24 0.09 2.87 43.82 40.46 3.15 2.57

0 0.01 3/24/2009 17:25 0.08 2.87 43.82 40.47 3.41 2.91

0 0.01 3/24/2009 17:26 0.08 2.88 43.82 40.47 3.41 2.61

0 0.01 3/24/2009 17:27 0.08 2.9 43.83 40.23 3.41 2.61

0 0.01 3/24/2009 17:28 0.08 2.88 43.82 39.96 3.41 2.73

0 0.01 3/24/2009 17:29 0.08 2.9 43.5 39.96 3.41 2.66

0 0.01 3/24/2009 17:30 0.09 2.88 43.32 39.96 3.48 2.75

0 0.01 3/24/2009 17:31 0.08 2.78 43.31 39.96 3.91 2.42

0 0.01 3/24/2009 17:32 0.08 2.41 37.07 37.06 0.26 2.61

0 0.01 3/24/2009 17:33 0.08 2.91

2 1.05
1.2 2.36

0 0.01 3/24/2009 17:34
0.3 2.88
0.3 0.4 0.42 2.31

0 0.01 3/24/2009 17:35 21.58 15.71 0.26 0.38 0.39 4.99 0.02 5.98 3/24/2009 17:36 20.38 88.63 18.73 16.41 2.28 16.18 0.24 19.61 3/24/2009 17:37 18.62 59.89 34.64 34.83 -0.22 14.05 0.19 20.3 3/24/2009 17:38 23.66 24.6 34.64 34.83 -0.22 9.06 0.12 20.5 STrailRidgeEnergyCEMDataMarch24,20093/24/200917:3927.2497.8534.6334.83-0.2224.360.3620.343/24/200917:400.13114.8634.8134.95-0.08234.250.1414.053/24/200917:410.092.8834.8334.96-0.07603.2800.873/24/200917:420.082.8634.8334.96-0.07605.4200.193/24/200917:430.082.8834.8334.64-0.06606.1100.013/24/200917:440.092.7334.8234.460.42606.1900.013/24/200917:450.092.8134.8234.450.42606.500.013/24/200917:460.082.8434.8234.460.42480.971.840.013/24/200917:470.082.8434.8334.460.4211.512.890.013/24/200917:480.082.8434.8234.460.422.3513.350.013/24/200917:490.092.8434.8234.130.421.7813.40.013/24/200917:500.082.8534.8333.960.421.8913.430.013/24/200917:510.082.8234.8233.960.751.9813.440.013/24/200917:520.081.8534.8733.990.931.8313.460.013/24/200917:530.131.334.8834.010.951.8713.460.013/24/200917:540.091.3334.8934.010.961.717.73.053/24/200917:550.081.3634.8934.010.952.210.227.973/24/200917:560.081.3234.8934.010.962.390.18.213/24/200917:570.081.3434.8933.590.952.660.068.273/24/200917:580.091.2834.8733.490.942.220.048.293/24/200917:59343.691.6234.8333.471.082.430.025.883/24/200918:00756.032.5734.5933.471.425.650.0619.383/24/200918:01909.422.8934.433.461.413.10.0120.443/24/200918:02533.142.8634.3233.461.412.67020.583/24/200918:03527.482.934.3233.041.412.73020.623/24/200918:04527.662.8934.3232.961.412.82020.643/24/200918:05844.032.9334.3232.961.412.88020.643/24/200918:06773.032.8834.3232.951.412.74020.643/24/200918:07516.572.8834.3132.951.492.95020.73/24/200918:08425.682.934.3232.961.922.37020.773/24/200918:09339.052.8434.3232.471.922.5020.823/24/200918:105682.8934.3232.461.912.78020.833/24/200918:11930.71523.2534.3332.461.912.48020.783/24/200918:12932.461905.6434.3232.461.912.31020.773/24/200918:13933.021923.3434.3232.451.912.39020.773/24/200918:14933.411916.6834.3332.461.912.27020.773/24/200918:15933.81907.334.3332.291.912.25020.783/24/200918:16933.991918.8234.3231.961.912.14020.773/24/200918:17934.681923.3434.3231.962.332.27020.783/24/200918:18935.011904.5934.3231.962.412.18020.783/24/200918:19935.171885.2434.3231.962.412.04020.793/24/200918:20935.741875.2534.1531.962.412.18020.793/24/200918:21936.231875.3936.6234.152.432.18020.793/24/200918:22936.451877.138.4734.943.492.09020.793/24/200918:23936.471876.3133.3431.591.812.24020.793/24/200918:24936.781876.6627.425.751.522.07020.83/24/200918:25916.071890.7736.0632.084.032.11020.793/24/200918:2679.421512.237.150.4537.188.010.0620.783/24/200918:2773.7109.5438.390.4538.2514.210.220.683/24/200918:2862.85119.5838.380.4538.0414.140.1820.713/24/200918:2963.47129.638.380.4537.9820.480.2820.643/24/200918:3085.17103.9338.270.4537.9827.080.3720.546Trail Ridge Energy CEM Data

March 25, 2009 Date Hour THC CH4 NOX NO N02 CO C02 02 3/25/2009 6:10 9.5 23.46 0.29 0.4 -0.07 2.2

0 20.83 3/25/2009 6:11 9.25 23.48 0.29 0.4 -0.07 2.18

0 20.83 3/25/2009 6:12 8.08 24.91 0.29 0.4 -0.07

2

0 20.84 3/25/2009 6:13 6.01 22.5 0.28 0.4 -0.06 2.04

0 20.85 3/25/2009 6:14 4.87 20.75 0.28 0.4 -0.07 1.93

0 20.86 3/25/2009 6:15 4.94 15.37 0.22 0.36 -0.13 1.84

0 20.84 3/25/2009 6:16 7.37 13.38 0.16 0.3 -0.21 109.21

0 20.15 3/25/2009 6:17 0.09 4.74 0.13 0.29 -0.23 964.59

0 3.35 3/25/2009 6:18 0.08 3.7 0.11 0.28 -0.23 1013.16

0 0.28 3/25/2009 6:19 0.09 2.43 0.11 0.28 -0.22 1014.31

0 0.01 3/25/2009 6:20 0.09 2.81 0.21 0.35 -0.14 1014,49

0 0.01 3/25/2009 6:21 0.41 3.64 0.22 0.35 -0.14 1010.95

0 0.01 3/25/2009 6:22 0.16 18.37 0.18 0.33 -0.16 665.58

0 5.44 3/25/2009 6:23 0.09 12.23 0.09 0.27 -0.22 604.5

0 1.28 3/25/2009 6:24 0.14 2.38
0.1 0.28 -0.23 571.84 0.18 0.01 3/25/2009 6:25 0.08 2.5 0.1 0.27 -0.24 33.32 11.63 0.04 3/25/2009 6:26 0.09 2.47
0.1 0.28 -0.23 0.67 13.22 0.01 3/25/2009 6:27 0.09 2.7 0.19 0.33 -0.16 0.42 13.42 0.01 3/25/2009 6:28 0.08 2.76 0.23 0.35 -0.13 0.49 13.52 0.01 3/25/2009 6:29
0.1 2.36 0.12 0.29 -0.21
0.5 13.14 0.01 3/25/2009 6:30 0.09 2.32
0.1 0.28 -0.22 0.19 8.29 0.01 3/25/2009 6:31 0.09 2.72 0.21 0.35 -0.15 0.26

8 0.01 3/25/2009 6:32 0.08 2.68 0.12 0.28 -0.23 0.49 4.36 6.89 3/25/2009 6:33 0.09 2.6 0.1 0.27 -0.24 1.01

0 20.25 3/25/2009 6:34 0,09 2.58 -0.55 0.27 -0.83

1

0 20.81 3/25/2009 6:35 0.08 2.48 0.09 0.27 0.25 0.84

0 20.95 3/25/2009 6:36 0.08 2.36 0.08 0.26 0.24 0.72

0 20.98 3/25/2009 6:37 0.09 2.25 0.07 0.26 0.25 0.91

0 20.07 3/25/2009 6:38 0.09 2.17 0.07 0.26 0.25 0.41

0 9.34 3/25/2009 6:39 0.08 2.15 0.07 0.27 0.26 0.72

0 8.4 3/25/2009 6:40 0.09 2.2 0.08 0.27 0.26 0.49

0 8.28 3/25/2009 6:41 0.08 2.71 0.19 0.34 0.25 0.79

0 6.19 3/25/2009 6:42 0.08 2.62 94.36 58.39 36.12 0.33

0 0.35 3/25/2009 6:43 0.09 2.67 251.08 250.58 0.76 0.22

0 0.01 3/25/2009 6:44 0.09 2.56 245.57 251,69 -1.87 0.56

0 0.01 3/25/2009 6:45 0.09 2.11 120 116.6 4.23 0.32

0 0.01 3/25/2009 6:46 0.08 2.68 99.68 98.5 1.27 0.43

0 0.01 3/25/2009 6:47 0.54 2.67 96.25 98.5 -0.95 0.72

0 0.01 3/25/2009 6:48 8.01 2.46 36.67 29.63 7.55 14.39 0.06 9.47 3/25/2009 6:49 0.08 2.57 21.05 28.48 -2.1 368.77 0.01 5.62 3/25/2009 6:50 0.09 2.54 1.11 0.27 0.75 601.74

0 0.35 3/25/2009 6:51 0.09 2.58

1.1 0.28 0.75 602.63

0 0.03 3/25/2009 6:52 0.08 2.53 0.68 0.27 0.74 602.89

0 0.01 3/25/2009 6:53 0.08 2.5 0.6 0.27 0.42 326.69 4.91 0.01 3/25/2009 6:54 0.09 2.5 0.6 0.27 0.25 2.53 13.15 0.01 3/25/2009 6:55 0.09 2.55 0.6 0.27 0.25

1 13.27 0.01 3/25/2009 6:56 0.08 2.16 0.57 0.26 0.25 0.29 13.31 0.01 3/25/2009 6:57 0.09 2.4 0,63 0.31 0.3 0.37 13.33 0.01 3/25/2009 6:58 0.09 2.48 0.65 0.31 0.31 0.34 13.34 0.01 3/25/2009 6:59 0.09 2.38 0.56 0.31 0.31 0.49 12.8 0.13 3/25/2009 7:00 0.07 2.67 0.29 0.34 0.35 0.62 1.38 6.8 3/25/2009 7:01 0.08 2,45 0.23 0.36 0.37 0.82 0.05 8.12 3/25/2009 7:02 0.08 2.74 0.24 0.36 0.38 1.06

0 8.23 3/25/2009 7:03 0.08 2.78 0.26 0.37 0.39 1.12

0 8.26 3/25/2009 7:04 0.08 2.46 0.27 0.38 0.4 1.05

0 8.27 3/25/2009 7:05 0.08
2.1 0.27 0.39 0.41 0,97

0 8.28 3)25/2009 7:06 0.08 2.78 7.91 13.2 -3.15 1.09

0 7.81 3/25/2009 7:07 0.08 2.76 92.43 91.69 0.93 0.79

0 0.99 3/25/2009 7:08 0.08 1.82 98.39 100.08 -1.49 0.78

0 0.14 3/25/2009 7:09 0.08 1.91 98.77 100.07 -1.59 1.18

0 0.01 ITrail Ridge Energy CEM Data

March 25, 2009 3/25/2009 7:10 277.81 0.93 98.56 100.04 -1.41
0.5

0 0.01 3/25/2009 7:11 869.88

1 27.05 24.45

3 1.36

0 12.33 3/25/2009 7:12 871.66 0.97 0.78 0.53 0.27 1.78

0 20.1 3/25/2009 7:13 871.99 0.83 0.61
0.3 0.29
1.6

0 20.45 3/25/2009 7:14 544.14 0.76 0.61
0.3 0.29 1.37

0 20.55 3/25/2009 7:15 514.55 0.77 0.61 0.29 0.28 1.11

0 20.68 3/25/2009 7:16 514.29 1.22 0.26 0.29 0.28 0.95

0 20.7 3/25/2009 7:17 373.91 1.34
0.1 0.29 0.28 0.96

0 20.71 3/25/2009 7:18 338.19 1.94 0.09 0.27 0.27 0.56

0 20.76 3/25/2009 7:19 337.64 1.05 0.12 0.3 0.28 0.63

0 20.77 3/25/2009 7:20 697.2 1.13 0.11 0.29 0.26 0.43

0 20.78 3/25/2009 7:21 932.07 1483.48 0.31 0.4 0.4 0.21

0 20.69 3/25/2009 7:22 932.7 1904.8 0.31 0.4 0.4 0.29

0 20.69 3/25/2009 7:23 933.35 1940.19 0.23 0.35 0.34 0.19

0 20.69 3/25/2009 7:24 933.17 1930.6 0.22 0.35 0.34 0.25

0 20.69 3/25/2009 7:25 933.68 1914.23 0.21 0.34 0.33 0.28

0 20.7 3/25/2009 7:26 933.88 1932.18 0.17 0.3 0.31 0.16

0 20.71 3/25/2009 7:27 933.52 1940.95 0.15 0.29
0.3 0.27

0 20.7 3/25/2009 7:28 933.82 1889.65 0.17 0.3 0.31 0.23

0 20.71 3/25/2009 7:29 933.43 1882.93 0.16 0.3 0.31 0.24

0 20.7 3/25/2009 7:30 933.7 1880.73 0.16 0.3 0.31 0.29

0 20.7 3/25/2009 7:31 933.87 1882.28 0.18 0.31 0.32 0.2

0 20.69 3/25/2009 7:32 762.4 1835.77 0.32 0.41 0.41 0.25

0 20.69 3/25/2009 7:33 556.58 1483.26 0.34 0.42 0.34 0.29

0 20.73 3/25/2009 7:34 555.31 1341.24 0.34 0.42 0.43 0.24

0 20.76 3/25/2009 7:35 554.7 1142.54 0.34 0.42 0.25 0.28

0 20.78 3/25/2009 7:36 511.52 1142.62 0.34 0.42 0.28 0.21

0 20.77 3/25/2009 7:37 366.21 1135.98 0.35 0.43 0.09 0.24

0 20.78 3/25/2009 7:38 365.06 755.53 0.37 0.45 -0.03 0.31

0 20.81 3/25/2009 7:39 364.98 753.63 0.38 0.46 -0.01 0.19

0 20.82 3/25/2009 7:40 364.12 749.73 0.38 0.46 -0.02 0.25

0 20.81 3/25/2009 7:41 28.55 730.73 0.32 0.42 -0.05 0.26

0 20.83 3/25/2009 7:42 1.06 718.44 0.32 0.42 -0.05 0.23

0 20.89 3/25/2009 7:43 291.72 52.33 1.57 1.45 0.39 14.54 0.07 20.89 3/25/2009 7:44 576.64 344.82 46.6 43.96 2.69 570.45 8.66 12.04 3/25/2009 7:45 578.41 1462.22 58.26 45.7 12.44 641.91 10.56 8.63 3/25/2009 7:46 567.24 1505.12 61.39 39.73 21.74 643.22 10.61 8.43 3/25/2009 7:47 564.13 1542.54 64.58 37.1 27.62 650.61 10.67 8.34 3/25/2009 7:48 579.42 1504.11 66.73 35.68 31.03 650.41 10.67 8.33 3/25/2009 7:49 584.02 1489.18 68.65 34.22 34.47 652.27 10.68 8.31 3/25/2009 7:50 559.89 1448.11 66.79 31.84 34.89 646.5 10.66 8.35 3/25/2009 7:51 570.89 1699.89 67.91 31.24 36.73 646.9 10.7 8.32 3/25/2009 7:52 572.82 2007.55 76.18 46.27 29.9 650.66 10.69 8.31 3/25/2009 7:53 569.39 1598.58 67.45 26.42 41.09 648.91 10.7 8.32 3/25/2009 7:54 558.31 1489.58 65.68 21.72 44.09 648.52 10.7 8.32 3/25/2009 7:55 558.65 2007.65 65.74 19.8 45.95 649.28 10.71 8.31 3/25/2009 7:56 570.02 1989.57 66.04 18.66 47.17 650.34 10.72 8.31 3/25/2009 7:57 566.52 1959.21 64.35 16.43 47.87 645.12 10.71
8.3 3/25/2009 7:58 556.78 1815.83 62.7 14.72 47.91 642.35 10.69 8.33 3/25/2009 7:59 554.6 1744.44 64.63 15.01 49.69 651.15 10.74 8.28 3/25/2009 8:00 582.99 1576.06 64.26 15.41 48.85 648.77 10.72 8.28 3/25/2009 8:01 569.58 1583.7 61.79 14.56 47.22 641.99 10.69 8.32 3/25/2009 8:02 565.91 1620.52 62.52 15.28 47.32 643.86 10.71 8.31 3/25/2009 8:03 560.66 1519.9 63.39 16.85 46,53 645.84 10.7 8.31 3/25/2009 8:04 563.06 1448.02 64.35 18.14 46.21 647.07 10.72 8.29 3/25/2009 8:05 565.79 1501.16 66.15 19.41 46.79 650 10.73 8.28 3/25/2009 8:06 571.32 1537.96 66.15 19.41 46.69 647.52 10.7
8.3 3/25/2009 8:07 565.41 1670.57 67.32 19.98 47.42 647.59 10.7
8.3 3/25/2009 8:08 562.94 1833.37 66.04 19.07 47.05 644.4 10.69 8.33 3/25/2009 8:09 562.9 2007.37 66.41 19.41 47.2 645.08 10.71
8.3 3/25/2009 8:10 563.85 2007.38 67.66 19.67 47.92 650.06 10.72 8.28 2Trail Ridge Energy CEM Data

March 25, 2009 3/25/2009 8:11 578.01 1949.62 66.72 19.42 47.25 644.76 10.69 8.31 3/25/2009 8:12 560.12 1429.98 65.68 18.59 47.09 641.5 10.67 8.33 3/25/2009 8:13 554.55 1655.88 66.7 18.49 48.23 648.18 10.72 8.29 3/25/2009 8:14 568.8 1985.34 66.15 18.22 47.97 645.21 10.69
8.3 3/25/2009 8:15 561.24 2000.79 65.54 17.92 47.62 646.16 10.69 8.31 3/25/2009 8:16 561.38 1977.73 66.21 17.79 48.5 646.01 10.7 8.3 3/25/2009 8:17 562.31 1929.95 65.43 17.17 48.06 642.07 10.68 8.32 3/25/2009 8:18 562.97 1912.8 65.65 17.2 48.39 644.93 10.7 8.3 3/25/2009 8:19 554.12 2007.39 65.07 16.99 48.19 645.7 10.69 8.31 3/25/2009 8:20 553.44 1976.17 66.3 17.16 48.97 650.04 10.71 8.28 3/25/2009 8:21 561.5 1957.25 65.63 16.74 48.89 647.65 10.7 8.29 3/25/2009 8:22 558.15 1885.94 64.1 16.13 47.89 641.97 10.68 8.32 3/25/2009 8:23 560.16 1931.45 64.52 16.33 48.1 645.8 10.69
8.3 3/25/2009 8:24 557.43 1957.25 63.89 15.87 48.14 644.35 10.69 8.31 3/25/2009 8:25 556.52 1938.07 64.51 15.96 48.59 646.27 10.69
8.3 3/25/2009 8:26 559.72 1906.25 63.85 16.29 47.68 645.85 10.69 8.31 3/25/2009 8:27 554.23 1889.23 63.47 15.88 47.56 645.85 10.7 8.29 3/25/2009 8:28 560.21 1861.03 63.31 15.75 47.55 645.74 10.69
8.3 3/25/2009 8:29 547.54 1881.87 63.81 15.67 48.14 647.29 10.7 8.3 3/25/2009 8:30 557.9 1846.86 63.73 15.54 48.02 645.6 10.71 8.28 3/25/2009 8:31 553.02 1826.24 63.72 15.71 47.97 647.12 10.7 8.29 3/25/2009 8:32 550.47 1833.79 64.89 15.88 48.97 651.64 10.72 8.28 3/25/2009 8:33 559.87 1834.6 63.94 15.92 47.93 646.79 10.71 8.29 3/25/2009 8:34 557.46 1902.21 62.81 15.91 47.01 642.17 10.72 8.29 3/25/2009 8:35 556.93 1877.66 63.4 16.5 47.02 645.98 10.71 8.28 3/25/2009 8:36 558.16 1883.99 63.81 15.95 47.9 646.44 10.71 8.28 3/25/2009 8:37 544.21 1866.28 63.06 15.75 47.44 644.93 10.71 8.28 3/25/2009 8:38 549.05 2007.37 63.32 17.25 46.07 652.24 10.75 8.25 3/25/2009 8:39 551.24 1958.18 64.28 25.05 39.14 649.1 10.71 8.28 3/25/2009 8:40 548.9 1913.17 68.84 30.77

38 647.1 10.71 8.27 3/25/2009
8:41 556.72 1875.97 64.88 21.37 43.59 644.24 10.71 8.28 3/25/2009 8:42 557.3 1857.69 64.77 19.03 45.82 644.79 10.71 8.28 3/25/2009 8:43 566.07 1973.18 63.99 17.91 46.09 641.55 10.7 8.3 3/25/2009 8:44 561.83 1875.71 63.99 17.16 46.83 642.92 10.71 8.29 3/25/2009 8:45 544.47 1855.04 63.49 16.38 47.17 641.61 10.71 8.29 3/25/2009 8:46 564 1938.63 65.65 17.03 48.57 648.4 10.75 8.25 3/25/2009 8:47 558.39 1859.18 64.08 16.28 47.76 643.59 10.71 8.29 3/25/2009 8:48 562.71 1874.22 64.57 15.49 49.15 643.39 10.72 8.28 3/25/2009 8:49 560.36 1834.94 63.54 14.42

49 643.49 10.73 8.28 3/25/2009 8:50 558.12 1846.67 65.2 14.5 50.69 646.78 10.74 8.26 3/25/2009 8:51 563.98 1922.58 64.25 12.27 51.84 645.82 10.74 8.26 3/25/2009 8:52 553.07 1864.54 63.96 11.64 52.34 649.79 10.75 8.27 3/25/2009 8:53 563.77 1877.41 64.33 11.2 53.14 647.14 10.74 8.26 3/25/2009 8:54 570.04 1882.73 63.29 11.12 52.36 644.59 10.73 8.28 3/25/2009 8:55 560.78 1854.3 62.23 10.47 51.6 642.21 10.72 8.29 3/25/2009 8:56 566.26 1874.19 65.15 13.42 51.68 646.08 10.76 8.25 3/25/2009 8:57 565.9 1858.31 64.41 13.7 50.74 643.37 10.73 8.28 3/25/2009 8:58 561.87 1823.94 62.85 12.89 49.99 641.13 10.73 8.29 3/25/2009 8:59 558.87 1883.77 64.48 12.96 51.39 648.45 10.76 8.26 3/25/2009 9:00 568.41 2007.45 67.22 17.37 49.97 650.75 10.75 8.26 3/25/2009 9:01 566.33 1994.25 72.52 25.76 46.99 652.29 10.75 8.25 3/25/2009 9:02 557.41 1996.67 69.38 22.28 47.15 647.67 10.76 8.26 3/25/2009 9:03 576.34 2006.62 71.48 22.16 49.37 655.87 10.78 8.23 3/25/2009 9:04 570.65 1940.9 67.16

18 49.12 646.14 10.73 8.28 3/25/2009 9:05 567.12 1920.96 64.99 15.39 49.56 642.85 10.75 8.27 3/25/2009 9:06 576.37 1969.86 62.96 10.3 52.7 644.35 10.74 8.28 3/25/2009 9:07 29.83 1278.83 49.32 12.95 36.22 371.6 6.86 6.13 3/25/2009 9:08 2.05 10.08 23.99 6.49 17.27 1.13 0.15 0.46 3/25/2009 9:09 1.06 7.36 20.02 5.25 14.82 0.23 0.04 0.07 3/25/2009 9:10 1.06 4.07 16.77 4.47 12.33 0.13 0.01 0.01 3/25/2009 9:11 0.08 2.86 13.85 3.96 9.81 0.25

0 0.01 3Trail Ridge Energy CEM Data

March 25, 2009 3/25)2009 9:12 2.54 2.86 11.28
3.6 7.87 177.93

0 0.08 3/25/2009 9:13
0.1 4.78 9.09 2.93 6.23 595.69

0 0.01 3/25/2009 9:14 0.08 4.09 7.37 2.43 4.96 599.45

0 0.01 3/25/2009 9:15 0.08 2.8 6.27 2.41 4.11 599.16

0 0.01 3/25/2009 9:16 0.16 2.8 5.51 2.01 3.44 580.88 0.13 0.01 3/25/2009 9:17 0.08 2.75 4.61 1.92 2.81 57.53 10.98 0.01 3/25/2009 9:18 0.07 2.82 4.26 1.91 2.43 0.31 13.17 0.01 3/25/2009 9:19 0.08 2.83 3.83 1.91 2.04 0.33 13.23 0.01 3/25/2009 9:20 0.08 2.85 3.34 1.49 1.87 0.23 13.26 0.01 3/25/2009 9:21 0.07 2.88 3.17 1.59 1.59 0.32 13.28 0.01 3/25/2009 9:22 0.08 2.86 2.68 1.34 1.43 0.27 13.3 0.01 3/25/2009 9:23 0.08 2.84 2.33 0.9 1.43 0.27 13.31 0.01 3/25/2009 9:24 0.08 2.88 2.09 0.9 1.11 0.29 13.32 0.01 3/25/2009 9:25 0.57 2.75 1.79 0.88 0.91 0.22 13.33 0.01 3/25/2009 9:26 1.26 2.77 1.86 0.86 0.89 0.54 9.8 1.68 3/25/2009 9:27 0.08 2.62 1.78 0.87 0.9 0.17 0.29 7.82 3/25/2009 9:28 0.07 2.79 1.79 0.87 0.9 0.19 0.07 8.19 3/25/2009 9:29 0.08 2.79 1.56 0.87 0.91 0.22 0.03 8.27 3/25/2009 9:30 0.08 2.89 1.32 0.9 0.92 0.13

0 8.29 3/25/2009 9:31 0.08 2.88 1.32 0.42 0.68 0.26

0 8.3 3/25/2009 9:32 0.07 2.77 1.33 0.41 0.44 0.15

0 8.3 3/25/2009 9:33 0.08 2.9 1.16 1.01 -0.16 0.2

0 8.3 3/25/2009 9:34 0.08 2.91 70.09 61.22 8.93 0.14

0 2.92 3/25/2009 9:35 0.08 1.67 99.34 100.32 -0.65 0.12

0 0.24 3/25/2009 9:36 0.19 1.68 99.43 100.62 -1.04 0.22

0 0.01 3/25/2009 9:37 433.85 2.16 58.64 62.54 -1.46 0.14

0 5.86 3/25/2009 9:38 481.82 2.62 1.93 1.14 0.96 0.26

0 19.88 3/25/2009 9:39 527 2.74 1.31 0.58 0.92 0.27

0 20.53 3/25/2009 9:40 527.98 2.79 1.32 0.42 0.84 0.2

0 20.67 3/25/2009 9:41 528.25 2.87 1.24 0.41 0.43 0.33

0 20.73 3/25/2009 9:42 532.28 2.82 0.83 0.41 0.43 0.2

0 20.73 3/25/2009 9:43 556.58 2.92 0.82 0.41 0.43 0.27

0 20.78 3/25/2009 9:44 557.03 1069.28 0.82 0.4 0.43 0.22

0 20.81 3/25/2009 9:45 557.06 1807.52 0.84 0.42 0.44 0.27

0 20.82 3/25)2009 9:46 557.73 1812.35 0.97 0.45 0.47 0.3

0 20.82 3/25/2009 9:47 558.35 1815.8 0.87 0.45 0.47 0.19

0 20.83 3/25/2009 9:48 559.97 1818.51 0.88 0.45 0.46 0.26

0 20.84 3/25/2009 9:49 656.56 1908.03 14.98 13.55 1.63 203.79 2.69 18.72 3/25/2009 9:50 668.26 1970.93 53.58 35.84 17.89 640.82 10.53 9.08 3/25/2009 9:51 683.12 1993.34 52.75 30.33 22.56 638.14 10.64 8.51 3/25/2009 9:52 649.61 1994.98 55.78 28.46 27.37 643.87 10.69 8.39 3/25/2009 9:53 639.15 1973.73 57.1 27.11 30.11 643.12 10.77 8.31 3/25/2009 9:54 662.5 1984.77 60.57 24.23 36.4 652.17 10.79 8.28 3/25/2009 9:55 651.91 1985.76 61.2 22.47 38.86 649.01 10.77 8.31 3/25/2009 9:56 654.98 1981.61 62.43 21.24 41.25 648.83 10.77 8.31 3/25/2009 9:57 644.79 1964.11 61.91 20.07 41.91 644.14 10.79 8.31 3/25/2009 9:58 645.52 1956.09 64.97 21.21 43.56 649.85 10.81 8.29 3/25/2009 9:59 650.09 1976.28 68.49 27.99 40.66 647.99 10.78 8.31 3/25/2009 10:00 653.41 1966.86 65.9 24.07 41.91 644.96 10.78 8.33 3/25/2009 10:01 646.23 1977.07 64.32 23.15 41.23 641.62 10.78 8.32 3/25/2009 10:02 626.89 1965.92 64.32 23.16 41.33 643.27 10.79 8.32 3)25/2009 10:03 631.33 2006.77 66.54 23.31 43.23 651.77 10.83 8.28 3/25/2009 10:04 645.52 2004.36 66.96 19.55 47.57 660 10.85 8.26 3/25/2009 10:05 652.45 2003.33 65.1 17.84 47.15 648.18 10.79 8.31 3/25/2009 10:06 657.43 2005.52 65.4 17.05 48.3 648.31 10.78 8.32 3/25/2009 10:07 624.89 2007.46 61.99

16 46.04 637.69 10.78 8.34 3/25/2009 10:08 631.66 2006.78 63.83 16.7 47.12 648.23 10.84 8.29 3/25/2009 10:09 638.8 2007.63 68.3
22 46.27 653.01 10.82 8.29 3/25/2009 10:10 616.06 2007.54 68.64 21.93 46.78 651.61 10.83 8.29 3/25/2009 10:11 630.68 2007.18 67.76 21.04 46.78 652.73 10.85 8.27 3/25/2009 10:12 633.14 2007.23 69.92 22.27 47.81 657.43 10.84 8.27 4Trail Ridge Energy CEM Data

March 25, 2009 3/25/2009 10:13 640.68 2007.34 69.06 22.11 47.02 653.01 10.81
8.3 3/25/2009 10:14 636.9 2007.27 66.26 20.52 46.06 644.95 10.8 8.31 3/25/2009 10:15 623.49 2007.81 64.02 17.22 46.88 646.12 10.82 8.31 3/25/2009 10:16 653.7 200786 66.5 17.61 48.96 654.46 10.84 8.27 3/25/2009 10:17 644.81 2007.51 66.73 17.49 49.42 652.83 10.79 8.31 3/25/2009 10:18 648.97 2007.85 64.87 16.64 48.31 645.34 10.78 8.33 3/25/2009 10:19 636.61 2007.46 63.68 15.61 48.31 641.23 10.77 8.34 3/25/2009 10:20 622.15 2007.12 62.73 15.29 47.51 642.86 10.81 8.31 3/25/2009 10:21 630.94 2007.4 62.63 12.21 50.56 649.91 10.84 8.27 3/25/2009 10:22 640.49 2007.58 62.19 10.52 51.8 651 10.83 8.28 3/25/2009 10:23 648.43 2007.32 62.61 12.4 50.28 657.5 10.83 8.28 3/25/2009 10:24 626.89 1936.79 61.99 13.09 48.98 653.22 10.83 8.28 3/25/2009 10:25 627.97 1927.14 64.69 13.9 50.83 661.67 10.89 8.23 3/25/2009 10:26 653.63 1957.03 63.38 13.64 49.82 650.56 10.83 8.29 3/25/2009 10:27 658.46 1979.08 62.85 13.74 49.12 645.92 10.8 8.33 3/25/2009 10:28 661.52 1988.12 63.94 13.6 50.4 648.59 10.83 8.29 3/25/2009 10:29 649.4 1970.4 62.05 12.63 49.44 641.37 10.8 8.34 3/25/2009 10:30 635.89 2006.58 61.41 12.92 48.47 642.86 10.84
8.3 3/25/2009 10:31 638.73 2006.64 62.64 13.09 49.56 648.44 10.85 8.29 3/25/2009 10:32 665.13 2006.87 64.7 14.03 50.75 652.74 10.84 8.29 3/25/2009 10:33 656.64 1980.63 63.46 13.76 49.85 645.86 10.81 8.32 3/25/2009 10:34 639.85 1989.4 63.32 13.54 49.94 649.63 10.83
8.3 3/25/2009 10:35 612.07 2006.71 62.49 13.21 49.36 644.94 10.84 8.31 3/25/2009 10:36 639.98 1998.45 63.01 15.9 47.09 656.23 10.88 8.26 3/25/2009 10:37 643.94 1985.14 66.06 18.8 47.42 658.52 10.85 8.28 3/25/2009 10:38 670.01 1999.75 63.75 15.53 48.46 645.43 10.8 8.33 3/25/2009 10:39 643.44 2006.6 62.2 13.61 48.39 641.31 10.79 8.36 3/25/2009 10:40 629.51 1913.68 62.15 13.63 48.53 643.82 10.83 8.32 3/25/2009 10:41 636.53 1970.19 61.93 13.43 48.35 645.77 10.85
8.3 3/25/2009 10:42 629.32 1967.59 65.05 13.97 51.04 654.7 10.85 8.29 3/25/2009 10:43 627.7 1966.57 64.95 13.91 51.18 651.37 10.84
8.3 3/25/2009 10:44 631.63 2006.64 64.09 14.03 50.31 649.24 10.85
8.3 3/25/2009 10:45 644.89 2007.03 63.24 13.73 49.52 646.53 10.84 8.31 3/25/2009 10:46 629.02 2007.03 62.63 14.61 48.07 650.42 10.84 8.32 3/25/2009 10:47 628.83 2007.5 61.92 15.99 45.96 646.41 10.86
8.3 3/25/2009 10:48 657.99 1892.05 65.69 16.13 49.63 655.81 10.87 8.28 3/25/2009 10:49 645.79 1915.83 65.21 15.6 49.7 652.13 10.85
8.3 3/25/2009 10:50 647.7 1899.07 64.74 15.28 49.42 649.6 10.84 8.31 3/25/2009 10:51 660.6 2003.51 61.84 16.03 45.93 643.99 10.81 8.33 3/25/2009 10:52 638.77 1973.39 63.91 17.19 46.76 646.89 10.84 8.32 3/25/2009 10:53 640.22 1979.53 62.95 15.26 47.73 642.01 10.85 8.31 3/25/2009 10:54 54.93 1987.34 56.92 19.11 37.93 397.25 7.32 6.46 3/25/2009 10:55 2.39 501.82 29.71 11.75 18.02 2.94 0.2 0.51 3/25/2009 10:56 1.32 6.51 23.28 8.17 15.18 1.23 0.07 0.09 3/25/2009 10:57 2.97 4.59 19.3 6.23 13.05 10.8 0.03 0.01 3/25/2009 10:58 1.06 4.61 15.58 4.92 10.69 520.66 0.01
0.1 3/25/2009 10:59 1.06 4.62 12.36 3.64 8.65 600.9

0 0.01 3/25/2009 11:00 0.59 3.34 9.66 2.69 7.06 601.68

0 0.01 3/25/2009 11:01 0.24 2.65 7.91 2.17 5.7 600.76

0 0.01 3/25/2009 11:02 0.08 4.55 6.23 1.76 4.57 135.18 9.19 0.01 3/25/2009 11:03 0.08 4.17 5.18 1.37 3.68 0.42 13.33 0.01 3/25/2009 11:04 0.09 2.69 4.33 1.24 3.09 0.42 13.4 0.01 3/25/2009 11:05 0.13 2.69 3.73 0.98 2.66 0.21 11.32 0.85 3/25/2009 11:06 0.08 2.72 3.25 0.91 2.38 0.37 0.48 7.57 3/25/2009 11:07 0.09 2.7 2.74 0.86 1.93 0.46 0.06 8.16 3/25/2009 11:08 0.08 2.71 2.3 0.86 1.76 0.26 0.01 8.25 3/25/2009 11:09 0.08 2.71 2.04 0.42 1.38 0.41

0 8.27 3/25/2009 11:10 0.09 2.29 1.77 0.39 1.39 0.19

0 8.27 3/25/2009 11:11 0.08 2.84 1.76 0.38 1.01 0.35

0 8.28 3/25/2009 11:12 0.08 2.82 1.32 0.38 0.89 0.27

0 8.27 3/25/2009 11:13 0.08 2.82 1.26 0.38 0.89 0.18

0 8.28 5Trail Ridge Energy CEM Data

March 25, 2009 3/25/2009 11:14 0.08 2.83 1.27 0.39 0.9 0.3

0 8.29 3/25/2009 11:15 0.08 2.37 1.32 0.43 0.94 0.15

0 8.28 3/25/2009 11:16 0.08 1.47 6.8 10.31 -1.6 0.29

0 7.93 3/25/2009 11:17 0.08 2.68 90.19 90.76 -0.17 0.14

0 1.06 3/25/2009 11:18 0.08 1.79 100.42 101.49 -1.03 0.16

0 0.15 3/25/2009 11:19 0.08 2.35 100.04 101.61 -1.04 0.19

0 0.01 3/25/2009 11:20 241.12 2.28 95.78 96.24 0.27 0.11

0 0.11 3/25/2009 11:21 526.3 1.48 9.63 12.39 -1.15 0.41

0 16.4 3/25/2009 11:22 527.46 2.21 1.35 0.65 0.91 0.32

0 20.33 3/25/2009 11:23 540.59 1.54 1.37 0.48 0.48 0.82

0 20.58 3/25/2009 11:24 561.72 944.52 0.96 0.43 0.45 0.29

0 20.69 3/25/2009 11:25 562.48 1091.64 0.83 0.42 0.45 0.21

0 20.74 3/25/2009 11:26 563.18 1101.46 0.82 0.43 0.45 0.32

0 20.75 3/25)2009 11:27 564.45 1099.52 0.82 0.42 0.44 0.22

0 20.75 3/25/2009 11:28 566.46 1097.42 0.82 0.42 0.45 0.29

0 20.75 3/25/2009 11:29 610.44 1084.26 2.38 0.81 1.68 12.81 0.07 20.76 3/25/2009 11:30 650.13 1172.98 46.65 37.47 9.21 565.77 8.78 12.05 3/25/2009 11:31 662.8 2006.56 53.92 35.89 18.03 652.47 10.81 8.56 3)25/2009 11:32 660.9 1794.4 53.81 30.86 23.04 647.31 10.82 8.38 3/25/2009 11:33 658.93 1867.27 56.54 26.87 29.79 649.01 10.86 8.33 3/25/2009 11:34 658.17 1834.57 57.43 24.12 33.4 645.92 10.86 8.33 3/25/2009 11:35 670.2 2005.58 60.76 22.78 38.16 651.41 10.89 8.29 3/25/2009 11:36 654.59 1811.46 61.02 20.93 40.15 646.31 10.88 8.31 3)25/2009 11:37 623.07 1815.82 60.26 20.34 39.89 644.54 10.93
8.3 3/25/2009 11:38 650.59 2007.62 64.41 20.58 43.81 655.5 10.95 8.25 3/25/2009 11:39 655.55 1882.94 65.95 20.19 45.83 653.42 10.92
8.3 3/25/2009 11:40 653.33 1872.29 65.17 18.61 46.54 648.44 10.9 8.32 3/25/2009 11:41 620.98 1864.28 65.82 18.18 47.74 652.89 10.92 8.31 3/25/2009 11:42 635.11 1891.7 64.01 17.55 46.57 648.85 10.96 8.27 3/25/2009 11:43 649.83 2007.59 67.72

18 49.79 660.62 10.94 8.28 3/25/2009 11:44 657.67 1845.77 64.22 16.75 47.59 647.63 10.92 8.31 3/25/2009 11:45 649.71 1808.43 63.36 16.8 46.64 646.2 10.9 8.34 3/25/2009 11:46 666.68 1877.19 63.62 16.86 46.98 643.46 10.9 8.33 3/25/2009 11:47 657.7 1853.83 63.16 16.3 46.93 643.24 10.88 8.35 3/25/2009 11:48 631.24 1831.96 64.98 16.44 48.69 648.48 10.91 8.33 3/25/2009 11:49 613.46 1918.27 62.27 15.58 46.76 641.5 10.95 8.31 3/25/2009 11:50 647.4 2006.69 66.28 16.69 49.66 657.8 10.97 8.27 3/25/2009 11:51 662.54 1962.21 65.86 16.21 49.81 650.66 10.91 8.32 3/25/2009 11:52 643.37 1949.41 66.32 16.58 49.81 655.71 10.93 8.31 3/25/2009 11:53 662.11 2006.54 65.68 16.21 49.47 649.95 10.91 8.31 3/25/2009 11:54 639 1812.68 63.93 16.38 47.73 645.54 10.9 8.33 3/25/2009 11:55 612.65 1843.23 62.71 15.38 47.24 639.62 10.92 8.33 3/25/2009 11:56 628.39 1880.26 64.27 15.74 48.53 651.7 10.97 8.28 3/25/2009 11:57 646.02 1966.7 66.32 17.15 49.5 655.65 10.93
8.3 3/25/2009 11:58 644.98 2006.14 64.02

17 47.1 648.05 10.91 8.32 3/25)2009 11:59 623.94 2007.56 66.2 17.79 48.39 656.41 10.93 8.31 3/25/2009 12:00 646.71 2007.46 64.23 17.03 47.37 646.56 10.91 8.33 3/25/2009 12:01 642.69 2007.47 62.64 17.2 45.49 644.57 10.89 8.35 3)25/2009 12:02 612.86 2007.51 63.47 17.33 46.06 643.58 10.89 8.35 3/25/2009 12:03 608.94 2007.48 62.39 16.97 45.41 642.67 10.96
8.3 3/25/2009 12:04 634.89 1902 68.44 18.97 49.63 666.29

11 8.24 3/25/2009 12:05 642.15 1932.1 67.34 19.84 47.65 652.64 10.94
8.3 3/25/2009 12:06 622.54 1950.65 66.15 20.74 45.49 650.9 10.9 8.32 3/25/2009 12:07 626.47 2007,61 66.34 19.75 46.66 649.35 10.9 8.32 3)25)2009 12:08 622.81 2006.77 65.66 20.06 45.77 647.77 10.87 8.35 3/25/2009 12:09 595.26 2006.58

81 44.9 36.14 647.82 10.92 8.31 3)25)2009 12:10 610.68 2006.59 97.84 78.69 19.3 670.53

11 8.21 3/25/2009 12:11 628.06 1978.79 86.94 63.54 23.37 662.6! 10.94 8.25 3/25/2009 12:12 621.79 1937.13 81.75 54.35 27.79 657.99 10.91 8.28 3/25/2009 12:13 615 1997.61

80 51.78 28.36 659.27 10.91 8.29 3/25/2009 12:14 624.55 1923.51 78.56 49.27 29.32 659.1 10.92 8.29 6Trail Ridge Energy CEM Data

March 25, 2009 3/25/2009 12:15 630.24 1973.19 70.23 40.34 29.92 644.45 10.88 8.33 3/25/2009 12:16 586.69 1966.77 68.56 29.73 38.93 658.02 10.93
8.3 3/25/2009 12:17 611.55 2007.23 66.44 30.67 35.77 650.03 10.95 8.28 3/25/2009 12:18 615.78 2007.55 70.91 36.37 34.56 658.39 10.93
8.3 3/25/2009 12:19 625.71 2007.56 72.43 39.3 33.31 659.08 10.94 8.28 3/25/2009 12:20 618.72 2007.4 71.09 36.57 34.6 658.79 10.93 8.28 3/25/2009 12:21 590.2 2006.75 67.03 32.99 34.16 649.46 10.91 8.31 3/25/2009 12:22 588.66 2006.57 65.09 31.15 34.14 652.41 10.98 8.25 3/25/2009 12:23 613.22 2006.58 72.85 34.55 38.32 670.02 10.99 8.22 3/25/2009 12:24 618.29 2006.55 68.69 3244 36.29 652.51 10.92 8.29 3/25/2009 12:25 602.47 2006.6 69.11 32.22 36.81 655.06 10.93 8.29 3/25/2009 12:26 606.24 1939.48 69.49 31.85 37.64 655.45 10.93 8,29 3/25/2009 12:27 590.58 1841.2 66.48 27.33 39.26 652.24 10.92 8.31 3/25/2009 12:28 560.96 1780.79 66.19 25.59 40.69 653.01 10.95 8.29 3/25/2009 12:29 564.1 2006.58 68.12 26.23 42.06 666.03 11.04 8.21 3/25/2009 12:30 598.8 2006.56 73.73 28.65 45.13 677.35 11.02
8.2 3/25/2009 12:31 595.79 2006.57 69.42 26.16 43.32 655.79 10.94 8.28 3/25/2009 12:32 594.12 2006.53 71.39 26.16 45.4 662.66 10.95 8.28 3/25/2009 12:33 601.22 1993.28 70.41 25.33 45.08 660.54 10.94 8.29 3/25/2009 12:34 578.84 1997.13 67.55 24.83 42.99 652.85 10.92 8.32 3/25/2009 12:35 572.83 1993.27 66.05 23.07 42.9 648.58

11 8.26 3/25/2009 12:36 598.12 2006.61 71.64 25.57 45.99 666.36 10.98 8.25 3/25/2009 12:37 582.81 2006,62 68.73 23.93 44.72 654.73 10.94
8.3 3/25/2009 12:38 576.48 1983 69.78 23.57 46.07 660.96 10.97 8.28 3/25/2009 12:39 578.67 1911.68 70.48 22.99 47.5 663.5 11.02 8.23 3/25/2009 12:40 605.39 1910.76 71.63 24.08 47.56 663.31 10.98 8.26 3/25/2009 12:41 250.69 1389 69.19 26.56 42.87 602.46 10.18 8.21 3/25/2009 12:42 2.64 219.84 29.7 11.59 18.18 34.04 0.83 1.67 3/25/2009 12:43 1.42 11.19 22.12
6.5 15.77 2.45
0.1 0.19 3/25/2009 12:44 1.07 4.66 16.87 3.49 13.52 2.17 0.06 0.01 3/25/2009 12:45 1.06 3.72 13.55 2.67 11.11 2.03 0.03 0.01 3/25/2009 12:46 0.18 2.71 11.3 2.33 8.87 1.98 0.01 0.01 3/25/2009 12:47 0.09 2.72 8.47 1.58 6.94 2.22

0 0.01 3/25/2009 12:48 0.08 2.65 6.54 0.99 5.51 2.28

0 0.01 3/25/2009 12:49 0.09 2.67 5.17 0.9 4.49 2.16

0 0.01 3/25/2009 12:50 0.08 2.47 4.23 0.64 3.66 2.15

0 0.01 3/25/2009 12:51 0.09 2.54 3.49 0.4 2.99 2.09

0 0.01 3/25/2009 12:52 0.09 2.77 2.94 0.41 2.5 2.12

0 0.01 3/25/2009 12:53
0.1 2.74 2.52 0.41 2.09 2.13

0 0.01 3/25/2009 12:54 0.31 2.73 2.28 0.41 1.92 2.25

0 0.01 3/25/2009 12:55 0.09 2.41 1.75 0.4 1.4 444.19

0 0.01 3/25/2009 12:56 0.09 1.34 1.77 0.42
1.4 604.6

0 0.01 3/25/2009 12:57 0.08 2.32 1.38 0.38
1.2 605.49

0 0.01 3/25/2009 12:58 0.16 2.55 1.21 0.37 0.87 381.38 3.88 0.01 3/25/2009 12:59 0.09 2.56 1.21 0.37 0.87 4.22 13.33 0.01 3/25/2009 13:00 0.08 1.44 1.16 0.41 0.9 2.24 13.49 0.01 3/25/2009 13:01 0.08 1.83 0.74 0.39 0.89 2.3 13.54 0.01 3/25/2009 13:02 0.09 1.78 0.74 0.39 0.55 2.17 13.56 0.01 3/25/2009 13:03 0.09

2 0.73 0.38 0.38 2.27 13.58 0.01 3/25/2009 13:04 0.08 1.97 0.73 0.39 038
2.1 11.86 0.63 3/25/2009 13:05 0.09 2.33 0.73 0.38 0.38 2.35 0.6 7.49 3/25/2009 13:06 0.09 2.39 0.72 0.38 0.38 2.69 0.09 8.15 3/25/2009 13:07 0.08 2.48 0.72 0.37 0.38 2.44 0.04 8.23 3/25/2009 13:08 0.09 2.56 0.71 0.37 0.37 2.46 0.02 8.26 3/25/2009 13:09 0.09 2.52 0.71 0.37 0.37 2.47

0 8.26 3/25/2009 13:10 0.08 2.48 0.71 0.37 0.37 2.44

0 8.27 3/25/2009 13:11 0.08 2.39 0.72 0.37 0.38 2.57

0 8.27 3/25/2009 13:12 0.09 2.51 11.19 16.06 -2.8 2.73

0 7.63 3/25/2009 13:13 0.08 2.45 95.96 95.15 0.92 2.72

0 0.82 3/25/2009 13:14 0.08 2.42 100.03 101.54 -1.47 2.53

0 0.12 3/25/2009 13:15 0.09 2.15 99.95 101.55 -1.61 2.78

0 0.01 7Trail Ridge Energy CEM Data

March 25, 2009 3/25/2009 13:16 0.08 1.48 99.81 101.57 -1.6 2.78

0 0.01 3/25/2009 13:17 0.09 1.99 99.8 101.56 -1.61
2.5

0 0.01 3/25/2009 13:18 176.6 2.34 99.64 100.6 -0.81 2.54

0 0.01 3/25/2009 13:19 533.83 2.47 24.77 21.76 3.47 2.85

0 13.29 3/25/2009 13:20 534.42 1.44 0.92 0.56 0.39 3.37

0 20.21 3/25/2009 13:21 535.34 2.12 0.74 0.39 0.38 3.25

0 20.54 3/25/2009 13:22 546.35 1.77 0.75 0.4 0.39 3.06

0 20.63 3/25/2009 13:23 592.97 2.07 0.74 0.39 0.38 3.04

0 20.65 3/25/2009 13:24 609.61 470.31 0.75 0.4 0.39 2.58

0 20.71 3/25/2009 13:25 609.8 1082.26 0.78 0.41 0.4 3.11

0 20.72 3/25)2009 13:26 609.94 1091.33 0.78 0.41 0.4 2.68

0 20.73 3/25/2009 13:27 609.77 1094.24 0.75 0.39 0.38 2.67

0 20.74 3/25/2009 13:28 609.68 1085.13 0.73 0.37 0.37 2.64

0 20.75 3/25/2009 13:29 643.57 1086.5 7.72 5.26 2.49 78.97 0.77 20.39 3/25/2009 13:30 643.19 1090.41 58.02 32.69 25.4 637.5 10.14 10.17 3/25/2009 13:31 628.31 1686.2 58.29 28.33 30.03 657.28 10.85 8.52 3/25/2009 13:32 86.96 1223.16 57.85 23.48 34.46 650.56 10.89 8.38 3/25/2009 13:33 -0.05 2.73 65.07 19.74 45.6 655.48

11 8.25 3/25/2009 13:34

0 1.34 74.4 22.55 52.02 675.43 10.99 8.23 3/25/2009 13:35 0.02 -0.22 23.06 7.88 15.31 665.71 10.95 8.27 3/25/2009 13:36 0.04 1.43 0.19 0.39 0.4 660.33 10.98 8.26 3/25/2009 13:37 0.05 -1.16 0.18 0.39 0.39 671.99 11.06 8.19 3/25/2009 13:38 0.04 0.57 6.51 1.68 5.34 673.07 11.01 8.22 3/25/2009 13:39 0.05 2.44 50.06 48.51 1.55 662.89 10.99 8.25 3/25/2009 13:40 0.05 0.31 49.08 50.37 -1.29 656.43 10.98 8.27 3/25/2009 13:41 0.07 -1.12 49.74 50.47 -0.73 665.09 10.98 8.26 3/25/2009 13:42 0.06 -1.85 49.99 50.58 -0.59 663.3 10.98 8.26 3/25/2009 13:43 0.06 -0.52 49.96 50.54 -0.58 657.43 10.95 8.31 3/25/2009 13:44 0.07 -1.25 50.27 50.48 -0.21 651.69 10.94 8.32 3/25/2009 13:45 0.06 2.37 50.4 50.48 -0.08 650.29 10.98
8.3 3/25/2009 13:46 0.06 2.79 49.96 50.04 -0.08 667.58 11.06 8.21 3/25/2009 13:47 0.07 3.68 50.05 50.01 0.04 677.38 11.02 8.23 3/25/2009 13:48 0.06 4.19 50.67 50.61 0.06 667.61

11 8.24 3/25/2009 13:49 0.06 6.86 50.86 50.69 0.41 669.16 10.99 8.24 3/25/2009 13:50 0.06 5.31 50.81 50.47 0.45 664.39 10.97 8.27 3/25/2009 13:51 0.06 3.76 50.7 50.28 0.91 656.15 10.94
8.3 3/25/2009 13:52 0.06 5.62 50.23 49.52 0.91 657.67 10.95 8.29 3/25/2009 13:53 0.07 0.4 50.25 49.48 0.92 658.81 10.95 8.29 3/25/2009 13:54 0.07 3.57 50.27 49.47 1.03 661.3 10.95 8.29 3/25/2009 13:55 0.05 3.4 50.33 49.48 1.42 652.14 10.98 8.27 3/25/2009 13:56 0.07 1.32 50.3 49.2 1.42 675.22 11.07 8.17 3/25/2009 13:57 0.06 3.19 50.25 48.98 1.42 670.17 10.99 8.22 3/25/2009 13:58 0.06 0.35 50.17 48.93 1.53 663.98 10.98 8.24 3/25/2009 13:59 0.07 3.57 50.13 48.7 1.79 671.22

11 8.22 3/25/2009 14:00 0.07
5.1 50.13 48.41
1.8 663.79 10.97 8.24 3/25/2009 14:01 0.07 1.61 50.1 48.38 1.78 659.11 10.94 8.29 3/25/2009 14:02 0.06 2.21 50.1 48.38 2.07 657.35 10.91
8.3 3/25/2009 14:03 0.07
1.9 50.1 47.92 2.28 661.02 10.94 8.28 3/25/2009 14:04 0.06

3 50.1 47.87 2.28 651.87 10.97 8.28 3/25/2009 14:05 0.07 -0.49 50.1 47.87 2.32 676.52 11.04 8.18 3/25/2009 14:06 0.07 1.86 50.1 47.41 2.77 662.58 10.97 8.24 3/25/2009 14:07 0.06 1.32 50.1 47.37 2.78 666.44 10.99 8.22 3/25/2009 14:08 0.07 0.54 50.1 47.37 2.77 670.72

11 8.21 3/25/2009 14:09 0.07 3.24 50.1 47.33 2.77 668.89 10.99 8.22 3/25/2009 14:10 0.06 1.97 50.1 46.87 3.23 656.99 10.94 8.28 3/25/2009 14:11 0.07

0 50.1 46.87 3.28 664.57 10.98 8.25 3/25/2009 14:12 0.07 2.57 50.1 46.87 3.27 664.31 10.98 8.24 3/25/2009 14:13 0.06 4.93 50.1 46.66
3.4 661.47 10.94 8.27 3/25/2009 14:14 0.07 1.21 50.1 46.38 3.78 651.92 10.89 8.32 3/25/2009 14:15 0.06 3.07 50.1 46.37 3.78 653.89 10.91
8.3 3/25/2009 14:16 0.07 3.52 50.1 46.33 3.78 650.2 10.91 8.29 8Trail Ridge Energy CEM Data

March 25, 2009 3/25/2009 14:17 0.08 1.82 50.13 45.9 3.8 648.09 10.98 8.26 3/25/2009 14:18 0.07 0.87 50.13 45.9 4.01 678.51 11.05 8.17 3/25/2009 14:19 0.07 -1.28 50.13 45.9 4.29 678.27 10.98 8.21 3/25/2009 14:20 0.06 -5.34 50.13 45.76 4.29 657.96 10.92 8.28 3/25/2009 14:21 0.08 0.11 50.03 45.38 4.29 661.51 10.93 8.28 3/25/2009 14:22 0.08 1.56 49.8 45.37 4.33 668.09 10.96 8.26 3/25/2009 14:23 0.07 3.13 49.68 45.36 4.77 657.7 10.91
8.3 3/25/2009 14:24 0.08 0.35 49.6 45.07 4.78 654.06 10.96 8.28 3/25/2009 14:25 0.06 -2.65 49.62 44.89 4.79 676 11.05 8.18 3/25/2009 14:26 0.08 4.17 49.62 44.89 4.79 673.58 10.96 8.24 3/25/2009 14:27 0.07 4.27 49.61 44.83 4.84 660.05 10.92 8.29 3/25/2009 14:28 0.06 -0.74 43.47 42.19 1.34 670.36 10.97 8.25 3/25/2009 14:29 0.06 0.87 2.64
1.8

1 662.98 10.95 8.27 3/25/2009 14:30 0.06 3.11
0.1 0.33 0.3 662.76 10.93 8.29 3/25/2009 14:31 0.06 -1.52
0.1 0.32
0.3 657.69 10.91 8.31 3/25/2009 14:32 0.08 3.63 0.08 0.31 0.29 663.36 10.93 8.28 3/25/2009 14:33 0.07 2.75 0.08 0.31 0.29 648.66 10.94 8.29 3/25/2009 14:34 0.05 0.24 0.08 0.3 0.29 662.45

11 8.24 3/25/2009 14:35 0.07 1.71 0.08
0.3 0.28 675.76 10.99 8.23 3/25/2009 14:36 0.07 1.05 0.08 0.31 0.29 667.6 10.95 8.26 3/25/2009 14:37 0.07 0.57 0.07 0.29 0.28 660.26 10.93 8.29 3/25/2009 14:38 0.05 4.92 0.07 0.3 0.28 677.88 10.98 8.24 3/25/2009 14:39 0.08 -2.38 0.07 0.3 0.28 667.08 10.94 8.27 3/25/2009 14:40 0.08 -0.55 0.07
0.3 0.28 660.15 10.92 8.29 3/25/2009 14:41 0.06 3.05 0.08 0.3 0.29 666.02 10.93
8.3 3/25/2009 14:42 0.05 5.04 0.07 0.3 0.28 660.68 10.93
8.3 3/25/2009 14:43 0.06 6.14 0.07 0.3 0.28 661.76 10.91 8.31 3/25/2009 14:44 0.06 5.17 0.07 0.29 0.28 649.15 10.9 8.33 3/25/2009 14:45 0.08 -1.23 0.07 0.29 0.28 655.28 11.01 8.24 3/25/2009 14:46 0.06 084 0.07
0.3 0.28 675.45 11.02
8.2 3/25/2009 14:47 0.07 0.64 0.07
0.3 0.28 671.14 10.98 8.24 3/25/2009 14:48 0.06 0.09 0.07 0.3 0.28 670.19 10.97 8.25 3/25/2009 14:49 0.06 0.6 0.07
0.3 0.28 664.06 10.95 8.27 3/25/2009 14:50 0.06 1.51 0.07 0.3 0.28 652.39 10.9 8.31 3/25/2009 14:51 0.05 4.94 0.07 0.3 0.28 656.29 10.91 8.31 3/25/2009 14:52 0.08 0.87 0.07 0.3 0.29 663.51 10.94 8.28 3/25/2009 14:53 0.07 -1.83 0.07 0.3 0.29 653.46 10.89 8.34 3/25/2009 14:54 0.07 0.67 0.09 0.31 0.29 648.23 10.97 8.28 3/25/2009 14:55 0.07 1.62 0.06 0.3 0.28 676.07

11 8.23 3/25/2009 14:56 0.07 -0.67 0.09 0.32 0.3 668.9 10.95 8.26 3/25/2009 14:57 0.07 1.28 0.08 0.31 0.29 659.99 10.98 8.26 3/25/2009 14:58 0.07 2.62 0.08 0.3 0.29 679.41 11.02
8.2 3/25/2009 14:59 0.06 4.57 0.08
0.3 0.28 660.43 10.92 8.27 3/25/2009 15:00 0.07 2.32 0.09 0.32 0.3 661.13 10.93 8.29 3/25/2009 15:01 0.06 0.67 0.08 0.31 0.29 657.56 10.9 8,31 3/25/2009 15:02 0.07 0.56
0.1 0.33 0.3 657.41 10.9 8.32 3/25/2009 15:03 0.07 -1.43 0.11 0.33 0.3 658.56 10.9 8.32 3/25/2009 15:04 0.07 2.89
0.1 0.33 0.3 656.01 10.88 8.34 3/25/2009 15:05 0.07 1.13
0.1 0.33 0.3 651.62 10.88 8.35 3/25/2009 15:06 0.07 4.43 0.08 0.31 0.29 648.4 10.97 8.28 3/25/2009 15:07 0.08 0.69 0.07 0.31 0.29 672.82 10.98 8.24 3/25/2009 15:08 0.07 3.38 0.07 0.31 0.29 672.9 10.98 8.23 3/25/2009 15:09 0.07 1.15 0.07 0.3 0.29 655.3 10.93 8.28 3/25/2009 15:10 0.07 0.96 0.08 0.31 0.29 656.84 10.92
8.3 3/25/2009 15:11 0.08 -0,03 0.08 0.31 0.29 659.95 10.91 8.32 3/25/2009 15:12 0.06 2.43
0.1 0.32 0.3 656.6 10.91 8.32 3/25/2009 15:13 0.07 0.14 0,08 0.31 0.29 654.55 10.89 8.34 3/25/2009 15:14 0.07 4.26 0.07 0.31 0.29 657.01 10.89 8.34 3/25/2009 15:15 0.07 4.06 0.07 0.3 0.29 511.31 11.18 7.71 3/25/2009 15:16 0.07 -1.62 0.07 0.3 0.29 6.99 13.48 0.73 3/25/2009 15:17 0.06 5.48 0.07 0.3 0.29 2.69 13.56 0.12 9Trail Ridge Energy CEM Data

March 25, 2009 3/25/2009 15:18 006 2.04 0.08 0.31 0.29 2.83 13.57 0.01 3/25/2009 15:19 0.07 -0.86 0.09 0.33 0.31 2.48 13.06 0.09 3/25/2009 15:20 0.07 -1.98 0.07
0.3 0.29 3.03 1.18 7.05 3/25/2009 15:21 0.06 3.24 0.08 0.31 0.29 2.99 0.15 8.14 3/25/2009 15:22 0.05 -1.39 0.07
0.3 0.29 2.88 0.09 8.25 3/25/2009 15:23 0.04 0.03 0.08 0.31 0.29 2.83 0.06 8.28 3/25/2009 15:24 0.03 3.21 0.08 0.31 0.29

3 0.04 8.29 3/25/2009 15:25 0.05 -0.07 0.09 0.32
0.3 2.93 0.27 8.15 3/25/2009 15:26 0.05 0.36 0.08 0.32
0.3 1.58 4.95 1.19 3/25/2009 15:27 0.03
0.3 0.08 0.31 0.3 1.85 5.27 0.16 3/25/2009 15:28 0.04 -1.92 0.09 0.33
0.3 1.84 5.29 0.01 3/25/2009 15:29 0.05 0.37 0.58 0.33
0.3
1.4 5.3 0.01 3/25/2009 15:30 0.04 -1.47 1.09 6.01 -1.53 1.69 5.04 0.01 3/25/2009 15:31 0.05 3.16 88.98 91.66 -0.94
2.8 0.34 0.01 3/25/2009 15:32 0.05 -2.71 99.64 101.41 -1.28 3.48 0.03 0.01 3/25/2009 15:33 0.04 -1.11 99.64 101.5 -1.69 3.62 0.01 0.01 3/25/2009 15:34 0.05 -1.69 100.15 101.5 -1.69 3.84

0 0.01 3/25/2009 15:35 0.04 -0.27 100.08 101.68 -1.68 3.78

0 0.01 3/25/2009 15:36 0.06 2.08 100.06 102 -1.69 3.64

0 0.01 3/25/2009 15:37 0.05 0.6 100.05 101.65 -1.36 3.17

0 0.01 3/25/2009 15:38 0.04 0.91 56.27 62.74 -3.87 3.31

0 0.01 3/25/2009 15:39 0.04 3.03 50.02 50.88 -0.7 3.39

0 0.01 3/25/2009 15:40 0.04
1.8 49.6 50.88 -0.7 3.64

0 0.01 3/25/2009 15:41 0.04 5.51 49.59 50.88 -0.7 3.88

0 0.01 3/25/2009 15:42 0.07 0.18 49.6 50.91 -0.69 3.87

0 0.01 3/25/2009 15:43 0.06

0 49.6 50.47 -0.7 3.45

0 0.01 3/25/2009 15:44 0.05 3.2 49.6 50.38 -0.7 3.37

0 0.01 3/25/2009 15:45 0.04 6.31 49.6 50.72 -0.7 3.97

0 0.01 3/25/2009 15:46 0.04 -109 49.6 50.63 -0.71 3.46

0 0.01 3/25/2009 15:47 0.05 4.46 49.6 50.55 -0.7 3.83

0 0.01 3/25/2009 15:48 0.04 0.79 49.6 50.88 -0.71 3.88

0 0.01 3/25/2009 15:49 0.06 0.15 59.7 36.52 23.16 480.43 7.08 4.56 3/25/2009 15:50 0.04 0.21 64.95 20.96 43.95 667.91 10.88 8.05 3/25/2009 15:51 0.04 -0.78 71.78 21.58 50.33 669.98 10.93
8.2 3/25/2009 15:52 0.05 3.25 75.45 22.03 53.47 671.29 10.95 8.23 3/25/2009 15:53 0.04 -0.74 72.5 20.06 52.56 659.55 10.92 8.27 3/25/2009 15:54 0.06 2.57 68.4 17.1 51.19 647.11 10.87 8.35 3/25/2009 15:55 0.05 2.95 70.88 17.25 53.69 656.74 10.9 8.33 3/25/2009 15:56 0.05 1.53 68.7 16.24 52.34 647.76 10.95 8.31 3/25/2009 15:57 0.05 4.77 70.79 17.62 53.23 665.89 11.05 8.21 3/25/2009 15:58 0.06 5.6 79.76 20.83 58.91 679.49 11.04
8.2 3/25/2009 15:59 0.06 7.11 78.74 19.71 59.01 670.1 11.01 8.23 3/25/2009 16:00 0.05 4.89 77.47 19.13 58.15 663.28

11 8.24 3/25/2009 16:01 0.05 1.36 77.16 19.92 57.13 668.92 11.01 8.24 3/25/2009 16:02 0.04 -1.31 75.2 19.29 55.9 662.99 10.97 8.27 3/25/2009 16:03 0.05 -1.58 73.78 18.18 55.73 657.71 10.95 8.29 3/25/2009 16:04 0.06 -1.16 75.69 18.64 57.24 665.98 10.97 8.28 3/25/2009 16:05 0.05 2.88 71.83 17.2 54.56 654.89 10.93 8.32 3/25/2009 16:06 0.05 -0.44 69.79 16.6 53.26 652.94 11.03 8.25 3/25/2009 16:07 0.04 -2.17 77.13 18.92 58.17 676.35 11.07 8.19 3/25/2009 16:08 0.04 1.52 79.11 19.9 59.28 672.9 11.03
8.2 3/25/2009 16:09 0.05 0.91 76.3 18.93 57.43 665.83 11.02 8.22 3/25/2009 16:10 0.04 1.22 75.77 19.55 56.28 663.99

11 8.23 3/25/2009 16:11 0.04 5.53 75.74 19.15 56.62 662.08 10.96 8.28 3/25/2009 16:12 0.05 -0.56 73.02 18.9 54.32 656.6 10.94
8.3 3/25/2009 16:13 0.06 -2.16 73.51 18.92 54.56 660.39 10.95
8.3 3/25/2009 16:14 0.04 6.47 76.16 19.31 56.95 667.33 10.99 8.26 3/25/2009 16:15 0.05 2.8 76.78 20.13 56.79 673.56 10.99 8.26 3/25/2009 16:16 0.05 0.54 69.9 16.54 53.47 652.03 10.99 8.27 3/25/2009 16:17 0.05 2.38 75.92 17.61 58.27 672.62 11.07 8.18 3/25/2009 16:18 0.05 1.58 78.33 19.72 58.64 677.02 11.03 8.21 10Trail Ridge Energy CEM Data

March 25, 2009 3/25/2009 16:19 0.05 3.94 77.03 18.05 58.86 668.2 10.99 8.25 3/25/2009 16:20 0.04 -2.18 76.37

18 58.26 666.59 10.97 8.27 3/25/2009 16:21 0.06 3.26 73.92 17.45 56.51 663.81 10.97 8.28 3/25/2009 16:22 0.05 1.25 75.68 17.4 58.35 666.47 10.98 8.26 3/25/2009 16:23 0.05 1.13 71.58 15.23 56.47 653.78 10.96 8.29 3/25/2009 16:24 0.04 -0.07 70.02 14.77 55.26 654.66 11.02 8.23 3/25/2009 16:25 0.05 1.64 76.14 16.97 59.12 671.58 11.02 8.21 3/25/2009 16:26 0.04 -1.23 75.54 18.06 57.6 671.95 10.99 8.25 3/25/2009 16:27 0.06 4.03 75.8 16.62 59.3 664.25 10.96 8.28 3/25/2009 16:28 0.05 1.23 75.63 16.76

59 665.3 10.97 8.27 3/25/2009 16:29 0.05 0.6 73.06 16.2 56.83 665.57 11.05 8.21 3/25/2009 16:30 0.04 -0.37 82.12 18.34 63.83 681.42 11.03
8.2 3/25/2009 16:3

1 0.07 5.41 78.82 17.48 61.38 671.74

Ii 8.24 3/25/2009 16:32 0.05 -0.11 80.74 18.17 62.62 678.21 11.01 8.22 3/25/2009 16:33 0.04 1.15 79.03 16.65 62.34 666.34 10.98 8.26 3/25/2009 16:34 0.04 -2.67 76.54 16.26 60.3 662.92 10.95 8.29 3/25/2009 16:35 0.06 1.54 73.44 15.88 57.71 657.97 10.97 8.28 3/25/2009 16:36 0.06 4.91 74.3 16.06 58.47 669.27 11.05
8.2 3/25/2009 16:37 0.05 -0.54 78.46 16.85 61.64 672.15

11 8.23 3/25/2009 16:38 0.05 4.8 79.02 16.81 62.3 672.89

11 8.24 3/25/2009 16:39 0.04 -1.41 74.16 17.07 57.! 658.32 10.96 8.28 3/25/2009 16:40 0.05 1.53 75.65 18.68 56.94 668.04 10.97 8.26 3/25/2009 16:41 0.05 1.23 75.17 20.84 54.42 661.28 10.94 8.29 3/25/2009 16:42 0.05 1.07 76.9 20.15 56.73 664.01 10.94
8.3 3/25/2009 16:43 0.04 -2.61 72.21 19.03 53.31 656.46 10.94
8.3 3/25/2009 16:44 0.05 2.33 74.27 16.78 57.54 665.66 11.05 8.21 3/25/2009 16:45 0.06 0.72 79.85 19.22 60.64 678.98 11.02 8.21 3/25/2009 16:46 0.05 0.4 78.51 18.04 60.54 670.4 10.97 8.25 3/25/2009 16:47 0.05 2.01 80.26 19.68 60.66 670.84 10.97 8.26 3/25/2009 16:48 0.05 -0.51 75.88 18.44 57.48 658.54 10.94 8.29 3/25/2009 16:49 0.06 5.28 74.57 18.1! 56.54 660.79 10.94
8.3 3/25/2009 16:50 0.05 1.93 71.45 15.66 55.97 655.73 11.02 8.25 3/25/2009 16:51 0.05 0.54 79.19 16.59 62.65 680.77 11.05
8.2 3/25/2009 16:52 0.06 4.39 77.23 15.97 61.39 670.37 10.99 8.26 3/25/2009 16:53 0.05 0.57 77.55 15.86 61.74 672.66 11.01 8.25 3/25/2009 16:54 0.05 1.54 77.61 15.61 62.15 675.12 11.01 8.25 3/25/2009 16:55 0.05 -2.19 74.82 13.62 61.25 664.69 10.98 8.28 3/25/2009 16:56 0.05 1.73 72.1 13.79 58.44 661.1 10.96 8.31 3/25/2009 16:57 0.04 -4.47 70.3 12.75 57.54 658.58 11.01 8.28 3/25/2009 16:58 0.05 -3.07 74.55 13.03 61.53 673.8 11.08 8.19 3/25/2009 16:59 0.06 -0.48 76.72 14.15 62.77 679.9 11.04 8.22 3/25/2009 17:00 0.06 0.01 74.46 14.16 60.29 675.35 11.03 8.24 3/25/2009 17:01 0.05 0.52 79.85 14.72 65.13 677.98 11.04 8.23 3/25/2009 17:02 0.05 2.84 74.55 14.47 60.34 666.1

11 8.26 3/25/2009 17:03 0.05 -2.53 73.2 13.36 59.82 664.11 11.03 8.25 3/25/2009 17:04 0.05 2.45 74.63 13.92 60.79 673.4 11.07 8.21 3/25/2009 17:05 0.05 2.51 79.73 15.6 64.18 684.98 11.07 8.19 3/25/2009 17:06 0.05 -2.09 74.68 15.01 59.54 666.22 11.01 8.26 3/25/2009 17:07 0.05 0.01 78.68 17.26 61.46 676.5 11.04 8.23 3/25/2009 17:08 0.05 -4.24 76.66 16.13 60.5 669.5 11.01 8.26 3/25/2009 17:09 0.05 -1.87 73.43 14.89 58.54 662 10.98 8.29 3/25/2009 17:10 0.04 -5.21 73.94 14.56 59.34 664.33 10.98 8.28 3/25/2009 17:11 0.05 -0.63 76.99 15.86 61.13 676.11 11.01 8.26 3/25/2009 17:12 0.04 -5.65 69.02 13.69 55.38 654.84

11 8.29 3/25/2009 17:13 0.05 -2.45 70.86 13.9 57.05 668.37 11.07 8.22 3/25/2009 17:14 0.05 -2.33 76.23 11.89 64.42 682.61 11.05 8.22 3/25/2009 17:15 0.05 -3.36 75.31 12.22 63.35 675.13 11.05 8.23 3/25/2009 17:16 0.05 -4.36 74.61 12.18 62.6 673.35 11.04 8.22 3/25/2009 17:17 0.05 -7.85 75.15 11.97 63.2 672.48 11.01 8.26 3/25/2009 17:18 0.05 -3.9 69.87 9.81 59.93 658.86 11.03 8.25 3/25/2009 17:19 0.06 -1.65 73.81 10.39 63.46 675.18 11.08 8.21 11Trail Ridge Energy CEM Data

March 25, 2009 3/25/2009 17:20 0.04 -4.91 76.46 12.69 63.83 682.78 11.06 8.22 3/25/2009 17:21 0.06 0.14 74.95 11.99 63.01 670.75 11.02 8.25 3/25/2009 17:22 0.06 -0.06 72.09 12.01 60.19 665.24

11 8.27 3/25/2009 17:23 0.05 2.5 73.96 13.3 60.78 672.23 11.03 8.25 3/25/2009 17:24 0.04 2.95 71.57 14.52 57.01 664.22

11 8.28 3/25/2009 17:25 0.06 0.14 71.01 14.88 56.33 662.49 11.03 8.26 3/25/2009 17:26 0.06
3.1 74.84 15.06 59.82 678.32 11.1 8.19 3/25/2009 17:27 0.05 3.71 76.67 16.51 60.46 679.73 11.04 8.23 3/25/2009 17:28 0.05 1.23 74.23 15.85 58.58 671.2 11.02 8.25 3/25/2009 17:29 0.04 3.74 73.31 15.11 58.09 669.63

11 8.27 3/25/2009 17:30 0.05 2.35 73.04 14.29 58.77 667.13 11.03 8.26 3/25/2009 17:31 0.05 2.67 73.51 14.64

59 672.6 11.06 8.22 3/25/2009 17:32 0.04
1.9 76.05 15.57 60.48 673.51 11.02 8.24 3/25/2009 17:33 0.06 4.01 74.49 14.99 59.58 667.14 11.01 8.27 3/25/2009 17:34 0.05 0.41 74.76 14.75 60.05 668.08 11.01 8.27 3/25/2009 17:35 0.06 -2.51 71.63 14.41 57.32 660.22 10.98 8.29 3/25/2009 17:36 0.05 1.77 72.92 15.31 57.51 669.89 11.07 8.22 3/25/2009 17:37 0.05 -0.01 75.35 15.52 59.87 672.24 11.04 8.23 3/25/2009 17:38 0.05 2.51 75.79 16.27 59.51 674.04 11.04 8.23 3/25/2009 17:39 0.06 -1.68 75.78 14.71

61 670.68 11.02 8.25 3/25/2009 17:40 0.06 -2.12 72.81 14.66 58.27 665.83

11 8.27 3/25/2009 17:41 0.05 -3.92 75.31 15.09 60.26 670.73

11 8.27 3/25/2009 17:42 0.04 -1.44 73.02 15.29 57.93 667.27

ii 8.27 3/25/2009 17:43 0.04 -2.59 70.35 13.2] 57.19 657.98 11.04 8.26 3/25/2009 17:44 0.06 -1.52 75.32 16.16 59.35 683.37 11.07
8.2 3/25/2009 17:45 0.05 -0.31 74.76 15.85 58.9 651.54 10.9 8.21 3/25/2009 17:46 0.05 4.03 34.53

10 24.47 49.16 12.49 1.76 3/25/2009 17:47 0.05 1.46 18.19 4.18 13.95 5.14 13.56 0.17 3/25/2009 17:48 0.05 -5.78 13.24 3.21 10.22 4.88 13.55 0.01 3/25/2009 17:49 0.05
1.4 8.79 2.04 6.92 5.25 2.74 6.06 3/25/2009 17:50 0.05 2.11 6,12 1.34 4.72 5.74 0.16 8.16 3/25/2009 17:51 0.06 0.75 4.56 1.32 3.25 5.23
0.1 8.28 3/25/2009 17:52 0.05 3.65 3.63 1.31 2.33 5.33 0.07 8.21 3/25/2009 17:53 0.04 -2.86
6.4 1.85 5.13 38.75 0.35 1.25 3/25/2009 17:54 0.06 5.2 59.35 21.28 38.6 634.62 10.01 7.04 3/25/2009 17:55 0.05 2.17 59.02 14.96 44.14 662.39 10.92 8.18 3/25/2009 17:56 0.04 -2.99 62.04 15.74 46.43 662.59 10.98 8.23 3/25/2009 17:57 0.06 4.03 70.87 20.19 50.64 675.44 10.99 8.25 3/25/2009 17:58 0.05 3.07 72.68 23.15 49.5 673.85 11.03 8.22 3/25/2009 17:59 0.05 0.61 77.63 25.14 52.47 679.4 11.02 8.22 3/25/2009 18:00 0.05 -2.27 72.67 23.2 49.53 661 10.97 8.28 3/25/2009 18:01 0.04 -0.35 74.5 24.12 50.53 666.59 10.99 8.27 3/25/2009 18:02 0.05 2.15 72.99 23.75 49.21 663.25 11.05 8.22 3/25/2009 18:03 0.05 2.26 77.59 25.18 52.36 678.12 11.04 8.22 3/25/2009 18:04 0.05 0.99 78.46 22.85 55.75 676.74 11.04 8.23 3/25/2009 18:05 0.05 1.15 77.84 20.47 57.51 668.02 11.02 8.24 3/25/2009 18:06 0.05 -0.42 73.45 18.81 54.66 667.03 11.01 8.26 3/25/2009 18:07 0.05 0.78 75.54 18.74 56.77 666.78 11.01 8.26 3/25/2009 18:08 0.04 -0.48 74.25 17.47 56.98 672.52 11.04 8.23 3/25/2009 18:09 0.06 1.14 75.23 16.5 58.6 672.46 11.04 8.24 3/25/2009 18:10 0.05 1.82 75.88 16.33 59.59 670.19 11.01 8.26 3/25/2009 18:11 0.04 3.89 74.29 15.88 58.61 666.14 11.03 8.25 3/25/2009 18:12 0.06 1.43 74.02 15.27 58.8 669.06 11.07 8.22 3/25/2009 18:13 0.05 -0.8 77.25 14.9 62.31 676.78 11.06 8.21 3/25/2009 18:14 0.05 0.06 77.08 14.87 62.25 674.31 11.04 8.23 3/25/2009 18:15 0.05 0.65 76.12 14.58 61.5 672.54 11.03 8.24 3/25/2009 18:16 0.05 3.42 75.38 13.71 61.63 665.98 11.02 8.25 3/25/2009 18:17 0.06 4.3 75.73 15.28 60.4 669.84 11.02 8.26 3/25/2009 18:18 0.04 -2.63 75.24 16.61 58.58 666.22 11.02 8.25 3/25/2009 18:19 0.05 -0.96 75.75 16.94 59.01 665.91 11.01 8.27 3/25/2009 18:20 0.05 1.56 72.69 16.78 55.87 659.84 11.01 8.27 12Trail Ridge Energy CEM Data

March 25, 2009 3/25/2009 18:21 0.05 -1.43 73.26 17.41 55.88 666.54 11.08 8.22 3/25/2009 18:22 0.05 -2.91 76.06 18,61 57.39 675.52 11.04 8.23 3/25/2009 18:23 0.05 -2.18 72.73 16.39 56.46 665.87 11.01 8.26 3/25/2009 18:24 0.05 -2.77 73.97 15.76 58.06 670.17 11.02 8.26 3/25/2009 18:25 0.06 -0.34 58.09 20.42 42.25 673.67 11.07 8.22 3/25/2009 18:26 0.06 8.42 13.04 12.62 10.64 672.69 11.05 8.23 3/25/2009 18:27 0.07 10.44 4.72 5.39 4.68 667.4 11.01 8.27 3/25/2009 18:28 0.05 3.02 4.13 3.24 3.08 669.11 11.01 8.27 3/25/2009 18:29 0.05 -5.36 2.78 2.79 2.12 667.13 11.03 8.26 3/25/2009 18:30 0,05 -5.92 1.95 2.88 1.72 670,95 11.06 8.23 3/25/2009 18:31 0.04 -6.28 1.76 2.66 1.55 673.22 11.09
8.2 3/25/2009 18:32 0,06 8,31 0.49 1.86 1.78 673.45 11.04 8.24 3/25/2009 18:33 0.06 9.41 0.72 1.61 1.78 665.65 11.01 8.27 3/25/2009 18:34 0.05 5.33 -0.03 1.91
1.4 674 11.03 8.25 3/25/2009 18:35 0,04 -4.65 1.12 1.97 1.54 669.58 11.01 8.26 3/25/2009 18:36 0.06 -1.43 0.62 1.93 1.68 667.14

11 8.29 3/25/2009 18:37 0,04 2.7 0.8 1.85 1.52 666.25 11.03 8.26 3/25/2009 18:38 0.06 0.01 1.79 1.57 2.13 668.17 11.07 8.21 3/25/2009 18:39 0.04 2.93 1.54 1.74 1.61 674.32 11.03 8.24 3/25/2009 18:40 0.05 -3.55 0.51 2.34 1.28 675.19 11.04 8.23 3/25/2009 18:41 0.05 -3.15 -0.37 2.16
1.5 675.66 11.06 8.22 3/25/2009 18:42 0.06 -2.4 -0.01 1.72 1.58 675.85 11.09 8.19 3/25/2009 18:43 0.05 3.08 0.88 1.82 1.65 678.09 11.04 8.23 3/25/2009 18:44 0.05 2.54 0,47 1.98 1.48 672.38 11.02 8.25 3/25/2009 18:45 0,05 -2.62 -0.52 1,87 1.37 671.19 11.01 8.26 3/25/2009 18:46 0.05 -0.48 1.05 1.48 2.04 663.57 10.99 8.28 3/25/2009 18:47 0,04 7.4 1.43 1.68 1.55 663.59 11.05 8.25 3/25/2009 18:48 0.05 4.89 1.28 1.56 1.66 679.67 11.07
8.2 3/25/2009 18:49 0.05 2.35 0.87 l.59 1.68 672.27 11.03 8.24 3/25/2009 18:50 0.04 1.04 -0.59
2.1 1.23 672.29 11.04 8.24 3/25/2009 18:51 0.04 2.22 -0.84

2 1.15 670.33 11.02 8.25 3/25/2009 18:52 0.05 0.02 -0.84 1.96 1.21 664.67

11 8.27 3/25/2009 18:53 0.05 -1.58 -0.36 1.71 1.38 664.68 11.06 8.23 3/25/2009 18:54 0.05 3.43 1.88 1.33 1.97 681.06 11.07
8.2 3/25/2009 18:55 0.05 -0.26 0.82 1.62 1.54 675.88 11.04 8.23 3/25/2009 18:56 0.05 4.71 0.49 1.65
1.4 674.82 11.04 8.23 3/25/2009 18:57 0.06 1.82 1.03 1.47 1.66 671.35 11.03 8.24 3/25/2009 18:58 0.05 1.94 0.26 1.71 1.41 662.78 11.03 8.26 3/25/2009 18:59 0.05 2.98 0.41 1.73 1.49 675.18 11.05 8.23 3/25/2009 19:00 0.05 2.9 0.89 1.73 1.55 675.92 11.05 8.23 3/25/2009 19:01 0.05 2.69 0.42 1.78 1.46 678.11 11.09
8.2 3/25/2009 19:02 0.05
3.3 0.68 1.74 1.51 674.l6 11.05 8.22 3/25/2009 19:03 0.05 2.35 0.82 1.69 1.52 668.25 11.04 8.24 3/25/2009 19:04 0.06 1.23 0.64 1.65 1.45 472.92 10.31 6.66 3/25/2009 19:05 0.05 2.15 0.71 1.69
1.5 6.9 13.45 0.48 3/25/2009 19:06 0.05 -2.87 0.66 1.53 1.21 4.43 13.56 0.06 3/25/2009 19:07 0.05 -1.51 0.47 1.53 1.21 4.23 13.57 0.01 3/25/2009 19:08 0.04

-1 0.6 1.61 1.34 3.81 13.58 0.01 3/25/2009 19:09 0.04 2.03 0.81 1.56 1.45 13.76 6.93 3.79 3/25/2009 19:10 0.06 6.47 1.54 1.39 1.59 4.54 0.21 8.09 3/25/2009 19:11 0.05 -0.07 1.26 1.55 1.28 4.1 0.13 8.27 3/25/2009 19:12 0.06 -1.03

0 1.65 1.65 4.06 0.09 8.32 3/25/2009 19:13 0.05 3.91 0.56 1.79 1.41 3.86 0.06 8.33 13Derenzo and Associates, Inc. USEPA Method

2 Gas Velocity Measurement Data Sheet Company Source Designation Test Date Test Number Time (24-hr clock) Barometric Press. (in. Hg) Static Pressure (in. H 2 0) jci 1F1 ?ceii

No. of Points Operator(s) Pitot Type Pitot Identification °2 Content (%) CO 2 Content (%) Wet Bulb Temp. Sr Standard Inches from Stack Wall Traverse Poini stacK Temperature Velocity Head Number
(°F) (in. H 2 0) Null Angel (zero angle)

- cj’

/ ,7L2

Z yf ci..cL1

3 /2L.H

1-I
3Lf’ 7:7tL

5 5?9 .6 (
32. : (çL) -zz çc:;

3 5 7
‘30 Stack

/ Duct Measurements A= Sample Ports r= zi.—L.j L L\ ‘,1;1)....

‘7 677 t 3,o z 3 c) L4 c-S’f ZZ C) QIL2

- x Round Duct Dia. (D) Square Duct (LxW) Square DuctDia. (De): De = 2LW

/ (L+W) Straight Length: (diameters) (., -zi

AID B/D Traverse Point 0.5

1

1.5

2

2.5 I

I 24 or 25 p:ateil2

No. of Traverse Points Per Dia. 6

8
10
12 4.4 14.6 29.6 70.4 85.4 9 5 2 3 4 5 6 7 8 9 10 II 12

3.2 10.5 19.4 32.2 67.7 80.6 89.5 96.8 B a- Higher No. for rectanguar stacks b- For stacks between
12 and 24 in.

2.6 8.2 14.6 22.6 34.2 65.8 77.4 85.4 91.8 I

2.1 6.7 11.8 17.7 25.0 35.6 64.4 75.0 82.3 88.2 93.3 97 9 97.Derenzo and Associates, Inc. USEPA Method

2 Gas Velocity Measurement Data Sheet Traverse Point 2 3 4 ) 6 7 8 9 10 11 12 BID No. of Traverse Points Per Dia. 6

8 10

12 4.4 3.2 2.6 14.6 10.5

8 2 29.6 194 14.6 704 322 22.6 85.4 67.7 34 2 96.5 80.6 65.8 89.5 77.4 85.4 F-:;
974
2.1 6.7 11.8 17.7 25.0 35.6 64.4 75.0 82.3 81.2 93.3 97.9 Company Source Designation TestDate

/

/ , Test Number -ppj Time (24-hr clock)

. LI 5 Baromet± Press. (in. Hg) Static Pressure (in. H,O)

,

-rsj )v) No. of Points Operator(s) Pitot Type Pitot Identification °2 Content (%) CO 2 Content (%) Wet Bulb Temp. Inches from Stack Wall

Standard Traverse Point Number Stack Temperature Velocity Head Null Angel (°F) (in. H 2 0) (zero angle) Stack

/ Duct Measurements I

.3 2- cgJ .(O
Z .3 c-Z 3(1-) C)—

9 WI’ •3A

3 6 O. 5—

M- :::

I
.z

5 —

2- —

3

cD—-

9. 35

5- S (1:,

Sample Ports Round Duct Dia. (D)___________ Square Duct (LxW)_____
x Square Duct Dia. (De):_____ De=2LW/(L+W) Straight Length:

A / D (diameters) A 1

1.5

2 0.5

2.5 I

I

I

I

I 24 or 25
If--

8 or 9 I

I

I 2

3

4

5

6

7

8

9
10 B a- Higher No. for rectanguar stacks b-

I or stacks hetween
12 and 24 in.Dercnzo and Associates, Inc. USEPA Method

2 Gas Velocity Measurement Data Sheet Company Source Designation Test Date Test Number Time (24-hr clock) Barometric Press. (in. Hg) Static Pressure (in. H 2 0) ‘r; icae_. 3/25 ic)9 Pcsf (/7’ieZ 6

7

8 B

No. of Points Operator(s) Pitot Type Pitot Identification 02 Content (%) CO 2 Content (%) Wet Bulb Temp. Traverse Point 2 3 4 5 6 7 8 9 10 11 12

I ‘S /r>vi (:E:)
or Standard BID No. of Traverse Points Per Dia. 6

8
10
12 4.4 3.2 2.6 14.6 20 5 8.2 296 19.4 146 704 322 226 85.4 67.7 342 96.5 80.6 65.8 89.5 774 968 854
2.1 6.7 11.8 17.7 25.0 35.6 64.4 75.0 82.3 88.2 93.3 97.9 Inches from Stack Wall Traverse Poini Number

Stack Temperature (°F) Velocity Head (in. H 2 0) Null Angel (zero angle) z —

. 3 I L .; I 2.O z

2 <glç —

. L
3,4/ — :::

3,3
Stack

I Duct Measurements Sample Ports Round Duct Dia. (D)__________________ Square Duct (LxW)

x Square Duct Dia. (De):__________________ De2LW/(L+W) Straight Length:

A I D (diameters) 0.5

A 1

1.5

2 I

I

I

I

I 24 or 25 12

8 or 9’ I

I

I 2

3

4

5

9 a- Higher No. for rectanguar stacks b- For stacks between
12 and 24 in.

2.5 10Derenzo and Associates, Inc. USEPA Method

2 Gas Velocity Measurement Data Sheet Company Source Designation Test Date Test Number Time (24-hr clock) Barometric Press. (in. Hg) Static Pressure (in. 1-170) .3 L 1 c ‘, .) q -Iz 1g9 Pct 7Pe ii: Velocity Head Null Angel (in. H 2 0) (zero angle) 13cD a’: c’Z

? I ZA 77Q q5 c-7 Y7

...-) -‘. .,‘ 5

No. of Points Operator(s) Pitot Type Pitot Identification 02 Content (%) CO 2 Content (%) Wet Bulb Temp. Traverse Point 2 3 4 5 6 7 8 9 10 II 12 BID No. of Traverse Points Per Dia. 6

8
10
12 4:4 3.2 2.6 14.6 10.5 8.2 29.6 19.4 14.6 70.4 32.2 22.6 85.4 67.7 34.2 96.5 80.6 65.8 89.5 77.4 96.8 85.4 91.8 i-i •7 1 S Inches from Stack Wall

(rp)or Standard Traverse Point Number Stack Temperature (°F) I ci 2 f7q ji z_

Stack

/ Duct Measurements {A= Sample Ports .-—-----.---—-

— -3 .3 Round Duct Dia. (D)__________________ Square Duct (LxW)

x Square Duct Dia. (De):_____ De=2LW/(L+W) Straight Length:

A / D (diameters) 0.5

A 1

1.5

2

2.5 I

I.

I 24or25

16

8 or 9’ I

I

I

I

I 2

3

4

5

6

7

8

9
10 B a- Higher No. for rectanguar stacks b-For stacks between
12 and 24 in.

2.1 6.7 11.8 17.7 25.0 35.6 64.4 75.0 82.3 88.2 93.3 97.9Derenzo and Associates, Inc. 0.5
1

Traverse Point 2 3 4 5 6 7 8 9 10 11 12 BID fTo. Of Traverse Points Per Dia. 6

8
10
12 4.4 3.2 26 146 10.5 82 296 194 146 70.4 32 2 22.6 85.4 67 7 34.2 965 806 65.8 89.5 77.4 96.8 854 918 974
2.1 6.7 11.8 17.7 25.0 35.6 64.4 75.0 82.3 88.2 93.3 97.9 US EPA Method

2 Gas Velocity Measurement Data Sheet — /4ic T)(dtçc’ Company Source Designation Test Date Test Number Time (24-hr clock) Barometric Press. (in. Hg) Static Pressure (in. f1 2 0)

3 I 2S

/ C) iy 3/P’€

4

No. ofPoints

JZ 77

73Jc) Inches from Stack Wall
Operator(s) Pitot Type Pitot Identification 02 Content (%) CO 2 Content (%) Wet Bulb Temp. Standard Traverse Point Number Stack Temperature Velocity Head Null Angel (°F) (in. H 2 0) (zero angle) Stack

/ Duct Measurements I 7•7_____
3.1-—

3..—-.

I 75—

Lt —

5 c’

[A= Sample Ports Round Duct Dia. (D)

x Square Duct (LxW)_____ Square Duct Dia. (De):_____ De = 2LW

/ (L+W) Straight Length:

A I D (diameters) A I

1.5 24 or 25

16 Non-particulate

12
2.5 8or9 I

I

I

I

I 2

3

4

5

6

7

8

9
10 B a- Higher No. for rectanguar stacks b- For stacks betv.’eeii
12 and 24 in.Derenzo and Associates, Inc.
US EPA Method

2 Gas Velocity Measurement Data Sheet Company Source Designation Test Date Test Number Time (24-hr clock) Barometric Press. (in. Hg) Static Pressure (in. 1120) 7, 6, Inches from Traverse Poini Stack Wall Number q 5 cj7 , ( .7 7Lç 77 c479 U c L

A 1.5 3

4

5

6 a- Higher No. for rectanguar stacks h For stacks hetwean

1 2 acd 24 in.
Stack! Duct Measurements Traverse Point 2 3 4 5 6 7 8 9 10 11 12 BID No. of Traverse Points Per Dia. 6

8
10
12 4.4 3.2 2.6 14.6 10.5 8.2 29.6 19.4 14.6 70.4 32.2 22.6 85.4 67.7 34.2 96.5 80.6 65.8 89.5 77.4 i- 96.8 85.4 91.8 97.1 rc;/ ‘V:dae ‘ 0 q L /7-

No. of Points

I Z Operator(s)

73 /72)Lj Pitot Type StandardPitotIdentification_____________________ °2 Content (%) CO 2 Content (%) Wet Bulb Temp. Stack Temperature (°F) Velocity Head Null Angel (in. 1120) (zero angle)—
c-7 —..o z 75 3J3—-. .33 3,4 .2,-7-

h. iic 3rt1 7z 3*-

Sample Ports .5 3,- 3’ 3,5 r79

.3 3, Round Duct Dia. (D)_________ Squate Duct (LxW)

x 0.5

Square DuctDia. (De):________________ De=2LW/(L+W) StraightLength; AID (diameters) 2

2.5 I

I

I

I

I 24 or 25 16 Non-particulate

12 8 or 9’’ 9
10 2

7 B

8

2.1 6.7 11.8 17.7 25.0 35.6 64.4 75.0 82.3 88.2 93.3 97.9Dereiizo and Associates, Inc. USEPA Method

2 Gas Velocity iVleasurement Data Sheet Company Source Designation Test Date Test Number Time (24-hr clock) Barometric Press. (in. Hg) Static Pressure (in. H 7 O)

No. of Points Operator(s) Pitot Type Pitot Identification °2 Content (%) CO 2 Content (%) Wet Bulb Temp. Stack Inches from Traverse Point Temperature Velocity Head Stack Wall Number (°F) (in. H 2 0) Round Duct Dia. (D) Square Duct (LxW)

x Square Duct Dia. (Be):_____ Be = 2LW

I (L+W) Straight Length:

A / B (diameters) BID 2 3 4 ) 6 7 8 9 1(1 11 12

4.4 32 26 14.6 105 82 296 194 146 704 322 226 854 677 342 965 806 658 89.5 77.4 96 8 85.4 91 8 97t 2.1 6.7 11.8 172 25.0 35.6 64.4 75.0 82.3 88.2 93.3 97.9 I

C, /25/9 ?r5/Pre(, /7/5

12 —7-)’;

I —

rpor Standard 5F Null Angel Stack

I Duct Measurements (zero angle)

A 1 ‘77 -_-*___

. 77

3 — 47I:7 z 79 3,4 . z__

q 76—-
173

Sample Ports 0.5

A
Traverse 1

1,5

2

2.5 Point I

I

I

I 24 cr25’

20
16 Non-particulate

12 8 or9b I

I 2

3

4

5

6

7

8

9
10

No. of Traverse Points Per Dia. 6

8
10 ._2 a a- Higher No. for rectanguar stacks h- For stacks between
12 and 24 itt.flerenzo and Associates, Inc. USEPA Method

2 Gas Velocity IVleasurernent Data Sheet Company Source Designation Test Date Test Number Time (24-br clock) Barometric Press. (in. Hg) Static Pressure (in. 1-120) 3/c5

No. of Points Operator(s) Pitot Type Pitot Identification °2 Content (%) CO 2 Content (%) Wet Bulb Temp. Round Duct Dia. (B)__________________ Square Duct (LxW)

x Square Duct Dia. (Be): Dc = 2LW

/ (L+W) Straight Length:

A I D (diameters) BID 4.4 3.2 26 146 .105 82 296 194 1’6 704 322 226 854 677 342 965 806 658 89.5 77.4 :>—; 96.8 854 918
2.1 6.7 11.8 17.7 25.0 35.6 64.4 75.0 82.3 88.2 93-3 97.9 1,,L- /_,7_

/t --. /q. 7.o

/2 or Standard Inches from Traverse Point Stack Wall Number Stack Temperature Velocity Head Null Angel (°F) (in. H 2 0) (zero angle) Stack

I Duct Measurements—

I 2 :z. Lk Z__

S 7c3,q—-- z—-- D 73 —_

2.- 3-’t 7t q .3 L -?‘l 73t .—_—z____

S 76 4 2 t3. C 73 73

Sample Ports EZZZ A

Traverse No. of Traverse Points Per Dia. Point

6

8
10
12 2 3 4 a 6 7 8 9 10 11 12 B a- Higher No for rectanguar stacks For stacks etwesu

2 and 24 in.G ‘J +

. p + C z p

II Ii 0’ 

# L z 

# H

C W r

, ., C

I I E B q BDererizo and Associates, Inc. Sample Recovery and Data Integrity Form Company Source Designation Sample Recovery Person

i 2 Acp Sample Date Run Number Recovery Date 3/z5 /o9 Tp..-

I 3iZ5/9 Exhaust Gas Composition % CO, Moisture Total Moisture Gain: Impingers
Silica gel
Total Description
of silica gel_______ Description
of irnpinger solution Recovered Sample Filter container number Description
of particulate

Sealed? Back half rinse container number Front half rinse container number_____ Liquid level marked- Liquid level marked Samples stored and locked

- Remarks_______________ Blank filter container no. Blanck PH rinse container no. Blank BH rinse container no. Blank reagent container no. Date of laboratory custody

— Remarks

Blanks

4 Method Used: Fyrite Orsat flO2 ECOH Impinger

1st
2 nd

3 rd

4 th

6 th Silica gel Final 77 mUg 709 J (ã-:,

mUg Initial (g7, 7 mug ?Oimug 7pL[3Jg

mug
mUg
mug Net Gain ,

mu 1 (, mu
mUg
mUg
mug

## -ofl

r I 

# El [I

I I I I I I I

— — + +

n 0 z +Dererizo and Associates, Inc. Sample Recovery and Data Integrity Form Company Source Designation Sample Recovery Person r- 21 i c 1 -i I

I” ic Lj Sample Date Run Number Recovery Date 3J2S/p’? 3/zs /o7 Exhaust Gas Composition Method Used: Fyrite Orsat

% CO 2 Moisture Total Moisture Gain: Impingcrs 1j Silica gel.

7 Total Description
of silica gel_______ Description

of iinpinger solution Recovered Sample Filter container number Description
of particulate

Sealed? Back half rinse container number Front half rinse container number Samples stored and lockedRemarks____________________ Blank filter container no. Blanck FH rinse container no. Blank BH rinse container no. Blank reagent container no. Date of laboratory custody Blanks

- Liquid level marked Liquid level marked Net Gain ‘7t( rLfg Impinger

1 5t
2

3 rd

4 th

5 th

6 th Silica gel Fm 77 mUg 710
3 m 7j

mUg Initial 7oo mUg
mig 7 oO .mJJg

mug
mUg
mUg 2J mug
mUg
mI_Jg
mug Remarks5”

fl ‘-a

a a a a a a I ‘‘—
+ C-) 0Dererizo and Associates, Inc. Sample Recovery and Data Integrity Form Company Source Designation Sample Recovery Person Ce-ri

4 J Sample Date Run Number Recovery Date

3/2-5 /g9 g3 Exhaust Gas Composition Method Used: Fyrite Orsat

or r’ /o_,

) Moisture Description
of silica gel______ Description
of irupinger solution Recovered Sample Filter container number Description
of particulate

Sealed? Back half rinse container number Front half rinse container number

Liquid level marked - Liquid level marked Samples stored and locked Remarks_________________ Blank filter container no. Blanck FH rinse container no. Blank BH rinse container no. B lank reagent container no. Date of laboratory custody Blanks Total Moisture Gain: irnpingers’
Silica ge1[\ L Total Remarks

# IsaIdneIje Field Sampling Data Sheet



# Pon

— 

# Pbar+ (H@/t36)

= 

# Phar + 

# (Potol/l36) Md

— 

# Ms

— 

# (Md)(l-(n 5 ,l OO))+lS(Sws/lQO) (VWC+VWO

6 )/(VWC+V+V) 

# Vwc

= 

# O. 0 4706(Vf_vj) 

# Vwsg OS4?lS(Wf-wj Coispairy 

# TestDale Tent Number Operator FitterNumbers Bar. Press (Pb) StatiePSess (Pa) Slack Di (hi,) Lash flteFired 

# (2

Mf 5 (TovTs) * 

# (dP) 

# MI— 846.72 ° 

# (Da°4)

Mf 

# Note: All tensperatuaes arc *R(*F+460) (H@) * 

# (Cp’2) ((l-(BwsIloo))e2) (Md/Lis) Mf 846.72 (Ps/Pin) (IC 

# () 5,0) 

# *(_

Nozzle 0 50ernsaoutjou. 4 

# H@ / Kisa*(cp)02* 0 .(BwsIlOO))e2*(Md/M)*(PSJ 

# (l°,ecoonrncndmaltiplyong calculate nozzle size by 5%) Do 

# 5(55= Yc— (lChVnt)*((oo519*(Tm))/pb)sg5



# DERENZO AND 

# ASSOCIATES, INC.Dererizo and Associates, Inc. Sample Recovery and Data Integrity Form Company Source Designation Sample Recovery Person

Sample Date Run Number Recovery Date 77?/rHCL

- 3iZ..S/ Exhaust Gas Composition of r /OL Moisture Initial ( 1 ,qq Jg Total Moisture Gain: (q/.3ig(,;o3;)

mUg inipingers Jf\s rnugq/,D mU[ rv I otaI Description
of silica gel_______ Description
of Impinger solution

- Recovered Sample Filter container number Description
of particulate

Sealed? Back half rinse container number Front half rinse container number Samples stored and locked Remarks_____________________ Blank ifiter container no. Blanck FH rinse container no. Blank BH rinse container no. Blank reagent container no. Date of laboratory custody_____ Remarks

Blanks

- Liquid level marked Liquid level marked Method Used: Fyrite Orsat

%O2J FCO npinger

I le
2 0d

3 rd

4 th

5 th

6 th Silica gel [Final 7 gjg 7Q 1 qrniig /,
/ mug

mUg
mug Zg \\\mUg
,\ mU m mUg
mUg Silica gel(

# Inokinelic Field Sompling Dots Sheet

Mf= 846.72’ (Dn4) * 

# (H@) (C2) 

# ((l-(Bws/loo)y 2 ) * 

# (Md’Ms) (Ps/Pin) 

# Mf=846.72 (tlj ‘(_2.2 LL1J_.J *

# LfL.jMf

# 3.%

NozzleDcleimjnoiion: 4 

# H@ / Kiso’(cpy2’(l.(8w 5 /l 

# OO)Y’ 2 ’(Md/Mo)*(Ps/Pm)*ç1’pJr

5 ). shP(, 0 (Recommend multiplying calculatenozzle

# sizeby5%) Do ‘I.05 Pm. Pbnr+(Hl36) Pn Pboe+(Pntnl/l3b) Md

— 

# O.44(%CQ2)fo32(%)+o2s(%N t’Co Ms (Md)(t-(flws/loo))÷lS(Bwu/l00) 

# Bws

— 

# (VWC+Vwsg)/(vwc+vwsg+vm) Vwc 

# O.O 4 7Q6(vfvl) Vwsg

— 

# O.O 4 7l5(Wf.\vi) 

# 3

# o 1 &
Nate: All lemperatores oreR (‘F+460) Yc— (lOfVm)’((003l9’(Tm))/pbyo5



# DERENZO AND ASSOCIATES INC.Derenzo and Associates, Inc. Sample Recovery and Data Integrity Form /‘d e

9 /L -z 3/5/o Exhaust Gas Composition Method Used: Fyrite Orsat

% CO 2 Moisture

0/ /0

2

% CO Inapinger

2’

3 rd

4 th

5 th

6 th Silica gel Final 77t’frsJg 747/ mL!g

Ug
mUg
mUg
mUg Initial

mJJg ( $r1ig (‘oq 1 mUg
mUg
mIJg
mUg NetGain

g mUg kUg

mUg
mUg
mUg Total Moisture Gaii: Impingers

[ \ ____I siiicagei

Total Description
of silica gel Description
of impinger solution Filter container number Description
of particulate Back half rinse container number Front half rinse container number Recovered Sample Sealed? - Liquid level marked- Liquid level marked Samples stored and locked— Remarks Blank filter container no. Blanck FH rinse container no. Blank BH rinse container no. B lank reagent container no. Date of laboratory custody Blanks Company Source Designation Sample Recovery Person

Sample Date Run Number Recovery Date Remarks

# Company Field Sampling Data Sheet

Tot Date 

# TestNunther Operator FillerNumber 0 Oar. Freon (Pb) Static Press (Ps) StoebDin 

# (to.)

ITein 1 t. Probe Filter13os Leo mop. toter 

# G Oatiel7 Trim, 1 5 

# Temp 

# 35 Trio 1 ,.



# Mfa (Tmns) (P) Note: 

# AU temperatemmore 5 R (‘F+460) Yc— (l0Nm)s((OO319sm))b) 5 

# Mf046.72 * 

# (0004) * 

# (M!@) * 

# (Cp 0 2) ((l-(Bws/loo)y2) (MW14 5 ) (Ps/Pm) Mf= 846.72 * ,‘ 

# s 

# ( • ( * 

# Pm

— 

# Pbor+ (H@/l3.6)

— 

# Pbur + 

# (Pstat/l3.6) Md

— 

# Ms

— 

# (Md)(l-(fl 5 ,j 00+j S(Bws/lOO) Nozzto Detemsmtm,aal,on Owl 

# (Vwc+Vwsg)/(Vwc+v+v) H@ / Ktso*(Cp)02.()(Bws/) OO 0 2(Md/1 5 )5( 5(,_n Vwc 0

# 4706(Vfv(( (Recoom.nieadmulliplytog calculatenozzle sizeby5%) On t.05= Vwog 0.0471 

# 5(Wf-W 1 ) 

# DERENZO AND ASSOCIATES, INC.Derenzo anti Associates, Inc. Sample Recovery and Data Integrity Form Company
Ic

j jc€ Sample Date 3/2 5/o9 Source Designation __________________________

Run Number

3 Sample Recovery Person __________________________ Recovery Date_______________ Exhaust Gas Composition Method Used:

r

% O

% COFyriteOrsat

[

]____________ Moisture pinger

l
nd

3 rd

6 th Silica gel [Final 7f mg ?SA al 7033mug t9Zrnvg c,oq/mug

mUg [Gain

mvg (‘mLIg \ mUg
mUg
mUg
mUg Total Moisture Gain: Impingers
Silica gel Total Description
of silica gel _______________________________________________ Description
of impinge: saiu:ioe. Recovered Sample Filter container number

Sealed? Description

of particulate _______________________________________________________ Back half rinse container number _________________________Liquid

level marked Front half rinse container number _________________________Liquid

level marked Samples stored and locked Remarks

Blanks Blank filter container no. Blanck FH rinse container no. Blank BH rinse container no. Blank reagent container no. Date of laboratory custody — Remarks2C?‘7’I-‘2.0Pagejofj‘(2,c2’70,,‘:20L.c2cc,iO,L(:3-cI_______(:(72ft7(a.çNotesCmTIoNSLy—-1‘:/ICylinderAnaleConcentrationUit/—2c-c,cICC‘_________________L________________[ugh,Mid,Low,Zero,forCH4,NMOC,THC___________________IEIRunHigh,Mid,Low(Zero)InstCal,andMid,ZeroDynamicCal-M’ei-4t---/$zforNOx,°2,CC,C02,SO2_____________________TimeProcedureResponseExp.ValueM205DividerCertification2Inst100%II(3(60%—12-,25(540%-.f8-o__________________0%C9c,(_________ioO2Lc(3260%_i2..C.(3_______(3)40%—C_____________________0%_______35Q100%_2,’D3‘-_______________________—60%______(2.—40%_____-C)(C)____________________j_02Instmid_g5Mustbewithin10%ofoneoftheabovecuts_________zero0(Zmid_La3I5________________________zero/C)LL7__mid(5AnalyzerCalibrationErrorIns_lgc(C_f5c5zero-(2..CO2Insthigh(•ç(73:5_______________________mid((.(________________zero_________OInsthighCa’zocp_____________________mid________(5-—zero/52NOxInst87(7__________________r1—ResponseTimes(see)SystemBias/Pre-StratificationCOupscale:(3C)3(5i’(I_yn_pscaleJc4o.@9JMustbeclosesttostackconcentration4COdownsca1er5af2q./,q‘_______downscale—CO2upscale:I5cf12t,-•5q3fLijP2Dynupscale,‘-52.5(CO2downsca1e;i5qq(2________________________________________________________downscaie02Upscale5’($_______________________________Stratificationprobelengths(m)[xUsc:7Eupscaijf_______________________N[OxDownscae:(,________________________________downscaleConcentrationdirectinstramentreadingCalibrationErroriC-C)/CSx100(mustbe<2%)Cv=ConcentrationvalueCs=ConcentrationofsystemInitialSystemBias(SB)=(C5-C)/CS*100(mustbe<5%)CS=CalibrationSpanSBf=SystemBiasfmalSBi=SystemBiasinitialc3.c(CalibrationDrift=(SB-SBi)(mustbe<3%)TimeProcedure(7(C(CODynmidzero(—7çz..CODynmidzeroO2Dynmidzero({7INOxDynmidL2-IzeroCdir=ConcentrationdirectinstrumentreadingCv=ConcentrationvalueCs=ConcentrationofsysteniCS=CalibrationSpanSBf=SystemBiasfmalSBi=SystemBiasinitialCALIBRATIONSUMMARYCylinderIDCompany:(g’,:i-Location:SourceDesignation:Date:perator(s):Pre1:RunHigh,Mid,Low,Zero,forCE4,NMOC,THCRunHigh,Mid,Low(Zero)InstCal,andMid,ZeroDynamicCalforNOx,02,CC,C02,SO2AnalyteConcentrationPage2ofUnit€c(CO0(7f,1C,ee*C0a.cd.:Q’t..2ocq(/c(frjJC2((7//.i—B(u’M44Ig-y-(t(-qzyo4RespnseExp.ValuePostStratificationCalibrationIS7t’(009.(i70-acNotes/3.5/____________________From:-0.0K2zI____NOxConverterTestNOxConverterPost-CalibrationI-H’To:J_4.O7H9.3HMustbeclosesttobagNOxhighvalueIO-o9I-I(0f9CalibrationErrorpre-test(Instrument)/‘.5-2,.oo0.o•9g--?,5’/o(7Mustbe100-20%ofsuckconcention/,(0-2Mustbeclosesttostackconcentration0.0(3.5.(i-C?.0.992.-Analyzer____________COInsthigh_______mid______zero________2.3COInsthigh________mid_____zero°2Insthigh_________çc________zero(>.O/________‘3NOxInsthigh25(.o3G.nidzeroSystemBiasCalibrationpre-test(dyn(p’52-CODynupscalet’02S90cf.-downscale0..‘(5CODynupscalef?.3(3,52-773doscale0.0•70502Dynupscale25270___________downscale-2-0,0.?c’9NOxDynupscale______________72.downscalePppieDynhigh______________mid_____________—low-io9____________7IMethaneDynhigh__________73,mid_____Z7(C)low__________________zeroimiccalibration)0%—7-7—0-cS(f,5,—zeroo.o9c-a50.(O7G52?3i(?f77Q0CalibrationError(C,-C)/CSx100(mustbe<2%)InitialSystemBias(SB)=(ç-Cd,)/CS*100(mustbe<5%)f2(/c/Z(f2’.Z7cf?.73752-i—CalibrationDrift(SBf-SBi)(mustbe<3%)CALIBRATIONSUMMARYCompany:ILocation:SourceDesignation:Date:2prator(s):Pre1:RunHigh,Mid,Low,Zero,forCl-4,NMOC,THCRunHigh,Mid,Low(Zero)InstCal,andMid,ZeroDynamicCalforNOx,02,CO,C02,SO2Page3of_EL_l5-cc(,c’-,c.7’CO3—c7,t’Oa-•0.èii/r7—Rz7-.7SystemBiasCalibration(dynamiccalibration)I.5-’((3.522ca3.o(O.(()00q-g-etáqhrR.CSystemBiasCalibration(dynamiccalibration)4os(O’/512’?—32.(c-’g—I—2C)co.o—-‘?oc2.7cto723-3O.cS/o?c2q((9-O.aCdir=ConcentrationdirectinstrumentreadingCvConcentrationvalueCsConcentrationofsystemCSCalibrationSpanSBf=SystemBiasfinalSBi=SystemBiasinitialCylinderIDAnalyteConcentrationLUnitSystemBiasCalibration(dynamiccalibration)_________tD/.çNotes____-R:m:523.23TimeProcedureResponseExp.ValueTest1PostTest1r-(CODynupscale-5Q‘.5—downscaleO.r30.Z‘2CO2Dynupscale—13.3(-aStartTime:(1—downscale-C).0QDynupscale—3c)_______If—downscale0(-oINOxDynupscale1t.g(.qc)433downsca(.(c3.(GStopTime:_______‘(F’_Propanemid—____________________zero_ç(MethanemidzeroTest2PostTest2_______CODynupscaleor,jcf.çftcc.(downscale-(Z7;’,c(22Dynupscale_________StartTime:1I(Idownscale_(((v..(O2Dynupscale_j2___________Jj{_downscaleof___________NOxDynupscale________/o-2(?downscale—ö.3_______StopTime:’((zPropanemid4(9—zero-.0‘r______((2CMethanemid/f’C)[.c./,f(972-zeroTest3PostTest3(257CODynupscale_________—downscale/3Dynupscale_______StTime:143(0doscale.-3((02Dynupscale827j3c’3—downscale0.c’((f,(7NOxDynupscale__________(2313(0—downscale_______StopTime:__L3-(Propanemidj36zero(37Methanemid_______zero-1a-s—geCalibrationError=(C-CV)!CSx100(mustbe<2%)InitialSystemBias(SB)(ç-Cdk)/CS*100(mustbe<5%)CalibrationDrift=(SBf-SBI)(mustbe<3%)CALIBRATIONSUMMARyPageofCompany:TCUnitLocation:SourceDesignation:Date:Operator(s):Pre1:RunHigh,Mid,Low,Zero,forCH4,NMOC,THCRunHigh,Mid,Low(Zero)InstrumentCal,andMid,ZeroDynamicCalforNOx,°2,CO,C02,SO2•Test7fJf-(Time:/f’7Time:_/Test7Time:___Time:(7d;Test’34T1’(-ct-3alibrationError(Cj.-C)ICSx100(mustbe<2%)CalibrationDrift(SBf-SBi)(mustbe<3%)nitialSystemBias(SB)’(C-Cdjr)/CS*100(mustbe<5%)C) C) j’.) C) i—i C) P.) N) P.) P1

0 (0 (0 _i 0) o _i C) C)— 0 U) (0- C) C) .P. C) N)- 0



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## co ecooo 0 

# oc dOaO0C’cY

. 

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# DOD 00

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01



# c 0 cDo0i 0) —I 0 --1 

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## - 0) C) .0- C.) N)- 0 CD CC) —J C)) CCI .0. (.3 C)- C) CD 0) -.) (3) (.31 0- C) N)- 

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# SOURCENAME 

# -7A/ 

# SOURCE IDNUMBER 

# ce_ PROCESS EQUIPMENT OPERATINGMODE 

# (1[ illuL- L. •( CONTROLEQUIPMENT OPERATING MODE DESCRIBE EMISSION POINT START STOP HTABOVEGRd&D LEVEL HTRELATIVETOOBSERVER STARTLSr STOP START STOP D)STANCEFROMOBSERVER DIRECTIONFROM OBSERVER START’ STOP 3çr 

# START 

# At’ STOP 

# tJ. DESCRIB EMISSIONS START STOP EMISSION COLOR PLUMETYPE: CONTINUOUSO STARTUSTOPeLtI— FUGITIVED INTERMITTENTD WATER DROPLETS PRESENT: IFWATERDROPLETPLUME: NO

- 

# YES D ATTACHED D DETACHEDD POINT INTHEPLUMEATWHICHOPACITYWAS DETERMINED START STOP DESCRIBEBACKGRO1JND START’?

# )ôxL STOP 5.C 

# BACKGROUN SKYCONDITIONS STARTS START? Ck’TOP IIND SPEED WIND DIRECTION TART71.i STOP 

# 712— STARTJL STOP \MBIENTTEMP WETBULB TEMP 

# RH % TART STOP 

# 9 (L, ______________________



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# Q INTERMITTENID WATERDROPLETS PRESENT: IFWATERDROPLETPLUME: NO 

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# D DETACHEDD SOURCE NAME SOURCEID NUMBER PROCESS EQUIPMENT OPERATINGMODE CONTROLEQUIPMENT OPERATINGMODE DESCRIBEEMISSION POINT START STOP HTABOVEGROUND LEVEL HTRELATIVETO OBSERVER START STOP START STOP DISTANCEFROM OBSERVER DIRECTION FROM OBSERVER START STOP START STOP DESCRIBEEMISSIONS START STOP EMISSION COLOR PLUMETYPE; CONTINUOUSD START STOP FUGITIVED INTERMITIENTO WATERDROPLETS PRESENT: IFWATERDROPLETPLUME. NO D YES 

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# LA -7Iac7aAPPENDBCALIBRATIONDATADerenzo and Associates, Inc. Summary
of Analyzer Calibration Error Data Client: Trail Ridge Ener’ Source:

IC Engine No.4 Date: 3/25/2009 NO, 246.7 ppm CO 1017 ppm CO 2 13.5

‘In 02 20.99

% Instrument: Themo Environmental Instruments, Inc., Model 42c

- NO, Span: 246.7 Response

to Calibration Gas (ppm) Expected Analyzer Calibration Concentration Anlyzer Outvut Error Gas Concentration

(ppm).. (ppm)‘‘

.. (%) /b High

246.7 251.1

1.78 Mid

98.7
96.3 -0.99 Low

0.00 0.10
004 Instrument: Fuji ZRF

- CO Span: 1017 Response

to Calibration Gas (ppm) Expected Analyzer Calibration Concentration Anlyzer Output Ertor Gas Concentration
(jipm) (ppm)

(7.) High

1017.0 1014.5 -0.25 Mid

610.2 604.5 -0.56 Low

0.00
0,42
0.04 Instrument: Fuji ZRF- CO 2 Span:
13.5 Response

to Calibration Gas (ppm) Expected Analyzer Calibration Concentration Anlyzer Output Error Gas Concentration

(ppm) (ppm

(%) High

13.5
13.5
0.15 Mid

8.10 8,00 -0.74 Low

0.00 0,00
0,00 Instrument: Fuji ZRF -02 Span: 20.99 Response

to Calibration Gas (ppm) Expected Analyzer Calibration Concentration Anlyzer Output Error Gas Concentration

(ppm) (ppm)

(%) High

20.99 20.98 -0.05 Mid

8.40
8.28 -0.57 Low

0.00
0.01
0.05Derenes and Associates, Inc. Client: Source: Date: NO, CO Cot 02 Trail Ridge Energy IC Engine No.4 3/25109 246.7 1017 13.5 20.99

Zero System Bias Averatte Un-Scale Calibrations NOx

CO C02

02 Eng.
4 Test

1 99.1

601 13.34
829 Eng.
4 Test

2 99.9

601 13.37
8.30 Eng.
4 Test

3 100.1
604 13.48
8.28 Eng.
4 Test
4

13.57
8.28 Eng.
4 TestS

I 3.57
8.29 Eng.
4 Test

6

13.57
8.30 Average Zeros NOx

CO C02

02 Eng.
4 Test! 0.66 0.24 0.00

0.01 Eng.
4 Test
2 1.00 0.28 0.00
0.01 Eng.
4 Test

3 0.77
1.26 0.00
0.01 F.ng.
4 Test
4

0.02
0.01 Eng.
4 TestS

0.07
0.01 Eng.
4 Test

6

0.10
0.01 Summary
of System Calibration Data ppm ppm % % Themo Environmental Instruments, Inc., Mode! 4 2c- NO, 246.7 Response
to Calibration Gas (ppm)_

- Instrument: Span: Un-Scale Gas SYstem Bias Drift

Drift Expected Cone. (ppm NO,)
96.3 ‘(%)‘ (%)
0.10

(%) (%) Engine 4, Pre Test

I

98.8
1.02-
0.15
0.02- Engine 4, Post Test 1/Pre Test
2 99.4
1.29
0.27

1,16
0.43 0.41 Engine
4, Post Test 2/Pre Test

3 100.4
1.69
0.40

0.83
0.30 0.13 Engine
4, Post Test

3
99.8
1.44
0.25

0.71
0.25 0.05 Instrument: Fuji ZRF- CO Span: 1017 Response

to Calibration Gas (ppm) Up-Scale Gas System Bias Drift
Zero System Bias Drift Expected Cone (ppm CO)
604
5“ (/) 1 I1fPS (%)$

“ 042

.. (°/) (%) Engine
4, Pre Test

I 602.9 -0.16-
0.34
-0.01- Engine 4, Post Test 1/Pre Test
2 599.5 -0.50
0.34

0,13
.0.03 0.02 Engine
4, Post Test 2/Pre Test

3 601.7 -0,28
0.22

0.42
0.00 0.03 Engine4,PostTest3

605.5 0.tO
0.37
2.10
0.17 0.17 Instrument: Fuji ZRF- CO 2 Span:
13,5 Response

to Calibration Gas (ppm) Up-Scale Gas System Bias Drift
Zero System Bias Dnft Eqsected Cone. (ppm CO,) 13.52
(%)‘ (%)< “‘v 000

(%) (%) Engine 4, Pre Test!
t3.34 -1.33-
0.00
0.00- Eisgine
4, Post ‘rest l.Pre Test
2 13.33 -141
0.07
0.00
0.00 0.00 Engine
4, Post Test 2/Pre Test

3 13.40 -0.89
0.52
0.00
0.00 0.00 Enmine
4, Post Test 3/Pre Test
4

1 3.56 0.30

1 .19
0.00
0.00 0.00 Engine
4, Post Test 4/Pre ‘rests 13.57 0.37
0.07
0.04
0.30 0.30 Engine
4, Post Test 5/Pre Test
6 13.56 0.30
0.07
0.10
0.74 0.44 Entiine4, Post Test
6
13.57 0.37
0.07
0.09
0.67 0.07 Instrument: Fuji iRE- 02 Span: 21.0 Response

to Calibration Gas (ppm) Up-Scale Gas System Bias Drift
Zero System Bias Drift Expected Conc (ppm O)
828 f4W4dW(%)

(‘) ‘W4s’ 44 001

(%) (‘7) Engine
4, Pie Test

1

8.28 0.00-
0.01
0.00- Engine
4, PostTest 1/PreTest2
8.30 0.10
0.10

0.01
0.00 0.00 Engine
4, Post Test 2/Pre Test

3 8.29 0.05
0.05

0.01
0.00 0.00 Engine
4, Post Test 3/Pre Test
4 8.27 -0.05
0.10

0.01
0,00 0.00 Engine4,PostTest4/PreTest5

8.29
0.05
0.10

0.01
0.00 0.00 Engine 4, Post Test 5/Pie Test

6 &28 0,00
0.05

0.01
0.00 0.00 Engine
4, Post Test
6

8.32 0.19
0.19

0.01
0.00 0.00Derenzo and Associates, Inc. Client: Source: Date: THC Run No. 1 2 3 Trail Ridge Energy IC Engine No. 4 3/25/2009 870 25-35% of Span 250 350 VOC Reference Method Analyzer Sampling System Bias Check arid Measured Value Correction VOC RM Monitor Span 1000.00 PPM 80-90% of Span 800 900 Zero Gas Drift 0.00% 0.00% 0.00% Z-Drift Pass if <3% Pass Pass Pass Average Up-Scale Calibrations
THC Eng.4Testl

521.40 Eng.4Test2

527.86 Eng.4Test3

531.40 Average Zeros

THC Eng.4Testl

0.1 Eng.4Test2

0.1 Eng.4Test3

0.1 ppm 45-55% of Span 450 550 Calibration Error Check Linearity Check (Must be within 5%) Cal. Gas Serial
# Tag Value Monitor Expected Monitor Duff. % Duff

Zero
Low
Mid High Gas
Gas
Gas Gas Propane Propane Propane :, 0.00 348.00I 522.00 870.00 0.08.
871.99- 348.84. 523.23* •. 338.19
.: 514.55 0.08 -10.65 -8.68 1.99 0.0 1% -3.06% -1.66% 0.23% Pass
Pass Pass Pass (Cavg) (Co)i (Co)f Ave. Measured Initial Zero Gas Final Zero Gas Raw (ppm) L 560.21
0.08
0.08 641.74
0.08
0.08. 623.29
0.08

.. 0.08 (Crn)i Initial Upscale Run No. 1 2 3

(Cm)f Final Upscale 514.55

528 25 528.25 527.46 527.46

535 34 Upscale Gas Drift 1.37% -0.08% 0.79% Up-Drift Pass if <3% Pass Pass PassDerenzo and Associates, Inc. Client: Source: Date: CH4

Trail Ridge Energy IC Engine No. 4 3/25/2009 1882
VOC Reference Method Analyzer Sampling System Bias Check and Measured Value Correction ppm 25-35% of 45-55% of 80-90% of Span Span Span 250 450 800 350 550 900 Calibration Error Check Linearity Check (Must be within 5%) Cal. Gas Serial
# Tag Value Monitor Expected Monitor Diff. % Duff

Zero
Low Mid High Gas
Gas Gas Gas Propane Propane Propane 0.00 752.80

1 1129.20

I 1882.00 0.76

1882.28 753.37 1129.7.

I 749.73 1142.6II -3.64 12.9 . -0.48% 1.15o6iaio 0 Pass Pass Pass Pass VOC RM Monitor Span

= 1000.00 PPM (Cavg) Ave. Measured Raw (ppm) (Co)i (Co)f Zero Initial Zero Final Zero Gas Gas Drift Run No. I 2 3 Run No. I 2 3 1919.99drnI
0.76 2.80 J1.54 1.77 Z-Druft Pass
if <3% Pass Pass Pass (Cm)i Initial Upscale (Cm)f Final Upscale
0.20% -0.13% 0.02% Up-Drift Pass
if <3% Pass Pass Pass k1142.62 1118.51 %1118.51: 1101.46 1094.24 Upscale Gas Drift -2.4 1% -1.71% -0.72%l)crenzo and Associates, Inc. Summary
of Analyzer Calibration Error Data Client: Trail Ridge Energy Source:

IC Engine Stratification Testing Date: 3/24/2009 NO 246.7 ppm CO 1017 ppm CO 2 13.5

% 02 20.99

% Instrument: Themo Environmental Instruments, Inc., Model 42c

- NO, Span: 246.7 Response

to Calibration Gas (ppm) Expected
Pre Stratification Analyzer Calibration Concentration Testing Error Gas .(ppm) (ppm) ‘..5(%) High

246.7 248.7
0.82 Mid

98.7 97.9
-0.33 Low

0.00 0.30
0.12 Instrument: Fuji ZRF

- CO Span: 1017 Response

to Calibration Gas (ppm) Expected
Pre Stratification Analyzer Calibration Concentration Testin, Error Gas Concentratonsf

(ppm) (ppm

( /) High

1017.0 1015.3
-0.17 Mid

610.2 609.7
-0.05 Low

0.00 005
0.00 Instrument: Fuji ZRF

- CO 2 Span:
13.5 Response

to Calibration Gas (ppm) Expected
Pre Stratification Analyzer Calibration Concentration Testing Error Gas Concentration

(ppm) (ppm)

(%) High

13.5
13.5
0.07 Mid

8.10
8.11
0.07 Low

0.00 0.00
0.00 Instrument: Fuji ZRF

- 0, Span: 20.99 Response

to Calibration Gas (ppm) Expected
Pre Stratification Analyzer Calibration Concentration Testing Error Gas Concentrahon

(ppm) (ppm)

(%) High

20.99 21.0
0.14 Mid

8.40 8.22 -0.86 Low

0.00
0.01
0.05Derenzo and Associates, Inc. Summary
of System Calibration Data Client: Trail Ridge Energy Source:

IC Engine Stratification Testing Date: 3/24/09 NO, 246.7 ppm CO 1017 ppm CO 1 13.5

% 02 20.99

% Instrument: Themo Environmental Instruments, Inc., Model 42c

- NO, Span: 246.7 Response
to Calibration Gas (ppm) Up-Scale Gas System Bias Drift
Zero System Bias Drift ExpectedConc.(ppmNOJ.

97.9

(%)
030

(%) Pre Stratification Test

97.9
0.03

-
0.30
0.00- Post Stratification Test
49.6
0.11
0.08

0.09 -0.09 0.09 System Response Time (see)

114

-

-

107

-

- Instrument: Fuji ZRF

- CO Span: 1017 Response
to Calibration Gas (ppm) Up-Scale Gas System Bias Drift
Zero System Bias Drift [xpeeted Cone (ppm CO)
609

( /o)

005

(%)

( /) Pre Stratification Test
606.1 -0.36-

1.77
0.17- Post Stratification Test 606.2 -0.34

0.01

1.78
0.17 0.00 System Response Time (see)

95--

106-- Instrument: Fuji ZRF- CO 2 Span:
13.5 Response

to Calibration Gas (ppm) System Bias Drift
Zero System Bias Drift F xpcctcd Coiic (ppm CO,)

13
(%)

(%)
000

(°‘)
(%) Pre Stratification Test
13.52
0.07-
0.03
0.22- Post Stratification Test
13.46 -0.37
0.44

0.02
0.15 0.07 System Response Time (see)

110--

104-- Instrument: Fuji ZRF- O Span: 21.0 Response
to Calibration Gas (ppm) Up-Scale Gas System Bias Drift
Zero System Bias Drift Expected Cone (ppm O) 822,-

s 5 (%)

001

(%)
(%) Pre Stratification Test

8.27 0.24-
0.01
0.00- Post Stratification Test

8.29
0.33
0.10

0.01
0.00 0.00 System Response Time (see)

113

--

133

-

-

# Derenzo andAssociates,Inc.

Divider Expected Injection Setting Concentration No. 1 No. 2 No. 3 Average %Error 

# 100% 20.99 21.03 21.05 21.03 21.04 0.22% 60% 12.59 12.44 12.43 12.40 12.42 -1.36% 40% 8.40 8.24 8.26 8.23 8.24 -1.82% 0% 0.00 0.01 0.01 0.01 0.01

- 

# Introducemid-levelprotocolgas (instrument). Repeattwice(totalof3 injections).

Mid-Range Expected Injection Gas Concentration No. 1 No. 2 No. 3 Average 

# %Error °2 

# 12.50 12.59 12.63 12.67 12.63 1.04%

1. Eachinjectionshalldiffernomorethan2% fromthetriplicateaverage. 2. No average shallbegreaterthan2% ofthepredictedvalue.

Date: Client: dilution moduleat Gasused: METHOD 205

-

# DILUTIONMODULEVERIFICATION 3/24/2009 TrailRidgeEnergy

20.99 

# %, oxygencalibrationgas IndividualResponseErrors as ComparedtoAverage 0.0% 0.1% 0.0% 0.1% 0.1% -0.2% 0.0% 0.2% -0.2%

Criteria: IndividualResponseErrors as ComparedtoAverage -0.3% 0.0% 0.3%

# DerenzoandAssociates,Inc.

METHOD7E

-

# NOxCONVERTERVERIFICATION Date: 3/25/2009 Client: TrailRidgeEnergy PreTestAnalyzerCalibration Introducehigh,mid, lowcalibrationgases (mustbewithin2% of calibrationspan). Expected Observed Percent Gas Time Concentration (ppmv) Concentration (ppmv) Error High 6:43 247 251.1 1.65 Mid 6:47 97 96.25 -0.17 Low 6:25 0.00 0.10 0.04 ConveterTest Introduceapproximate 1:1 mixofNOxcalibrationgas andzero air. NOxreadingmustremain stable (cannotdropmorethan2% ofhighestpeakobserved) for30minutes. Beginning Beginning Ending Ending Elapsed Pollutant Time Concentration(ppmv) Time Concentration(ppmv) Time %Change

NO 13:49 50.86 14:19 50.13 0:30 -1.44% NO 13:49 50.69 14:19 45.9 0:30

- 

# NO 2 13:49 0.41 14:19 4.29 0:30

- 

# PostTestAnalyzerCalibration Introduceacalibrationgasthatmostcloselymatchestheconcentrationobserved duringthetest(mustbewithin 1% ofcalibrationspan). Expected Observed Percent Gas Time Concentration(ppmv) Concentration(ppmv) Error Mid 15:47 49.3 49.60 0.11 Zero 15:28 0.00 0.09 0.04

# Derenzo andAssociates,Inc.



# Measurethreepoints locatedat 16.7%,50.0% and 83.3% ofstackdiameterfortwicethesystemresponsetime. Determine thepecentdifferenceoftheresponseateachpointcomparedthethethreepointaverage. EngineNo. 3 Recorded RecordedConcentrations(ppm) Point Time CO CO 2 02 

# 1 16:39 658 10.96 8.28 2 16:48 659 10.94 8.29 3 16:57 659 11.01 8.28 Average

- 

# 658 10.97 

# 8.28 Criteria: 1. Iftheresponsediffersnomorethan5% fromthethreepointaverage, measureatonepoint. 2. Iftheresponsediffersmorethan5%butnomorethan 10% fromthethreepointaverage, measureatthreepoints. 3. Iftheresponsediffersmorethan 10% fromthethreepointaverage,measureattwelvepoints. Date: Client: METHOD7E

- 

# STACKSTRATIFICATIONDETERMINATION 3/24/2009 Trail

# RidgeEnergy



# Responseas ComparedtoAverage CO CO 2 02 

# 0.0% -0.1% 0.0% 0.0% -0.3% 0.1% 0.0% 0.4% 0.0%NOZZLE INSPECTION CRITERIA CHECKLIST Nozzle ID: f-z B

Date: A: B: C: Average: /t) /c’ F//a Comments: S/
/NOZZLE INSPECTION CRiTERIA CHECKLIST Nozzle ID: Date: A

A: B: B

C: Average: C Comments:NOZZLE INSPECTION CRITERIA CHECKLIST Nozzle ID: i1 B

Date: zq—o A: B: C: Average: /;__ Comments:Figure PROBE AND PITOT TUBE INSPECTION CRITERIA CHECKLIST
Tube#: Date:3—i-°__- A. x1.9cm

No w

z Z 31. z1.9cm w7.62 cm Or 32. Z 5.O8 cm . Y7.62cm
Figure Bi

or Figure B2

No B2.Yes
No Y Figure
C

No Pitot Tube Correction Factor:PITOT TUBE INSPECTION CRITERIA CHECKLIST Tube#: 6 Date:
3 —l3-/ 3/1 6”ZD/ 3/8” = IDS 1 .05D A,B 1 .5D Longitudinal Tube Axis

PA PB

No No No No z < 0.32 cm

No w < 0.08 cm Transversal Tube Axis

U.’

L and a 2 < 100 and 12 < 50

No J3 1 12 Hz

No Pitot Tube Correction Factor:

# METHOD 

# 5 DRYGAS METERCALIBRATION USING CRITICAL ORIFICES 1) Selectthree critical orifices tocalibratethedrygas meterwhichbracketthe expected operating range. 2> Recordbarometricpressurebefore and aftercalibrationprocedure. 3) Run atmaximum attainable vacuum (open coarse valve, closefine valve),

tarperiod of5 minutes minimumforlargeorifice up to 10 minutes forsmatlestorifice. 4) Recordreadings in outlined bones below, otherColumns are automaticallycalculated. 

# DERENZO & ASSOCIATES,INC

TEMPERATURES F 0GM READINGS (FT’) AMBIENT 0GM INLET 0GM OUTLET 0GM TIME (MIN) 

# r INITIAL FINAL NET (V,> INITIAL FINAL INITIAL

— 

# FINAL

- - 

# AVG 1429 1 O.708 16.5 760.120 765,26 5.140 _________



# Crass 2 0.7968 16.5 765.26 770.4.4 5.180 _________



# 3 0.7960 16.5 770.44 775.625 5.109 _________



# 02$ I 0.6534 10 775.620 7e4.17 8.541 __________



# Crass 2 5.6534 16 7e4.17 792.76 8.590 _________



# 3 O.e534 18 792.76 809.355 e.oao __________



# 520 1 0.5333 19.5 801.350 ao9.32 6.970 _________



# 0rs 2 0.5333 19.5 eoe.32 015.28 6.960 _________



# 3 0.5333 19.5 895.28 e22,2s6 6,976 _________



# LSINDTHE CRITICALORIFICESASCALIBRATION STANDARDS: films 1n2...’.;ngnqua2onx areusudtocalculatethe standardvolumosofairpassedthroughlire

# 0GM, 14,

# (old), andthearilicalorifice, 14/,,(old), andthe DCVvu uratJnntaclur, Y. These equationsare axIomaticallynalculaledirslIre spreadsheetabous.

(31 Y = 

# ‘4, (old) = 

# 0GM calibration factor V 01 

# (slid) 76 76 65 69 :L_

L 2



# Netvolume ofgas samplepassedthrough DGI,I, corrected to standard condilians K, 17.64 ‘K/in. Hg (English), S.3050’l(lmm Hg )Mvtric)

= 

# Absolute

# 0GMavg. temperalure(‘K.English,’K- l.lelnc)

= 

# Volume ofgas samplepassed through the critical orifice, correctedto slarudard condiIios = 

# Absoluteambienttemperature(‘Fl -English, ‘K

. 

# Melds) K’ = 

# AverageK’ laclurfromCriticalOrihceCalibralmon 67 67 67
67 67 67
67 67 67 77 77 76 77 76 77 70 71 71 71 79 72 IFYVARIATION EXCEEDS 2.00%, ORIFICESHOULDBERECALIBRATED DATE: 3/6/09 METER SERIALS: NT 1.IETER PART 14: NI CRITICAL ORIFICESET SERIALS: 1316

ORIFICE0 RUN 0 K’ FACTOR (AVG) TESTED VACUUM (InHO) INITIAL BAROMETRIC PRESSURE(In

# Hg)L_2aj5 AVG (P 5 .,) 29.15 FINAL 29.15

ELAPSED

72,20 72.5 73 DGM&-I (1) (2) (3) Y (in H

5 O) V,,,)STD( V, (STO( I VARIATIONl’l 5.00 3.9 0.00 3.5 

# L 5.00 3.8 73.75 10.05 2.5 73.75 10.00 2.5 74 10.00 2.5 74 10.00 1.7 74 10.00 1.7 74 10.00 1.7

(1) V,,, (std)o

i2 V, 1 (std) K 1 V,,, P 5 •, + 

# (AH!13.6( 1’,, ________________



# 5.0163 5,0603 1,0088 5,0529 5.0603 1,0015 5,0570 5.0663 1,6007 AVG = 

# 1,0036 0.15 ________________



# 8.2850 8.2993 1,0017 5,3325 8.2993 0.9960 8.3286 8.2993 0.9065 AVG 0,9589 -0.40 _________________



# 6,7443 6.7738 1,004.4 ________________



# 6.7347 6.7730 1,0050 6.7501 6,7739 1.0035 AVG 1,0046 0.20 AVERAGE DRYGAS METER CALIBRATION FACTOR, Y = 

# 1.0021 Y-S% 0,952 1,052 Delta H@ 2.026 K/so 1623.534 PYROMETERCALIBRATION Meter 32 100 252 500 1500 1500 Ome9a 32 150 255 550 1009 1500 ‘I. DIfference 0.0 0.5 0.0 0.0 0.5 5,0

I’tulech#1 Calibration

# METHOD 5 DRY

# GAS METERCALIBRATIONUSING CRITICAL ORIFICES 1) Selectthree critical orittces to calibrate the drygas meterwtrich bracketthe expected operating range. 2) Recordbarometricpressure before arid aftercahbration procedure. 3) Run atmaximum attainablevacuum (open coarse valve, closefine valve>.

forperiod of5 mInutes 

# minimumforlargeorifice upto 10 minutes forsmallest

# orifice. 4) Recordreadings ml outlined boxes below, othercolumns are automaticallycalculated. 

# DERENZO &ASSOCIATES,INC

731.649 738.57 738.57 745.52 745.52 752.478 5.160 5.220 5.219
8.601 8.650 8.611 6.521 6.550 6.958 TEMPERATURES’F

65 74 75 69 70

_



# Netvolume ofgas samplepassedthrough DGM, correctedto standard conditions K 17.04 ‘Rim. Hg(English), 0.3058 ‘K/mm Hg )f.lelnc) 1’,. = 

# Absolute0GM avg. temperatureR- Engimsh,’lc- Metric)

= 

# Volumeofgas samplepassedthroughthe critical orifice, corrected to standard Conditions = 

# Absoluteambienttemperature)R

- 

# English.‘K

-

# f.letmic) K’ Average

# K’ factor1mmCritIcalOrificeCalibration 66 67 68 75 76 76 76 76 76 70 71 71 71 71 72 IFVVARIATION EXCEEDS 2.00%, ORIFICESHOULD BERECALIBRATED

5.0448 5.0569 1.0024 5.6790 5.0569 0.9957 5.0756 5.0569 0.9563 AVG 0.9551 -0.09 8.3335 8.2858 0.9943 8.3732 8.2779 0.5806 8,3315 o.27sI 0,9926 AVG = 

# 0.9918 6.6798 6.750 1.0105 6,7109 6.750 1.0058 6.7218 6.7564 1.0051 AVG 1.0072 DATE: 411105 METER SERIAL6: Ni 1.IETER PART6: Ni CRITICALORIFICESET SERIAL6: 1316

ORIFiCE II RUN S K’ FACTOR (AVG) TESTED VACUUM (In tl) INITIAL FINAL AVG(Pu.,) 8AROMETRIC PRESSURE (in Hg(: 20.08 

# I 29.07 29.075

0GM READINGS (PT’) AMBIENT 0GM INLET 0GM OUTLET 0GM TIME(fAIN) INITIAL FINAL NET (V,,) INITIAL FINAL INITIAL FINAL AVG 

# 0 689,170 694.30 694.35 699.57 699.57 704.789 020 1 0.7968 16.5 Oruss 2 0.7968 16.5 _____________



# 16,5

024 1 0.6534 16 OrasS 2 0.6534 18 _____________



# 3 8.6534 18 1120 1 0.5333 19.5 Orass 2 0.5333 19,5 3 19,5 ELAPSED


# L 704.789 713.39 713.39 722,04 722.84 730.651 DGM4H 

# (I) (2) (3) V (InH,D) V, )5TD( V,,)STD( V VARIATION(%l

SiNG THE CRITICALOOIFICESAS CALIBRATION STANDARDS: lilalois...g nquaLuos are usedtucalculalethe otandardvolumesofair

# passedthraughthe0GM, V. (std), andthecribcalwince,V (std),andthe )Gl,lcu.bratioo boor, V. Thrseequationsare automaticallycalculatedinthe spreadsheetabnoe. 72 5.00 3.8 72.5 5.00 3.8 72.75 5.00 3.8 73 10.50 2.5 73.5 10.00 2.5 73.75 10.00 2.5 74 10,00 1.7 73.75 10.00 1.7 73.0 10.00 1.7

>1) V,, (stct) = 

# K 5 V,, Pb., + 

# (0H113.6) T, 5 12) V,, )std) u 

# K’


# 131 Y = 

# 1,, (sOd) 

# V,, (sOd) = 

# 0GMCalibrationfactor 072

o.an AVERAGE DRYGAS METER CALIBRATION FACTOR,y = 

# 0,9990 Y-5% 0.949 1,049 DettaH@ 2.031 KIso 1534.575 PYROMETERCALIBRATION 

# Meter 32 99 

# I 252 500 1000 1501 Omega 32 100 250 500 1000 lOOT 

# 1% Difference 0.0 .1.0 0.8 0.0 0.0 0.1

Nutocli 1111 CalibrationMpr 27 200S 2:07PM ]Jer-enzo and Associates,

I 517-324-5409 C

,

SPECIALTh’ GASES OF AMERICA, INC. AMERICAN INDUSTRIAL GASES. INC. AMERICAN RARE GASES. INC. ‘.iI

% ..

6055 DRENT DR TOLEDO, OH 4351 4

4I9-729--T72 FAX 419-725-2411 THE AMERICAN GAS GROUP www.americanásgroup..com

P. 1 Certificate
ID: Customer Name: Customer Address: ANALYTICAL REPORT 091 808038 Derenzo

& Associates Inc 39395 Schoolcraft
Rd Date: 9/18/2008 Livonia 734-464-3880

Ml 48150 LAN-I 81 0902SC08 Al 6 Purchase Order: Lot Number: Size: Content: Serial #: Analysis Date: Shelf Life:

NIA
Work Order: Product Name: Pressure: ET000205

0 9/18/2008 36 monThs
080466-03 2-Component Mixture, EPA Protocol 2300 pslg @ 89 Deg F Expiration Date: 9/1812011 Component Nominal Actual Accuracy Method Methane

1850 ppm 1882 ppm +/-2% rel FID Air Balance Balance REFERENCE STANDARD
Std Type Std# Concentration
Exp Date GMIS 0327AB08 EB0001183 104.1000 3/27/2010 4: INSTRUMENTATION Instrument

I ID CAl 300S-HFID

CH4 I Note:

* ANALYZED ACCORDING
TO EPA TRACEABILITY PROTOCOL FOR ASSAY AND CERTIFICATION OF GASEOUS CALIBRATION STANDARDSSEPTEMBER 1997:01 DO NOT USE STANDARD WHEN PRESSURE

IS BELOW 150 PSIG

H r -4

Issued by: GJI, 9c’n.e& pecialty Gases of America, Inc. QFO5I, Rev 0Apr 27 2009 2:07PM Derenzo and Associates,

I 517—324-6409

P- 2 SPECLLYGASESOFPMERICA,

INC. AMERICAM INDUSTRIAL GASES, INC. AMERICAN RARE GASES INC. 6DSRENTDR. TOLEDO ON4ll 497S-7732 FPX419729241l THE AMERICAN GAS GROUP www.amerlcangasgroup.com... ANALYTICAL REPORT Certificate
ID: 060408007

Date: 6/412008 Customer Name: Derenzo

& Associates Inc Customer Address: 39395 Schoo!craft Rd e -

. Livonia

Ml 48150 734-464-3880 Purchase Order: LAN-175

. Work Order; 076935-01 Lot Number: 0304HF08 Product Name: 2-Component Mixture, EPA Protocol :4

-. Size:

31A Pressure: 2000 psig @ 70 Deg F Content:

NFAV Serial#: SX28217 Analysis Date: 3/14/2008 Slielf Life:

36 months Expiration Date:
3J1 412011 _4 Component Nominal

. Actual

,. Accuracy Method .21 0% 20.a% +J- 1% reL— Paramagneitc

._ Nitrogen Balance Balance

•1 REFERENCE STANDARD
Std Type Concentration

Exp Date GMIS 1206BN05 EB0001234 2156% 10/2/2009 V. IV.

I INSTRUMENTATION InstrumentIlD Component Rosemount 755R

02 •.•••

....•V•V-.•••

- -t.4t.•-.‘-V. 4.

. Note:

* ANALYZED ACCORDING
TO EPA TRACEABILIT’? PRO1 .LFDR ASSAVAND CERTFIAT1ON OFGASEOUS CALIBRATION STANDARDS

- SEPTEMBER 1997G1 * DO NOT USEVSTANDARD WHEN PRESSURE

IS ELd’Vv: ió-P’sid

. Issued by &nz ciaIt Gases of Atnerlca 3 Inc. QFO5I Rev 0.-.:ç. ‘---.:--,•-.-.-

SPECIALTY GASES OF AMERICA, INC-—

..,.

AMERICAN INDUSTRIAL GASES INC 1 I- \
.

AMERICAN RARE GASES INC G

6O55BRENTDR TOLEDO,0H43611 419-729-7732 FAX 419-729-2411 THE AMERiCAN GAS GROUP www.americangasgroup.com

JI 1 ANALYTICAL REPORT

- Certificate
ID: 041408036

Date: 4/14/2008 Customer Name: Derenzo

& Associates Customer Address: 39395 Schoolcraft Rd Livonia

MI 48150__ Purchase Order: LAN-171
Work Order: 074669-00 Lot Number: 0410HA08 Product Name: 2-Component Mixture, EPA Protocol I.I 4 Size:

31A Pressure: 2015 psig @ 70 Deg F Content:

N/A Serial #: EB0006707 Analysis Date: 4/14/2008 4 Shelf Life:

36 months Expiration Date: 4/14/2008 Component Nominal Actual Accuracy Method Carbon Dioxide 13.5% 13.5%

+1- 1% rel NDIR Nitrogen Balance Balance

ii REFERENCE STANDARD
Std Type Std Concentration

Exp Date

-I GMIS 0306JD08 EB0000776 7.5230 316/2010 INSTRUMENTATION Instrument

I ID Component on a-

002 Note:

* ANALYZED ACCORDING TO EPA TRACEABILITY PROTOCOL FOR ASSAY AND CERTIFICATION OF GASEOUS CALIBRATION STANDARDS

- SEPTEMBER 1997:G1 * DO NOT USE STANDARD WHEN PRESSURE

IS BELOW 150 PSIG Issued by: ___________________ W y’ Specialty Gases of America, Inc. 0F051, Re’i
0

# z u>cnocnr-- 0 Ct 0 

# F 0 t CD 

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# C)SPECIALTh’ GASES OF AMERICA. INC. AMERICAN INDUSTRIAL GASES, INC. AMERICAN RARE GASES, INC 6055 BRENT DR. TOLEDO. OH 43611 419-729-7732 FAX 419-729-2411 dtRit.S%.*lqi

a...... THE AMERICAN GAS GROIWV

www americangasgroup
corn ANALYTICAL REPORT Certificate
ID: 112006030

Date: 11/20/2006 Customer Name: Derenzo

& Associates Customer Address: 39395 Schoolcraft
Fd-- Livonia

MI•. :. 48150

j Purchase Order: 0924
Work Order: 055955-02 Lot Number: I1O1SCO6. Product Name: 4-Component Mixture, EPA Protocol Size:

31A Iressure: 2250 psig @ 90 Deg F Content:

NA 4 Serial #: EB0004361-- Analysis Date: 11/18/2006 Shelf Life:

36 months Expiration Date: 11/18/2009 Component Nominal Actual Accuracy Method 15%..-. 15.0%. +/-Qi%

GC-TCD- l000ppm lOl6ppm +/-3ppm NDIR 12.5% 12.5%

+1- 0.2% Paramagnetic Balance Balance Std Type Std# Concentration

Exp Date GMIS IO11BKO5 EB0000880 1000 ppm 1)20/2008 GMIS 1206BL05 EB0001508 15.16% 1/31/2008 GMIS 1O11SHO5 EB0000776 7.53% 2)3/2008 Instrument!

ID Component Horiba VA-3000

co Rosemount 755R

02 GOWMAC-580 TCD

C02 Note: *ANALYZEDACCORDGTOEPRACEALYOO

ASSAY AND CERTIFICATION DO NOT USE STANDARD WHEN PRESSURE

IS BELOW 150 PSIG Issued by: 9-n& = Carbon Dioxide Carbon Monoxide Oxygen Nitrogen REFERENCE STANDARD INSTRUMENTATION 4 1 4SPECIALTY GASES OF AMERICA, INC.— AMERICAN INDUSTRIAL GASES, INC. AMERICAN RARE GASES, INC. 6055 BRENT DR. TOLEDO, 01-i 43611 419-729-7732 FP(419-729-2411 THE AMERICAN GAS GROUP www.americangasgroup.com ANALYTICAL REPORT Certificate
ID: 121107014

pate: 12/11/2007 Customer Name: Derenzo

& Associates Inc Customer Address: 39395 SchooIcraft Rd.,.
Livonia

Ml 48150 734-464-3880 b ‘1 Purchase Order: LAN-161
Work Order: 069795-00 Lot Number: 1128SA07 Product Name: 2-Component Mixture, EPA Protocol Size:

31A Pressure: 2200 psig @ 80 Deg F Content:

NA II4 Serial#: CC181509 ‘4 Analysis Date: 12/11/2007

. Shelf Life:

36 months Expiration Date: 12/11)2010 Component Nominal Actual Accuracy Method Carbon Monoxide 1000 ppm 1017 ppm
+1- 1% rel NDIR Nitrogen BaIac Balane--.--_.-.--.... .IL4 REIERENCE STANDARD
Std Type Concentration

Exp Date 4

GMIS 1012BC05 EB0000962 2514 ppm 1/20)2008 INSTRUMENTATION Instrument/ID Component Horiba VA-3000

CO

P ‘1 Note:

* ANALYZED ACCORDING
TO EPA TRACEABILITY PROTOCOL FOR ASSAY AND CERTIFICATION OF GASEOUS CALIBRATION STANDARDS

- SEPTEMBER 1997:G1 * DO NOT USE STANDARD WHEN PRESSURE

IS BELOW 150 PSIG Issued by: j2cJi, C4l,QA, Specialty Gases of America, Inc. QFO51, Rev
0Scott Specialty Gases ./\IR LIcJ.Jl DEJ Air Liquide America Specialty Gases LLC RATA CLASS Dual-Analyzed Calibration Standard 1290 COMBERMERE STREET, TROY, Ml 48083

Phone: 248-589-2950

Fax: 248-589-2134 CERTIFICATE
OF ACCURACY: EPA Protocol Gas Assay Laboratory

Customer P.O. No.: 56547-7165000 CLEAN AIR ENGINEERING SCOTT SPECIALTY GASES Project No.: 05-65079-003

DON ALLEN 1290 COMBERMERE STREET

500 W. WOOD STREET TROY, MI 48083

PALATINE

IL 60067 ANALYTICAL INFORMATION This certification was performed according

to EPA Traceability Protocol For Assay
& Certification

of Gaseous Calibration Standards; Procedure G-1; September, 1997. Cylinder Number: ALM008541 Certification Date: 06May2008
Exp. Date: O6May2OlO Cylinder Pressure***:
1983 PSIG COMPONENT ___________________________________________ NITRIC OXIDE NITROGEN- OXYGEN FREE TOTAL OXIDES OF NITROGEN

246.7 PPM Reference Value Only Do not use when cylinder pressure

is below 150 psig. R=Reterence Gas T=Test Gas Second Triad Analysis

= Correlation Coefficient) Calibration Curve NITRIC OXIDE APPROVED BY: CERTIFIED CONCENTRATION (Moles) 246.7 PPM BALANCE

ANALYTICAL ACCURACY*

* +1- 1% TRACEABILITY Direct NIST and NMi “ Analytical accuracy

is based on the requirements

of EPA Protocol Procedure Ri, September 1997. REFERENCE STANDARD TYPEISRM NO. EXPIRATION DATE CYLINDER NUMBER CONCENTRATION COMPONENT NIRM 1685 OiSop2OlO KAL003527

247.1 PPM NITRIC OXIDE INSTRUMENTATION INSTRUMENT!M ODEL/SERIA
L#

DATE LAST CALIBRATED ANALYTICAL PRINCIPLE FTIR//0928621

24Apr2008

FTIR ANALYZER READINGS first Triad AnalysIs (Z=Zero Gas Oate: 28Apr2006 Response Untt:PPM 11 -.0.31274 R1Z46.9272 T1—246.7670 R2= 246.9446 Z2-O.1389B
T2. 246.7452 Z3 O.31568

T3 ..247.2013 H3247.874O AS,g. concentration: 246.4 PPM
DOte: O6May200B Response Unit: PPM Z1—-O.64681 R1245,4a17

Ti =244.9912 R2= 245.5777 22= .0.32221 T2= 245.0868 23 --0.24644

T3 =245.3372

R3 = 246.6467 Asg. Concentration: 246.9 PPM Concentration=A+Bs

+ 0e2 + De3+6x4 r= 9.99999E.1 Constants: A=0.00000E+0 6=9.825760-1 C4.60O00E-5 o=O.000000+0 E=0.000000+0 Rob McCrandall

fl...

I .4
IHoriba Instruments 5900 Hines Drive Ann Arbor, Michigan 48108 Certificate
of Calibration Certificate Number: 2011197-1 23008 All instruments

in the performance

of the below calibration have direct traceability to the National Institute of Standards and Technology (NIST). The calibration has been performed using the below listed procedure number. Customer: Customer Address: Manufacturer: STEC Description: Gas Divider Condition Received: Passed Cal Procedure: BPP.-QM1001-012 Date Calibrated: 12/30/08
Part Number: SGD-SC-5L Serial Number: 2011197 Condition Returned: Passed Uncertainty:
+1- 2% point Recalibration Due: 12/30/09 Standards Traceability Service Technician: A4I ji___ QAManager:___________________________________ This certificate/report may not be reproduced, except
in full, without the written approval
of Horiba F1QM1001015

Issue Date: 3/27/01 Page

1 Derenzo

& Associates,
Inc 39395 Schoolcraft
Rd Livonia, MI 48150-5036 Mfr./Model Number Serial
# Test Number Cal. Date Due Date DHI/3E5
1015 59148 02/29/08 02/28/09 DHI/3E5 1016 59149 02/29/08 02/28/09 DHI/Molbox
IA 448 59147 02/29/08 02/28/09 Revision Date: N/A

Date: 12/30/08 Date: 12/30/08 Revision Level:
A ri -‘
4’SGD-A10, SGD-710 GAS DIVIDERS VERIFICATION CHECK SHEET CUSTOMER: Derenzo
As Found Data DATE: 12/30/08 MODEL: SGD-SC5L SERIAL NUMBER: 2011197 CUT COMP
A COMP

B TOTAL FLOW MIXTURE %POINT ERROR PT. MIXTURE GAS DILUTANT GAS POINT FLOW
% >2.0% 0 0.0000 4.0042 4.0042 0.000 0.000 20 0.8031 3.2292 4.0323 19.917 0.416 40 1.6104 2.4273 4.0377 39.883 0.292 60 2.4176 1.6250 4.0426 59.803 0.330 80 3.2279 0.81 00 4.0379 79.940 0.075 100 4.0397 0.0000 4.0397 100.000 0.000 STD. DEV. 0.0142 LPM MIXTURE GAS INLET PRESSURE TO DIVIDER: DILUTION GAS INLET PRESSURE TO DIVIDER:
21.0 PSIG (At 100% CUTPOINT) 17.0 PSIG (AT 0.0% CUTPOINT) OUTLET FLOW FROM GAS DIVIDER:

4.00 LPM

# WhitlowEnterprises,LLC 

# www.smokeschooLnet Certifiesthat 

# DanielWilsonofDerenzo&Associates,Inc Haspassedthecertificationtestrequiredby40CFR60AppendixA andisqualifiedasavisibleemissionsevaluator CertificationDate: October31 2008 Location: Toledo, OH 

# Qeorae‘T4)fiit(ow President

T0H103108-19Method 7E Interference Response Verification Date: 7/26/2006 Analyzer: Thermo Model 42c Tested Calibration Span:

44.0 ppm Deviation from Expected Test Gas Type Concentration (ppm) Analyzer Response Response (ppm) C0 2 /N0 1.72%/26.4
26.20

0.20 CO 2 4.29%
-0.10

0.10 0 2 1N0 8.36%/26.4
26.27

0.13 02 20.9%

0.00

0.00 C0/N0 23.88/26.4
26.40

0.00 CO
59.70

-0.11

0.11 CH 4 /NOX 33.6/26.4
26.10

0.30 CH 4

84.0

-0.11

0.11 S0 2 /NOX 8.16/26.4
26.20

0.20 SO 2

20.4
-0.10

0.10 C 3 H 8 INOX
33.32

/ 26.4 26.34

0.06 C 3 H 8

83.3

-0.11

0.11 2 Total Deviation (ppm)

1.0 % of Calibration Span 3 2.38 1 - Measured concentrations were corrected for system bias. 2 - In summing the total deviation use the larger of the absolute values obtained for the interferent tested with and without the pollutant present. 3 - Total Interference must be less than 2.50% of the calibration span.Method 7E Interference Response Verification Date: 7/26/2006 Analyzer:

Fuji ZRF CO Cell Tested Calibration Span:
298.8 ppm Deviation from Expected Test Gas Type Concentration (ppm) Analyzer Response

‘ Response (ppm) C0 2 /CO 1.72%! 179.3
179.1

0.20 CO 2
1.72%

0.06

0.06 0 2 1C0 8.36%! 179.3
180.6

1.37 02 20.9%

-0.09

0.09 NOX/CO 26.4/179.3

179.3

0.02 NO

44.0
-0.10

0.10 CH 4 /CO
33.6/ 179.3
180.6

1.28 CH 4

84.0

-0.01

0.01 SO.,/CO 8.16/179.3
179.08

0.20 SO 2

20.4

1.29

1.29 C 3 H 8 /CO 33.32/179.3
179.42

0.14 C 3 H 8

83.3

0.02

0.02 Total Deviation (ppm) 2 4.38 % of Calibration Span 3
1.46 1- Measured concentrations were corrected for system bias. 2- In summing the total deviation use the larger of the absolute values obtained for the interferent tested with and without the pollutant present. 3- Total Interference must be less than 2.50% of the calibration span.Method 7E Interference Response Verification Date: 7/26/2006 Analyzer:

Fuji ZRF CO 2 Cell Tested Calibration Span:

4.29 %----- Deviation from Expected I

n Test Gas Type Concentration (ppm) Analyzer Response .ftesponse tppm) NOX/CO,

26.4

/ 1.72%

1.72

0.01 NO

44.0

0.00

0.00 0 2 /C0 8.36%

/ 1.72%

1.73

0.02 20.9%

0.00

0.00 CO/CO 2 23.88 /2.57%

2.57

0.00 CO
59.70

0.00

0.00 CH 4 /CO 2

33.6
/ 2.57%

2.57

0.00 CE 4

84.0

0.00

0.00 C 3 H 8 /C0 2 33.32/2.57

2.57

0.00 C 3 H 8

83.3

0.00

0.00 Total Deviation (ppm) 2
L03 / of Cahbration Span 0.59 I - Measured concentrations were corrected for system bias. 2 - In summing the total deviation use the larger of the absolute values obtained for the interferent tested with and without the pollutant present. 3 - Total Interference must be less than 2.50% of the calibration span.Method 7E Interference Response Verification Date: 7/26/2006 Analyzer:

Fuji ZFK3 02 Cell Tested Calibration Span:

20.9 % Deviation from Expected Test Gas Type Concentration (ppm) Analyzer Response’ Response (ppm) C0 2 /0 1.72%! 12.54%
12.62

0.08 Co 2 4.29%

0.00

0.00 NO/0 2 26.4/8.36%

8.41

0.05 N0

44.0

0.00

0.00 C0/0 2 23.88/12.54

12.56

0.02 CO
59.70

0.00

0.00 S0 2 /0

8.16

/ 12.54
12.62

0.08 SO 2

20.4

0.29

0.29 C 3 H 8 /0 2
33.32

/ 12.54
12.58

0.04 C 3 H 8

83.3

0.00

0.00 Total Deviation (ppm) 2
0.48 % of Calibration Span 3 2.30 1 - Measured concentrations were corrected for system bias. 2- In summing the total deviation use the larger of the absolute values obtained for the interferent tested with and without the pollutant present. 3 - Total Interference must be less than 2.50% of the calibration span.APPENDIXCLABORATORYDATAApril 14, 2009 Daniel Wilson DERENZO

& ASSOCIATES, iNC. 39395 Schoolcraft Road Livonia,MI 48150- Bureau Veritas Work Order No. 09031333 Reference: 0901014 Dear Daniel Wilson: Bureau Veritas North America, Inc. received

11 samples on 3/3 1/2009 for the analyses presented

in the following report. Enclosed

is a copy of the Chain-of-Custody record, acknowledging receipt of these samples. Please note that any unused portion of the samples will be discarded
30 days after the (late of this report, unless you have requested othenvise. This material

is confidential and is intended solely for the person to whom
it is addressed.

If this is received
in error, please contact the number provided below. We appreciate the opportunity

to assist you. If you have any questions concerning this report, please contact

a Client Services Representative

at (800) 806-5887. Scott Caillouette Client Services Representative cc: Bureau Veritas North America, Inc. 223i

S Rucuhel Drive Novi, MI 48375

\L4: 7 (248) 3q417() Fax: (248) 3442F55 BUREAU VE R ITASCASE NARRATIVE

Date: 14-Apr-09 Client: DERENZO

& ASSOCIATES, INC. Project: 0901014 Work Order No 09031333 The results of this report relate only to the samples listed in the body of this report. Unless otherwise noted below, the following statements apply:
1) all samples were received
in acceptable condition,

2) all quality control results associated with this sample set were within acceptable limits and/or do not adversely affect the reported results, and 3) the industrial hygiene results have not been blank corrected. Impinger volumes: TREP-

1 Cont#2
81 mL TREP-2 Cont#2
41 mL TREP-3 Cont#2 60 mL Analytical Comments for Method EPA2O2: Volumes of impinger solutions follow below. Lab ID Water (mL) Me2CI2 (mL) 09031333-2
390
110 09031333-4
400
140 09031333-6
400
150 0903 1333-7 495

88 Analytical Comments for Method EPA2O2, sample -007A: Please note an oily residue was observed for the methylene chloride blank. The blank sample was received
in a plastic polypropylene sample jar. The value of the blank may not be representative
for samples, since samples were received
in glass jars. A white powdery residue was observed
in the aqueos client blank.ANALYTICAL RESULTS

Date: 14-Apr-09 Client: DERENZO

& ASSOCIATES, INC. Project: 0901014 Sample Type: Acetone Rinse

Work Order No: 09031333 Method Reference Method EPA5

Date Received: 03/31/2009 RL (mg):
0.5

Analyst: MLG Air Particulate
by Method EPAS Lab Sample

Volume

Date No. Identification

(liters)
(mg) (mg/rn 3 ) (ppm) Analyzed OOIB TREP-1 CONT #2 03/25/09

0

6.4---- 04/03/2009 0033 TREP-2 CONT #2 03/25/09

0

6.4---- 04/03/2009 0053 TREP-3 CONT #2 03/25/09

0

9.4---- 04/03/2009 General Notes: <: Less than the indicated reporting limit (RL). Information not available
or not applicable. Back sections (if applicable) were checked and showed rio significant breakthrough unless otherwise noted.•:tIIUXI ANALYTICAL RESULTS

Date: 14-Apr-09 Client: DERENZO

& ASSOCIATES, INC. Project: 0901014 Sample Type: GF Filter, Tared

Work Order No: 09031333 Method Reference Method EPAS

Date Received: 03/31/2009 RL (mg):
0.5

Analyst: MLG Air Particulate
by Method EPAS Lab Sample
Volume

Date No. Identification

(liters)
(mg) (mgIm) (ppm) Analyzed OOIA TREP-l CONT#1 03/25/09

0

1.7---- 04/03/2009 003A TREP-2 CONT#I 03/25/09

0

1.8---- 04/03/2009 005A TREP-3 CONT#1 03/25/09

0

1.8---- 04/03/2009 General Notes: <: Less than the indicated reporting limit (RL). Information not available
or not applicable. Back sections (if applicable) were checked and showed no significant breakthrough unless otherwise noted.ANALYTICAL RESULTS

a III; WI

Date: 14-Apr-09 Client: DERENZO

& ASSOCIATES, INC.

Work Order No: 09031333 Project: 0901014 Lab ID: 09031333-002A

Client Sample ID: TREP-1 CONT #4/CONT
#5 Matrix: AIR

Tag Number: Collection Date: 3/25/2009 Reporting Analyses

Result Limit Qual Units
DF Date Analyzed Analyst EPA METHOD 202 Inorganic Condensible Particulate Matter Organic Condensible Particulate Matter Qualifiers:

ND- Not Detected

at the Reporting Limit (RL). .1- Analyte detected below the Reporting Limit B- Analyte detected

in the associated Method Blank *- Value exceeds Maximum Contaminant Level

mg mg S- Spike Recovery outside accepted recovery limits R- RPD outside accepted recovery limits E- Value above quantitation range T- Tenta1iely dentied Compound (TI()

19 0.50 8.3 0.50

4/6/2009 MEN 4/6/2009 MENANALYTICAL RESULTS

vc 3

Date: 14-Apr-09 Client: DERENZO

& ASSOCIATES, INC.

Work Order No: 09031333 Project: 0901014 Lab ID: 09031333-004A

Client Sample ID: TREP-2 CONT #4/CONT
#5 Matrix: AIR

Tag Number: Collection Date: 3/25/2009 Reporting Analyses

Result Limit Qual Units
DF Date Analyzed Analyst EPA METHOD 202 Inorganic Condensible Particulate Matter Organic Condensible Particulate Mattcr Qualifiers:

ND- Not Detected

at the Reporting Limtt (RL).- Analyte detected below the Reporting Limit B- Analyte detected

in the associated Method Blank * Value exceeds Mairnum Contaminant Level

S- Spike Recovery outside accepted recovery limits R- RPD outside accepted recovery limits E- Value above quantitatlon range- fe tat vely

I den ti lect Co rnpound

( li(

) 19 0.50

mg

1 4/6/2009 MEN 8.6 0.50

4/6/2009 MEN mgANALYTICAL RESULTS

V ER

I TAS

Date: 14-Apr-09 Client: DERENZO

& ASSOCIATES, INC.

Work Order No: 09031333 Project: 0901014 Lab ID: 09031333-006A

Client Sample ID: TREP-3 CONT #4/CONT
#5 Matrix: AIR

Tag Number: Collection Date: 3/25/2009 Reporting Analyses

Result Limit Qual Units
DF Date Analyzed Analyst EPA METHOD 202 Inorganic Condensible Particulate Matter Organic Condensible Particulate Matter Qualifiers:

ND- Not Detected

at the Reporting Limit (RL).- Analyte detected below the Reporting Limit B- Analyte detected
in the associated Method Blank *- Value exceeds Maximum Contaminant evel

mg mg S- Spike Recovery outside accepted recovery limits R- RPD outside accepted recovery limits E- Value above quantitation range I- Ten tatis ely den tiled (‘on pound (TIC)

27 0.50 4.9 0.50

4/6/2009 MEN 4/6/2009 MEN _7, I.,EPA METHOD 202 Inorganic Condensible Particulate Matter Organic Condensible Particulate Matter Qualifiers:

Nt)- Not Detected

at the Reporting Limit (RL).- Analyte detected below the Reporting Limit B- Analyte detected
in the associated Method Blank *- Value exceeds Maximum Contaminant

I evel

S- Spike Recovery outside accepted recovery limits R- RPD outside accepted recovery limits E- ValLie above quantitatlon range 1— Tentati vcl y ldeiio tied C ornpound

(I l( ANALYTICAL RESULTS

Date: 14-Apr-09 Client: DERENZO

& ASSOCIATES, INC.

Work Order No: 09031333 Project: 0901014 Lab ID: 0903 1333-007A

Client Sample ID: TREP-4 CONT #6- H20/CONT #7-MECL2 BLANK Matrix: AIR

Tag Number: Collection Date: 3/25/2009 Reporting 9.9 0.50
mg

I 4/6/2009 MEN 3.8 0.50
mg

1 4/6/2009 MEN
C i-i•;1I;lI’I ANALYTICAL RESULTS

Date: 14-Apr-09 Client: DERENZO

& ASSOCIATES, INC.

Work Order No: 09031333 Project: 0901014 Lab ID: 09031333-008A

Client Sample ID: TREHCL-1 CONT #3 Matrix: AIR

Tag Number: Collection Date: 3/25/2009 Reporting Analyses

Result unit Qual Units
DF Date Analyzed Analyst EPA 26 Hydrochloric Acid

530 500

jig

I 4/6/2009 MLG Qualifiers:

ND- Not Detected

at the Reporting Limit (RL).

S- Spike Recovery outside accepted recovery limits- Analyte detected below the Reporting Limit

R- RPD outside accepted recovery limits 13- Analyte detected

in the associated lethod Blank

E- Value above quantitation ratige *- Value exceeds Maximum Contaminant Level

T- Tentatively Identified Compound (Tl()

0

1ANALYTICAL RESULTS

iu VC

Date: 14-Apr-09 Client: DERENZO

& ASSOCIATES, INC.

Work Order No: 09031333 Project: 0901014 Lab ID: 0903 1333-009A

Client Sample ID: TREHCL-2 CONT #3 Matrix: AIR

Tag Number: Collection Date: 3/25/2009 Reporting Analyses

Result Limit Qual Units
DF Date Analyzed Analyst Qualifiers:

ND- Not Detected
at the Reporting Limit (RL).- Analyte detected below the Reporting Limit B- Analyte detected

in the associated Method Blank *- Value exceeds Maximum Contaminant level

S- Spike Recovery outside accepted recovery limits R- RPD outside accepted recovery limits E- Value above quantitation range T- Fentatively denti tied Compound (IC) EPA 26 Hydrochloric Acid

3,400 500

4/6/2009 MLG

I I

I

IANALYTICAL RESULTS

,U CC

Date: 14-Apr-09 Client: DERENZO

& ASSOCIATES, INC.

Work Order No: 09031333 Project: 0901014 Lab ID: 09031333-OIOA

Client Sample ID: TREHCL-3 CONT #3 Matrix: AIR

Tag Number: Collection Date: 3/25/2009 Reporting Analyses

Result Limit Qual Units
DF Date Analyzed Analyst S- Spike Recovery outside accepted recovery limits R- RPD outside accepted recovery limits E- Value above quantitation range T- Tentatively Identified Compound (TIC) 500

4/6/2009 MLG EPA 26 Hydrochloric Acid

3,500 Qualifiers:

ND- Not Detected
at the Reporting Limit (RL).- Analyte detected below the Reporttng Limit B- Analyte detected

In the associated Method Blank C- Value exceeds Maximum Contaminant Level

ti

I 1)ANALYTICAL RESULTS

inJ ye ;J!Ii VI

Date: 14-Apr-09 Client: DERENZO

& ASSOCIATES, INC.

Work Order No: 09031333 Project: 0901014 Lab ID: 09031333-O1IA

Client Sample ID: TREHCL-4 CONT #6 BLANK Matrix: AIR

Tag Number: Collection Date: 3/25/2009 Reporting Analyses

Result Limit Qual Units
DF Date Analyzed Analyst S- Spike Recovery outside accepted recovery limits R- RPD outside accepted recovery limits E- Value above quantitation range T- Tentatively ldeiiti tied Compound

(1 IC) 420

4/6/2009 MLG EPA 26 Hydrochloric Acid

ND Qualifiers:

ND- Not Detected

at the Reporting Limit (RL).- Analyte detected below the Reporting Limit B- Analte detected

in the associated Method Blank *- Value exceeds Maximum (‘ontaminant Level7 Air A Toxics LTb AN ENVIRONMENTAL ANALYTICAL LABORATORY 4/9/2009 Mr. David Derenzo Derenzo

& Associates 39395 Schoolcraft Road Livonia Ml 48150 Project Name: Trail Ridge Project
#: 0901014 Workorder

#: 0903722A Dear Mr. David Derenzo The following report includes the data for the above referenced project for sample(s) received on 3/27/2009

at Air Toxics Ltd. The data and associated QC analyzed by Modified TO-is (5&20 ppbv) are compliant with the project requirements

or laboratory criteria with the exception
of the deviations noted in the attached case narrative. Thank you for choosing Air Toxics Ltd. for you air analysis needs. Air Toxics Ltd. is committed

to providing accurate data of the highest quality. Please feel free to contact the Project Manager: Ausha Scott at 916-985-1000

if you have any questions regarding the data in this report. Regards, Ausha Scott Project Manager 180 BLUE RAVINE ROAD, SUITE

B FOLSOM, CA- 95630 (916) 985-1000 .FAX (916) 985-1020 Hours 8:00 A.M to 6:00 P.M. Pacific Page lofl3Air 4 Toxics LTD. AN ENVIRONMENTAL ANALYTICAL LABORATORY WORK ORDER
#: 0903722A Work Order Summary CLIENT:

Mr. David Dereazo Derenzo
& Associates 39395 Schoolcraft Road Livonia,Ml 48150

BILL TO: Ms. Donna Povich Derenzo
& Associates 39395 Schoolcraft Road Livonia,Ivll 48150 PHONE: FAX: DATE RECEWED: DATE COMPLETED: 734-464-3880 734-464-4368 03/27/2009 04/09/2009

P.O.# 1002 PROJECT

# 0901014 Trail Ridge CONTACT: Ausha Scott CERTIFIED BY: _)

DATE: 04/09/09 Laboratory Director Certfication numbers: CA NELAP -0211 OCA, LA NELAP/LELAP-

Al 30763, NJ NELAP

- CAOO4 NY NELAP

- 11291, UT NELAP- 9166389892, AZ Licensure AZ0719 Name of Accrediting Agency: NELAP/Florida Department
of Health, Scope of Application: Clean Air Act, Accreditation number: E87680, Effective date: 07/01/08, Expiration date: 06/30/09 Air Toxics Ltd. certifies that the test results contained

in this report meet all requirements

of the NELAC standards This report shall nut he reproduced, except in full, without the written approval of Air Toxics Ltd. 180 BLUE RAVINE ROAD, SUITE

B FOLSOM, CA -95630 (916) 985-1000 (800) 985-5955 FAX (916) 985-1020 RECEWT FINAL FRACTION

# NAME

TEST VAC./PRES. PRESSURE O1A TRE-1
Modified TO-IS (5&20 ppbv)
4.0 “Hg

5 psi 02A

Lab Blank ModifiedTO-15(5&20ppbv)

NA
NA 03A
CCV
Modified TO-15 (5&20 ppbv)
NA
NA 04A

LCS
Modified TO-iS (5&20 ppbv) NA
NA Page 2of13Air 4 Toxics LTD 4 AN ENVIRONMENTAL ANALYTICAL LABORATORY LABORATORY NARRATIVE Modified TO-iS Soil Gas Derenzo
& Associates Workorder# 0903722A One
6 Liter Summa Canister sample was received on March 27, 2009. The laboratory performed analysis via modified EPA Method TO- 15 using GC/MS
in the full scan mode. The method involves concentrating

up to 50 rnLs of air. The concentrated aliquot
is then flash vaporized and swept through

a water management system to remove water vapor. Following dehumidification,

the sample passes directly into the GC/MS for analysis. This workorder was independently validated prior to submittal using ‘USEPA National Functional Guidelines’ as generally applied
to the analysis of volatile organic compounds

in air. A rules-based, logic driven, independent validation engine was employed

to assess completeness, evaluate pass/fail of relevant project quality control requirements and verification of all quantified amounts. Method modifications taken to mn these samples are summarized

in the table below. Specific project requirements may over-ride the ATL modifications. Requirement

TO-IS

A TL ModUications Daily CCV

±- 30% Difference

<1= 30% Difference with two allowed out up to </=40%.; flag and narrate outliers Sample collection media Surmna canister ATL recommends use of summa canisters
to insure data defensibility, but will report results from Tedlar bags at client request Method Detection Limit Follow 4OCFR PL136 The MDL met all relevant requirements

in Method TO-15 App. B (statistical MDL less than the LOQ). The concentration

of the spiked replicate may have exceeded lOX the calculated MDL in some cases Receiving Notes There were no receiving discrepancies. Analytical Notes The canisters
in this work order were pressurized with Helium prior to sampling, per client request. Dilution factors have been adjusted accordingly. Defmition
of Data Qualifying Flags Eight qualifiers may have been used on the data analysis sheets and indicates
as follows: B- Compound present
in laboratory blank greater than reporting limit (background subtraction
no performed).

J- Estimated value. E- Exceeds instrument calibration range. S- Saturated peak. Q- Exceeds quality control limits.
Page 3of13TOXICS LTD. AN ENVIRONMENTAL ANALYTICAL LABORATORY U
- Compound analyzed for but not detected above the reporting limit. UJ- Non-detected compound associated with low bias in the CCV N

- The identification

is based on presumptive evidence. File extensions may have been used on the data analysis sheets and indicates as follows: a-File was requantified b-File was quantified by a second column and detector ri-File was requantified for the purpose of reissue Page

4 of 13Air A Toxics LTD AN ENVIRONMENTAL ANALYTICAL LABORATORY Cumene Propylbenzene 4-Ethyltoluene 1 ,3,5-Trimethylbenzene 1 ,2,4-Trimethylbenzene 1 ,4-Dichlorobenzene Summary
of Detected Compounds MODIFIED EPA METHOD TO-15 GC/MS Rrt. Limit (ppbv) Client Sample ID: TRE-1 Lab ID#: 0903722A-O1A

Amount (ppbv)
Rpt. Limit (uglm3) Amount (uglm3) Compound Freon 12

80
600
390 3000 Vinyl Chloride

80

97
200

250 Ethanol

320 66000

600 120000 Acetone

320 15000

760 36000 2-Propanol

320 18000

780 45000 Hexane

80
250
280

870 2-Butanone (Methyl Ethyl Ketone)

80 17000

230 50000 cis-1,2-Dichloroethene

80

320
320 1300 Tetrahydrofuran

80 3200

230 9600 Cyclohexane

80
220
270
750 2,2,4-Trimethylpentane

80

140
370

640 Benzene

80
950
250 3000 Heptane

80
410

320 1700 Trichloroethene

80

130
430
710 4-Methyl-2-pentanone

80
910

320 3700 Toluene

80 12000

300 47000 Tetrachloroethene

80
250
540 1700 Ethyl Benzene

80 6400

340 28000 m,p-Xylene

80 13000

340 56000 o-Xylene

80 3800

340 16000 Styrene

80
600
340 2600 80
590
390 2900 80
480

390 2400 80 2000

390 9700 80 80 80

800 1700 270
390 390 480 4000 8300 1600 Page 5of 13Freon 12 Freon 114 Chioromethane Vinyl Chloride 1 ,3-Butadiene Bromomethane Chloroethane Freon 11 Ethanol Freon 113 1 ,1-Dichloroethene Acetone 2-Pro parlol Carbon Disulfide 3-C h lo rap rope
n e Methylene Chloride Methyl tert-butyl ether trans-i ,2-Dichloroethene Hexane 1 ,1-Dichloroethane 2-Butanone (Methyl Ethyl Ketone) cis-i ,2-Dichloroethene Tetrahydrofuran Chloroform 1,1 ,i-Trichloroethane Cyclohexane Carbon Tetrachioride 2,24-Trimethylpentane 1 ,4-Dioxane Bromodichloromethane cis-i ,3-Dichloropropene 4-Methyl-2-pentanone Toluene trans-i ,3-Dich)oropropene

80 80 320 80 80 80 80 80 320 80 80 320 320 80 320 80 80 80 80 80 80 80 80 80 80 80 80 80 80 80 320 80 80 80 80 80

600 Not Detected Not Detected 97 Not Detected Not Detected Not Detected Not Detected 66000 Not Detected Not Detected 15000 18000 Not Detected Not Detected Not Detected Not Detected Not Detected 250 Not Detected 17000 320 3200 Not Detected Not Detected 220 Not Detected 140 130 Not Detected Not Detected Not Detected Not Detected 910 12000 Not Detected

390 560 660 200 180 310 210 450 600 610 320 760 780 250 1000 280 290 320 280 320 230 320 230 390 430 270 500 370 430 370 1100 530 360 320 300 360
3000 Not Detected Not Detected 250 Not Detected Not Detected Not Detected Not Detected 120000 Not Detected Not Detected 36000 45000 Not Detected Not Detected Not Detected Not Detected Not Detected 870 Not Detected 50000 1300 9600 Not Detected Not Detected 750 Not Detected 640 710 Not Detected Not Detected Not Detected Not Detected 3700 47000 Nat Detected Air Toxics LTD AN ENVIRONMENTAL ANALYTICAL LA8ORATORY Client Sample ID: ThE-i Lab ID#: 0903722A-O1A MODIFIED EPA METHOD TO-is CC/MS File Name: b040217

Date of Collection: 3/25109 5:05:00 PM Dii. Factor:

15.9

Date of Analysis: 4/2/09 06:12 PM RDt. Limit Amount
Rpt. Limit Amount Compound

(ppbv) (ppbv) (uglm3) (uglm3) Benzene

80
950
250 3000 1 ,2-Dichloroethane

80
Not Detected

320
Not Detected Heptane

80
410

320 1700 Trichloroethene 1 ,2-Dichloropropane

Page 6of 134 Toxics LTD AN ENVIRONMENTAL ANALYTICAL LABORATORY 1 ,2-Dichloroethane-d4 Toluene-d8 4-B ro mofi uo ro benze ne
Client Sample ID: TRE-1 Lab ID#: 0903722A-O1A 1TIrn EPA METHOD TO-IS GC/MS

70-1 30 70-130 70-130 File Name:
b04021

7

Date of Collection: 3125109 5:05:00 PM Dii. Factor:

15.9

Date of Analysis: 412/09 06:12 PM Rpt. Limit Amount
Rpt. Limit Amount Compound

(ppbv) (ppbv) (uglm3) (uglm3) 1,1 ,2-Trichloroethane

80
Not Detected

430
Not Detected Tetrachloroethene

80
250

540 1700 2-Hexanone

320
Not Detected
1300
Not Detected Dibromochloromethane

80
Not Detected

680
Not Detected 1 ,2-Dibromoethane (EDB)

80
Not Detected

610
Not Detected Chlorobenzene

80
Not Detected

360
Not Detected Ethyl Benzene

80 6400

340 28000 m,p-Xylene

80 13000

340 56000 o-Xylene

80 3800

340 16000 Styrene

80
600

340 2600 Bromoform

80
Not Detected

820
Not Detected Cumene

80

590

390 2900 1,1 ,2,2-Tetrachloroethane

80
Not Detected

540
Not Detected Propylbenzene

80
480

390 2400 4-Ethyltoluene

80 2000

390 9700 1 ,35-Trimethylbenzene

80
800

390 4000 1,2,4-Trimethylbenzene

80 1700

390 8300 1 ,3-Dichlorobenzene

80
Not Detected
480
Not Detected 1,4-Dichlorobenzene

80
270
480 1600 alpha-Chiorotoluene

80
Not Detected
410
Not Detected 1 ,2-Dichlorobenzene

80
Not Detected
480
Not Detected 1 ,2,4-Trichlorobenzene

320
Not Detected 2400
Not Detected Hexachlorobutadiene

320
Not Detected 3400
Not Detected Container Type:

6 Liter Summa Canister

Method Surrogates
%Recovery

Limits 101 103 98 Page 70113Air i Toxics LW AN ENVIRONMENTAL ANALYTICAL LABORATORY Freon 12 Freon 114 Chloromethane Vinyl Chloride 1 ,3-Butadiene Bromomethane Chloroethane Freon
11 Ethanol Freon 113 1 ,1-Dichloroethene Acetone 2-Propanol Carbon Disulfide 3-Chioropropene Methylene Chloride Methyl tert-butyl ether trans-i ,2-Dichloroethene Hexane 1 ,1-Dichloroethane 2-Butanone (Methyl Ethyl Ketone) cis-1 ,2-Dichloroethene Tetrahydrofuran Chloroform 1,1 ,1-Trichloroethane Cyclohexane Carbon Tetrachioride 2,2,4-Trimethylpentane Benzene 1 ,2-Dichloroethane Heptane Trichloroethene 1 ,2-Dichloropropane 1 4-Dioxane Bromodichloromethane cis-i ,3-Dichloropropene 4-Methyl-2-pentanone Toluene trans-i 3-Dichioropropene

5.0 5.0 20 5.0 5.0 5.0 5.0 5.0 20 5.0 5.0 20 20 5.0 20 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 20 5.0 5.0 5.0 5.0 5.0

Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected

25 35 41 13 11 19 13 28 38 38 20 48 49 16 63 17 18 20 18 20 15 20 15 24 27 17 31 23 16 20 20 27 23 72 34 23 20 19 23
Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Not Detected Client Sample ID: Lab Blank Lab ID#: 0903722A-02A MODIFIED EPA METhOD TO-is GC/MS File Name: b040206c

Date of Collection: NA Oil. Factor:

1.00

Date of Analysis: 4/2/09 11:58 AM Rpt. Limit Amount
Rpt. Limit Amount Compound

(ppbv) (ppbv) (uglm3) (ug/m3) Page 8of 13Air

- 4 Toxics LTD AN ENVIRONMENTAL ANALYTICAL LABORATORY Client Sample ID: Lab Blank Lab ID#: 0903722A-02A MODIFIED EPA METHOD TO-15 GC!MS File Name: b040206c

Date of Collection: NA DII. Factor:

1.00

Date of Analysis: 4/2/09 11:58 AM Rpt. Limit Amount
Rpt. Limit Amount Compound

(ppbv) (ppbv) (uglm3) (ugIm3) 1,1,2-Trichloroethane

5.0 Not Detected

27
Not Detected Tetrachloroethene

5.0 Not Detected

34
Not Detected 2-Hexanone

20 Not Detected

82
Not Detected Dibromochloromethane

5.0 Not Detected

42
Not Detected 1 ,2-Dibromoethane (EDB)

5.0 Not Detected

38
Not Detected Chlorobenzene

5.0 Not Detected

23
Not Detected Ethyl Benzene

5.0 Not Detected

22
Not Detected m,p-Xylene

5.0 Not Detected

22
Not Detected o-Xylene

5.0 Not Detected

22
Not Detected Styrene

5.0 Not Detected

21
Not Detected Bromoform

5.0 Not Detected

52
Not Detected Cumene

5.0 Not Detected

24
Not Detected 1,1 22-Tetrachloroethane

5.0 Not Detected

34
Not Detected Propylbenzene

5.0 Not Detected

24
Not Detected 4-Ethyltoluene

5.0 Not Detected

24
Not Detected 1 ,3,5-Trimethylbenzene

5.0 Not Detected

24 Not Detected 1 ,2,4-Trimethylbenzene

5.0 Not Detected

24 Not Detected I ,3-Dichlorobenzene

5.0 Not Detected

30
Not Detected 1 ,4-Dichlorobenzene

5.0 Not Detected

30
Not Detected aipha-Chlorotoluene

5.0 Not Detected

26
Not Detected I ,2-Dichlorobenzene

5.0 Not Detected

30
Not Detected 1 ,2,4-Trichlorobenzene

20 Not Detected

150
Not Detected Hexachlorobutadiene

20 Not Detected
210
Not Detected Container Type: NA

- Not Applicable

Method Surrogates
%Recovery

Limits 1,2-Dichloroethane-d4

98
70-130 Toluene-d8

100
70-130 4-Bromofluorobenzene

94
70-130 Paqe 9of13— SAir wAToxics LTD. AN ENVIRONMENTAL ANALYTICAL LAEORATORY 1 2-Dichloropropane 1 4-Dioxane B rom od ich bra methane cis-1 3-Dichboropropene 4-Methyl-2-pentanone Toluene trans-i ,3-Dichboropropene

Client Sample ID: CCV Lab ID#: 0903 722A-03A MODIFIED EPA METHOD TO-15 GC!MS Fe Name: b040202- Date of Collection: NA j Dii. Factor:

1.00

Date of Analysis: 412109 10:40 AM Compound

%Recovery Freon 12

97 Freon 114

92 Chboromethane

106 Vinyl Chloride

98 1,3-Butadiene

96 Bromomethane

105 Chloroethane

98 Freon
11

96 Ethanol

103 Freonli3

93 1 ,1-Dichboroethene

97 Acetone

92 2-Propanol

86 Carbon Disulfide

98 3-Chboropropene

94 Methylene Chloride

99 Methyl tert-butyl ether

98 trans-I ,2-Dichboroethene

94 Hexane

96 1 ,1-Dichboroethane

97 2-Butanone (Methyl Ethyl Ketone)

96 cis-1 ,2-Dichboroethene

95 Tetrahydrofuran

101 Chloroform

95 1,1 ,1-Trichboroethane

92 Cyclohexane

96 Carbon Tetrachboride

87 22,4-Trimethylpentane

98 Benzene

99 1 ,2-Dichloroethane

96 Heptane

100 Trichboroethene

94 95 92 93 93 94 97 89 Page 10 of 13AToxIcs LTD. AN ENVIRONMENTAL ANALYTICAL LABORATORY Client Sample ID: CCV Lab ID#: 0903722A-03A MODIFIED EPA MET[IOD TO—15 (X/MS File Name: b040202

Date of Collection: NA DII. Factor:

1.00

Date of Analysis: 412109 10:40 AM 1,1 ,2-Trichloroethane Tetrachloroethene 2-Hexanone Di brom och to ro methane 1 ,2-Dibromoethane (EDB) Oh to robe nzen
e Ethyl Benzene m,p-Xylene o-Xylene S tyrene Bromoform Cumene 1
1 ,2,2-Tetrachtoroethane Propylbenzene 4-Ethyltoluene 1 ,35-Trimethylbenzene 1 ,2,4-Trimethylbenzene 1 ,3-Dichlorobenzene 1 ,4-Dichtorobenzene 1 ,2-Dichtoroethane-d4 Toluene-d8 4-B romofi uorobenzen

e

%Recovery 96 95 92 92 95 95 95 96 96 96 88 95 96 94 97 94 91 91 88 83 90 107 103 97
70-130 102
70-130 98
70-130 Compound alpha-Chiorotoluene 1 ,2-Dichlorobenzene 1 ,2,4-Trichlorobenzene Hexachiorobutadiene Container Type: NA

- Not Applicable

Method Surrogates
%Recovery

Limits Page llofl34Air. 4 Toxics LTD 4 AN ENVIRONMENTAL ANALYTICAL LABORATORY Client Sample ID: LCS B ro mod ch oro methane cis-1 ,3-Dichloropropene 4-Methy?-2-pentanone Toluene trans-i ,3-Dichloropropene

Lab ID#: 0903722A-04A

90 102 89 100 99 MODIFIED EPA METHOD TO-15 CC/MS File Name: b040203

Date of Collection: NA Dii. Factor:

1.00

Date of Analysis: 4/2/09 10:59AM Compound

%Recovery Freon 12

98 Freon 114

97 Chloromethane

98 Vinyl Chloride

100 1,3-Butadiene

94 Bromomethane

112 Chloroethane

100 Freon
11

99 Ethanol

76 Freon 113

98 I ,1-Dichloroethene

102 Acetone

92 2-Propanol

102 Carbon Disulfide

95 3-Chloropropene

88 Methylene Chloride

104 Methyl tert-butyl ether

104 trans-i ,2-Dichloroethene

91 Hexane

91 1,1-Dichloroethane

101 2-Butanone (Methyl Ethyl Ketone)

93 cis-1 ,2-Dichloroethene Tetrahydrofuran

93 Chloroform

99 1,1 ,1-Trichloroethane

97 Cyclohexane

91 Carbon Tetrachloride

85 2,2,4-Trimethylpentane

91 Benzene

102 1,2-Dichloroethane

99 Heptane

92 Trichloroethene

100 1 ,2-Dichloropropane

99 14-Dioxane

88 Page 12of13Air

- 4Toxics LTD AN ENVIRONMENTAL ANALYTICAL LABORATORY Client Sample ID: LCS Lab ID#: 0903 722A-04A MODF[ED EPA METHOD TO-15 CC/MS File Name: b040203

Date of Collection: NA Dii. Factor:

1.00

Date of Analysis: 412109 10:59 AM 1 ,1 ,2-Trichloroethane Tetrachioroethene 2-Hexanone Dibromochloromethane 1 ,2-Dibromoethane (EDB) C h lorobenzen

e Ethyl Benzene m,p-Xylene o-Xylene Styrene Bromoform Cumene 1,1 2,2-Tetrachloroethane Pro pyl be nzene 4-Ethyltoluene 1 ,3,5-Trimethylbenzene 1 ,2,4-Trimethylbenzerie 1 3-Dichlorobenzene 1 ,4-Dichlorobenzene aipha-Chlorotoluene 1 ,2-Dichlorobenzene 1 ,2,4-Trichlorobenzene H exach lo rob utad len e

%Recovery 102 99 90 91 100 98 100 100 100 106 92 101 101 89 92 96 97 96 93 104 94 104 102 1 2-Dichloroethane-d4 Toluene-d8 4-Bromofluorobenzene

70-130 70-1 30 70-1 30 Compound Container Type: NA- Not Applicable

Method Surrogates
%Recovery

Limits 98 102 98 Page l3of 13

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Ftii i253 rsei1APPENDIXDSAMPLECALCULATIONSEXAMPLE CALCULATIONS Equation

1 a - Dry Molecular Weight: MWd

= 0.440(%C02)

+ O.320(%02)

+ 0.280(%N2

+ %CO) Equation
lb

- Wet Molecular Weight: MWw MWd(l-Bws)

+ 18.0(Bws) Equation 2a

- Meter Volume
at Standard Conditions: Vm(std)

= VmY (Tstd)(Pbar

+ LJH/13.6) (Tm)(Pstd) Equation 2b

- Volume of Water Vapor Condensed: Vwc(std) Kl(Wf-Wi) Equation 2c
- Moisture Content: Bws Vwc(std)/(Vwc(std)

+ Vm(std)) Equation 3a

- Velocity
at a Traverse Point: Vd

= KpCp(T5LIP/PsMWw)” 2 Equation 3b

- Volumetric Flow Rate (Actual Basis): Q

= Vd(avg)Ad
60 Equation
3c

- Volumetric Flow Rate (Standard Basis): Qstd

=
Q (Tstd)(Ps) (Ts)(Pstd) Equation 3d

- Volumetric Flow Rate (Standard Dry Basis): Qstd(dry) Qstd(l-Bivs) Equation 4a — Particulate Matter Concentration: (gr/dscf) PMC (gr/dscf)

= (mg*0.01543)/Vm Equation 4b — Particulate Matter Emission Rate: (lb/hr) PMER (lb/br)

= PMC*0.00858*Qstd Equation 4c — Particulate Matter Emission Rate: (g/bHp-hr) PMER (g/bHp-hr) PMER(lb/hr)

* 453.6

* 0.7457

/ (kW/0.96) Equation 4d — PM-10 Emission Rate: (lb/br) PMI
0 (lb/br)

= PMER(lb/hr)-- Condensible ER(lb/hr) Equation 4e— PM- 10 Emission Rate: (g/bHp-hr) PM1O ER (g/bHp-hr)

= PMER(g/bHp-hr)

+ Condensible ER(g/bHp-hr) Equation 5a— Nitrogen Oxides Concentration (ppmvd) NOxC

= ((NOx pprnvd-avg. zero)
x Cal. Gas conc.))

/ Avg. cal.— Avg. zero)Equation 5b— Nitrogen Oxides Emission Rate: (lb/br) NOxER (lb/br)

= NOxC

x Qstd(dry)

x 46.01

x 0.07524/28950000 Equation 5c — Nitrogen Oxides Emission Rate: (g/bHp-hr) NOxER (g/bHp-hr)

= NOxER (lb/br) *( 453.6 g/ib) 0.7457 kW/bHp)

/ (kW /0.96) Equation 6a — Carbon Monoxide Concentration (ppmvd) COC (ppmvd) (ppmCO

x (1-(%CO 2 /l00)))-avg.
zero)
x Cal. Gas conc.))/ Avg. cal. — Avg. zero) Equation 6b — — Carbon Monoxide Emission Rate: (lb/br) COER (lb/br)

= COC
x Qstd(dry)

x 28.20
x 0.07524/28950000 Equation 6c — Carbon monoxide Emission Rate: (g/bHp-hr) COER (g/bHP-hr)

= (COER (lb/br) *( 453.6 g/ib) 0.7457 kW/bHp)

/ (kW /0.96) Equation 7a — Brake-horse Power (bHp) bHp (kW/0.96)

* bHp/0.7457kW Equation 8a — Hydrogen Chloride Concentration: (gr/dscf) HCIC (gr/dscf)

= (mg*0.01543)/Vm Equation
8b— Hydrogen Chloride Emission Rate: (lb/br) HC1ER (lb/hi)

= HC1C*0.00858*Qstd Equation
8c — Hydrogen Chloride Emission Rate: (lb/MMsct) HCIER (lb/MMscf)

= HCIER(lb/hr)

/ MMscf/hr fuel consumption SYMBOL IDENTIFICATION Ad Area of duct (ft 2 ) bHp Brake-horse Power Bws

= Water vapor in gas stream, proportional
by volume COC Carbon monoxide concentration (ppmvd) COER

= Carbon monoxide emission rate (lb/br) Cp

= Pitot tube calibration factor (unitless) Ki Constant (0.047 15 fi 3 /g) Kp

= Constant (85.49) kW Kilowatt lb/MMscf pounds per million standard cubic foot MWd

= Duct gas dry molecular weight (lb/lb-mole) MWw

= Duct gas wet molecular weight (lb/lb-mole) NOxC

= Nitrogen Oxides Concentration (ppmvd) NOxER

= Nitrogen Oxides Emission Rate (g/bHp-hr) Pbar

= Barometric pressure (“Hg) PMC

= Particulate matter concentration (gr/dscf) PMER

= Particulate matter emission rate (lb/hi) PMIOER PM-l0 emission rate (g/b}lp-hr)Ps Absolute stack pressure (“Hg) Pstd

= Standard pressure (29.92”Hg) Q

= Duct volumetric flow rate (actual cfiu) Qstd
Duct volumetric flow rate (scfrn) Qstd(dry)
Duct volumetric flow rate (dscfm) Tm Absolute temperature

at meter (°R) Ts

= Absolute temperature
of duct gas (°R) Tstd

= Standard temperature (528°R) Vd
Duct velocity
at a traverse point (flJs) Vm

Dry test meter volume (cf) Vm(std)

Dry test meter volume
at standard conditions (scf) Vwc(std) Volume of water vapor condensed

at standard conditions (scf) Wf Final weight of impinger/absorber train (g) Wi

= Initial weight of impinger/absorber train (g) Y

= Dry test meter calibration factor (unitless) %C02

= Duct gas carbon dioxide content (%volume) %CO
Duct gas carbon monoxide content (%volume) %N2

= Duct gas nitrogen content (%volume) %02

= Duct gas oxygen content (%volume) AH

= Pressure drop across orifice (“H20) tiP Pressure drop across pitot tube (“H20)APPENDIXEPROCESSDATATrailRidgeEnergySourcetestingUnit#4March252009LandfillgasQualityisrunning@48.9%methane39.3%co21.47%oxygenTimeKwFuelFlow8:0016145388:1515925368:3015995378:4516145399:0016045389:45159653610:00161254010:15160753710:30161554010:45159353711:30160453911:45161254012:00159853712:15159153612:30159554047.4%methane38.03%co21.8%oxygen14:00160655314:15160055014:30159054814:45159855015:00161055416:00159553916:15161254516:30160254316:45159754317:00159454118:00160654518:15159254018:30159854118:45160454219:00159253848.4%methane38.9%co21.4%oxygenAPPENDIXFDETAILEDDESCRIPTIONSOFSAMPLFNGPROCEDURESINSTRUMENT SAMPLING AND CALIBRATION PROCEDURES 1.0 Extractive Gas Sampling System for Instrumental Analyzers The extractive gas sampling system that serves the instrumental analyzers used for Methods 3A, 7E, 10 18 and 25A was configured

as described below. Sample probe- Stainless steel single opening probe located
at predetermined sampling locations within the exhaust stack cross-section. Three-way valve

- A stainless steel three-way valve is installed between the sample probe and
a stainless steel particulate filter to allow the introduction

of calibration gases into the sampling system. The three-way valve is turned toward the desired gas flow direction during this sampling. During system bias checks, excess calibration gas exits the sampling probe tip to avoid the introduction
of process gas or ambient air during calibration. Heated sample line— A heated Teflon® line is used to transport the sample gas from the stack to the instrument rack. The heated Teflon® line is equipped with

a temperature controller which maintains the temperature
of the sample line at approximately 250°F to prevent moisture condensation. Sample pump and flow control valve— A single head 100% oil-free vacuum pump fitted with

a stainless steel flow control valve is used to transfer sampled gases from the heated sample line to the instrumental analyzer. The vacuum pump
is leak-free and non-reactive

to the gases being sampled. Subsequent sample transport lines and fittings are either stainless steel or Teflon®. Gas Conditioner- A refrigerant-based condenser equipped with
a peristaltic pump is used to remove moisture from the sampled gas stream that is directed
to the instrumental analyzers, which require

a conditioned (or dry) gas samples. From the moisture removal system,

a sample gas manifold constructed
of Teflon® transport lines and stainless steel Tee fittings
is used to continuously deliver the sampled gas to the instrumental analyzers. Since the instrumental analyzers are equipped with internal sampling pumps, the end of the sample gas manifold

is equipped with an atmospheric dump (or bypass discharge vent) to avoid over pressurization

of the instrumental analyzers. Data Logger— A data logging system
is used to record I-minute average data from the analog output of the instrumental analyzers. 2.0 Instrumental Analyzer Quality Assurance

/ Calibration Procedures Upon site arrival, the instrumental analyzers are set-up in accordance with the manufacturer’s written recommended procedures. Upon setting the appropriate range for the instrument, zero and appropriate span gases are introduced sequential order to verify instrument accuracy (three- point analyzer calibration error test).Prior to the first test run, appropriate upscale and low-range (zero) span gases are introduced

in series at the three-way valve in the sampling system. This dynamic calibration procedure

is the sampling system bias check, and the analyzer’s response time is recorded. The start of the test run occurs when the calibration gases are cleared from the sampling system and the data acquisition system records

a consistent instrumental analyzer response on the stack gas sample (at least twice the system response time is allowed
to verify representative readings). At the conclusion
of the sampling period, appropriate upscale and low-range (zero) gases are re introduced

in series at the three-way valve in the sampling system to check against the method’s performance specifications
for calibration drift and zero drift error. If the drift error is within 3% of the span over the period of the test run, the test run is considered acceptable 3.0 Isokinetic Sampling System and Procedures for PM-l0 PM-l0 concentrations
are equal to the sum of the USEPA Method

5 sampling train (filterable) and the USEPA Method 202 sampling train (condensible) measured values. Therefore, combining the results of the
5 and 202 sampling train was performed for the determination

of PM-l0 concentrations and emission rates from the engine exhaust. A preliminary traverse of the duct was performed

to determine duct velocity head and temperature distributions,

as well as duct static pressure. Preliminary Method

3 and 4 runs were performed

to determine duct moisture and fixed gas content. Based on this information,

a sample nozzle of appropriate inside diameter was selected, and the impinger train charged
as described below. Traverse points were marked on the probe. Sample time per traverse point was calculated based on the total anticipated sampling time. A “goose-neck’ nozzle constructed
of stainless steel was connected via stainless steel Swagelok® fitting to a borosilicate glass probe liner within

a stainless steel probe. Attached

to the sample probe was
a Stausscheibe (Type S) pitot tube and type K thermocouple which was used to measure duct velocity head pressure and temperature. The probe liner was attached
to a glass filter holder containing

a glass fiber filter. The back half of the filter holder was connected via connecting glassware, with temperature monitoring probe, to the impinger train. The impinger train consisted of a set of impingers, connected
in series and immersed
in an ice bath. Crushed ice was placed around the impingers

to keep the temperatures
of the gases leaving the last impinger

at 68 °F or less. The train was constructed and charged
as follows: Standard Greenberg-Smith (G-S) impinger containing 100 ml of DI H 2 0; Standard G-S impinger containing 100 ml of DI H 2 0; Modified G-S impinger containing 100 ml of DI H 2 0; Modified G-S impinger containing approximately 200- 300 grams of pre-dried silica gel and glass fiber. The sampling train was followed
in series by an umbilical line, dry gas meter and calibrated orifice connected

to an inclined manometer. Type-K thermocouples were used to measure the stack, impinger outlet, and dry gas meter inlet and outlet temperatures.

A carbon vane pump was used to provide the necessary vacuum for the sampling train.paper will used to verify the p1-I of the contents.
If the verified pH was less than 4.5 after each test then

a nitrogen purge was performed. The samples were recovered into appropriate, pre-cleaned jars with Teflon liners. The samples were clearly and uniquely marked prior to shipment. Shipment was performed

in accordance with the prescribed procedures
of the International Air Transport Association for dangerous goods if applicable. 4.0 Isokinetic Sampling System and Procedures for HC1 Hydrogen chloride concentrations and emission rates are determined
by isokinetically drawing stack gas from the source through

a filter and
a 0.1 Normality of Sulfuric acid (0.1 N H 2 S04) absorbing solution. The filter collects particulate matter including halide salts but is not routinely recovered
or analyzed. Acidic and alkaline absorbing solutions collect the gaseous hydrogen halides and halogens, respectively. A preliminary traverse of the duct was performed

to determine duct velocity head and temperature distributions,

as well as duct static pressure. Preliminary Method

3 and 4 runs were performed

to determine duct moisture and fixed gas content. Based on this information,

a sample nozzle of appropriate inside diameter was selected, and the impinger train charged
as described below. Traverse points were marked on the probe. Sample time per traverse point was calculated based on the total anticipated sampling time. A ‘goose-neck nozzle constructed
of borosilicate glass was connected via stainless steel Swagelok® fitting to a borosilicate glass probe liner within

a stainless steel probe. Attached
to the sample probe was
a Stausscheibe (Type S) pitot tube and type K thermocouple which was used to measure duct velocity head pressure and temperature. The probe liner was attached
to a glass filter holder containing

a quartz filter. The back half of the filter holder was connected via connecting glassware, with temperature monitoring probe, to the impinger train. The impinger train consisted of a set of impingers, connected

in series and immersed

in an ice bath. Crushed ice was placed around the impingers

to keep the temperatures
of the gases leaving the last impinger

at 68 °F or less. The train was constructed and charged
as follows: Standard Greenberg-Smith (G-S) impinger containing 100 ml of 0.1 N H 2 S0 4 ; Standard G-S impinger containing 100 ml of 0.1 N H 2 S0 4 ; Modified G-S impinger empty; Modified G-S impinger containing approximately 200- 300 grams of pre-dried silica gel and glass fiber. The 0.1 N NaOH impingers required by USEPA Method 26A were replaced with an empty knockout impinger,

as chloride concentrations
are not required for this compliance emissions testing event. The sampling train was followed
in series by an umbilical line, dry gas meter and calibrated orifice connected

to an inclined manometer. Type-K thermocouples were used to measure the stack, impinger outlet, and dry gas meter inlet and outlet temperatures.

A carbon vane pump was used to provide the necessary vacuum for the sampling train.The sample train was assembled

as completely

as possible
in the staging area and transported

to the sampling site. Openings were sealed with aluminum foil to prevent potential contamination of the sample train prior to final assembly. Once in the sampling area, each train was assembled and each apparatus was leak checked. Upon successful completion
of the leak check, the initial dry gas meter reading was recorded. The engine exhaust sampling locations were selected based on the availability
of straight duct, which meet the requirements

of USEPA Method

1. Prior to performing the HCI sampling, preliminary flowrate measurements were obtained for the proper operation of the metering console. The preliminary traverse velocity pressure values were used during the isokinetic testing rather than concurrent measurements

of the velocity pressures. This approach was necessary

to eliminate high biased flow rate measurements encountered when concurrent measurements
are conducted. The high bias is caused by the high static pressure encountered

at the sampling locations within the ductwork because of the close proximity

to the muffler. The dry gas meter temperatures were recorded on the data sheets. The isokinetic-sampling
rate in terms of pressure drop across the calibrated orifice were calculated and recorded on the data sheets. The pump and timer was turned on, and the sample rate adjusted
to correspond

to the calculated isokinetic rate. Once the sample rate is set, the following data was recorded: - Dry gas meter inlet and outlet temperatures - Sample vacuum - Probe temperature - lmpinger outlet temperature - Filter holder outlet temperature - Orifice differential pressure- Sample volume (dry gas meter readings) At the end of the sample time for the first point, the probe was moved to the next point; sampling and recording of data was repeated. Upon completion
of sampling (each traverse), the probe, and nozzle was removed from the port. The sampling train assembly was placed into the next traverse port and the previously described sampling procedures were repeated. When the sample run was complete, the final, dry gas meter reading was recorded. The probe and filter assembly were removed from the sampling port and allowed
to cool. A post-test leak check was performed
on the sampling train at a vacuum
at least as great as that of the highest sample vacuum measured during each sample run. The final leak rate was recorded on the data sheets. The sample train was sealed from contamination and transported

to the staging area for recovery. Recovery consisted of the measurement

of the liquid in the acid impingers

to +1 ml by using

a graduated cylinder or by weighing

it to +0.5
g by using

a balance. The impinger contents were quantitatively transferred

to a leak-free sample storage container.

A rinse of the impingers and connecting glassware including the back portion of the filter holder (and flexible tubing, if used) was conducted with water and was added to the storage container. The container was sealed,shaken
to mix, and labe’ed. The fluid level was marked so that if any sample
is lost during transport,

a correction proportional

to the lost volume can be applied. The Alkaline impinger (or empty knockout impinger) catch was measured and recorded for the determination

of the stack gas moisture content.