DAQ-2024-008640

1

DAQC-610-24
Site ID 10327 (B5)
MEMORANDUM

TO: CEM FILE – INTERMOUNTAIN POWER SERVICE CORPORATION (IPSC)

THROUGH: Harold Burge, Major Source Compliance Section Manager

FROM: Rob Leishman, Environmental Scientist

DATE: June 21, 2024

SUBJECT: Source: Units 1 and 2 (coal fired boiler/steam turbine generator units)
Contact: Mike Ferrell – 435-864-6487
Location: 850 Brush Wellman Road, Delta, Millard County, UT
Test Contractor: Catalyst Air Management
FRS ID#: UT0000004902700010
Permit/AO#: Title V operating permit# 2700010005 dated
September 12, 2018
Subject: Review of RA/PST Protocol dated May 15, 2024

On May 23, 2024, DAQ received a protocol for a RA/PST (relative accuracy/performance specification
test) of the IPSC Units 1 and 2 in Delta, UT. Testing will be performed on July 11-15, 2024, to determine
the relative accuracy of the CO2, NOX, SO2, and flow monitoring systems.

PROTOCOL CONDITIONS:

1. RM 1 used to determine sample velocity traverses: OK
2. RM 2G or 2H used to determine stack gas velocity and volumetric flow rate: OK
3. RM 3A used to determine dry molecular weight of the gas stream: OK
4. RM 4 used to determine moisture content: OK
5. RM 6C used to determine SO2 emissions: OK
6. RM 7E used to determine NOX concentrations of emissions: OK
7. RM 19 used to determine volumetric flow: OK
DEVIATIONS: No deviations were noted.

CONCLUSION: The protocol appears to be acceptable.

RECOMMENDATION: Send attached protocol review and test date confirmation notice.

ATTACHMENT: IPSC RA/PST Test Plan

1 8 2
lntermountain Power Service Corporation
May !5,2024 UTAH DEPARTMENT OF
ENVIRONMENTAL OUAUTY
Mr. Bryce Bird, Director
Utah Department of Environmental Quality
Division of Air Quality
195 North 1950 West
PO Box L44820
Salt Lake City, UT 847L4-482O
Dear Mr. Bird:
DiViSiON OF AIR QUALITV
I ntermountain Generating Station
Continuous Emission Monitorins Svstems (CEMS)
2024 Relative Accuracv Test Audit
lntermountain Power Service Corporation (IPSC) has scheduled the Relative Accuracy Test Audit (RATA)
for lntermountain Generating Station's Units l and 2. Testing is scheduled July 11to July L5,2024.Ihe
testing will be coordinated by IPSC, and performed by Catalyst Air Management personnel.
Attached is the CEMS Relative Accuracy Test Plan for your review and approval. UDAQ personnel are
invited to observe the testing.
Based on the information and belief formed after reasonable inquiry, I certify that the statements and
information in the document are true, accurate, and complete.
lf you have any questions or comment, please contact Mr. Michael Ferrell at [phone] or
michael.ferrell @ ipsc.com.
Sincerely,
fur qfu,/,,,,-"
Jon A. Finlinson
President and Chief Operations Officer and Responsible Official
nr"A-'tt'-
MAF/HBl:he
Attachment
Gregory S. Huynh
Tamer Ellyahky
Mike Utley
850 West Brush Wellman Road, Delta, Utah,84624 lTelephone: (4351864-M14 I FAJ: [phone] / Fed. LD. #87-0388573
INTERMOUNTAIN GENERATING STATION
RELATIVE ACGURACY TEST PLAN
UNIT 1 AND 2
TITLE V OPERATING PERMIT
#2700010005
oRrsPL# 06481
FRS# 110000470053
July 10 - 15,2024
UTNN OEPRRTMENT OF
E NVI RO N l\,lE I'ITAL g UAtlT'f
MAY ?3 2024
INTERMOUNTAIN POWER SERVICE CORPOMTION
PROJECT FACT SHEET
NAME OF SOURCE OWNER: Intermountain Power Agency
10653 South River Front Parkway
South Jordan, UT 84095
OPERATING AGENT: Los Angeles Department of Water and Power
111 Hope St.
Los Angeles, CA 90012
SOURCE OPERATIONS: Intermountain Power Service Corporation (IPSC)
850 West Brush Wellman Rd
Delta, uT 84624
ryPE OF OPERATION: Coal Fired Steam Electric Generating Unit (EGU)
SOURCE IDENTIFICATION: Units l SGA and 2SGA
SOURCE LOCATION: 850 West Brush Wellman Road
Delta, Utah84624
President and Chief Operations Officer: Jon A. Finlinson
Environmental Section Supervisor: Mike Utley
Test Coordinator, site contact: Michael Ferrell, 435-864-4414 ext.6487
Test Contractor: Catalyst Air Management, Inc.
2505 Byington-Solway Road
Knoxville, Tennessee 37 93 |
Regulatory Oversight: Utah Department of Environmental Quality
Utah Division of Air Quality
P.O. Box 144820
Salt Lake City, UT 84114-4820
1.0 INTRODUCTION
This document presents the objectives of the test protocol program and the approach that will be
used to achieve the compliance objectives. Section 1 .l presents a summary of the test program,
the AETB and QSTI requirements. Section 2.0 presents a general description of the Electric
Generating Units (EGU) and process, the Continuous Emission Monitoring Systems (CEMS),
and the reference method sample locations. The test program objectives, test matrix and
schedule, and the test procedures that will be used in this test program are presented in Section
3.0.
The RATA testing shall take place July 11 - 15, 2024. If additional testing is required, it will be
performed as soon as practical. Testing is contingent on the Electrical Generating Unit(s)
availability.
1.1 TEST PROGRAM SUMMARY
The Clean Air Act (CAA) of 1990 required all major utilities to install Continuous Emissions
Monitoring Systems (CEMS) to measure NOx and SOz emissions. The CEMS requirements of
the CAA, 1990, are presented in the Code of Federal Regulations (CFR) 40Part75. Units I and
2 arelocated at Intermountain Power Project (IPP), approximately 12 miles north of Delta, Utah.
In addition to the requirements of the CAA, both Units have CEMS installed at the inlet to the
wet scrubber. These CEMS were installed to meet the requirements of 40 CFR Part 60 and
Utah State regulations.
Since the CEMS at the stack and the inlet to the scrubber (WFGD) were installed to meet
different regulations, they have different audit requirements. One of the audit requirements for
both regulations is to perform a Relative Accuracy Test Audit (RATA). The RATAs have to be
performed periodically. The frequency of the RATAs depends on which regulation the CEMS
were installed to meet. Briefly, the RATA requirernents are:
l. 40 CFR Part 60 requires an annual RATA to be performed on the CEMS.
2. 40 CFR Part75 requires a semiannual RATA. However, 40 CFR Part75
provides an incentive to reduce the frequency of the RATAs. The incentive is
based on the relative accuracy (RA) during the previous RATA. If the RA is
below 7.5 percent, the next RATA has to be performed within four quarters (or
annually) instead of semiannually. The RATA incentive requirements are
presented in Part 75, Appendix B, Section2.3.
The last RATA on all of these CEMS was performed in the Third Quarter of 2023. The primary
objective of this test program is to perform RATAs on:
1. The stack constituent analyzers: NOx, SOz, and COz stack flow rate CEMS.
2. The WFGD Inlet constituent analyzers: SOz andCOz.
I.2 AETB AND QSTI REQUIREMENTS
The testing for the Part75 CEM systems must be performed by an Air Emission Testing Body
(AETB) with a Qualified Individual (QI). PSC intends to meet this requirement through a
qualified contractor. The Contractor, Catalyst Air Management, Inc. shall submit to the IPSC
test coordinator all relevant information for compliance with the 40 CFR Part 75 AETB
requirements. The Inlet to the scrubber CEM's testing will be performed by Catalyst personnel.
2.0 GENERATING UNIT DESCRIPTION
The Federal EGU identification numbers are 1SGA and 2SGA.
2.I PROCESS DESCRIPTION
Units I and2 are identical, each consisting of a Babcock and Wilcox utility boiler and General
Electric steam turbine generator. The Units bum a western bituminous coal. Both boilers are
natural circulation, radiant reheat units designed for a continuous rating of 6,900,000 lb/hr of
superheated steam. Each Unit is capable of generating approximately 950 MW. Steam at the
superheater outlet is at2,412 psig and 1,005o F. Steam temperature at the reheater outlet is at
1,005" F. The furnaces are opposed wall fired with24 burners in 4 rows and 6 columns on each
wall for a total of 48 burners. The flow through the burners on each wall is designed to enter the
boiler in a clockwise direction from one side and in a counter-clockwise direction from the other
side. Eight mills feed fuel to each Unit. Each mill supplies coal to one row of burners on each
side of the furnace.
Both Units have emission controls for particulate and sulfur oxides. The flue gases leaving the
boiler pass through a fabric filter baghouse and a Wet Flue Gas Desulfurization (WFGD) unit.
There are four induced draft fans between the baghouse and WFGD. After passing through the
WFGD, the flue gases are discharged into the atmosphere through a fiberglass liner. The
fiberglass liners are enclosed in a concrete stack annulus.
2,2 CEMS DESCRIPTION
The CEMS on both Units I and2 were originally supplied by Graseby STI of Waldron,
Arkansas. There is a CEMS at the stack and a CEMS at the inlet to the WFGD on each Unit.
All the CEMS are extractive, out-of-stack, dilution systems and use ambient analyzers to monitor
the gaseous emissions for COz, SOz, and NOx. The CEMS are updated as different pieces of the
equipment reach their end of life cycle.
CEMS at the Stack
The CEMS at the stack were installed to meet the requirements of 40 CFR Parts 60 and75.
Each Unit has a COz, SOz, NOx, and stack gas volumetric CEMS. The ranges of the monitors
(analyzers) used in the CEMS installed at the stack are presented in Table 2-1.
The stack gas flow rate monitoring system uses an Stype pitot tube (manufactured by EMRC) to
measure the velocity of the stack gases. There are two pitot tubes installed 180 degrees apart.
The differential pressures from both pitots are averaged to determine the average stack gas
volumetric flow rate.
Signals from the monitors use Opto-22UOboards to gather data and send it to the PC
controllers. The PC reduces the emissions data and sends raw and calculated data to a file
server for storage. A workstation is used to interface with the file server to generate the
quarterly reports and to perform additional calculations.
TABLE 2.1
ANALYZERSIVIONITORS USED IN THE CEMS AT THE STACK
UNITS 1 AND 2
IPP
Parameter Measurement
Principle
Full Span
Range
Comments
NOx Chemiluminescent 500 ppm
1,000 ppm
Dual Range
SOz Pulsed Fluorescence 50 ppm
1,000 ppm
Dual Range
COz Non-Dispersive Infrared 20%Single Range
Stack Flow Differential Pressure
S-type Pitot
179705.6 kscflr Single Range
CEMS at the Inlet to the WFGD
There are NOx, SOz, and COz CEMS installed at the inlet to the WFGD. The SOz and COz
CEMS were installed to meet Part 60 and state regulations. The systems at the inlet to the
WFGD are similar to the CEMS at the stack except for the following differences:
l. Stack gas volumetric flow monitoring systems are not required.
2. Reporting in units of measure.
For this application, 40 CFR Part 60 does not require monitoring mass emission rates. Hence, a
flow monitoring system is not required at the inlet to the WFGD (scrubbers). The reporting
units of measure for emissions at the inlet to the WFGD are different from those at the stack.
Part 60 emissions have to be reported in units of the applicable standard. In this case, the units
of the applicable standard are lbs/mmBtu. Table 2-2 presents the ranges of the analyzerc used in
the CEMS at the inlet to the WFGD.
TABLE,2-2
ANALYZERS/MONITORS USED IN THE CEMS AT THE
WFGD INLET
UNITS 1 AND 2
IPP
Parameter Measurement
Principle
Full Span
Range
Comments
NOx(r)Chemiluminescent 500 ppm
1,000 ppm
Dual Range
SOz Pulsed Fluorescence 500 ppm
1,000 ppm
Dual Range
COz Non-Dispersive Infrared 20%Single Range
(1) Not required by 40 CFR Part 60
2.3 SAMPLE LOCATION
A brief description of the reference method sampling locations at the stack and the inlet to the
WFGD are presented below. At both of these locations, the Unit CEMS is located in close
proximity to the reference method sampling location.
Reference Method Sample Location at the Stack
A schematic of the stacks for Units I and 2 is presented in Figure 2- I . Units I and 2 are
identical Units. The flue gases from the scrubbers discharge into the atmosphere through
separate fiberglass liners enclosed within a common concrete stack. The flue gases from each
WFGD enter the concrete stack horizontally. The gases then make a 90 degree vertical turn at
an elevation of 1 17 feet above grade (the vertical portion of the stack starts at this elevation).
The reference method sample location plane (the unit CEMS is also at this location) is at an
elevation of approximately 356 feet above grade. There are four ports equally spaced around
the circumference of the stack. The stack diameter at the reference method sample location is
28 feet. The reference method sample location is 8.5 diameters downstream and more than2
diameters upstream of any disturbances.
Methods 3A,4,6C, and 7E tests will be performed using a three-point traverse. The three
points will be located across the stack at 4.7,14, and 23.3 feet corresponding to 16.7,50, and
87.3 percent of stack diameter. Optionally, a twelve point stratification test may be performed
to allow for a single point traverse for the above methods testing. Methods 2,2F, andlor 2G, will
be performed using a twelve-point to sixteen-point traverse, depending upon the method
requirement. If required, a Method 2H will be performed to determine the near Wall Affect
Factor (WAF). The sample points will be located using the stack inside diameter (inside
diameter is 28 feet) and the table for non-particulate traverses from EPA Method 1, Appendix A,
40 CFR Part 60. The as measured diameter for the stack Units are; 1SGA 27.883':334.600",
2SGA 27.859':334.31". These measurements were made January 15,2013 by a licensed
surveyor.
Reference Method Sample Location at the Inlet to the WFGD
On both Units, the reference method sample locations at the inlet to the WFGD are identical to
each other. Flue gases from the baghouse are exhausted into a common plenum through four ID
fans. This plenum is approximately 50 feet wide by 2l feet high. The common plenum tums
into a duct that feeds the six WFGD units. This duct is parallel at the top and tapers at the
bottom. The reference method sample ports are adjacent to each other. A schematic of the
sample location at the inlet to the WFGD is presented inFigne2-2.
Methods 3A and 6C tests will be performed using a three-point traverse. Since this sample
location is ahead of the WFGD, the three points that will be used for the reference method tests
will be located at 1.2, 1 .6, and 2.0 meters from the top inside wall of the duct and near the center
of the duct. Stratification tests were conducted on the Inlet to the WFGD by CARNOT.
It was recofllmended that three sample points be used for reference method tests. This location
near the center of the duct represents the average concentration within the duct for each Unit.
Figure 2-1 Stack Reference Method Sample Location
Refertrce Method
Sample L@ation
Figure 2-2lnletto WFGD Reference Method Sample Location
2I'
-ITo
Scrubber
8
3.0 TEST PROGRAM
3.1 TEST PROGRAM OBJECTIVES
The primary objective of this test program is to perform RATAs on the CEMS installed on
Units: 1SGA, 2SGA, at the IGS, Delta, Utah. The RATAs are being performed to meet the
requirements of 40 CFR Parts 60 and75. The specific objectives are:
1. At the stack, the CEMS RATA for NOx, SOz, and COz, shall be performed at the
second normal load condition. The stack flow rate will be performed at the
Three (3) required load ranges.
2. At the inlet to the WFGD, RATAs shall be performed on the SOz and COz
CEMS.
TABLE 3.1
TEST MATRIX
RELATIVE ACCURACY TEST AUDIT
IPP UNITS 1 AND 2
(1) Minimum of nine runs.
(2) 40 CFR Part 60 and 75 RATAs at the stack.
(3) 40 CFR Part 60 RATAs at inlet.
(4) The testing this year is Two (2) load, normal and second normal load for the flow
monitors.
I
Sample
Location
System Parameters RATA Units No. of
Runs(r)
Comment
Stack(2)Primary NOx lbs/mmBtu 9
9
9
g$)
Second
Normal Load
Load
SOz ppm and
lbs/mmBtu
COz oh or %oCOz
Flow Rate scfh
Inlet(3)Primary SOz Ibs/mmBtu 9 >50o/o Rated
Load
COz o/o or o/oCOz 9
Notes:
TABLE 3-2
TEST SCHEDULE
RELATIVE ACCURACY TEST AUDIT
IPP UNITS 1 AND 2
2024
The proposed test dates and times for this program are presented in Table 3-2. However,
Unit operation and test load may change due to Electrical Generation dispatch uncertainty.
As such, altemate testing schedules may occur during this period due to reference test equipment
logistical requirements, and or, ECC load requirements.
Day Date f,'rom To Unit Load Activity
luly 10,2024
Wednesday
7:00 l7:00 Security Training, Testing
equipment setup.
Stratification tests
2
July 11,2024
Thursday
05:00
10:00
08:00
17:00 1
Stack
385 MW
625MW
385 MW Flow
625 MW Flow and Gas
SOz, COz, NOx.Flow
J
July 12,2024
Friday
05:00
10:00
08:00
17:00 2
Stack
385 MW
625MW
385 MW Flow
625 MW Flow and Gas
SOz, COz, NOx, Flow
4
Ju,ly 13,2024
Saturday 7:00 l7:00
1
Inlet
>485MW Inlet SOz, COz
5
July 15,2024
Monday
7:00 l7:00
2
Inlet >485MW Inlet SOz, COz
10
3.2 TEST PROCEDURES
A summary of the test methods that shall be used in this program is presented in Table 3-3. The
40 CFR Part75 RATAs will be performed with the Unit at the required operating conditions.
The 40 CFR Part 60 RATAs shall be performed with the Unit at the required operating
conditions. The RATAs shall be performed using the procedures presented in 40 CFR 75,
Section 6, Appendix A and 40 CFR 60, Appendix A.
TABLE 3.3
REFERENCE METHODS
Notes:
(l) Minimum number of runs for each RATA.
Primary NOx, SOz, and COz CEMS tests shall be performed at the Second Normal load.
(2) Minimum 9 runs per load range for flow. Load profile shall be calculated prior to the
RATA.
(3) Sample run time shall meet the standard of not less than 21 minutes and correct sample
volume for moisture. Collected data is compared against the I minute and or 15 minutes
data for the CEMs.
Parameter Measurement
Principle
EPA
Reference
Method
Sample
Time,
Minutes
Number
of Runs(l)
Comments
NOx Chemiluminescent 7E 30(3)I At Second Normal Load at
the stack.
SOz Ultra-Violet 6C 30(3)9 At Second Normal Load at
the stack,
> 50o of rated load at the
inlet to scrubber.
COz NDIR 3A 30(3)9 At Second Normal Load at
the stack, > 5ooh of rated
load at the inlet to scrubber
and at all loads for
molecular weight.
Oz Electrochemical
Cell
3A 30(3)9 At all loads for molecular
weight.
Flow rate Differential
Pressure
2,2F,2G,
2H
As
Required
gQ)At required load ranges, at
the stack only.
Moisture Condensation/
Gravimetric
4 30(3)9 At all loads at the stack
only.
11
4.0 DATA CALCULATIONS AND PER RUN ASSESSMENTS
The contractor shall submit in the bid return package a list of formulas and calculations for the
methods to be performed. An example spreadsheet for each of the methods and data entry field
sheets must accompany the bid package.
List of Expected Reference Methods:
EPA Method 1 Sample and Velocity Traverse for Stationary Sources
EPA Method2G Determination of Stack Gas Velocity and Volumetric Flow Rate
with Two-Dimensional Probes
EPA Method 2H Determination of Stack Gas Velocity and Volumetric Flow Rate
Taking into Account Velocity Decay Near Stack Wall
EPA Method 3,A. Gas Analysis for COz, 02, Excess Air, and Dry Molecular Weight
( Instrum en tal Analy zer Method)
EPA Method 4 Determination of Moisture Content in Stack Gas
EPA Method 6C Determination of SOz Emissions from Stationary Sources
( Instrumen tal Analy zer Method)
EPA MethodTB Determination of Nitrogen Oxides Emissions from Stationary
Sources (Instrument al Analyzer Method)
4.I ASSESSMENTS
After the performance of each run the contractor shall furnish the collected run data to the IPSC
test coordinator for data evaluation and preliminary assessment by the State Regulatory
Observer. This data shall be in a timely manner but as not to impair the ability of the contractor
to continue the testing program. A11 completed field data sheets shall be provided to the IPSC
test coordinator for photocopying. Transfer of data can be both electronic form and paper form.
IPSC and the State Regulator separately and individually have assessment tools available for the
data evaluation. However, IPSC reserves the right to require full access to the Contractors'
active spreadsheet function and calculation routines. The foregoing requirement is for DATA
verification and validation error checking during source testing.
4.2 METHOD 7E NOX ANALYZER CONVERTER EFFICIENCY
The testing Contractor shall perform the NO2-NO efficiency test for the converter prior to the
beginning of the first field test at this location.
12
4.3 CONTRACTOR QUALITY ASSURANCE PROGRAM DOCUMENTS
The Contractor shall submit their Quality Assurance Program procedures for the AETB and all
necessary information required for the Qualified Stack Test Individual(s) that will be performing
the tests and data collection.
4.4 PROTOCOL GAS VERIFICATION PROGRAM
The Contractor shall submit a copy of the reference gas cylinder calibration certificates to the
IPSC test coordinator prior to testing.
4.5 REQUIRED REPORTING DOCUMENTS
The contractor shall furnish to IPSC, two (2) original copies of the test report and one (l)
electronic media copy within forty-five (45) days upon completion of the testing cycle.
a. The original copies shall be in a binder with appropriate cover labeling
information.
b. The electronic media can be compact disc (CD) or USB data storage drive. The
electronic version of the report can be converted to a PDF file.
The Contractor shall submit to the IPSC test coordinator, the complete and correct report in
XML format compliant with the Emission Collection and Monitoring Plan System (ECMPS).
a. The Contractor shall submit to IPSC test coordinator, the ECMPS XML file
within forty-five (45) days upon completion of the testing cycle, but no longer
than the first day of the first month of the next quarter following the testing. If
the next quarter following the testing begins with January, the XML file is due by
January l.
b. IPSC reserves the full right to utilize a third party contractor for the XML file
error checking and file correction analysis.
13
APPENDIX A
Pretest Information
Appendix A is a list of information previously requested by the UDAQ prior to the RATA.
Source Information
l. A sketch or plans of the sample port location in the stack or duct work. The drawings
must show plan view and elevation view of the sample port location such that the
following can be determined:
a. Cross section dimensions of stack or duct at the sample site.
b. Distance from the sample port location to the nearest upstream flow disturbance.
c. Distance from the sample port location to the nearest downstream flow
disturbance.
d. Nature of the nearest upstream and downstream flow disturbance.
e. If nearest flow disturbances are caused by bends in the duct work, the plane of the
bend must be shown.
f. Any potential cause of the cyclonic flow should be shown or mentioned.
Refer to Section 2.3 of the testine plan
1. List all instrumentation available to record the operating parameters of the process during
the test. Indicate which parameters will be recorded during the test, along with the
proposed method and frequency of recording.
The Plant Information system (PI) will be used to record the following during the testing:
a. Coal flow rate.
b. Unit load.
This information will be recorded at five minute intervals.
2. List the ranges of the above parameters at normal process operation.
a. Coal flow rate: approximately 390 tonlhr.
b. Unit load: Normal load is determined by 40 CFR Part 75, Appendix A, Section 6.
3. State the production rate at which the process will be operated during the testing.
14
a. Unit One load: >485 MW during test at the inlet to the WFGD, 385 MW for the
normal load stack flow measurement, and greater than 660MWfor the second
normal load condition during the stack test.
b. Unit Two load: : >485 MW during test at the inlet to the WFGD, 385 MW for the
normal load stack flow measurement, and greater than 660MWfor the second
normal load condition during the stack test.
4. State proposed method and frequency of recording stack opacity during the test.
Opacity will be recorded at six-minute intervals. Opacity is not required for this test.
5. Are there any potentiallyhazardous conditions associated with the source to be tested?
Testing will be on the 350-foot level of the stack. This area is accessed by an elevator.
The testing area is a safe working environment. The data acquisition system for the
testing is located at the base of the stack in a climate controlled enclosure.
6. State the name(s) of the person(s) responsible for submittal of the preliminary results and
the final report to the Director of the Utah Division of Air Quality. Speciff the date by
which the preliminary results and the final report will be submitted.
The person responsible for submittal of the preliminary results and the final report is
Michael Ferrell. Preliminary results of the testing will be given to the UDAQ
representative witnessing the testing at the end of the testing day. The final report will
be submitted to the Director within sixty (60) days after the completion of the testing.
Test Information
Example of items previously submitted
t. What method will be used to determine the dry molecular weight of the gas stream to be
sampled?
EPA Reference Method 3 (A) will be used.
What method will be used to determine the moisture content of the gas stream to be
sampled?
EPA Reference Method 4 will be used.
What method will be used to determine the velocity of the gas stream to be sampled?
EPA Reference Method2,2F, andlor 2G, and 2H for near wall effect if required.
If method 2 is to be used, what type of pitot tube will be used?
2.
J.
4.
15
S-type pitot tube for method 2, spherical for 2F, 2G,2H.
5. What method will be used to monitor the gas temperature at the exit end of the probe
during the test?
Thermocouples that are an integrated part of the RATA sampling system.
6. Show the number of sample points in the cross section of the stack to be used for this test.
How much time will be spent at each sample point? What minimum sample volume will
be collected during the test?
All gas samples will be taken from one sample port, at 16.7, 50, and 87.3 percent of the
diameter of the stack. Ten minutes will be spent at each sample point, for a total run of
30 minutes.
7. What method will be used to measure barometric pressure during the test?
A mercury barometer.
8. Please submit the most recent calibration data for the following equipment, with date of
calibration:
a. Gas stream temperature sensor.
b. Filtration temperature sensor - NA.
c. Condenser outlet temperature sensor.
d. Sample volume meter temperature sensor.
e. Sample volume meter calibration "Y" factor.
f. Filter balance calibration - NA.
g. Nozzle diameter calibration - NA.
A copy of all calibration and certification data will be available on the first day of testing.
9. Where will sample recovery and laboratory work be conducted?
Method 4laboratory work will take place at the stack.
16