2019.04.10_CCO.p8_Fluoromonomers Manufacturing Process Vinyl Ethers North Carbon Bed Removal Efficiency Test Report

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FLUOROMONOMERS
MANUFACTURING PROCESS
VINYL ETHERS NORTH CARBON BED
REMOVAL EFFICIENCY TEST REPORT
TEST DATES: 26-28 FEBRUARY, 1 MARCH 2019
THE CHEMOURS COMPANY
FAYETTEVILLE, NORTH CAROLINA
Prepared for:
THE CHEMOURS COMPANY
22828 NC Hwy 87 W
Fayetteville, North Carolina 28306
Prepared by:
WESTON SOLUTIONS, INC.
1400 Weston Way
P.O. Box 2653
West Chester, Pennsylvania 19380
April 2019
W.O. No. 15418.002.010

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TABLE OF CONTENTS
Section Page
1. INTRODUCTION..............................................................................................................1 
1.1 FACILITY AND BACKGROUND INFORMATION ...........................................1 
1.2 TEST OBJECTIVES ...............................................................................................1 
1.3 TEST PROGRAM OVERVIEW .............................................................................1 
2. SUMMARY OF TEST RESULTS ...................................................................................3 
3. PROCESS DESCRIPTIONS ............................................................................................4 
3.1 FLUOROMONOMERS ..........................................................................................4 
3.2 PROCESS OPERATIONS AND PARAMETERS .................................................4 
4. DESCRIPTION OF TEST LOCATIONS .......................................................................6 
4.1 VINYL ETHERS NORTH CARBON BED INLET AND OUTLET .....................6 
5. SAMPLING AND ANALYTICAL METHODS .............................................................8 
5.1 STACK GAS SAMPLING PROCEDURES ...........................................................8 
5.1.1 Pre-Test Determinations ...........................................................................8 
5.2 STACK PARAMETERS .........................................................................................8 
5.2.1 EPA Method 0010.....................................................................................8 
5.2.2 EPA Method 0010 Sample Recovery .....................................................10 
5.2.3 EPA Method 0010 Sample Analysis.......................................................13 
5.3 GAS COMPOSITION ...........................................................................................14 
6. DETAILED TEST RESULTS AND DISCUSSION .....................................................16 

APPENDIX A PROCESS OPERATIONS DATA
APPENDIX B RAW AND REDUCED TEST DATA
APPENDIX C LABORATORY ANALYTICAL REPORT
APPENDIX D SAMPLE CALCULATIONS
APPENDIX E EQUIPMENT CALIBRATION RECORDS
APPENDIX F LIST OF PROJECT PARTICIPANTS

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LIST OF FIGURES
Title Page
Figure 4-1 VE North Process Carbon Bed Inlet and Outlet Schematic ......................................... 7 
Figure 5-1 EPA Method 0010 Sampling Train ............................................................................... 9 
Figure 5-2 HFPO Dimer Acid Sample Recovery Procedures for Method 0010 ......................... 12 
Figure 5-3 WESTON Sampling System ...................................................................................... 15 

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LIST OF TABLES
Title Page
Table 1-1 Sampling Plan for VEN Carbon Bed Testing ................................................................. 2 
Table 2-1 Summary of HFPO Dimer Acid VEN Carbon Bed Test Results ................................... 3 
Table 3-1 Test Campaign Process Conditions ................................................................................ 5 
Table 6-1 Summary of HFPO Dimer Acid Test Data and Test Results Carbon Bed Inlet – Runs
1-8 ......................................................................................................................................... 17 
Table 6-2 Summary of HFPO Dimer Acid Test Data and Test Results Carbon Bed Outlet – Runs
1-8 ......................................................................................................................................... 23 

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1. INTRODUCTION
1.1 FACILITY AND BACKGROUND INFORMATION
The Chemours Fayetteville Works (Chemours) is located in Bladen County, North Carolina,
approximately 10 miles south of the city of Fayetteville. Chemours operating areas on the site
include the Fluoromonomers, IXM and Polymers Processing Aid (PPA) manufacturing areas,
Wastewater Treatment, and Powerhouse.
Chemours contracted Weston Solutions, Inc. (Weston) to perform HFPO Dimer Acid Fluoride,
captured as HFPO Dimer Acid, emission testing on the Vinyl Ethers North (VEN) Carbon Bed at
the facility. Testing was performed on 26-28 February and 1 March 2019 and generally followed
the “Emission Test Protocol” reviewed and approved by the North Carolina Department of
Environmental Quality (NCDEQ). This report provides the results from the emission test
program.
1.2 TEST OBJECTIVES
The specific objectives for this test program were as follows:
 Measure the emissions concentrations and mass emissions rates of HFPO Dimer Acid
Fluoride from the Carbon Bed inlet and outlet which are located in the Fluoromonomers
process area.
 Calculate the Carbon Bed removal efficiency for HFPO Dimer Acid.
 Monitor and record process and emissions control data in conjunction with the test
program.
 Provide representative emissions data.
1.3 TEST PROGRAM OVERVIEW
During the emissions test program, the concentrations and mass emissions rates of HFPO Dimer
Acid were measured at two locations.
Table 1-1 provides a summary of the test locations and the parameters that were measured along
with the sampling/analytical procedures that were followed.

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Table 1-1
Sampling Plan for VEN Carbon Bed Testing
Sampling Point & Location VE North Carbon Bed
Number of Tests: 16 (8 Carbon Bed inlet, 8 Carbon Bed outlet)
Parameters To Be Tested: HFPO Dimer
Acid
(HFPO-DA)
Volumetric
Flow Rate and
Gas Velocity
Carbon
Dioxide
Oxygen Water Content
Sampling or Monitoring Method EPA M-0010 EPA M1, M2,
M3A, and M4
in conjunction
with M-0010
tests
EPA M3/3A EPA M4 in
conjunction
with M-0010
tests
Sample Extraction/ Analysis Method(s): LC/MS/MS NA6 NA NA
Sample Size ≥ 1.5m3 NA NA NA NA
Total Number of Samples Collected1 16 16 16 16 16
Reagent Blanks (Solvents, Resins)1 1 set 0 0 0 0
Field Blank Trains1 1 per source 0 0 0 0
Proof Blanks1 1 per train 0 0 0 0
Trip Blanks1,2 1 set 0 0 0
Lab Blanks 1 per fraction3 0 0 0 0
Laboratory or Batch Control Spike Samples
(LCS) 1 per fraction3 0 0 0 0
Laboratory or Batch Control Spike Sample
Duplicate (LCSD) 1 per fraction3 0 0 0 0
Media Blanks 1 set4 0 0 0 0
Isotope Dilution Internal Standard Spikes Each sample 0 0 0 0
Total No. of Samples 205 16 16 16 16
Key:
1 Sample collected in field.
2 Trip blanks include one XAD-2 resin module and one methanol sample per sample shipment.
3 Lab blank and LCS/LCSD includes one set per analytical fraction (front half, back half and condensate).
4 One set of media blank archived at laboratory at media preparation.
5 Actual number of samples collected in field.
6 Not applicable.

Section 2 provides a summary of test results. A description of the processes is provided in
Section 3. Section 4 provides a description of the test locations. The sampling and analytical
procedures are provided in Section 5. Detailed test results and discussion are provided in
Section 6.
Appendix C includes the summary reports for the laboratory analytical results. The full
laboratory data packages are provided in electronic format and on CD with each hard copy.

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2. SUMMARY OF TEST RESULTS
A total of eight test runs each were performed on the VEN Carbon Bed inlet and outlet. Table 2-
1 provides a summary of the HFPO Dimer Acid emissions test results and Carbon Bed removal
efficiencies. Detailed test results summaries are provided in Section 6.
It is important to note that emphasis is being placed on the characterization of the emissions
based on the stack test results. Research conducted in developing the protocol for stack testing
HFPO Dimer Acid Fluoride, HFPO Dimer Acid Ammonium Salt and HFPO Dimer Acid
realized that the resulting testing, including collection of the air samples and extraction of the
various fraction of the sampling train, would result in all three compounds being expressed as
simply the HFPO Dimer Acid. However, it should be understood that the total HFPO Dimer
Acid results provided on Table 2-1 and in this report include a percentage of each of the three
compounds.
Table 2-1
Summary of HFPO Dimer Acid VEN Carbon Bed Test Results
Run Number
and
Condition
Inlet Outlet Removal
Efficiency
g/sec lb/hr g/sec lb/hr %
R1
ABR Op. 1.25E-02 9.96E-02 6.92E-05 5.50E-04 99.4
R2
Burnout Run 1.41E-02 1.12E-01 2.14E-05 1.70E-04 99.8
R3
ABR Off 6.58E-03 5.23E-02 3.15E-05 2.50E-04 99.5
R4
ABR Op. 7.11E-03 5.65E-02 1.42E-03 1.13E-02 80.0
R5
ABR Op. 6.41E-03 5.09E-02 6.30E-06 5.00E-05 99.9
R6
Burnout Run 7.11E-03 5.64E-02 8.81E-06 7.00E-05 99.9
R7
ABR Op. 5.97E-03 4.74E-02 5.04E-06 4.00E-05 99.9
R8
Burnout Run 4.39E-03 3.49E-02 6.30E-06 5.00E-05 99.9
Average 8.02E-03 6.37E-02 1.96E-04 1.56E-03 97.3

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3. PROCESS DESCRIPTIONS
The Fluoromonomers area is included in the scope of this test program.
3.1 FLUOROMONOMERS
These facilities produce a family of fluorocarbon compounds used to produce Chemours
products such as Nafion®, Krytox®, and Viton®, as well as sales to outside customers.
Process emissions are vented to the Division waste gas scrubber system (which includes the
secondary scrubber) which then vents to the Carbon Bed and then to the Division Stack.
The VE North building air systems are also vented to the carbon bed and connected to the Tower
Exhaust Blower.
3.2 PROCESS OPERATIONS AND PARAMETERS
The following table is a summary of the operation and products from the specific areas tested.
Source Operation/Product Batch or Continuous
VE
North
PPVE Condensation is continuous. Agitated Bed Reactor
and Refining are batch.
During the test program, the following parameters were monitored by Chemours and are
included in Appendix A.
 Fluoromonomers Process
o VEN Precurser Rate
o VEN Condensation Rate
o VEN ABR Rate

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The following table provides a summary of the process conditions established for each of the
eight test runs:
Table 3-1
Test Campaign Process Conditions
Run No. Date ABR
1 2/26/19 Feeding
2 2/26/19 Burnout
3 2/27/19 Off
4 2/27/19 Feeding
5 2/28/19 Feeding
6 2/28/19 Burnout
7 3/1/19 Feeding
8 3/1/19 Burnout

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4. DESCRIPTION OF TEST LOCATIONS
4.1 VINYL ETHERS NORTH CARBON BED INLET AND OUTLET
The fiberglass reinforced plastic (FRP) ducts at the inlet and outlet of the carbon bed are 34” ID.
The test ports are located as shown below. Based on EPA Method 1, a total of 24 traverse points
(12 per port) were required for HFPO Dimer Acid sampling at both locations. Figure 4-1
provides a schematic of the test port and traverse port locations.
Location Distance from Flow Disturbance Downstream (B) Upstream (A) Carbon Bed Inlet 67 inches > 1.9 duct diameters 61 inches > 1.8 duct diameters Carbon Bed Outlet 58 inches > 1.7 duct diameters 57 inches > 1.5 duct diameters
34 "TRAVERSE
POINT
NUMBER
DISTANCE FROM
INSIDE NEAR
WALL (INCHES)
1
2
3
4
5
6
7
8
9
10
11
12
FIGURE 4-1
VE NORTH PROCESS CARBON BED INLET AND OUTLET SCHEMATIC
IASDATA\CHEMOURS\15418.002.010\FIGURE 4-1 VE NORTH PROCESS SCHEMATIC
7
ID
FAN
CARBON BED
67 "
3/4
2 1/4
4
6
8 1/2
12 1/8
21 5/8
25 1/2
28
30
31 3/4
33 1/4
DRAWING NOT TO SCALE
57 "
58 "
INLET OUTLET
61 "
CEMENT BLOCK WALL

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5. SAMPLING AND ANALYTICAL METHODS
5.1 STACK GAS SAMPLING PROCEDURES
The purpose of this section is to describe the stack gas emissions sampling trains and to provide
details of the stack sampling and analytical procedures utilized during the emissions test
program.
5.1.1 Pre-Test Determinations
Preliminary test data were obtained at each test location. Stack geometry measurements were
measured and recorded, and traverse point distances verified. A preliminary velocity traverse
was performed utilizing a calibrated S-type pitot tube and an inclined manometer to determine
velocity profiles. Flue gas temperatures were observed with a calibrated direct readout panel
meter equipped with a chromel-alumel thermocouple. Preliminary water vapor content was
estimated by wet bulb/dry bulb temperature measurements.
A check for the presence or absence of cyclonic flow was previously conducted at each test
location. The cyclonic flow checks were negative (< 20°) verifying that the test locations were
acceptable for testing.
Preliminary test data was used for nozzle sizing and sampling rate determinations for isokinetic
sampling procedures.
Calibration of probe nozzles, pitot tubes, metering systems, and temperature measurement
devices was performed as specified in Section 5 of EPA Method 5 test procedures.
5.2 STACK PARAMETERS
5.2.1 EPA Method 0010
The sampling train utilized to perform the HFPO Dimer Acid sampling at the outlet locations
was an EPA Method 0010 train (see Figure 5-1). The Method 0010 consisted of a borosilicate
nozzle that attached directly to a heated borosilicate probe. In order to minimize possible thermal
degradation of the HFPO Dimer Acid, the probe and particulate filter were heated above stack
temperature to minimize water vapor condensation before the filter. The probe was connected
directly to a heated borosilicate filter holder containing a solvent extracted glass fiber filter.
VENTWALLICE WATER RECIRCULATION PUMPCONDENSATE TRAPIMPINGERSICE BATHVACUUM LINEMAINVALVETEMPERATURESENSORSBY-PASS VALVEAIR-TIGHT PUMPDRY GAS METERORIFICEMANOMETERCHECKVALVETEMPERATURESENSORHEATED AREAFILTER HOLDERORIFICESILICA GELCONDENSERXAD-2 SORBENTMODULES ONE AND TWOTEMPERATURESENSORTEMPERATURESENSORVACUUMGAUGEIASDATA\CHEMOURS\15418.002.010\FIGURE 5-1 METHOD 0010FIGURE 5-1EPA METHOD 0010 SAMPLING TRAINHEATED PROBE/BUTTON HOOKNOZZLEREVERSE TYPEPITOT TUBE9 NOTE: THE CONDENSER MAY BE POSITIONED HORIZONTALLY. THE XAD-2 SORBENT MODULE WILL ALWAYS BE IN A VERTICAL POSITION..RIGID BOROSILICATE TUBINGOR FLEXIBLE SAMPLE LINEICE WATERRECIRCULATIONCONDENSATE TRAPIMPINGER

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A section of borosilicate glass or flexible polyethylene tubing connected the filter holder exit to a
Grahm (spiral) type ice water-cooled condenser, an ice water-jacketed sorbent module containing
approximately 40 grams of XAD-2 resin. The XAD-2 resin tube was equipped with an inlet
temperature sensor. The XAD-2 resin trap was followed by a condensate knockout impinger and
a series of two impingers that contained 100 mL of high purity distilled water. The train also
included a second XAD-2 resin trap behind the impinger section to evaluate possible sampling
train breakthrough. Each XAD-2 resin trap was connected to a 1-liter condensate knockout trap.
The final impinger contained 300 g of dry pre-weighed silica gel. All impingers and the
condensate traps were maintained in an ice bath. Ice water was continuously circulated in the
condenser and both XAD-2 modules to maintain method-required temperature. A control console
with a leakless vacuum pump, a calibrated orifice, and dual inclined manometers was connected
to the final impinger via an umbilical cord to complete the sample train.
HFPO Dimer Acid Fluoride (CAS No. 2062-98-8) that is present in the stack gas is expected to
be captured in the sampling train along with HFPO Dimer Acid (CAS No. 13252-13-6). HFPO
Dimer Acid Fluoride underwent hydrolysis instantaneously in water in the sampling train and
during the sample recovery step, and was converted to HFPO Dimer Acid such that the amount
of HFPO Dimer Acid emissions represented a combination of both HFPO Dimer Acid Fluoride
and HFPO Dimer Acid.
During sampling, gas stream velocities were measured by attaching a calibrated S-type pitot tube
into the gas stream adjacent to the sampling nozzle. The velocity pressure differential was
observed immediately after positioning the nozzle at each traverse point, and the sampling rate
adjusted to maintain isokineticity at 100% ± 10. Flue gas temperature was monitored at each
point with a calibrated panel meter and thermocouple. Isokinetic test data was recorded at each
traverse point during all test periods, as appropriate. Leak checks were performed on the
sampling apparatus according to reference method instructions, prior to and following each run,
component change (if required) or during midpoint port changes.
5.2.2 EPA Method 0010 Sample Recovery
At the conclusion of each test, the sampling train was dismantled, the openings sealed, and the
components transported to the field laboratory trailer for recovery.
A consistent procedure was employed for sample recovery:

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1. The two XAD-2 covered (to minimize light degradation) sorbent modules (1 and 2) were
sealed and labeled.

2. The glass fiber filter(s) were removed from the holder with tweezers and placed in a
polyethylene container along with any loose particulate and filter fragments.

3. The particulate adhering to the internal surfaces of the nozzle, probe and front half of the
filter holder were rinsed with a solution of methanol and ammonium hydroxide into a
polyethylene container while brushing a minimum of three times until no visible
particulate remains. Particulate adhering to the brush was rinsed with methanol/
ammonium hydroxide into the same container. The container was sealed.

4. The volume of liquid collected in the first condensate trap was measured, the value
recorded, and the contents poured into a polyethylene container.

5. All train components between the filter exit and the first condensate trap were rinsed with
methanol/ammonium hydroxide. The solvent rinse was placed in a separate polyethylene
container and sealed.

6. The volume of liquid in impingers one and two, and the second condensate trap, were
measured, the values recorded, and the sample was placed in the same container as Step 4
above, then sealed.

7. The two impingers, condensate trap, and connectors were rinsed with methanol/
ammonium hydroxide. The solvent sample was placed in a separate polyethylene
container and sealed.

8. The silica gel in the final impinger was weighed and the weight gain value recorded.

9. Site (reagent) blank samples of the methanol/ammonium hydroxide, XAD resin, filter
and distilled water were retained for analysis.

Each container was labeled to clearly identify its contents. The height of the fluid level was
marked on the container of each liquid sample to provide a reference point for a leakage check
during transport. All samples were maintained cool.
During each test campaign, a Method 0010 blank train was set up near the test location, leak-
checked and recovered along with the respective sample train. Following sample recovery, all
samples were transported to TestAmerica Laboratories, Inc. (TestAmerica) for sample extraction
and analysis.
See Figure 5-2 for a schematic of the Method 0010 sample recovery process.
IASDATA\CHEMOURS\15418.002.010\FIGURE 5-2 EPA 0010FIGURE 5-2HFPO DIMER ACID SAMPLE RECOVERY PROCEDURES FOR METHOD 0010NOZZLE, PROBE ANDFRONT-HALF FILTER HOLDERSAMPLE FRACTION 2FILTERSAMPLE FRACTION 1BACK-HALF FILTER HOLDER CONNECTORS, FLEXIBLE LINE CONDENSER SAMPLE FRACTION 5XAD-2 MODULE ONESAMPLE FRACTION 3REMOVE FROM IMPINGER TRAINWASH WITH NANOGRADE METHANOL/AMMONIUM HYDROXIDESEAL IN LABELED POLYETHYLENE BOTTLE. COMPLETE CUSTODY FORM, SECURE SAMPLE AND KEEP COOLWASH WHILE BRUSHING WITH NANOGRADE METHANOL/ AMMONIUM HYDROXIDESEAL ENDS WITH GLASS CAPS, COVER, LABEL, COMPLETE CUSTODY FORM, SECURE SAMPLE AT AND KEEP COOLTRANSFER WASHINGS TO POLYETHYLENE BOTTLE; LABEL, SEAL AND MARK LIQUID LEVEL, COMPLETE CUSTODY FORM, SECURE SAMPLE AND KEEP COOLSEAL WASHINGS IN LABELED POLYETHYLENE BOTTLE. MARK LIQUID LEVEL, COMPLETE CUSTODY FORM, SECURE SAMPLE AND KEEP COOLFIRST AND SECOND CONDENSATE TRAPS AND IMPINGER NOS. 1 AND 2SAMPLE FRACTION 4IMPINGER NO. 4 (SILICA GEL)WEIGH AND RECORDMEASURE VOLUME OF LIQUID AND RECORDTRANSFER WASHINGS TO POLYETHYLENE BOTTLE; LABEL, SEAL AND MARK LIQUID LEVEL, COMPLETE CUSTODY FORM, SECURE SAMPLE AND KEEP COOL12WEIGH AND RECORDRETAIN FOR REGENERATIONFIRST AND SECOND CONDENSATE TRAPS AND IMPINGER NOS. 1 AND 2SAMPLE FRACTION 6WASH WITH NANOGRADE METHANOL/AMMONIUM HYDROXIDETRANSFER WASHINGS TO POLYETHYLENE BOTTLE; LABEL, SEAL AND MARK LIQUID LEVEL, COMPLETE CUSTODY FORM, SECURE SAMPLE AND KEEP COOLXAD-2 MODULE TWOSAMPLE FRACTION 7REMOVE FROM IMPINGER TRAINSEAL ENDS WITH GLASS CAPS, COVER, LABEL, COMPLETE CUSTODY FORM, SECURE SAMPLE AT AND KEEP COOL

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5.2.3 EPA Method 0010 Sample Analysis
Method 0010 sampling trains resulted in four separate analytical fractions for HFPO Dimer Acid
analysis according to SW-846 Method 3542:
 Front-half Composite—comprised of the particulate filter, and the probe, nozzle, and
front-half of the filter holder solvent rinses;
 Back-half Composite—comprised of the first XAD-2 resin material and the back-half of
the filter holder with connecting glassware solvent rinses;
 Condensate Composite—comprised of the aqueous condensates and the contents of
impingers one and two with solvent rinses;
 Breakthrough XAD-2 Resin Tube—comprised of the resin tube behind the series of
impingers.
The second XAD-2 resin material was analyzed separately to evaluate any possible sampling
train HFPO-DA breakthrough.
The front-half and back-half composites and the second XAD-2 resin material were placed in
polypropylene wide-mouth bottles and tumbled with methanol containing 5% NH4OH for 18
hours. Portions of the extracts were processed analytically for the HFPO dimer acid by liquid
chromatography and duel mass spectroscopy (HPLC/MS/MS). The condensate composite was
concentrated onto a solid phase extraction (SPE) cartridge followed by desorption from the
cartridge using methanol. Portions of those extracts were also processed analytically by
HPLC/MS/MS.
Samples were spiked with isotope dilution internal standard (IDA) at the commencement of their
preparation to provide accurate assessments of the analytical recoveries. Final data was corrected
for IDA standard recoveries.
TestAmerica developed detailed procedures for the sample extraction and analysis for HFPO
Dimer Acid. These procedures were incorporated into the test protocol.

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5.3 GAS COMPOSITION
The Weston mobile laboratory equipped with instrumental analyzers was used to measure carbon
dioxide (CO2) and oxygen (O2) concentrations. A diagram of the Weston sampling system is
presented in Figure 5-3.
Each analyzer was set up and calibrated internally by introduction of calibration gas standards
directly to the analyzer from a calibration manifold. The calibration manifold is designed with an
atmospheric vent to release excess calibration gas and maintained the calibration at ambient
pressure. The direct calibration sequence consisted of alternate injections of zero and mid-range
gases with appropriate adjustments until the desired responses were obtained. The high-range
standards were then introduced in sequence without further adjustment.
The sample line integrity was verified by performing a bias test before and after each test period.
The sampling system bias test consisted of introducing the zero gas and one up-range calibration
standard in excess to the valve at the probe end when the system was sampling normally. The
excess calibration gas flowed out through the probe to maintain ambient sampling system
pressure. Calibration gas supply was regulated to maintain constant sampling rate and pressure.
Instrument bias check response was compared to internal calibration responses to insure sample
line integrity and to calculate a bias correction factor after each run using the ratio of the
measured concentration of the bias gas certified by the calibration gas supplier.
The oxygen and carbon dioxide content of each stack gas was measured according to EPA
Method 3A procedures which incorporate the latest updates of EPA Method 7E. A Servomex
Model 4900 analyzer (or equivalent) was used to measure oxygen content. A Servomex Model
4900 analyzer (or equivalent) was used to measure carbon dioxide content of the stack gas. Both
analyzers were calibrated with EPA Protocol gases prior to the start of the test program and
performance was verified by sample bias checks before and after each test run.

HEATEDSAMPLEPROBESTACK WALLHEATED FILTERHOLDER OR METHOD0010 SAMPLE TRAINHEATED SAMPLE LINESAMPLECONDITIONINGSYSTEMMOISTUREREMOVALVENTCO2O2GASANALYZERSACQUISTIONINTERFACEANALOGSIGNALLINECOMPUTER FOR DATAACQUISITION ANDREDUCTIONSAMPLEPUMPCALIBRATIONGASES= ON / OFF VALVECALIBRATION BIAS LINEFIGURE 5-3WESTON SAMPLING SYSTEMIASDATA\CHEMOURS\15418.002.010\FIGURE 5-3 WESTON SAMPLING SYSTEM215

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6. DETAILED TEST RESULTS AND DISCUSSION
Each test was a minimum of 96 minutes in duration. A total of eight test runs were performed at
each location.
Tables 6-1 and 6-2 provide detailed test data and test results for the Carbon Bed inlet and the
Carbon Bed outlet, respectively.
The Method 3A sampling on all sources indicated that the O2 and CO2 concentrations were at
ambient air levels (20.9% O2, 0% CO2), therefore, 20.9% O2 and 0% CO2 values were used in all
calculations.
The carbon bed removal efficiency was calculated based upon the HFPO Dimer Acid inlet and
outlet mass emission rates in lb/hr.
Seven of the eight runs were >99% efficiency. The one run where the measured efficiency was
80% is being investigated further.

TABLE 6-1
CHEMOURS - FAYETTEVILLE, NC
SUMMARY OF HFPO DIMER ACID TEST DATA AND TEST RESULTS
CARBON BED INLET
Test Data
Run number 1 2 3
Location CBed Inlet CBed Inlet CBed Inlet
Date 2/26/2019 2/26/2019 2/27/2019
Time period 0927-1143 1335-1530 0840-1035
SAMPLING DATA:
Sampling duration, min.96.0 96.0 96.0
Nozzle diameter, in.0.215 0.215 0.215
Cross sectional nozzle area, sq.ft.0.000252 0.000252 0.000252
Barometric pressure, in. Hg 30.29 30.20 30.22
Avg. orifice press. diff., in H2O 1.33 1.31 1.27
Avg. dry gas meter temp., deg F 58.7 74.0 60.2
Avg. abs. dry gas meter temp., deg. R 519 534 520
Total liquid collected by train, ml 24.7 20.4 28.5
Std. vol. of H2O vapor coll., cu.ft.1.2 1.0 1.3
Dry gas meter calibration factor 1.0027 1.0027 1.0027
Sample vol. at meter cond., dcf 52.809 56.260 55.079
Sample vol. at std. cond., dscf (1)54.721 56.462 56.773
Percent of isokinetic sampling 93.9 99.6 100.4
GAS STREAM COMPOSITION DATA:
CO2, % by volume, dry basis 0.0 0.0 0.0
O2, % by volume, dry basis 20.9 20.9 20.9
N2, % by volume, dry basis 79.1 79.1 79.1
Molecular wt. of dry gas, lb/lb mole 28.84 28.84 28.84
H20 vapor in gas stream, prop. by vol.0.021 0.017 0.023
Mole fraction of dry gas 0.979 0.983 0.977
Molecular wt. of wet gas, lb/lb mole 28.61 28.65 28.59
GAS STREAM VELOCITY AND VOLUMETRIC FLOW DATA:
Static pressure, in. H2O -6.50 -6.50 -6.50
Absolute pressure, in. Hg 29.81 29.72 29.74
Avg. temperature, deg. F 69 78 71
Avg. absolute temperature, deg.R 529 538 531
Pitot tube coefficient 0.84 0.84 0.84
Total number of traverse points 24 24 24
Avg. gas stream velocity, ft./sec.41.3 40.7 40.3
Stack/duct cross sectional area, sq.ft.6.31 6.31 6.31
Avg. gas stream volumetric flow, wacf/min.15613 15409 15264
Avg. gas stream volumetric flow, dscf/min.15187 14774 14739
(1)Standard conditions = 68 deg. F. (20 deg. C.) and 29.92 in Hg (760 mm Hg)
3/22/2019 2:37 PM 17 022619 CBed IN 1-3
CARBON BED INLET
TEST DATA
Run number 1 2 3
Location CBed Inlet CBed Inlet CBed Inlet
Date 2/26/2019 2/26/2019 2/27/2019
Time period 0927-1143 1335-1530 0840-1035
CONDITION ABR Op.Burnout
Run
ABR off
LABORATORY REPORT DATA, ug.
HFPO Dimer Acid 2713.12 3227.18 1521.59
EMISSION RESULTS, ug/dscm.
HFPO Dimer Acid 1750.56 2018.04 946.27
EMISSION RESULTS, lb/dscf.
HFPO Dimer Acid 1.09E-07 1.26E-07 5.91E-08
EMISSION RESULTS, lb/hr.
HFPO Dimer Acid 9.96E-02 1.12E-01 5.23E-02
EMISSION RESULTS, g/sec.
HFPO Dimer Acid 1.25E-02 1.41E-02 6.58E-03
TABLE 6-1 (cont.)
SUMMARY OF HFPO DIMER ACID TEST DATA AND TEST RESULTS
CHEMOURS - FAYETTEVILLE, NC
4/10/2019 1:55 PM
18
022619 CBed IN 1-3
TABLE 6-1 (cont.)
CHEMOURS - FAYETTEVILLE, NC
SUMMARY OF HFPO DIMER ACID TEST DATA AND TEST RESULTS
CARBON BED INLET
Test Data
Run number 4 5 6
Location CBed Inlet CBed Inlet CBed Inlet
Date 2/27/2019 2/28/2019 2/28/2019
Time period 1231-1426 0823-1018 1429-1627
SAMPLING DATA:
Sampling duration, min.96.0 96.0 96.0
Nozzle diameter, in.0.215 0.215 0.215
Cross sectional nozzle area, sq.ft.0.000252 0.000252 0.000252
Barometric pressure, in. Hg 30.17 29.95 29.95
Avg. orifice press. diff., in H2O 1.28 1.25 1.28
Avg. dry gas meter temp., deg F 68.8 59.5 70.9
Avg. abs. dry gas meter temp., deg. R 529 519 531
Total liquid collected by train, ml 31.8 28.5 33.1
Std. vol. of H2O vapor coll., cu.ft.1.5 1.3 1.6
Dry gas meter calibration factor 1.0027 1.0027 1.0027
Sample vol. at meter cond., dcf 58.052 57.133 58.141
Sample vol. at std. cond., dscf (1)58.762 58.444 58.199
Percent of isokinetic sampling 104.4 104.2 103.9
GAS STREAM COMPOSITION DATA:
CO2, % by volume, dry basis 0.0 0.0 0.0
O2, % by volume, dry basis 20.9 20.9 20.9
N2, % by volume, dry basis 79.1 79.1 79.1
Molecular wt. of dry gas, lb/lb mole 28.84 28.84 28.84
H20 vapor in gas stream, prop. by vol.0.025 0.022 0.026
Mole fraction of dry gas 0.975 0.978 0.974
Molecular wt. of wet gas, lb/lb mole 28.57 28.59 28.55
GAS STREAM VELOCITY AND VOLUMETRIC FLOW DATA:
Static pressure, in. H2O -6.50 -6.50 -6.50
Absolute pressure, in. Hg 29.69 29.47 29.47
Avg. temperature, deg. F 74 70 79
Avg. absolute temperature, deg.R 534 530 539
Pitot tube coefficient 0.84 0.84 0.84
Total number of traverse points 24 24 24
Avg. gas stream velocity, ft./sec.40.5 40.2 41.1
Stack/duct cross sectional area, sq.ft.6.31 6.31 6.31
Avg. gas stream volumetric flow, wacf/min.15335 15222 15534
Avg. gas stream volumetric flow, dscf/min.14667 14610 14589
(1)Standard conditions = 68 deg. F. (20 deg. C.) and 29.92 in Hg (760 mm Hg)
3/22/2019 2:40 PM 19 022619 CBed IN 4-6
CARBON BED INLET
TEST DATA
Run number 4 5 6
Location CBed Inlet CBed Inlet CBed Inlet
Date 2/27/2019 2/28/2019 2/28/2019
Time period 1231-1426 0823-1018 1429-1627
CONDITION ABR Op. ABR Op. Burnout Run
LABORATORY REPORT DATA, ug.
HFPO Dimer Acid 1711.1700 1540.6200 1702.1090
EMISSION RESULTS, ug/dscm.
HFPO Dimer Acid 1028.16 930.72 1032.60
EMISSION RESULTS, lb/dscf.
HFPO Dimer Acid 6.42E-08 5.81E-08 6.45E-08
EMISSION RESULTS, lb/hr.
HFPO Dimer Acid 5.65E-02 5.09E-02 5.64E-02
EMISSION RESULTS, g/sec.
HFPO Dimer Acid 7.11E-03 6.41E-03 7.11E-03
TABLE 6-1 (cont.)
SUMMARY OF HFPO DIMER ACID TEST DATA AND TEST RESULTS
CHEMOURS - FAYETTEVILLE, NC
4/10/2019 1:48 PM
20
022619 CBed IN 4-6
TABLE 6-1 (cont.)
CHEMOURS - FAYETTEVILLE, NC
SUMMARY OF HFPO DIMER ACID TEST DATA AND TEST RESULTS
CARBON BED INLET
Test Data
Run number 7 8
Location CBed Inlet CBed Inlet
Date 3/1/2019 3/1/2019
Time period 0813-1008 1237-1433
SAMPLING DATA:
Sampling duration, min.96.0 96.0
Nozzle diameter, in.0.215 0.215
Cross sectional nozzle area, sq.ft.0.000252 0.000252
Barometric pressure, in. Hg 30.09 30.08
Avg. orifice press. diff., in H2O 1.29 1.26
Avg. dry gas meter temp., deg F 53.7 61.9
Avg. abs. dry gas meter temp., deg. R 514 522
Total liquid collected by train, ml 28.1 29.5
Std. vol. of H2O vapor coll., cu.ft.1.3 1.4
Dry gas meter calibration factor 1.0027 1.0027
Sample vol. at meter cond., dcf 57.793 57.189
Sample vol. at std. cond., dscf (1)60.070 58.483
Percent of isokinetic sampling 104.9 104.7
GAS STREAM COMPOSITION DATA:
CO2, % by volume, dry basis 0.0 0.0
O2, % by volume, dry basis 20.9 20.9
N2, % by volume, dry basis 79.1 79.1
Molecular wt. of dry gas, lb/lb mole 28.84 28.84
H20 vapor in gas stream, prop. by vol.0.022 0.023
Mole fraction of dry gas 0.978 0.977
Molecular wt. of wet gas, lb/lb mole 28.60 28.58
GAS STREAM VELOCITY AND VOLUMETRIC FLOW DATA:
Static pressure, in. H2O -6.50 -6.50
Absolute pressure, in. Hg 29.61 29.60
Avg. temperature, deg. F 64 72
Avg. absolute temperature, deg.R 524 532
Pitot tube coefficient 0.84 0.84
Total number of traverse points 24 24
Avg. gas stream velocity, ft./sec.40.4 40.1
Stack/duct cross sectional area, sq.ft.6.31 6.31
Avg. gas stream volumetric flow, wacf/min.15295 15173
Avg. gas stream volumetric flow, dscf/min.14917 14557
(1)Standard conditions = 68 deg. F. (20 deg. C.) and 29.92 in Hg (760 mm Hg)
3/22/2019 2:47 PM 21 022619 CBed IN 7-8
CARBON BED INLET
TEST DATA
Run number 7 8
Location CBed Inlet CBed Inlet
Date 3/1/2019 3/1/2019
Time period 0813-1008 1237-1433
CONDITION ABR Op.Burnout
Run
LABORATORY REPORT DATA, ug.
HFPO Dimer Acid 1.44E+03 1.06E+03
EMISSION RESULTS, ug/dscm.
HFPO Dimer Acid 8.49E+02 6.39E+02
EMISSION RESULTS, lb/dscf.
HFPO Dimer Acid 5.30E-08 3.99E-08
EMISSION RESULTS, lb/hr.
HFPO Dimer Acid 4.74E-02 3.49E-02
EMISSION RESULTS, g/sec.
HFPO Dimer Acid 5.97E-03 4.39E-03
TABLE 6-1 (cont.)
SUMMARY OF HFPO DIMER ACID TEST DATA AND TEST RESULT
CHEMOURS - FAYETTEVILLE, NC
4/10/2019 1:49 PM
22
022619 CBed IN 7-8
TABLE 6-2
CHEMOURS - FAYETTEVILLE, NC
SUMMARY OF HFPO DIMER ACID TEST DATA AND TEST RESULTS
CARBON BED OUTLET
Test Data
Run number 1 2 3
Location CBed Outlet CBed Outlet CBed Outlet
Date 2/26/2019 2/26/2019 2/27/2019
Time period 0927-1143 1335-1530 0840-1035
SAMPLING DATA:
Sampling duration, min.96.0 96.0 96.0
Nozzle diameter, in.0.215 0.215 0.215
Cross sectional nozzle area, sq.ft.0.000252 0.000252 0.000252
Barometric pressure, in. Hg 30.29 30.20 30.22
Avg. orifice press. diff., in H2O 1.61 1.65 1.64
Avg. dry gas meter temp., deg F 60.2 79.4 63.3
Avg. abs. dry gas meter temp., deg. R 520 539 523
Total liquid collected by train, ml 17.9 28.3 33.8
Std. vol. of H2O vapor coll., cu.ft.0.8 1.3 1.6
Dry gas meter calibration factor 1.0010 1.0010 1.0010
Sample vol. at meter cond., dcf 54.493 55.964 55.596
Sample vol. at std. cond., dscf (1)56.245 55.551 56.924
Percent of isokinetic sampling 95.3 93.6 98.6
GAS STREAM COMPOSITION DATA:
CO2, % by volume, dry basis 0.0 0.0 0.0
O2, % by volume, dry basis 20.9 20.9 20.9
N2, % by volume, dry basis 79.1 79.1 79.1
Molecular wt. of dry gas, lb/lb mole 28.84 28.84 28.84
H20 vapor in gas stream, prop. by vol.0.015 0.023 0.027
Mole fraction of dry gas 0.985 0.977 0.973
Molecular wt. of wet gas, lb/lb mole 28.68 28.58 28.54
GAS STREAM VELOCITY AND VOLUMETRIC FLOW DATA:
Static pressure, in. H2O 3.50 3.50 3.50
Absolute pressure, in. Hg 30.55 30.46 30.48
Avg. temperature, deg. F 69 76 78
Avg. absolute temperature, deg.R 529 536 538
Pitot tube coefficient 0.84 0.84 0.84
Total number of traverse points 24 24 24
Avg. gas stream velocity, ft./sec.40.6 41.7 40.9
Stack/duct cross sectional area, sq.ft.6.31 6.31 6.31
Avg. gas stream volumetric flow, wacf/min.15341 15789 15489
Avg. gas stream volumetric flow, dscf/min.15383 15463 15044
(1)Standard conditions = 68 deg. F. (20 deg. C.) and 29.92 in Hg (760 mm Hg)
3/22/2019 2:57 PM 23 022619 CBed OUT 1-3
CARBON BED OUTLET
TEST DATA
Run number 1 2 3
Location CBed Outlet CBed Outlet CBed Outlet
Date 2/26/2019 2/26/2019 2/27/2019
Time period 0927-1143 1335-1530 0840-1035
CONDITION ABR Op.Burnout
Run
ABR Off
LABORATORY REPORT DATA, ug.
HFPO Dimer Acid 15.1080 4.6752 7.0900
EMISSION RESULTS, ug/dscm.
HFPO Dimer Acid 9.48 2.97 4.40
EMISSION RESULTS, lb/dscf.
HFPO Dimer Acid 5.92E-10 1.86E-10 2.75E-10
EMISSION RESULTS, lb/hr.
HFPO Dimer Acid 5.50E-04 1.70E-04 2.50E-04
HFPO Dimer Acid (From Inlet Data)9.96E-02 1.12E-01 5.23E-02
EMISSION RESULTS, g/sec.
HFPO Dimer Acid 6.92E-05 2.14E-05 3.15E-05
Carbon Bed Removal Efficiency, %99.4 99.8 99.5
TABLE 6-2 (cont.)
CHEMOURS - FAYETTEVILLE, NC
SUMMARY OF HFPO DIMER ACID TEST DATA AND TEST RESULTS
4/10/2019 1:53 PM
24
022619 CBed OUT 1-3
TABLE 6-2 (cont.)
CHEMOURS - FAYETTEVILLE, NC
SUMMARY OF HFPO DIMER ACID TEST DATA AND TEST RESULTS
CARBON BED OUTLET
Test Data
Run number 4 5 6
Location CBed Outlet CBed Outlet CBed Outlet
Date 2/27/2019 2/28/2019 2/27/2019
Time period 1231-1426 0823-1018 1429-1627
SAMPLING DATA:
Sampling duration, min.320.1 96.0 1.3
Nozzle diameter, in.0.215 0.215 0.215
Cross sectional nozzle area, sq.ft.0.000252 0.000252 0.000252
Barometric pressure, in. Hg 30.17 29.95 29.95
Avg. orifice press. diff., in H2O 1.63 1.67 1.61
Avg. dry gas meter temp., deg F 71.5 61.4 76.7
Avg. abs. dry gas meter temp., deg. R 532 521 537
Total liquid collected by train, ml 32.8 35.1 39.8
Std. vol. of H2O vapor coll., cu.ft.1.5 1.7 1.9
Dry gas meter calibration factor 1.0010 1.0010 1.0010
Sample vol. at meter cond., dcf 56.016 56.152 55.732
Sample vol. at std. cond., dscf (1)56.369 57.190 55.132
Percent of isokinetic sampling 97.8 98.9 97.0
GAS STREAM COMPOSITION DATA:
CO2, % by volume, dry basis 0.0 0.0 0.0
O2, % by volume, dry basis 20.9 20.9 20.9
N2, % by volume, dry basis 79.1 79.1 79.1
Molecular wt. of dry gas, lb/lb mole 28.84 28.84 28.84
H20 vapor in gas stream, prop. by vol.0.027 0.028 0.033
Mole fraction of dry gas 0.973 0.972 0.967
Molecular wt. of wet gas, lb/lb mole 28.55 28.53 28.48
GAS STREAM VELOCITY AND VOLUMETRIC FLOW DATA:
Static pressure, in. H2O 3.50 3.50 3.50
Absolute pressure, in. Hg 30.43 30.21 30.21
Avg. temperature, deg. F 82 78 81
Avg. absolute temperature, deg.R 542 538 541
Pitot tube coefficient 0.84 0.84 0.84
Total number of traverse points 24 24 24
Avg. gas stream velocity, ft./sec.41.2 41.4 41.1
Stack/duct cross sectional area, sq.ft.6.31 6.31 6.31
Avg. gas stream volumetric flow, wacf/min.15581 15647 15534
Avg. gas stream volumetric flow, dscf/min.15022 15065 14807
(1)Standard conditions = 68 deg. F. (20 deg. C.) and 29.92 in Hg (760 mm Hg)
3/22/2019 3:07 PM 25 022619 CBed OUT 4-6
CARBON BED OUTLET
TEST DATA
Run number 4 5 6
Location CBed Outlet CBed Outlet CBed Outlet
Date 2/27/2019 2/28/2019 2/27/2019
Time period 1231-1426 0823-1018 1429-1627
CONDITION ABR Op.ABR Op.Burnout Run
LABORATORY REPORT DATA, ug.
HFPO Dimer Acid 320.0500 1.3000 1.9400
EMISSION RESULTS, ug/dscm.
HFPO Dimer Acid 200.46 0.80 1.24
EMISSION RESULTS, lb/dscf.
HFPO Dimer Acid 1.25E-08 5.01E-11 7.76E-11
EMISSION RESULTS, lb/hr.
HFPO Dimer Acid 1.13E-02 5.00E-05 7.00E-05
HFPO Dimer Acid (From Inlet Data)5.65E-02 5.09E-02 5.64E-02
EMISSION RESULTS, g/sec.
HFPO Dimer Acid 1.42E-03 6.30E-06 8.81E-06
Carbon Bed Removal Efficiency, %80.0 99.9 99.9
TABLE 6-2 (cont.)
CHEMOURS - FAYETTEVILLE, NC
SUMMARY OF HFPO DIMER ACID TEST DATA AND TEST RESULTS
4/10/2019 1:56 PM
26
022619 CBed OUT 4-6
TABLE 6-2 (cont.)
CHEMOURS - FAYETTEVILLE, NC
SUMMARY OF HFPO DIMER ACID TEST DATA AND TEST RESULTS
CARBON BED OUTLET
Test Data
Run number 7 8
Location CBed Outlet CBed Outlet
Date 3/1/2019 3/1/2019
Time period 0813-1008 1237-1433
SAMPLING DATA:
Sampling duration, min.96.0 96.0
Nozzle diameter, in.0.215 0.215
Cross sectional nozzle area, sq.ft.0.000252 0.000252
Barometric pressure, in. Hg 30.09 30.08
Avg. orifice press. diff., in H2O 1.67 1.64
Avg. dry gas meter temp., deg F 56.4 67.1
Avg. abs. dry gas meter temp., deg. R 516 527
Total liquid collected by train, ml 34.2 32.5
Std. vol. of H2O vapor coll., cu.ft.1.6 1.5
Dry gas meter calibration factor 1.0010 1.0010
Sample vol. at meter cond., dcf 55.779 55.822
Sample vol. at std. cond., dscf (1)57.623 56.473
Percent of isokinetic sampling 98.6 98.0
GAS STREAM COMPOSITION DATA:
CO2, % by volume, dry basis 0.0 0.0
O2, % by volume, dry basis 20.9 20.9
N2, % by volume, dry basis 79.1 79.1
Molecular wt. of dry gas, lb/lb mole 28.84 28.84
H20 vapor in gas stream, prop. by vol.0.027 0.026
Mole fraction of dry gas 0.973 0.974
Molecular wt. of wet gas, lb/lb mole 28.54 28.55
GAS STREAM VELOCITY AND VOLUMETRIC FLOW DATA:
Static pressure, in. H2O 3.50 3.50
Absolute pressure, in. Hg 30.35 30.34
Avg. temperature, deg. F 72 77
Avg. absolute temperature, deg.R 532 537
Pitot tube coefficient 0.84 0.84
Total number of traverse points 24 24
Avg. gas stream velocity, ft./sec.41.2 40.9
Stack/duct cross sectional area, sq.ft.6.31 6.31
Avg. gas stream volumetric flow, wacf/min.15574 15486
Avg. gas stream volumetric flow, dscf/min.15233 15018
(1)Standard conditions = 68 deg. F. (20 deg. C.) and 29.92 in Hg (760 mm Hg)
3/22/2019 3:12 PM 27 022619 CBed OUT 7-8
CARBON BED OUTLET
TEST DATA
Run number 7 8
Location CBed Outlet CBed Outlet
Date 3/1/2019 3/1/2019
Time period 0813-1008 1237-1433
CONDITION ABR Op.Burnout
Run
LABORATORY REPORT DATA, ug.
HFPO Dimer Acid 1.2200 1.4400
EMISSION RESULTS, ug/dscm.
HFPO Dimer Acid 0.75 0.90
EMISSION RESULTS, lb/dscf.
HFPO Dimer Acid 4.67E-11 5.62E-11
EMISSION RESULTS, lb/hr.
HFPO Dimer Acid 4.00E-05 5.00E-05
HFPO Dimer Acid (From Inlet Data)4.74E-02 3.49E-02
EMISSION RESULTS, g/sec.
HFPO Dimer Acid 5.04E-06 6.30E-06
Carbon Bed Removal Efficiency, %99.9 99.9
TABLE 6-2 (cont.)
CHEMOURS - FAYETTEVILLE, NC
SUMMARY OF HFPO DIMER ACID TEST DATA AND TEST RESULTS
4/10/2019 1:57 PM
28
022619 CBed OUT 7-8
IASDATA\CHEMOURS\15418.002.009\CBED IN OUT REPORT FEB 2019-AMD 4/10/2019
APPENDIX A
PROCESS OPERATIONS DATA
29
DateTimeStack TestingHFPOVEN ProductVEN PrecursorVEN Condensation (HFPO)VEN ABRVEN RefiningStripper Column VentDivision WGS Recirculation FlowDivision WGS Inlet FlowDateTimeStack TestingHFPOVEN ProductVEN PrecursorVEN Condensation (HFPO)VEN ABRVEN RefiningStripper Column VentDivision WGS Recirculation FlowDivision WGS Inlet FlowPPVE15000 kg/h75 kg/h98 kg/h140 kg/h125 kg/h145 kg/h1300140015001600Run 3Run 42/26/20198009001000110012002/27/2019Burnout15000 kg/h125 kg/h105 kg/h90 kg/h70 kg/h140015001600Run 1Run 2PPVE800900100011001200130030
DateTimeStack TestingHFPOVEN ProductVEN PrecursorVEN Condensation (HFPO)VEN ABRVEN RefiningStripper Column VentDivision WGS Recirculation FlowDivision WGS Inlet FlowDateTimeStack TestingHFPOVEN ProductVEN PrecursorVEN Condensation (HFPO)VEN ABRVEN RefiningStripper Column VentDivision WGS Recirculation FlowDivision WGS Inlet Flow15000 kg/h120 kg/h80 kg/h 60 kg/h3/1/2019PPVEBurnout1300140015001600Run 7Run 82/28/2019800900100011001200Burnout15000 kg/h125 kg/h100 kg/h140015001600Run 5Run 6PPVE800900100011001200130031
IASDATA\CHEMOURS\15418.002.009\CBED IN OUT REPORT FEB 2019-AMD 4/10/2019
APPENDIX B
RAW AND REDUCED TEST DATA
32
CHEMOURS - FAYETTEVILLE, NC
INPUTS FOR HFPO DIMER ACID CALCULATIONS
CARBON BED INLET
Test Data
Run number 1 2 3
Location CBed Inlet CBed Inlet CBed Inlet
Date 2/26/2019 2/26/2019 2/27/2019
Time period 0927-1143 1335-1530 0840-1035
Operator RS/JL RS/JL RS/JL
Inputs For Calcs.
Sq. rt. delta P 0.72952 0.71386 0.71111
Delta H 1.3292 1.3125 1.2667
Stack temp. (deg.F) 69.4 77.7 70.8
Meter temp. (deg.F) 58.7 74.0 60.2
Sample volume (act.) 52.809 56.260 55.079
Barometric press. (in.Hg) 30.29 30.20 30.22
Volume H2O imp. (ml) 13.5 6.4 10.6
Weight change sil. gel (g) 11.2 14.0 17.9
% CO2 0.0 0.0 0.0
% O2 20.9 20.9 20.9
% N2 79.1 79.1 79.1
Area of stack (sq.ft.) 6.305 6.305 6.305
Sample time (min.) 96.0 96.0 96.0
Static pressure (in.H2O) -6.50 -6.50 -6.50
Nozzle dia. (in.) 0.215 0.215 0.215
Meter box cal. 1.0027 1.0027 1.0027
Cp of pitot tube 0.84 0.84 0.84
Traverse points 24 24 24
4/12/2019 9:34 AM 022619 CBed IN 1-3
CHEMOURS - FAYETTEVILLE, NC
INPUTS FOR HFPO DIMER ACID CALCULATIONS
CARBON BED INLET
Test Data
Run number 4 5 6
Location CBed Inlet CBed Inlet CBed Inlet
Date 2/27/2019 2/28/2019 2/28/2019
Time period 1231-1426 0823-1018 1429-1627
Operator RS/JL/JD RS/JL RS/JL
Inputs For Calcs.
Sq. rt. delta P 0.71144 0.70689 0.71440
Delta H 1.2792 1.2542 1.2750
Stack temp. (deg.F) 74.0 69.5 79.1
Meter temp. (deg.F) 68.8 59.5 70.9
Sample volume (act.) 58.052 57.133 58.141
Barometric press. (in.Hg) 30.17 29.95 29.95
Volume H2O imp. (ml) 14.0 12.0 13.8
Weight change sil. gel (g) 17.8 16.5 19.3
% CO2 0.0 0.0 0.0
% O2 20.9 20.9 20.9
% N2 79.1 79.1 79.1
Area of stack (sq.ft.) 6.305 6.305 6.305
Sample time (min.) 96.0 96.0 96.0
Static pressure (in.H2O) -6.50 -6.50 -6.50
Nozzle dia. (in.) 0.215 0.215 0.215
Meter box cal. 1.0027 1.0027 1.0027
Cp of pitot tube 0.84 0.84 0.84
Traverse points 24 24 24
4/12/2019 9:35 AM 022619 CBed IN 4-6
Test Data
Run number 7 8
Location CBed Inlet CBed Inlet
Date 3/1/2019 3/1/2019
Time period 0813-1008 1237-1433
Operator RS/JL RS/JL
Inputs For Calcs.
Sq. rt. delta P 0.71577 0.70463
Delta H 1.2917 1.2583
Stack temp. (deg.F) 64.0 71.7
Meter temp. (deg.F) 53.7 61.9
Sample volume (act.) 57.793 57.189
Barometric press. (in.Hg) 30.09 30.08
Volume H2O imp. (ml) 10.7 11.6
Weight change sil. gel (g) 17.4 17.9
% CO2 0.0 0.0
% O2 20.9 20.9
% N2 79.1 79.1
Area of stack (sq.ft.) 6.305 6.305
Sample time (min.) 96.0 96.0
Static pressure (in.H2O) -6.50 -6.50
Nozzle dia. (in.) 0.215 0.215
Meter box cal. 1.0027 1.0027
Cp of pitot tube 0.84 0.84
Traverse points 24 24
CHEMOURS - FAYETTEVILLE, NC
INPUTS FOR HFPO DIMER ACID CALCULATIONS
CARBON BED INLET
4/12/2019 9:36 AM 022619 CBed IN 7-8
36
~..~a
.8~
ISOHINETIC FIELD DATA SHEET ~
Client Chemours Stack Conditions
w.o.#~sa~a Assumed Actual
Project ID Chemours °/ Moisture 2
Mode/Source ID Carbon Bed Impinger Vol (ml)
Samp. Loc. ID IN Silica gel (g)
Run No.ID 1 CO2, % by Vol 'Q
Test Method ID M0010 02, % by Vol ~,c~
Date ID 25FEB2019 Temperature (°F)~ Q
Source/Locatlon VE Norlfi I~det Meter Temp ("F),~~
Sample Date 2- 2b Z~,q v Static Press (in HZO)- ~,
Baro. Press (In Hg)3C , ~,<~ ~/
Operator / ~'L ~/Ambient Temp (°F),~s
sou ~: ~ ~~ n G ~ ~~ l.,v~ a,.~
EPA Method 0010 - HFPO Diener Acid Page i of ~
Meter Box ID ~~
Meter Box Y r, ~~~7 K Factor 1 S
Meter Box Del H 2. aE~~" Initial Mid-Point Final
Probe ID /Length }~ r.t",<j ~- ~e;~; Sample Train (ft')
Probe Material ' Bo Leak Check @ (in Hg)
Pftot /Thermocouple ID ~T' ~,;~',-*p 7 t a Pitot leak check good
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ISOHINETIC FIELD DATA SI3EET EPA Method 0010 - HFPO Diener Acid
Cent ct~r,ours Stack Conditions nneter sox i~Zvw.o.#15a~s Assumed Actual Metereox v i. ec~~-~
Project ID Chemours °/, Moisture Meter Box Del H '2. C~ gay s
ModelSource ID Carbon Bed Impinger Vol (ml)Probe ID /Length '7 (p Sample Train (ft9)
Samp. Loc. ID IN Silica gel (g)Probe Material Born Leak Check Q (in Hg)
Run No.ID 2 CO2, % by Vol 4 Pitot /Thermocouple ID "'1(Q Pitot leak check good
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- E, . $' ~✓ Avg Noale Dia (in)
~~s , ~~ ~ .~~~Temp Check Pre-Test et Post- est Set
Meter Box Temp. z ~ f' ~,/
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Total Traverse Pts 2H Temo Chance Response 5 vas / rx,, .Q ~ r,.,
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38
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ISOHINETIC FIELD DATA SHEET
c~~ent ~,ecnaMs Stack Conditions
w.o.#i say a Assumed
ProJectlD Chemours %Moisture ~
Mode/Source ID Carbon Bed Impinger Vol (ml)
Samp. Loc. ID IN SiAca gel (g)
Run No.ID 3 CO2, % by Vol Q
Test Method ID M6010 02, % by Vol Z~.q
Date ID Temperature (°F)—[
Source/Loratlon
^~"L~BFEB2019
VE North Inlet Meter Temp ("F)j~
Sample Date Z ~j> ~j q Static Press (In HZO).—
Baro. Press (in Hg)~Q , u p
5OperatorS ~1~,~Ambient Temp (°F)~
Actual
G ~ ~~
Probe ID /Length ""~ lt5 Sample Train (ft3)
Probe Material oro 'Leak Check @ (in Hg)
Pftot /Thermocouple ID t~ Pitot leak check good
Pitot Coefficient .84 +l Pitot Inspection goad
EPA Method 0010 - HFPO Dimer Acid Page! or l
Meter Box ID lg
K FaCtofMeterBox Y ~,~p~,'7 2'
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Noale ID ~ ~~ ~7'~ Method 3 System good
• • .G + a ~
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Area of Stack (fl2)(~. 3p5 Reference Temp . S ~
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SAMPLE RECOVERY FIELD DATA
EPA Method 0010 - HFPO Diener Acid
Cllent Chemours W.O. #
Location/Plant Fayetteville, ►vc Source &Location
Run No. 1 ~ ~ ~ Q ~ ~' Sample Date ~b ~ Recovery Date ~ l~~ ,~af/~Sample I.D. Chemours -Carbon Bed - IN - 1 - M0010 - Analyst ~5 Filter Number
Im in er
1 2 3 4 5 6 7 Imp.Total 8 Total
Contents Empty HPLC H2O HPLC H2O ~~~~Silica Gel
Final i ~'~J'~~ ~'~2,~311 ~a
Initial ~100 100 Q ~~, ov 300
Gain ~1 ~'d ~c O~ ~ ~~ ~~ ~ ~?
Impinger Color ~ ~ le~ Labbl d~ ~ ~ 0
Silica Gel Condition ~ ~ Sealed?
Run No. 2 T—' ~ _~.p ~ ~ ~ ~ ~ Sample Date ~'ar~ ~ Recovery Date o~ ~ d ~ `
Sample I.D. Chemours -Carbon Bed - IN - 2 - Moo10 - Analyst ~7 5 Filter Number NI"{
Impin er
1 2 3 4 5 6 7 Imp.Total 8 TotalContentsEmptyHPLC H2O HPLC H2O # ~1,~Silica Gel
Final ~ ~0 ~~O`1.~31,G ~~' ~
Initial ~goo goo ~ ~ 7,l~soo
Gain ~n l~fl ~Q ~'~'
Impinger Color Labeled? V
Silica Gel Condition ~~ Sealed?
Run No. 3 ~ ~ ~ ~~ Sample Date .h ~ ~ g Recovery Date Q~ ~7
Sample I.D. Chemours -Carbon Bed - IN - 3 - M0010 - Analyst nj Qf' Filter Number /1/~
Impin er
1 2 3 4 5 6 7 Imp.Total 8 TotalContentsEmptyHPLC H2O HPLC H2O Silica Gel
Fina~~1~-~j r~ ~Z~7 ~o~ ~1 317 `1
Initial Q 100 100 ~~ ~300
Gain O ~~m ~ b / ~O '7.~,
Impinger Color ,/~ Labeled?
Silica Gel Condition ~ ~ Sealed?
Check COC for Sample IDs of Media Blanks ~~~~~~6we~~,~,I"~~3-b ~ ~ c1 j pt~.
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15418
VE North Inlet
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ISOHINETIC FIELD DATA SHEET EPA Method 0010 - HFPO Diener Acid Pam ~ ofdclient cnemou~s Stack Conditions nneter eox to Z~ K Factorw.o.# isms Assumed Actual Metersox v ~,o~~-~ ~ ~.$
Project ID chemours %Moisture Meter Box Del H 2. ~~qS Initial Mid-Point Finalnnoaeisource iu
Samp. Loc. ID
carbon Bed.
IN
Impinger Vol (ml)
Silica gel (g)
Probe ID /Length (3'7i0 ,,,,, ~
Probe Material Boro~ -
Sample Train (ft')
Leak Check @ (in Hg)
~ f~ r-~.<Cc o
~$~~ , l ~ s' `•
Run No.ID 4 CO2, % by Vol ~ _~/ Pitot /Thermocouple ID ~ ~ ~Pitot leak check good ey / no ~ / no e / noTest Method ID M0010 02, % by Vol 2o.~j Pltot Coefficient 0.8 Pftot Inspection good e / no / no es / rroDate ID 2Z~BFE82019 Temperature (°F)"jQ Noz~e ID ~ S 'Method 3 System good at ye~yrrff no raSource/LocaHon VE Norlh Inlet Meter Tem FPC )Noale Measurements . Z~S . 21 , 2 Temp Check Pre-Test Set Post-Test etSample Date ~- 21_ ~~q StaUc Press (In HZO)~ b, ~ Avg Noale Dia (in)~Meter Box Temp b2,`7 ~Baro. Press (in Hg) ~, rJ Area of Stack (ftZ)(e • 305 Reference Temp ~~ , I `? 1. $Operator ~ Ambient Temp (°F) fp~L~ Sample Time q (~ ~/Pass/FaU (+/- z°~a /Fail /Fail
T0121 Tf~veBB Pts 2~Tamn (:hannw Raannnca vae 1 m ~ i ..
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EPA Method 0010 from EPA SW-846
~ = . ~ i~ ~41
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OHINE IC FIELD DATA SHEETIS T
c~~ent ct,em«xs Stack Conditions
w.o.#15ai s Assumed
Project ID Chemours °/a Moisture Z
Mode/Source ID Carbon Bed Impinger Vol (ml)
Samp. Loc. ID IN Silica gel (g)
Run No.ID 5 CO2, % by Vol C>
Test Method ID M0010 02, % by Vol :Z~ . c~
Date ID ~g~E82019 Temperature (°F)(,~.
Source/Location VE Noth Inlet Meter Temp ("F)~ .
Sample Date 2.Zg_ 7,,alq Static Press (In HZO)~ {o, 5
Baro. Press (in Hg)29.95 f o
53Operator~$ TL..Ambient Temp (°F)
V ~ ~ l
EPA Method 0010 - HFPO Dimer Acid Page ~ of ~
Meter Box Iv 28 K FactorMeter Box Y t . ot9~]
Meter Box Del H 2.08'15 Initial Mid-Point Final
Probe ID /Length Q?l0~_Sample Train (ft')~ O. ~ i . tProbe Material or ~ Leak Check Q (In Hg)~~j •'~ ~«
Pitot /Thermocouple ID P'1 ~6 ', Pitot leak check good ~'sl / no 1 no / no
Pitot Coefflclent 0.84 Pitot Inspection good es / no e / no / no
Noale ID McUiod 3 System good ►~! Yes.Lrt6'o io
Actual
Noale Measurements . 2~5 - 2iS •21S Temp Check Pre-Test Set Post-Test Set—~,.5 Avg Noah Dla (in) . Z l $ Meter Box Temp r~.~ ~S
Area of Stack (ft2) . 3 OS ~/ Reference Temp '.5$~ 1
i Sample Time (o Pass/Fail (+/- 2°) / FaH f~;9 / FaiiTotal Traverse Pts ,1~} Temp Change Response 5 yes / no yes /. no
~~—~~irZt:Ql~~~.'~~~~—
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Avg Sgrt Delta P Avg Sgrt Del H Comm t
blswl = X93 ."780 -~i Sy 3 . q ~ b
~k .13b~-
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S 3S ~ ~}o
EPA Method 0010 from EPA SW-846
42
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B1 • • ~ "~~~ ~ISOKINETIC FIELD DATA SHEET EPA Method 0010 - I3FP0 Dimer Acid Page ~ of ~
client ct,e~,o~xs Stack Conditions Meter Box ID
w.o.#isaia Assumed Actual nnetersox v
Project ID Chemours %Moisture 2 Meter Box Del H
Mode/Source ID Carbon Bed Impinger Vol (ml)Probe ID /Length
Samp. Loc. ID IN Silica gel (g)Probe Material
Run No.ID 6 CO2, % by Vol cv Pftot /Thermocouple ID
Test Method ID M0010 02, % by Vol ZO.q Pitot Coefficient
Date ID ~Q~QFE82019 Temperature (°F)Noale ID
Source/Locatlon VE rFb~ti Inlet .Meter Temp ("F)-25 NoaJe Measurements
Sample Date 2~ . ~~q Static Press (in H2O).— ; 5 _ b,Avg Noale Dia (in)
Baro. Press (in Hg)Lq .q 5 Area of Stack (ft2)
Operator (~,~~- ~ '3 L ~r Ambient Temp (°F)~jg~ Sample Time
Total Traverse Pts
2~ K Factor 2 , s
2 •a Initial Mid-Point Final
~~71b Sample Traln (ft9)
Boro Leak Check @ (In Hg)
f `7 ~ti Pitot leak check good
0.84 Pitot Inspectbn good
• 2 'Method 3 System good ~y
d, o ~"7
`b n
:G
tS,,~7 t
s / no e ' / no / no
esll no / no I no
yes / no .y,.yes: P no
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.215 Meter Box Temp (uc~•-~ i
(p. gyp$ Reference Temp (p$, $'~ ~ , ~
~ Pass/Fall (+/- p°~(~~~l Fab ' as ~ ! Fail
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•
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EPA Method 0010 from EPA SW-846
l ~ 6~0 ~
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SAMPLE RECOVERY FIELD DATA
EPA Method 0010 - HFPO Diener Acid
Cllent Chemours W.O. # 15418
Location/Plant Fayetteviue, Nc Source &Location VE North inlet
Run No. 4 Sample Date ~ ~ ~ Recovery Date ~ ~7
Sample I.D. Chemours -Carbon Bed - IN - 4 - M0010 - Analyst f~ ~ Filter Number
Im in er
1 2 3 4 5 6 7 Imp.Total 8 Total
Contents Empty HPLC H2O HPLC H2O Silica Gel
Final S~/~~~~,1~'~'S •'i 4~ ,~~317
Initial ~goo goo fl ~j ~Q~j~soo
Gain ~~~,~p ~`~', v
Impinger Color V Labeled?
Silica Gel Condition ~Sealed?
Run No. 5 Sample Date ~ 7" ~ ~ Recovery Date ~ /~~
Sample I.D. Chemours -Carbon Bed - IN - 5 - M0010 - Analyst Filter Number _~_~
Impin er
1 2 3 4 5 6 7 Imp.Total 8 Total
Contents Empty HPLC H2O HPLC H2O Silica Gel
Final ~G ~~~ ~ !r ~Z`~9.7 ~a~v. 7 /~ . 5
Iflit181 100 100 0 ~ay~a~~300
Gain ~(~~j~`5 ,/~ >~
Impinger Color ~ Labeled? ~~
Silica Gel Condition Sealed?
Run No. 6 ~ ~ ~ ~Q ~ ~ Sample Date ✓` ~ v ~ ~ Recovery Date ~~
Sample I.D. Chemours -Carbon Bed - IN - 6 - M0010 - Analyst ~ Filter Number /r
Impin er
1 2 3 4 5 6 7 Imp.Total 8 Total
Contents Empty HPLC H2O HPLC H2O Silica Gel
Final ~ ~~ f~ ~~~~~~ ~5 ~.~.~31'r- ~
Initial ~100 100 ~~ ~t~i /~,300
Gain C/~~ ~j l`1°3 3 ~0
Impinger Color
Silica Gel Condition ~
Labeled?
Sealed?
Check COC for Sample IDs of Media Blanks
~ a~~ l 1 ~i
~~Z~~~~~~
~,~~.~
~~,~ 1~
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44
~.-i~'a~
ISOHINETIC FIELD DATA SHEET
Client Chemours SteCk COnditiOns
W.o.#iaa~s Assumed Actual
Project ID Chemours %Moisture
Made/Source ID Carbon Bed Impinger Vol (mq
Samp. Loc. ID IN Silica gel (g)
Run No.ID 7 CO2, °/, by Vol (,•
Test Method ID M0010 02, % by Vol 6
Date ID ~SF~1019 Temperature (°F)
Source/LocaUon VE No~ih kiiet Meter Temp ("F)j~`
Sample Date 3 - ~-2 p ~ Static Press (in H2O)__ ~
Baro. Press (in Hg)
~1 ~Operator AmWent Temp (°F)
EPA Method 0010 - HFPO Diener Acid
Meter Box ID Z$
Meter Box Y t , OC ~
Meter Box Del H Z • ~s
P~be ID /Length p~7 t G Sample Train (fl')
Probe Material oro Leak Check @ (in Hg)
PRot / Thermocrouple ID t Pitot leak check good
Pitot Ccefticfent 0.84 Pkot Inspection good
Noale ID , L ~~ Method 3 System good ~J~
Page 1 of ~
K Factor ~~ $
Initial Mid-Point Final
r;.[;iC ~~—~ .~.~.C.~~
~~no
—~'y
5; / no —)/ no
~_/ no ~! no y(~A no
i~ Ye Y .Y~s-,~'TttfNoaJe Measurements _2~ 5 - 2~5 - 2l5 Temp Check Pre-Test Set Post-Test Set
Avg Noale Dia (in), ~ 5 ~/ Meter Box Temp r{ g ~'Z
Area of Stack (ftZ)Ip. C 5~.: ~/ Reference Temp S'i I,~
Sample Time ~(p Pass/Fafl (+/- 2°~as5 / FaH
_...
s /Fail
~Tot21 Traverse Pts 'Z+~} ~ Temp Change Response 5 yas ! no yes / no
0~~~~~
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EPA Method 0010 from EPA SW-846
45
4`
ISOHINETIC FIELD DATA SHEET
client chess Stack Condit(ons
w.o.#~ say a Assumed
Project ID Chemours %Moisture 2
Mode/Source ID Carbon Bed Impinger Vol (ml)
Samp. Loc. ID IN Spica gel (g)
Run No.ID 8 CO2, % by Vol ~
Test Method ID M0010 02, % by Vol `Lc' ~'t
Date ID ?,~EfeB2Q1g Temperature (°F)
Source/Locatlon VE North Inlet ~ Meter Temp ("F)
Sample Date 3 ~ ~ _ 20, 9 Static Press pn Hz0) ', - ~, ~'
Baro. Press (in Hg)p . U
Operator ~ L ~~Ambient Temp (°F) i ~3.
~ C^i~.~~ L t' —
s no l no e / no
s /no e /no e !no
yes 1 no no }rae?"no
Noale Measurements .215 •21S •21S Temp Check Pre-Test Set Post-Test Set
Avg NoaJe Dia (in) _ 2~ s' ~/ Meter Box Temp ~ ~ ~_
Area of Stack (ftZ) b •30 S ~ Reference Temp ~ ; ],fC• .—Sample Time (~ ~p V Pass/Fail (+/- p°~ as ~ / Faii as / Faii
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~~-~~~~~~~~~-
~~~~~~7 ~~ ~ ~rs~mr~w~~.w~~~~~~~~-
~~ ~ 7 ~. 5P3 $'~. ~~q "il-bb 1•B'?s It9 ►~~ t~qAvg Sgrt Delta Avg Sgrt Del H Comments:
~ i22 ~
Actual
~~ ~~~
EPA Method 0010 - HFPO Dimer Acid Pam ~ ofd
Meter Box ID 7S K FactorMeter Box Y ~ , ~,Z 7 ~ ~,
tvieter sox oei H Z, , a Initial Mid-Point FinalProbe ID /Length P'7 i p 'Sample Train (ft3)
Probe Material Boro Leak Check @ (in Hg)
V Pitot /Thermocouple ID '7 ( ; PltoYleak check good
3 Pitot Coefficient 0.84 Pitot Inspection good
NoaJe ID , 21 ~ Method 3 System good ~
man rviax vac MINMBJ(
5`l 5.5 ~~.~5~.
EPA Method 0010 from EPA SW-846
46
~ ~'h~~
SAMPLE RECOVERY FIELD DATA
EPA Method 0010 - HFPO Dimer Acid
Client
Location/Plant
Chemours W.O. # 15418
Source &Location vE Norm InletFayetteville, NC
Run No. 7 Sample Date,~~~~~ Recovery Date 3
Sample I.D. Chemours -Carbon Bed - IN - 7 - M0010 - Analyst Filter Number
Im In er
1 2 3 4 5 6 7 Imp.Total 8 Total
Contents Empty HPLC H2O HPLC H2O Silica GeI
Final ~1.7 `~ ~l ~ ~~3//.. $~c~ ~C .~~'
Initial 6 goo goo d D ~,(,, ~soo
Gain C~~~6 Q ~~~ ~~ L .~
Impinger Color Labeled? ~~ V
~Silica Gel Condition Sealed?
Run No. 8 Sample Date ~~~Jt1 I -I Recovery Date~-~—~
Sample I.D. Chemours -Carbon Bed - IN - 8 - M0010 - Analyst Filter Number
Im in er
1 2 3 4 5 6 7 Imp.Total 8 TotalContentsE ty HPLC H2O HPLC H2O Silica Gel
Final ,~~3~ 'I ~ ~.? (~~
Initial ~100 100 ~~ / ~~~300
Gain ~,~~5 ~~~~ 1 ~~,Q (7.~'
Impinger Color L~~~/I Labeled?
~,Silica Gel Condition Sealed?
Run No. Sample Date Recovery Date
Sample I.D. Chemours -Carbon Bed - IN - 0 - M0o10 - Analyst Filter Number
Impin er
1 2 3 4 5 6 7 Imp.Total 8 TotalContentsEmptyHPLC H2O HPLC H2O Silica Gel
Final
Initial 100 100 300
Gain
Impinger Color Labeled?
Silica Gel Condition Sealed?
Check COC for Sample IDs of Media Blanks
47
SAMPLE RECOVERY FIELD DATA
Client W.O. # ~'L`~~ L~) ~l~V V'Location/Plant „ n_ ~ Source & Location~~ ~~7 IT / ' n - - ~... ~v► 'NL ~ ~~
Run No. 1 )~ Sample Date J ~ Recovery Datet.f—
Sample I.D. Analyst Filter Number
Im in er
1 2 3 4 5 6 7 Im .Total 8 TotalContentsSilica Gel
Final ~a~~Q ,7 ~D~~
Initial ~('~,~ ~,d.O'~
Gain Q
Impinger Color 3 Labeled?
Siliq Gel Condition ~ Sealed7
Run No. Sample Date Recovery Date
Sample I.D. Analyst Filter Number
Im in er
1 2 3 4 5 6 7 Imp.Total 8 Total
Contents Silica Gel
Final
Initial
Gain
Impinger Color Labeled?
Silica Gel Condition Sealed?
Run No. Sample Date Recovery Date
Sample I.D. Analyst Filter Number
Im in er
1 2 3 4 5 6 7 Im .Total 8 Total
Corrtents Silica Gel
Final
Initial
Gain
Impinger Color Labeled?
Silica Gel CondiBon Sealed?
Check COC for Sample IDs of Media Blanks
48
CHEMOURS - FAYETTEVILLE, NC
INPUTS FOR HFPO DIMER ACID CALCULATIONS
CARBON BED OUTLET
Test Data
Run number 1 2 3
Location CBed Outlet CBed Outlet CBed Outlet
Date 2/26/2019 2/26/2019 2/27/2019
Time period 0927-1143 1335-1530 0840-1035
Operator KA/AS KA/AS KA/AS
Inputs For Calcs.
Sq. rt. delta P 0.72636 0.74086 0.72467
Delta H 1.6079 1.6463 1.6433
Stack temp. (deg.F)69.5 75.8 78.5
Meter temp. (deg.F)60.2 79.4 63.3
Sample volume (act.)54.493 55.964 55.596
Barometric press. (in.Hg)30.29 30.20 30.22
Volume H2O imp. (ml)2.9 10.1 10.6
Weight change sil. gel (g)15.0 18.2 23.2
% CO2 0.0 0.0 0.0
% O2 20.9 20.9 20.9
% N2 79.1 79.1 79.1
Area of stack (sq.ft.)6.305 6.305 6.305
Sample time (min.)96.0 96.0 96.0
Static pressure (in.H2O)3.50 3.50 3.50
Nozzle dia. (in.)0.215 0.215 0.215
Meter box cal.1.0010 1.0010 1.0010
Cp of pitot tube 0.84 0.84 0.84
Traverse points 24 24 24
3/22/2019 3:33 PM 022619 CBed OUT 1-3
49
CHEMOURS - FAYETTEVILLE, NC
INPUTS FOR HFPO DIMER ACID CALCULATIONS
CARBON BED OUTLET
Test Data
Run number 4 5 6
Location CBed Outlet CBed Outlet CBed Outlet
Date 2/27/2019 2/28/2019 2/27/2019
Time period 1231-1426 0823-1018 1429-1627
Operator KA/AS/JO KA/AS/JO KA/AS/JO
Inputs For Calcs.
Sq. rt. delta P 0.72615 0.72908 0.72133
Delta H 1.6338 1.6721 1.6075
Stack temp. (deg.F)81.8 77.9 80.6
Meter temp. (deg.F)71.5 61.4 76.7
Sample volume (act.)56.016 56.152 55.732
Barometric press. (in.Hg)30.17 29.95 29.95
Volume H2O imp. (ml)10.3 14.1 17.8
Weight change sil. gel (g)22.5 21.0 22.0
% CO2 0.0 0.0 0.0
% O2 20.9 20.9 20.9
% N2 79.1 79.1 79.1
Area of stack (sq.ft.)6.305 6.305 6.305
Sample time (min.)96.0 96.0 96.0
Static pressure (in.H2O)3.50 3.50 3.50
Nozzle dia. (in.)0.215 0.215 0.215
Meter box cal.1.0010 1.0010 1.0010
Cp of pitot tube 0.84 0.84 0.84
Traverse points 24 24 24
3/22/2019 3:34 PM 022619 CBed OUT 4-6
50
CHEMOURS - FAYETTEVILLE, NC
INPUTS FOR HFPO DIMER ACID CALCULATIONS
CARBON BED OUTLET
Test Data
Run number 7 8
Location CBed Outlet CBed Outlet
Date 3/1/2019 3/1/2019
Time period 0813-1008 1237-1433
Operator KA/AS/JO KA/RS/JO/AS
Inputs For Calcs.
Sq. rt. delta P 0.73119 0.72378
Delta H 1.6713 1.6425
Stack temp. (deg.F)72.4 77.3
Meter temp. (deg.F)56.4 67.1
Sample volume (act.)55.779 55.822
Barometric press. (in.Hg)30.09 30.08
Volume H2O imp. (ml)16.8 12.8
Weight change sil. gel (g)17.4 19.7
% CO2 0.0 0.0
% O2 20.9 20.9
% N2 79.1 79.1
Area of stack (sq.ft.)6.305 6.305
Sample time (min.)96.0 96.0
Static pressure (in.H2O)3.50 3.50
Nozzle dia. (in.)0.215 0.215
Meter box cal.1.0010 1.0010
Cp of pitot tube 0.84 0.84
Traverse points 24 24
3/22/2019 3:34 PM 022619 CBed OUT 7-8
51
~~~~ ~
Sample and Velocity Traverse Point Data Sheet -Method 1
Client (,,~ ~ Operator V~Ti of
Loactlon/Plant~ VI ~ Date
Source 1 V I! .O. Number
Duct Type ~ Circular q Rectangular Duct ~"`~~0 ~PfO~"~~0 ~
Traverse Type ~, Particulate Traverse q Velocity Traverse q CEM Traverse
Distance from far wall to outside of ort In. = C
Port De th in. = D
De th of Duct, diameter in. = C-D
Area of Duct ft~
Total Traverse Points
Total Traverse Points er Port
Port Diameter in. —Flan e-Threaded-Hole
Monorail Len th
Rectan ular Ducts Onl
Width of Duct, rectan ular duct onl in.
Total Ports rattan ular duct onl
E uivalent Diameter = 2`L'W L+W
reverse Pol ocatlons
Traverse
Point % of Duct
Distance from
Inside Duct
Wall in
Distance from Outside of
Port n
.o ~ y
2 ' 7 /'
3
4
5 ~0 ~~ '~
6 i
7 ~'8 a ~
9 ~
10 ~~ ~/
11 ~~~/1 jJ
CEM 3 Point(Lony M~asurmant Una) SfraUfleaton Point Locations
1 0.167
2 0.50
3 0.833
NOIB: IT SI2CK the < l'L If7C11 US8 th'A Me[I10tl lA
(Sample port upsVeam of pilot port)
Note: If stack die >24" then adjust traverse point to 1 loch from wall
If stack die X24" then adjust traverse point to OS (nth from wall
Flow Disturbances
U stream - A ft
Downstream - B ft ~ D ~
U stream - A duct diameters
Downstream - B duct diameters
Diagram tack
1r
f~
lJ
_r
t/ ~ t>
V
~-~-+
~~
Duct Olamefers Upstream from Flow Disturbance (Distance A)
o.s +.o ~.s 2.0 2ssa
Stack Dfameter> 24 Inches ~.~~
t40 A~~%~ T ---
t~ l~Minimum Number of B } ~
30 pBrtiwtete Traverse PakNs
zs ~arcwa.> zs ~rxm~au~e. duo
zo
zo
Traverse Pdnta for Velocity 1e
li
nO~OOOOOOOmm~
~'~s~~~~~~16~~'m~~
m~-_________~
m~~~~~~~s~~~~
12
10 a fctdx) e (~ira~er)(D~Wrbance =Bend, Ecpansbn, ContracUa~, etc.)
a
2 3 4 5 6 ~ 8 9 10
Dud Diameters Downstream from Fbw Dleturbance (Distance B)
.000OOOOOOmmml
~~~~~~ '~~~~~~m
~~--~1 1 ~4"Ya~~~~~~
~-----_-_m~~~~.
W-----_-__-~~,
m~~~~-~~~~~~~~
52
~~~
I50HINETIC FIELD DATA SHEET ~ L EPA Method 0010 - I3FP0 Diener Acid
client Ghemours Stack Conditions nneter aox i~ 1, y
w.o.#~5gaa,t~.v oi, of t? ~~,~ Assumed
,
Actual Meter eox r j , ~,, ~
P~ject ID Chemours %Moisture ~ ':.Meter Box Del H ~ ~ -'
Mode/Source ID Carbon Bed Impinger Vol (m~Probe ID /Length ' Sample Train (ft')
Samp. Loc. ID OUT SINca gel (g)Probe Material ~ Bo Leak Check @ Qn Hg)
Run No.ID 1 CO2, °/ by Vol lj <~'Pitot /Thermocouple ID (~ ~Pitot leak check good
Test Method ID M0010 02, % by Vol ' s ~ , r, , J Pitot Coefficient 0.84 Pitot Inspection good
Date ID r~'~ £5FEB2019 Temperature (°F)Noale ID Method 3 System g
Source/Location VE North O tlet Meter Tem ("F)
Page l of
K Factor '`Z , ~ /~ ~ 9
Initial Mirl-Point Final
~~
t~~~~v°
~~::
u P =, ~. NoaJe Measurements , ~ ~ , L ~S ~ Temp Check re- es B OS - es eSample Date Static Press (In HZO) ~ ; ~ Avg NonJe Dfa (in) , L Meter Box Temp
Baro. Press (in Hg) ' , L~ Area of Stack (ft~) ~ Reference Temp
Operator ~ ~ Ambient Temp ~`F) ~ ~~ Sample Time l Pass/Fail (+/- 2°~ Pass ; Fall Pass / F811
Total Traverse Pts l- Temp Change Response r y~ss nn yes rN,
~~~~~~c~r~~~r~~~«~■~~~~~~~~~~~~~~~~~~~~~~~~a~~~~e~~~~~i~r~~~~r~•~s~r~~~~~r~~~~~~~~~■~r~~~r~~~~~~~r~~~~a~a~r~~~~~~r~~~~~~~~~~~~■~~i~~~~~~~~~~~~~~r~~~~~~~~~~►~~i~ra~r~~r~~«~r~~■~~~~~~~■►~~~~~r~z~r~~~~~~~`~~~~~~a~f~is~~~~~~~~r~y~~~~~~~~.~~o~~~~~~~~«~~~■~~«~~~~~~~~~~u~~~~~~~~~~r~~i~r~~~■t~~r~~rr~~~i~~~~~-~~r~r~~~~~«r~~~~~~~~
~~~,...~~~J
Avg Sgrt D~fta P ,~-1'1-~ J
~ ,~~b~~
~ uu'~J ~//. y ~.~
vg agrc uei n Comments;.v-t2J 1/
~v
.~ y / rvm uman mnuman mac vac mlfll 87(
EPA Method 0010 from EPA SW-846
53
G~ V ~~
ISOHINETIC FIELD DATA SHEET EPA Method 0.010 - HFPO Diener Acid Page ~ ofCAent Chemours Stack Conditions Meter Box ID Z ~w.o.# 154 8 Assumed Actual Meter Box Y . (~~,(~' K Factor ~`~ Gil
Pro)ect io Chemours %Moisture ~ Meter Box Del H Iflltlel Mid-Point FinalModelSource ID Carbon Bed Impinger Vol (ml) ~~ Probe ID /Length ~ Sample Train (ft') ~,J t ~ ~ ~_Samp. Loc. ID OUT Silica gel (g) Probe Material oro Leak Check @ ((n Hg) " t' ~~Run No.ID 2 CO2, % by Vol (s? , ~.' Pitot /Thermocouple ID Pitot leak check good / na / na / ~oTest Method ID M0010 02, % by Vol 2 ~D . C' Pkot Coefficient .84 Pitot Inspection good ! r10 I no s / noDate ID 25FEB2019 Temperature (°F) ~j ~ ~ Noale ID . ~,. Method 3 System c~"Source/Location 1!E Nprih putleti Meter Temp ("F) ~, } ~ C1,3 NoaJe Measurements ~~ Temp Check f8-T@St et ost- est etSample Date 7 ~P (~ ~ d~ Static Press (in HZO) ~ _Avg Noale Dia (in) , ` ~ Meter Box TempBaro. Press (in Hg) Q~10 l~~ V Area of Stack (ft2) p Reference TempOperator ` ~ ~ ` Ambient Temp (°F) ~ ~ Sample Time ~ Pass/Fafl (+/- 2°~ Prig / FaU pass /Fail
Total Traverse Pts 2'~ Temp Change Response yes ,' rw ,vs rx~
4 ~ ~V~ ~
i~- i -. 6 ~~5 ~~`~1 6 ~-1.1 C7 ~'c '~--2 -
Z.3 1 t7, ~L ~2 ' 2 l`~1 G . S ~Z2J2
7 ti ~(,~l ~'L ~2.
~3 '-~2 3 ~t ,.U ~'-23.2t~~lU S
Z ~~ 'L ~J,'L ~5 5 LID M~ Lc:
7 ~.~2 2 5 5
`l c -y p ~
2 ~'-7 ~t 2 'L7'L 9 2.'L ~'L~ 2 ~ ~t . 6 . ~L ~(-S~o.
t~~1~`i 2 811~I 2 ~3~S ~~1,L5 `iAv Delta P
.5~9~ `~
Av D
1.6~t~
Total Volume Av Ts Av Tm 1 MIn/Max i au Max Max Vac MinlMa~c55.x,6 ~ 15.1~~ 7a. 7`i ~ 1251126 ~ti`~tio G'1- `~ 3~" ~'
Comments: EPA Method 0010 from EPA SW-846Avg Sgrt Detta P Avg Sgrt Del
A 54
ISOHINETIC FIELD DATA SHEET EPA Method 0010 - HFPO Dimer Acid
Client
e/L
Chemours Stack Conditions Meter Box ID 22
w.o.#~sa~a Assumed Actual nneteraox v ~,p~~~
Project ID Chemours %Moisture ;Meter Box Del H 2
Mode/Source ID Carbon Bed Impinger Vol (ml)Probe ID /Length ~ Sample Train (k')
Samp. Loc. ID OUT Silica gel (g)Probe Material Boro ~ Leak Check Q (in Hg)
Run No.ID 3 CO2, °/a by Vol Q,Q Pitot /Thermocouple ID ~Pftot leak check good
Test Method ID M0010 02, °/a by Vol ~, ~~ Pitot Coefficient 0.84 Pitot Inspection good
Date ID
S ti
25FEB2019
VE
Temperature (°F)
Meter Tem ("F)
'r ~','~ Noale ID . 1 Method 3 System goon
Page ~ of
K Factor~ ~,p
Initial Mir1-Point Final
~ ~~J 9•m
~~
~~~~~~
~V ~t1i'~Dort oca on
Sample Date
:North Outlet P ,'L Noale Measurements ,~~C~ •~,~l~ .'L~K
'~+j,
Temp Check ~fe-"1851 be o5 -18S 2
a Static Press (in H2O)Avg Nome Dia (in)Meter Box Temp ~'y 2
Baro. Press (in Hg)0.Area of Stack (ft2)Reference Temp ~~~ ~,r—
Operator v Ambient Temp ~F)5~' Sample Time ~Pass/Fall (+/- p°~ as Fail ~ Fall
Total Traverse Pts `L~ ~/Temp Change Response i y~cs ' r~yes " r
~V`i:~~~L".~i'i~~i:iii ~ f~rT~iYi~~~~~'~~L~~
~`I'~~~+~a~~r~~~~'~~_~~i~~~~~~L~~i'~~i~~ii~~-~~
~~~~~~~ ~ ~t%1V~~~~~~~~~—orn~~~~dt~r~~~~~•~~;~~~~~~r~.~~~.~~o~~~~n~r_~ -~~~s~~~~~~`~~o~'~s~~~~~r•~~~~~«~~~~r~L~~~~~~:~~~1Q~~1~~rr~ r c!F~~«~~Ql~~~,~~:~~~~
~~~~~~~n~~~ ~~~~~~~.r~~~:~~
Avg qrt Delta
~ ~~~~~
r~i~;~~ Iti~~gr~'J IZ~."~~
.vg aq ~ ei n Commeryts:
,`~ ~~, /l
I/
nv i ni muumnn rvmuman I a7c I m vac I MI ~~~d'3,z [~li~ [~l~tib 6 yQ
EPA Method 0010 from EPA SW-846
J ~~,~
--f
55
SAMPLE RECOVERY FIELD DATA
EPA Method 0010 - HFPO Diener Acid
Client
Location/Plant
Chemours
Fayetteville, NC
W.O. #
Source &Location VE North Outlet
15418
Run No. 1 ~ ~, ~ ~ ~j ~~ Sample Date ~ /' ~ ~ ~ Recovery Date j' ~~
Sample I.D. Chemours -Carbon Bed -OUT - 1 - M0010 - Analyst /tij Filter Number /~'
Impin er
1 2 3 4 5 6 7 Imp.Total 8 Total
Contents Empty HPLC H2O HPLC H2O ~'~Silica Gel
Final d,1 ~i~o ~ O Q /0~~l~ y~~i ~lS~'
Initial goo goo ~O ~soo
Gain ~'~~c~~~ /~ ~~~
Impinger Color ~j.~ Labeled?
Silica Gel Condition ~~~ Sealed?
Run No. 2 ~ ~. O ~ fl Sample Date ~' . ~'G~1 ~ Recovery Date
Sample. I.D. Chemours -Carbon Bed OUT - 2 - M0010 - Anal st ,y~y ~~ f' Filter Number /~i'G
Impin er
1 2 3 4 5 6 7 Imp.Total 8 Total
Contents Empty HPLC H2O HPLC H2O Silica Gel
Final ~~D~r ~~~,~~j Igo
Initial p goo goo ,3 /soo
Gain ~~/~/~~~j ~~ r~
ImpingerColor ~~ ~ Labeled.
Silica Gel Condition Sealed?
Run No. 3 ~ ~, a. ~;~ Sample Date ~ ~'/ ~ ~!Recovery Date ~
Sample I.D. Chemours -Carbon Bed -OUT - 3 - M0010 - Analyst ,~f' Filter Number
Impin er
1 2 3 4 5 6 7 Imp.Total S Total
Contents Empty HPLC H2O HPLC H2O Silica Gel
Final D 71 ~ 9 ~~~. (✓~b~. ~i 3Z3.Z
Initial ~goo goo ~~~soo
Gain b r~O '~j ipr ~~
ImpingerColor a~1 r,1,~,~ Labeled?
Silica Gel Condition ~ Sealed?
Check COC for Sample IDs of Media Blanks
56
~""
ISOHINETIC FIELD DATA SHEET o ~ EPA Method 0010 - HFPO Dimer Acidci~ent Cnamours Stack Conditions nneter sox i~ `'L'Lw.o.# ~Sa~B Assumed Actual Meter sox v ,pt~[Project ID Chemours %Moisture i Meter Box Del H
Page ~ of,~
K Factor ~, j~
Initial Mid-Point Final
f /s v • 'a
~I
~T~t'•~~E~%'r.~
Made/Source ID Carbon Bed Impinger Vol (ml)Probe ID /Length Sample Train (ft')
~~
Samp. Loc. ID OUT Sipca gel (g)P~be Material Bor Leak Check Q (in Hg)Run No.ID 4 CO2, % by Vol ~Pitot /Thermocouple ID Pitot leak check goodTest Method ID M0010 02, % by Vol ~ ~~ °Pitot Coefficient 0.Pitot Inspection goodDate ID 25FEB2019 Temperature (°F) =}, NonJe ID ~,: T"Method 3 System go/~Source/Location VE--North Outlet Meter Temp (F) "~ ~ t~; ' Noale Measurements i1, ~, ,y ,Z Temp Check ~1 e~ se t Sei I o WiestSample Date ~ StaUc Press (in H2O) '~, Avg NoaJe Dia (in) 15' Meter Box TempBaro. Press (in Hg) K , ~ D.~ Area of Stack (ft2) ,3 5 ~ Reference TempOperator ~ Ambient Temp (°F) ~ ~ Sample Time Pass/Fail (+/- z°) Pas r` Falt a / F80Total Traverse Pts Temp Change Resppnse i y?s r no yq3 ! po
~~r,~ry~
~~-~~~~~LZ~l~~~~r ~~~~l~~~fi~-
~~~!rnL'~~~li~t1~~E6~~E~1~~~3~~1+~fir~L~'~~~.`~~I.~!~r~1~'~ati~~~b`~~I.~~~" ~G~~:~~~~Q~~~lL~~~'~~1~~
0~~~~l~:~l~~~;~~~'~~~l~tL~itG~~~i'=~~'~C~~
~i~L'~~~~tl~`,~f;~i'~iL~~~~~G~'!`~lLti~~
IIe~Tt~~~r~~[~~E%~~~~~~~[irll~lft~l~[~~~~Ci~~
~~~~l~~~#I~E~~~~~~~~:~Ri1~~~~~~fi'liif~~
~~~-~~~ i ~~~~~~~~~~-~i L
~[~L'L'~~6~~~~E7~~~~N~:~~r alt,.i~i1~~~
,vv uetta r Av u n i oral v wme v i s~ r~vg i
Avg Sgrt Delta P Avg Sgrt Del H CommenT~:~.~r►.6 ~~;~( ~.~~ J
~5~~~ I ~tis~i ~ ~ c~ ~~ ~ ~ ~e~ ~ ~ o ~S7 I I ~ ~' ~ v~EPA Method 0010 from EPA SW-846 ~~ e~
~ ✓~57
~ r/V ~/t ~/ ~i
ISOHINETIC FIELD DATA SHEET EPA Method 0010 - HFPO Dimer Acid
client chemours Stack Conditions _ Meter eox io ti2
w.o.#~s41a Assumed Actual Meter Box Y , i'1p ~
Project ID Chemours %Moisture I i Meter Box Del H l{
Mode/Source ID Carbon Bed Impinger Vol (ml) !Probe ID /Length '~0 o Sample Traln (ft')
Samp. Loc. ID OUT SIHca gel (g)Probe Material Leak Check @ (in Hg)Run No.ID 5 CO2, % by Vol 0 ~ ~Pitot /Thermocouple ID (?Pitot leak check good
Test Method ID M0010 02, % by Vol ~ ~~,Pitot Coefficient .84 Pitot Inspection good
Date1D
Souroe/Location
25FEB2019 Temperature (°F)
Meter Temp ("F)
Noale ID ~ ~..j,
N Method 3 System g~
VE North Outlet
Page of
K Factor ~'~~
Initial Mir1-Point Final
J t ~1 + ~/ i
~~~~
~
~~~~~~_ oaJe Measurements ~~j S' ~ rj,~ ~ • Temp Check - es e os - I eS eSample Date Static Press (In HZO) ~ ~~ ~/ Avg NoaJe Dia (in) . `L~ ~/ Meter Box Temp C~'
Baro. Press (fn Hg) 29 •Q$ - Area of Stack (ft2) 0 Reference Temp rj' ' rOperator ,(}~l S~ ~ AmWent Temp (°F) ~~j Sample Time Pass/Fail (+/- 2~ as Fail Pa Fa0
TOtal TrdVeBe Pts Temo Chancre Resrxinsw 5 vac ;' rn ~~t .;,.
are.~~~~~~~~r~~~irr~~~~c~~~
~R~~~~~~c~~~~~~~~~~`~~~~r~~~
s;~~~~~~a~~~~RE ~r~-_~~~e~~~~■rs~u~~~~~~~~~d~~~-a -~~~~~r~~~~~~~~~~~~~~F-~r~~~~-~~~~~~~~~~r~~~~~~~~~~~~~~—
~c~lE:~~~~~+~~ ~ ~~~~rnr~~~~=r•~~ou~~~~- r ~~r~r ~~~`~~~~r~~~o~~■~~~~~~u~r~i~r.~~r~~~~~
~~~~~~[c~I~~~,C~~~i~Qi~l~~'~r3=~i~~~l4~~~f~L~#'r,iG'~~6Z~~~iI~~iL~~.L~■f~~fQ'~~~t~4RF~~~~~~~G~~41['~~~~~Ir~l~~~~~L'L'~~
~~i~~~~~~~~'~r3~~~:i~Rill~~il~[.t~~74~~~~~fa~i~~~~~~~4~~iT~~~i!~~~t3~7~ic~L~~~OL['l~~~
.551 J
Avg Sgrt Delta f
.~~~
~ ~ ~~ ~
~, 1.~
J ~•~~~• o.. ~.~~~~~.~a.. ~ ian mru vac muuivia~cItis~i26 tisf i2~ G ( 7 `~1 g
EPA Method 0010 from EPA SW-846 ~~~~q~~
j~ o~V~~o~ s
~ 7 ~~58
(~c~~l~~~~l
ISOHINETIC FIELD DATA SHEET EPA Method 00!1~0^ - HF.PO Dimer Acid
Client ChBmours StBCk Condl~ions Meter Box ID {~
w.o.# ~5ata Assumed Actual Meter eox r .DO ti_ ..._,Project ID Chemaurs % Moisture Meter Box Del H L
Mode/Source ID Carbon Bed Impinger Vol (ml) ~ _ Probe ID /Length Sample Train (ft3)
Samp. Loc. ID OUT Silica gel (g) Probe Material Leak Check @ (In Hg)Run No.ID ^6~ CO2, % by Vol ~'~~ ~ 3 Pitot /Thermocouple ID Pitot leak check goodTest Method ID M0010 02, % by Vol ~,¢~', ~1 Pttot Coefficient 0.84 Pitot Inspection goodDate ID ~ 25FEB2019 Temperature (°F) ~ y NonJe ID ~ Method 3 System goo
Page ~ of
K Factor ~ O
Initial Mid-Point Final
•i :7
`
t%A~~~•'
Source/LocaUon U~ North Outlet Meter Temp (F) ~{ Noale Measurements ~ Temp Check ~eSt b2 OS - S2 t 5~Sample Date ~ Static Press (in HZO) , . ~/ Avg Noa1e Dia (in) ~ Meter Box Temp 7Baro. Press (In Hg) ~ Area of Stack (kZ) ~/ Reference TempOperator Ambient Temp (°F) ~q Sample Time Pass/Fail (+/- 2°~ Fell FaIC
Total Traverse Pts Temp Change Response i y?s i np yres ! r~
oIL~4~ JTrc~a~~~~n~~~~~~m~~~~~~~~
~i~~t~~■L*~'~L~G~~~~1_~i►L7'~llr~~i ~7~~~i~L'i~~~~~~~.'f~liL'' ~~" /~G11!l~i~1~lL'~~L~~.►`L'~~
~~~~~~~~~~~~~~~~r~~■~~-r~~~~~~i~~~~~~■d~~~~~~~~~~~r~r~■rc~~~r,~~.7~:~~
~~~~~~~~~~~Lfr~~~~~~~-Y
~7~~~i ~it~4 ~ '~~[~~~i~►'~t~«~~~~`'~4~~~~~~~R~~~~-r;~~r~~r~~~~~r"~~~~~~~~~~~-~~~~~~~~~~~r~~~c~~~~~~~d~~rrr~,~~~V~~~~~~r~-~~~~r~oe~~ih~~u
avg uerta r/ ~~ bCl~~~ "J ~l ~I a1Z `~. Avg Sgrt De Avg Sgrt Del H Comm ts:
J ~ ~r
`L~i { ?b.70 ~m `~ ~ G~'IIti6 ~t~511ti6 ~ 6~~7~8~,~`1571 I ~ ~~0~
EPA Method 0010 from EPA SW-846 f r/
~ ~ ~~v~59
~~ c~~ ~.~
SAMPLE RECOVERY FIELD DATA
EPA Method 0010 - HFPO Diener Acid
Cllent Chemours W.O. # 15418
Location/Plant Fayetteville, NC Source &Location vE North ouuet
Run No. 4 Sample Date ~ ~7 f~ Recovery Date ~~
Sample I.D. Chemours -Carbon Bed -OUT - 4 - M0010 - Analyst ~ Filter Number /v~
Im in er
1 2 3 4 5 6 7 Imp.Total 8 Total
Contents Empty HPLC H2O HPLC H2O Silica Gel
Final -Q a~Z'~~:i~3~ 3 ;g22.s'
Initial goo goo ~ i soo
Gain ~O ~0~~~j~~y
Impinger Color ~ , (~' ti Labeled?
0 ~Silica Gel Condition Sealed?
Run No. 5 Sample Date ~ ,'~ ~ "/ Recovery Date
Sample I.D. Chemours -Carbon Bed -OUT - 5 - M0010 - Analyst ~ ~ Filter Number ~~
Impinger
1 2 3 4 5 6 7 Imp.Total 8 Total
Contents Empty HPLC H2O HPLC H2O Silica Gel
Fina~fJ/D ~~ ~p ?~~~i. ~3~ ~3z/ ~
Initial ~100 100 Q ~j i !~~,7 300
Gain V ~~~~ ~ ~~ ~~
Impinger Color ~ Labeled? / f
Silica Gel Condition ~ Sealed? ~~
Run No. 6 ~ ~{ ~ ~~ '►/~ n Sample Date ~ /'~ ~ y Recovery Date ~~.i ~~ v
Sample I.D. Chemours -Carbon Bed -OUT - 6 - M0010 - Analyst S Filter Number
Im in er
1 2 3 4 5 6 7 Imp.Total 8 TotalContentsEmptyHPLC H2O HPLC H2O Silica Gel
Final ~1 ~~~~~~~. ~~ ~ 7, `~~ZZ.~;
Initial ~goo goo ~ `~300
Gain ~`~~~,'1 ~~~ Z d /
Impinger Color ,/I Labeled? ~ ~/~Silica Gel Condition Sealed?
Check COC for Sample IDs of Media Blanks
f.,, ~ ~ Jc~~ r~~ ~~~1~~ I ~ ~o , ~ ~ ~ ~, ~ ~1 ~
60
1 ,~/ v v s - v vv
ISOHINETIC FIELD DATA SHEET EPA Method 0010 - HFPO Diener Acid Pam I or ICuent Chemours Stack Conditions Meter sox to ~'L~-w.o.# ~5a18 Assumed Actual nneter sox r ~ ,Fjp ~ b ~ K Factor ~3 d
Project ID Chemours °/a Moisture ~ MeterBox Del H ~_, ~ ~y Initial Mid-Point FinalMode/Source ID Carbon Bed Impinger Vol (ml) ~ Probe ID /Length ~ ~Q --T~~ Sample Train (ft3) p QT.„.t._Samp. Loc. ID OUT Silica gel (g) Probe Material Boro Leak Check @ (in Hg) ~ ~~Run No.ID 7 CO2, % by Vol ~ .~ ~ Pitot /Thermocouple ID ~ Pitot leak check good / no C no (noTest Method ID M0010 02, % by Vol •'~l ,/ Pitot Coefficient 0.84 3 Pitot Inspection good / no / na / noDate ID 25FEB2019 Temperature (°F) - ~ ~ NonJe ID , r Method 3 System good yerf-noSource/Locatlon VE North pullet Meter Temp ("F) ~ '~, ,+j~ NonJe Measurements ~'~,j5 ifs , 'Z ~ Temp Check fe- est 2t Ost- Bst etSample Date J~~ ~ ~q Static Press (in H2O) Avg Noale Dia (in) . '~5~—Meter Box Temp
Baro. Press pn Hg) '3 ~i J Area of Stack (ft2) (~ Reference Temp "LOperator S ~' Ambient Temp (°F) ~~ Sample Time ~ V Pass/Fail (+/- z°~ Fap R FallTotal Traverse Pts 2 Temp Change Response i yes ,' rro yes i no
~~
~l~~~~~~~~~~^,ft~tQ'~II~L"ji~i~i~~~
ii~~~R~~~~ir~GG~~!■l~r~~~~~~~~."~~
~7~7~~~i'~~G~ ~i~~.'oiII~~~l~r~~.~~~~~~~it!!
~~J~~~~~~ ,Ri~~l~~~ ~ i!!i~fII~l~il~l~i`~fi~~~~
~t~JE-~~■~3~~:~[[~~!~i7c~■cif r~l.~L'~~~~~~~~~l~~dC+~[t]II~~iT~~L'~'~~1r ~l~~L'l~~ic~i~i~~~7►~I~l~~~~ ~i~l~t~i`i~~~~II~l~~~L~~ii~~iF~sl~i~~10~l~~~~~..~'~~iTi ~~i i■f~~L`[~it•~~T~~. ~~~l~3'.~~~L~I~~I~~i~~-~II~l~II~~Tc~s.'~~~~~~I~~~~t3~~~i~~t~~ . '~~~'iL~~~r '~L~i7~~ifF3~~~5~~~~6~[~~~~i~~L'~i~~i~~~r~~.'Ti~~:~Q'~~
~i~~' ;i~~lIIiT~i7F~~~'~~II~~~f~~~f~~3•~~1~i~i+'~/,I
,vv~~ rta r~~~~Avg~ ~a nJ6
Avg Sgrt Delia P,-~ 3 ~~q Avg Sgrt Del h1, ~~ ~
OI81 VOIUff18 HV9 I SJ avg i m MINM3X MINM2X M2X M2X V8C MINMaJ(5~5,~ Zq ~ l2~It7 SG,tit7 f ltisl nb I tiSl itib 5 L ~ `~51 u 9
EPA Method 0010 from EPA SW-846
i ~~ ~ o
J~~~
~ t~✓61
ISOKINETIC FIELD DATA SHEET EPA Method 0010 - HFPO Diener Acid Page~of~client Chemnurs Stack Conditions Meter Box ID 2-w.o.#~54~8 Assumed Actual nneter eox r K Factor ~
Project ID Chemours °io Moisture ~Meter Box Del H Initial Mid-Point FinalMode/Source ID Carbon Bed Impinger Vol (ml)Probe ID /Length ,Sample Traln (ft')d:,,(If ~ ,Samp. Loc. ID OUT Silica gel (g)Probe Material 8oro Leak Check @ (in Hg)Run No.ID 8 CO2, °/a by Vol (^ ~+Pftot /Thermocouple ID 7 fj' Pitot leak check good / no / no / noTest Method ID M0010 02, % by Vol '~`,~/ Pitot Coefflclent 0.84 Pitot Inspection good / ~o / no j npDate ID 25FE82019 Temperature (°F)NoaJe ID , `~ Method 3 System good .yee-~-f~e ~ye6•E+gqSource/LocaUon VE Notth Outlet Meter Temp ("F)(,Noale Measurements ~ y ~ ti( , ~.~ Temp Check ~B- eSt et OSt-BSt BtSample Date ~ f~Ar ~ °Static Press (in HZO)`~3, Avg No~Je Dfa (in)~ Meter Box Temp 3Baro. Press (in Hg)~ E! V Area of Stack (ftZ)~ 0 Reference Temp ~LOperatort ~'T Ambient Temp (°F)~2„Sample Tlme Pass/Fafl (+/- 2°)a / Feif —i FaII
Total Traverse Pts ~.~ Temp Change Response is res I no yes no
~~.ice
~~T~~~d~fi~~C~~iiZ~~~:~t~i~L~`~ir"~~
~'~~~~~~~~e~~~7~'~C~i~,i`^~~l~i~Q~~
~~~~~~~~~~~~r~~~~t~~'~~~~~~~~~~~~~7~~~«r~~~«'~~~~~:~~~~~~~~~~ ~~■~c~«~r~~i~r~'~~~~~~~~~~:~~~.~~~~~~~~~«~~~►rn~~~~~~~~
~rl~~~~■■~~fr~~~i~r~~~~~~~~s.~~~~~~~t~~R~3i'~~~'-i~~-~~~~1►~L7~iE~s'~~
~'~~~R~~~~~ii~fr~t ~~~~~L'f~i~~i~~~
~~~~dti~~~~~~~r~r~m~~~a~~~~~~~~~
~r~~ ~ lf~L~~~fl~~~f~alLs~iZ~I■rit~~~~~. ~L~it ~i~~■-~e~~1 J
Avg Sgrt C
.~2
n i oral vowme J Avg i s J Avg rm J
Avg Sgrt Del Hl
~t ~' J l
MINMax Min/Max Max Man Vac MIN ax~'l~,b 1251izs 58 7 ~7 Sti
EPA Method 0010 from EPA SW-846
62
G ~ c~
SAMPLE RECOVERY FIELD DATA
EPA Method 0010 - HFPO Dimer Acid
a
Client
Location/Plant
Chemours
Fayetteville, NC
W.O. #
Source &Location
15418
VE North Outlet
Run No. 7 Sample Date ~ ~, ! Recovery Date /~
Sample I.D. Chemours -Carbon Bed -OUT - 7 -M0010 - Analyst Filter Number
Im in er
1 2 3 4 5 6 7 Imp.Total 8 Total
Contents Empty HPLC H2O HPLC H2O Silica Gel
Final ' J ~l ~~"~,31 ~ ~ 7 2 ~' ~- ~j I'7.4
Initial Q goo goo l~f ~~,~~j ~. 7 300
Gain ~~~Q ~~~ O r
Impinger Color n Labeled?
ySilica Gel Condition Sealed?
Run No. 8 Sample Date J Recovery Date 3
Sample I.D. Chemours -Carbon Bed -OUT - 8 - M0010 - Analyst ~ ~ Filter Number !~
Impinger
1 2 3 4 5 6 7 Imp.Total 8 Total
Contents Empty HPLC H2O HPLC H2O Silica Gel
Final 2 -`3 3J'L. ~,~I ~ ."7
Initial 100 100 ~~-i~,f 300
Gain ~ •Q /9
Impinger Color Q p Labeled?
Silica Gel Condition l Sealed?
Run No. Sample Date Recovery Date
Sample I.D. Chemours -Carbon Bed -OUT - 0 - M0010 - Analyst Filter Number
Im in er
1 2 3 4 5 6 7 Imp.Total 8 Total
Contents Empty HPLC H2O HPLC H2O Silica Gel
Final
Initial 100 100 300
Gain
Impinger Color Labeled?
Silica Gel Condition Sealed?
Check COC for Sample IDs of Media Blanks
~l ~~ 1 ~
~~ ~ v'
~~~fro ~ ~~t ~
5 100 100
0
5 0 0 12.8
63
METHODS AND ANALYZERS
Client:
Location:
Source:
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
25 Feb 2019
Project Number:
Operator:
Date:
Folders.A-F\Chemours Fayetteville\15418.002.010 VE North 2019\Data\FEBUARY_MARCH 2019\022519 DIVISION
Program Version: 2.1, built 19 May 2017 File Version: 2.03
Computer: WSWCAIRSERVICES Trailer: 27
Analog Input Device: Keithley KUSB-3108
Channel 1
Analyte O2
Method EPA 3A, Using Bias
Analyzer Make, Model & Serial No. Servomex 4900
Full-Scale Output, mv 10000
Analyzer Range, %25.0
Span Concentration, %21.0
Channel 2
Analyte CO2
Method EPA 3A, Using Bias
Analyzer Make, Model & Serial No. Servomex 4900
Full-Scale Output, mv 10000
Analyzer Range, %20.0
Span Concentration, %16.6
64
CALIBRATION DATA
Number 1
Client:
Location:
Source:
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
25 Feb 2019
Project Number:
Operator:
Date:
Start Time: 10:59
O2Method: EPA 3A
Calibration Type: Linear Zero and High Span
Calibration Standards
%Cylinder ID
12.0 CC18055
21.0 SG9169108
Calibration Results
Zero 6 mv
Span, 21.0 %7997 mv
Curve Coefficients
Slope Intercept
380.5 6
CO2
Method: EPA 3A
Calibration Type: Linear Zero and High Span
Calibration Standards
%Cylinder ID
8.9 CC18055
16.6 SG9169108
Calibration Results
Zero 4 mv
Span, 16.6 %8287 mv
Curve Coefficients
Slope Intercept
499.6 4
65
CALIBRATION ERROR DATA
Number 1
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
25 Feb 2019
Project Number:
Operator:
Date:
Start Time: 10:59
O2Method: EPA 3A
Span Conc. 21.0 %
Slope 380.5 Intercept 6.0
Standard
%
Result
%
Difference
%
Error
%Status
Zero 0.0 0.0 0.0 Pass
12.0 12.0 0.0 0.0 Pass
21.0 21.0 0.0 0.0 Pass
CO2
Method: EPA 3A
Span Conc. 16.6 %
Slope 499.6 Intercept 4.0
Standard
%
Result
%
Difference
%
Error
%Status
Zero 0.0 0.0 0.0 Pass
8.9 8.9 0.0 0.0 Pass
16.6 16.6 0.0 0.0 Pass
66
BIAS
Number 1
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
25 Feb 2019
Project Number:
Operator:
Date:
Start Time: 11:05
O2Method: EPA 3A
Span Conc. 21.0 %
Bias Results
Standard Cal.Bias Difference Error
Gas %%%%Status
Zero 0.0 0.0 0.0 0.0 Pass
Span 12.0 12.0 0.0 0.0 Pass
CO2Method: EPA 3A
Span Conc. 16.6 %
Bias Results
Standard Cal.Bias Difference Error
Gas %%%%Status
Zero 0.0 0.0 0.0 0.0 Pass
Span 8.9 8.8 -0.1 -0.6 Pass
67
RUN DATA
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
25 Feb 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
response times
11:07:50 12.1 8.8
11:08:00 16.9 4.7
11:08:10 20.4 0.9
11:08:20 20.7 0.4
11:08:30 12.4 2.0
11:08:40 1.6 0.6
11:08:50 0.1 0.1
O2/CO2 UP
11:09:00 0.0 0.0
11:09:10 0.0 0.0
11:09:20 0.0 0.0
11:09:30 3.0 1.8
11:09:40 10.4 7.1
11:09:50 11.8 8.6
11:10:00 12.0 8.8
O2/CO2 DOWN
11:10:10 12.0 8.8
11:10:20 12.0 8.8
11:10:30 12.0 8.8
11:10:40 9.6 7.2
11:10:50 1.5 1.8
11:11:00 0.1 0.3
11:11:10 0.0 0.1
END
11:11:20 0.0 0.1
11:11:30 0.0 0.1
Avgs 7.3 3.5
68
RUN SUMMARY
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
25 Feb 2019
Project Number:
Operator:
Date:
O2 CO2
Method EPA 3A EPA 3A
Conc. Units %%
Time: 11:07:40 to 11:11:30
Run Averages
7.3 3.5
Pre-run Bias at 11:05
Zero Bias
Span Bias
Span Gas
0.0 0.0
12.0 8.8
12.0 8.9
Post-run Bias at 07:37
Zero Bias
Span Bias
Span Gas
0.0 0.1
12.0 8.9
12.0 8.9
Run averages corrected for the average of the pre-run and post-run bias
7.3 3.4
69
BIAS AND CALIBRATION DRIFT
Number 2
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
26 Feb 2019
Project Number:
Operator:
Date:
Start Time: 07:37
O2 Method: EPA 3A
Span Conc. 21.0 %
Bias Results
Standard Cal.Bias Difference Error
Gas %%%%Status
Zero 0.0 0.0 0.0 0.0 Pass
Span 12.0 12.0 0.0 0.0 Pass
Calibration Drift
Standard Initial*Final Difference Drift
Gas %%%%Status
Zero 0.0 0.0 0.0 0.0 Pass
Span 12.0 12.0 0.0 0.0 Pass
*Bias No. 1
CO2
Method: EPA 3A
Span Conc. 16.6 %
Bias Results
Standard Cal.Bias Difference Error
Gas %%%%Status
Zero 0.0 0.1 0.1 0.6 Pass
Span 8.9 8.9 0.0 0.0 Pass
Calibration Drift
Standard Initial*Final Difference Drift
Gas %%%%Status
Zero 0.0 0.1 0.1 0.6 Pass
Span 8.8 8.9 0.1 0.6 Pass
*Bias No. 1
70
RUN DATA
Number 1
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
26 Feb 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
RUN 1
PORT 1
09:27 20.9 0.1
09:28 20.9 0.1
09:29 20.9 0.1
09:30 20.9 0.1
09:31 20.9 0.1
09:32 20.9 0.1
09:33 20.9 0.2
09:34 20.9 0.2
09:35 20.9 0.2
09:36 20.9 0.2
09:37 20.9 0.2
09:38 20.9 0.2
09:39 20.9 0.2
09:40 20.9 0.2
09:41 20.9 0.2
09:42 20.9 0.2
09:43 20.9 0.2
09:44 20.9 0.2
09:45 20.9 0.2
09:46 20.9 0.2
09:47 20.9 0.2
09:48 20.9 0.2
09:49 20.9 0.2
09:50 20.9 0.2
09:51 20.9 0.2
09:52 20.9 0.2
09:53 20.9 0.2
09:54 20.9 0.2
09:55 20.9 0.2
09:56 20.9 0.2
09:57 20.9 0.2
09:58 20.9 0.2
09:59 20.9 0.2
10:00 20.9 0.2
10:01 20.9 0.2
10:02 20.9 0.2
10:03 20.9 0.2
10:04 20.9 0.2
71
RUN DATA
Number 1
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
26 Feb 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
10:05 20.9 0.2
10:06 20.9 0.2
10:07 20.9 0.2
10:08 20.9 0.2
10:09 20.9 0.2
10:10 20.9 0.2
10:11 20.9 0.2
10:12 20.9 0.2
10:13 20.9 0.2
10:14 20.9 0.2
10:15 20.9 0.2
PORT CHANGE
PORT 2
10:55 20.9 0.1
10:56 20.9 0.1
10:57 20.8 0.1
10:58 20.8 0.2
10:59 20.8 0.2
11:00 20.9 0.2
11:01 20.9 0.3
11:02 20.9 0.3
11:03 20.9 0.3
11:04 20.9 0.2
11:05 20.9 0.2
11:06 20.9 0.2
11:07 20.9 0.2
11:08 20.9 0.2
11:09 20.9 0.2
11:10 20.9 0.2
11:11 20.9 0.2
11:12 20.9 0.2
11:13 20.9 0.2
11:14 20.9 0.2
11:15 20.9 0.2
11:16 20.9 0.2
11:17 20.9 0.2
11:18 20.9 0.2
11:19 20.9 0.2
11:20 20.9 0.2
11:21 20.9 0.2
72
RUN DATA
Number 1
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
26 Feb 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
11:22 20.9 0.2
11:23 20.9 0.2
11:24 20.9 0.2
11:25 20.9 0.2
11:26 20.9 0.2
11:27 20.9 0.2
11:28 20.9 0.2
11:29 20.9 0.2
11:30 20.9 0.1
11:31 20.9 0.1
11:32 20.9 0.1
11:33 20.9 0.1
11:34 20.9 0.1
11:35 20.9 0.1
11:36 20.9 0.1
11:37 20.9 0.1
11:38 20.9 0.1
11:39 20.9 0.1
11:40 20.9 0.1
11:41 20.9 0.1
11:42 20.9 0.1
11:43 20.9 0.1
Avgs 20.9 0.2
73
RUN SUMMARY
Number 1
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
26 Feb 2019
Project Number:
Operator:
Date:
O2 CO2
Method EPA 3A EPA 3A
Conc. Units %%
Time: 09:26 to 11:43
Run Averages
20.9 0.2
Pre-run Bias at 07:37
Zero Bias
Span Bias
Span Gas
0.0 0.1
12.0 8.9
12.0 8.9
Post-run Bias at 11:44
Zero Bias
Span Bias
Span Gas
0.0 0.1
12.0 8.9
12.0 8.9
Run averages corrected for the average of the pre-run and post-run bias
20.9 0.1
74
BIAS AND CALIBRATION DRIFT
Number 3
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
26 Feb 2019
Project Number:
Operator:
Date:
Start Time: 11:44
O2 Method: EPA 3A
Span Conc. 21.0 %
Bias Results
Standard Cal.Bias Difference Error
Gas %%%%Status
Zero 0.0 0.0 0.0 0.0 Pass
Span 12.0 12.0 0.0 0.0 Pass
Calibration Drift
Standard Initial*Final Difference Drift
Gas %%%%Status
Zero 0.0 0.0 0.0 0.0 Pass
Span 12.0 12.0 0.0 0.0 Pass
*Bias No. 2
CO2
Method: EPA 3A
Span Conc. 16.6 %
Bias Results
Standard Cal.Bias Difference Error
Gas %%%%Status
Zero 0.0 0.1 0.1 0.6 Pass
Span 8.9 8.9 0.0 0.0 Pass
Calibration Drift
Standard Initial*Final Difference Drift
Gas %%%%Status
Zero 0.1 0.1 0.0 0.0 Pass
Span 8.9 8.9 0.0 0.0 Pass
*Bias No. 2
75
RUN DATA
Number 2
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
26 Feb 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
R2 START
13:35 20.8 0.1
13:36 20.7 0.5
13:37 20.7 0.6
13:38 20.8 0.4
13:39 20.8 0.3
13:40 20.8 0.3
13:41 20.8 0.2
13:42 20.8 0.2
13:43 20.8 0.2
13:44 20.8 0.2
13:45 20.8 0.2
13:46 20.8 0.2
13:47 20.9 0.2
13:48 20.9 0.2
13:49 20.9 0.1
13:50 20.9 0.2
13:51 20.9 0.2
13:52 20.8 0.2
13:53 20.8 0.2
13:54 20.8 0.2
13:55 20.8 0.2
13:56 20.8 0.2
13:57 20.8 0.1
13:58 20.8 0.1
13:59 20.8 0.1
14:00 20.8 0.1
14:01 20.8 0.1
14:02 20.8 0.1
14:03 20.8 0.1
14:04 20.8 0.1
14:05 20.8 0.1
14:06 20.8 0.1
14:07 20.8 0.1
14:08 20.8 0.1
14:09 20.9 0.1
14:10 20.8 0.1
14:11 20.8 0.1
14:12 20.8 0.1
14:13 20.8 0.1
76
RUN DATA
Number 2
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
26 Feb 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
14:14 20.8 0.1
14:15 20.8 0.1
14:16 20.8 0.1
14:17 20.8 0.1
14:18 20.8 0.1
14:19 20.8 0.1
14:20 20.8 0.1
14:21 20.8 0.1
14:22 20.8 0.1
14:23 20.8 0.1
PORT CHANGE
PORT 2
14:42 20.8 0.1
14:43 20.8 0.1
14:44 20.8 0.1
14:45 20.8 0.1
14:46 20.8 0.1
14:47 20.8 0.1
14:48 20.8 0.1
14:49 20.8 0.1
14:50 20.8 0.1
14:51 20.8 0.1
14:52 20.8 0.1
14:53 20.8 0.1
14:54 20.8 0.1
14:55 20.8 0.1
14:56 20.8 0.1
14:57 20.8 0.1
14:58 20.8 0.1
14:59 20.8 0.1
15:00 20.8 0.1
15:01 20.8 0.1
15:02 20.8 0.1
15:03 20.8 0.1
15:04 20.8 0.1
15:05 20.8 0.1
15:06 20.8 0.1
15:07 20.8 0.1
15:08 20.8 0.1
15:09 20.8 0.1
77
RUN DATA
Number 2
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
26 Feb 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
15:10 20.8 0.1
15:11 20.8 0.1
15:12 20.8 0.1
15:13 20.8 0.1
15:14 20.8 0.1
15:15 20.8 0.1
15:16 20.8 0.1
15:17 20.8 0.1
15:18 20.8 0.1
15:19 20.8 0.1
15:20 20.8 0.1
15:21 20.8 0.1
15:22 20.8 0.1
15:23 20.8 0.1
15:24 20.8 0.1
15:25 20.8 0.1
15:26 20.8 0.1
15:27 20.8 0.1
15:28 20.8 0.1
15:29 20.8 0.1
15:30 20.8 0.1
Avgs 20.8 0.1
78
RUN SUMMARY
Number 2
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
26 Feb 2019
Project Number:
Operator:
Date:
O2 CO2
Method EPA 3A EPA 3A
Conc. Units %%
Time: 13:34 to 15:30
Run Averages
20.8 0.1
Pre-run Bias at 11:44
Zero Bias
Span Bias
Span Gas
0.0 0.1
12.0 8.9
12.0 8.9
Post-run Bias at 15:33
Zero Bias
Span Bias
Span Gas
0.0 0.1
11.9 9.0
12.0 8.9
Run averages corrected for the average of the pre-run and post-run bias
20.9 0.0
79
BIAS AND CALIBRATION DRIFT
Number 4
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
26 Feb 2019
Project Number:
Operator:
Date:
Start Time: 15:33
O2 Method: EPA 3A
Span Conc. 21.0 %
Bias Results
Standard Cal.Bias Difference Error
Gas %%%%Status
Zero 0.0 0.0 0.0 0.0 Pass
Span 12.0 11.9 -0.1 -0.5 Pass
Calibration Drift
Standard Initial*Final Difference Drift
Gas %%%%Status
Zero 0.0 0.0 0.0 0.0 Pass
Span 12.0 11.9 -0.1 -0.5 Pass
*Bias No. 3
CO2
Method: EPA 3A
Span Conc. 16.6 %
Bias Results
Standard Cal.Bias Difference Error
Gas %%%%Status
Zero 0.0 0.1 0.1 0.6 Pass
Span 8.9 9.0 0.1 0.6 Pass
Calibration Drift
Standard Initial*Final Difference Drift
Gas %%%%Status
Zero 0.1 0.1 0.0 0.0 Pass
Span 8.9 9.0 0.1 0.6 Pass
*Bias No. 3
80
METHODS AND ANALYZERS
Client:
Location:
Source:
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
27 Feb 2019
Project Number:
Operator:
Date:
Folders.A-F\Chemours Fayetteville\15418.002.010 VE North 2019\Data\FEBUARY_MARCH 2019\022719DIVISION
Program Version: 2.1, built 19 May 2017 File Version: 2.03
Computer: WSWCAIRSERVICES Trailer: 27
Analog Input Device: Keithley KUSB-3108
Channel 1
Analyte O2
Method EPA 3A, Using Bias
Analyzer Make, Model & Serial No. Servomex 4900
Full-Scale Output, mv 10000
Analyzer Range, %25.0
Span Concentration, %21.0
Channel 2
Analyte CO2
Method EPA 3A, Using Bias
Analyzer Make, Model & Serial No. Servomex 4900
Full-Scale Output, mv 10000
Analyzer Range, %20.0
Span Concentration, %16.6
81
CALIBRATION DATA
Number 1
Client:
Location:
Source:
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
27 Feb 2019
Project Number:
Operator:
Date:
Start Time: 07:29
O2 Method: EPA 3A
Calibration Type: Linear Zero and High Span
Calibration Standards
%Cylinder ID
12.0 CC18055
21.0 SG9169108
Calibration Results
Zero -3 mv
Span, 21.0 %8006 mv
Curve Coefficients
Slope Intercept
381.4 -3
CO2
Method: EPA 3A
Calibration Type: Linear Zero and High Span
Calibration Standards
%Cylinder ID
8.9 CC18055
16.6 SG9169108
Calibration Results
Zero -5 mv
Span, 16.6 %8288 mv
Curve Coefficients
Slope Intercept
500.2 -5
82
CALIBRATION ERROR DATA
Number 1
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
27 Feb 2019
Project Number:
Operator:
Date:
Start Time: 07:29
O2 Method: EPA 3A
Span Conc. 21.0 %
Slope 381.4 Intercept -3.0
Standard
%
Result
%
Difference
%
Error
%Status
Zero 0.0 0.0 0.0 Pass
12.0 12.1 0.1 0.5 Pass
21.0 21.0 0.0 0.0 Pass
CO2
Method: EPA 3A
Span Conc. 16.6 %
Slope 500.2 Intercept -5.0
Standard
%
Result
%
Difference
%
Error
%Status
Zero 0.0 0.0 0.0 Pass
8.9 8.6 -0.3 -1.8 Pass
16.6 16.6 0.0 0.0 Pass
83
BIAS
Number 1
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
27 Feb 2019
Project Number:
Operator:
Date:
Start Time: 07:39
O2 Method: EPA 3A
Span Conc. 21.0 %
Bias Results
Standard Cal.Bias Difference Error
Gas %%%%Status
Zero 0.0 0.0 0.0 0.0 Pass
Span 12.1 12.0 -0.1 -0.5 Pass
CO2Method: EPA 3A
Span Conc. 16.6 %
Bias Results
Standard Cal.Bias Difference Error
Gas %%%%Status
Zero 0.0 0.1 0.1 0.6 Pass
Span 8.6 8.4 -0.2 -1.2 Pass
84
RUN DATA
Number 1
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
27 Feb 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
RUN 3
POINT 1
08:40 20.8 0.1
08:41 20.7 0.1
08:42 20.8 0.1
08:43 20.8 0.1
08:44 20.8 0.1
08:45 20.8 0.1
08:46 20.8 0.1
08:47 20.8 0.1
08:48 20.8 0.1
08:49 20.8 0.1
08:50 20.8 0.1
08:51 20.8 0.1
08:52 20.8 0.1
08:53 20.8 0.1
08:54 20.8 0.1
08:55 20.9 0.1
08:56 20.9 0.1
08:57 20.9 0.1
08:58 20.9 0.1
08:59 20.9 0.1
09:00 20.9 0.1
09:01 20.9 0.1
09:02 20.9 0.1
09:03 20.9 0.1
09:04 20.9 0.1
09:05 20.9 0.1
09:06 20.9 0.1
09:07 20.9 0.1
09:08 20.9 0.1
09:09 20.9 0.1
09:10 20.9 0.1
09:11 20.9 0.1
09:12 20.9 0.1
09:13 20.9 0.1
09:14 20.9 0.1
09:15 20.9 0.1
09:16 20.9 0.1
09:17 20.9 0.1
85
RUN DATA
Number 1
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
27 Feb 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
09:18 20.9 0.1
09:19 20.9 0.1
09:20 20.9 0.1
09:21 20.9 0.1
09:22 20.9 0.1
09:23 20.9 0.1
09:24 20.9 0.1
09:25 20.9 0.1
09:26 20.9 0.1
09:27 20.9 0.1
09:28 20.9 0.1
PORT CHANGE
PORT 2
09:47 20.8 0.1
09:48 20.8 0.1
09:49 20.8 0.1
09:50 20.8 0.1
09:51 20.7 0.1
09:52 20.7 0.1
09:53 20.7 0.1
09:54 20.8 0.1
09:55 20.9 0.1
09:56 20.9 0.1
09:57 20.9 0.1
09:58 20.9 0.1
09:59 20.9 0.1
10:00 20.9 0.1
10:01 20.9 0.1
10:02 20.9 0.1
10:03 20.9 0.1
10:04 20.9 0.1
10:05 20.9 0.1
10:06 20.9 0.1
10:07 20.9 0.1
10:08 20.9 0.1
10:09 20.9 0.1
10:10 20.9 0.1
10:11 20.9 0.1
10:12 20.9 0.1
10:13 20.9 0.1
86
RUN DATA
Number 1
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
27 Feb 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
10:14 20.9 0.1
10:15 20.9 0.1
10:16 20.9 0.1
10:17 20.9 0.1
10:18 20.9 0.1
10:19 20.9 0.1
10:20 20.9 0.1
10:21 20.9 0.1
10:22 20.9 0.1
10:23 20.9 0.1
10:24 20.9 0.1
10:25 20.9 0.1
10:26 20.9 0.1
10:27 20.9 0.1
10:28 20.9 0.1
10:29 20.9 0.1
10:30 20.9 0.1
10:31 20.9 0.1
10:32 20.9 0.1
10:33 20.9 0.1
10:34 20.9 0.1
10:35 20.9 0.1
Avgs 20.9 0.1
87
RUN SUMMARY
Number 1
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
27 Feb 2019
Project Number:
Operator:
Date:
O2 CO2
Method EPA 3A EPA 3A
Conc. Units %%
Time: 08:39 to 10:35
Run Averages
20.9 0.1
Pre-run Bias at 07:39
Zero Bias
Span Bias
Span Gas
0.0 0.1
12.0 8.4
12.0 8.9
Post-run Bias at 10:36
Zero Bias
Span Bias
Span Gas
0.0 0.1
12.1 8.4
12.0 8.9
Run averages corrected for the average of the pre-run and post-run bias
20.8 0.0
88
BIAS AND CALIBRATION DRIFT
Number 2
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
27 Feb 2019
Project Number:
Operator:
Date:
Start Time: 10:36
O2Method: EPA 3A
Span Conc. 21.0 %
Bias Results
Standard Cal.Bias Difference Error
Gas %%%%Status
Zero 0.0 0.0 0.0 0.0 Pass
Span 12.1 12.1 0.0 0.0 Pass
Calibration Drift
Standard Initial*Final Difference Drift
Gas %%%%Status
Zero 0.0 0.0 0.0 0.0 Pass
Span 12.0 12.1 0.1 0.5 Pass
*Bias No. 1
CO2
Method: EPA 3A
Span Conc. 16.6 %
Bias Results
Standard Cal.Bias Difference Error
Gas %%%%Status
Zero 0.0 0.1 0.1 0.6 Pass
Span 8.6 8.4 -0.2 -1.2 Pass
Calibration Drift
Standard Initial*Final Difference Drift
Gas %%%%Status
Zero 0.1 0.1 0.0 0.0 Pass
Span 8.4 8.4 0.0 0.0 Pass
*Bias No. 1
89
RUN DATA
Number 2
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
27 Feb 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
RUN 4
PORT 1 ONLY ( SEE NEXT RUN FOR SECOND PORT)
12:31 20.7 0.1
12:32 20.7 0.1
12:33 20.7 0.1
12:34 20.7 0.1
12:35 20.7 0.1
12:36 20.7 0.1
12:37 20.7 0.1
12:38 20.7 0.1
12:39 20.7 0.1
12:40 20.7 0.1
12:41 20.7 0.1
12:42 20.7 0.1
12:43 20.7 0.1
12:44 20.7 0.1
12:45 20.7 0.1
12:46 20.7 0.1
12:47 20.7 0.1
12:48 20.7 0.1
12:49 20.7 0.1
12:50 20.7 0.1
12:51 20.7 0.1
12:52 20.7 0.1
12:53 20.7 0.1
12:54 20.7 0.1
12:55 20.7 0.1
12:56 20.8 0.1
12:57 20.8 0.1
12:58 20.8 0.1
12:59 20.8 0.1
13:00 20.8 0.1
13:01 20.8 0.1
13:02 20.8 0.1
13:03 20.8 0.1
13:04 20.8 0.1
13:05 20.8 0.1
13:06 20.8 0.1
13:07 20.8 0.1
13:08 20.8 0.1
90
RUN DATA
Number 2
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
27 Feb 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
13:09 20.8 0.1
13:10 20.8 0.1
13:11 20.8 0.1
13:12 20.8 0.1
13:13 20.8 0.1
13:14 20.8 0.1
13:15 20.8 0.1
13:16 20.8 0.1
13:17 20.8 0.1
13:18 20.8 0.1
13:19 20.8 0.1
Avgs 20.7 0.1
91
RUN SUMMARY
Number 2
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
27 Feb 2019
Project Number:
Operator:
Date:
O2 CO2
Method EPA 3A EPA 3A
Conc. Units %%
Time: 12:30 to 13:19
Run Averages
20.7 0.1
Pre-run Bias at 10:36
Zero Bias
Span Bias
Span Gas
0.0 0.1
12.1 8.4
12.0 8.9
Post-run Bias at 13:21
Zero Bias
Span Bias
Span Gas
0.1 0.0
12.0 8.4
12.0 8.9
Run averages corrected for the average of the pre-run and post-run bias
20.7 0.1
92
BIAS AND CALIBRATION DRIFT
Number 3
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
27 Feb 2019
Project Number:
Operator:
Date:
Start Time: 13:21
O2Method: EPA 3A
Span Conc. 21.0 %
Bias Results
Standard Cal.Bias Difference Error
Gas %%%%Status
Zero 0.0 0.1 0.1 0.5 Pass
Span 12.1 12.0 -0.1 -0.5 Pass
Calibration Drift
Standard Initial*Final Difference Drift
Gas %%%%Status
Zero 0.0 0.1 0.1 0.5 Pass
Span 12.1 12.0 -0.1 -0.5 Pass
*Bias No. 2
CO2
Method: EPA 3A
Span Conc. 16.6 %
Bias Results
Standard Cal.Bias Difference Error
Gas %%%%Status
Zero 0.0 0.0 0.0 0.0 Pass
Span 8.6 8.4 -0.2 -1.2 Pass
Calibration Drift
Standard Initial*Final Difference Drift
Gas %%%%Status
Zero 0.1 0.0 -0.1 -0.6 Pass
Span 8.4 8.4 0.0 0.0 Pass
*Bias No. 2
93
RUN DATA
Number 3
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
27 Feb 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
RUN 4
PORT 2
13:38 20.7 0.1
13:39 20.7 0.1
13:40 20.7 0.1
13:41 20.7 0.2
13:42 20.6 0.2
13:43 20.6 0.2
13:44 20.7 0.2
13:45 20.7 0.2
13:46 20.8 0.2
13:47 20.8 0.2
13:48 20.8 0.2
13:49 20.8 0.2
13:50 20.8 0.2
13:51 20.8 0.2
13:52 20.8 0.2
13:53 20.8 0.2
13:54 20.8 0.2
13:55 20.8 0.2
13:56 20.8 0.2
13:57 20.8 0.2
13:58 20.8 0.2
13:59 20.8 0.2
14:00 20.8 0.2
14:01 20.8 0.2
14:02 20.8 0.2
14:03 20.8 0.1
14:04 20.8 0.1
14:05 20.8 0.1
14:06 20.8 0.1
14:07 20.8 0.1
14:08 20.8 0.1
14:09 20.8 0.1
14:10 20.8 0.1
14:11 20.8 0.1
14:12 20.8 0.1
14:13 20.8 0.1
14:14 20.8 0.1
14:15 20.8 0.1
94
RUN DATA
Number 3
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
27 Feb 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
14:16 20.8 0.1
14:17 20.8 0.1
14:18 20.8 0.1
14:19 20.8 0.1
14:20 20.8 0.1
14:21 20.8 0.1
14:22 20.8 0.1
14:23 20.8 0.1
14:24 20.8 0.1
14:25 20.8 0.1
14:26 20.8 0.1
Avgs 20.8 0.1
95
RUN SUMMARY
Number 3
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
27 Feb 2019
Project Number:
Operator:
Date:
O2 CO2
Method EPA 3A EPA 3A
Conc. Units %%
Time: 13:37 to 14:26
Run Averages
20.8 0.1
Pre-run Bias at 13:21
Zero Bias
Span Bias
Span Gas
0.1 0.0
12.0 8.4
12.0 8.9
Post-run Bias at 14:28
Zero Bias
Span Bias
Span Gas
0.1 0.0
12.0 8.4
12.0 8.9
Run averages corrected for the average of the pre-run and post-run bias
20.9 0.2
96
BIAS AND CALIBRATION DRIFT
Number 4
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
27 Feb 2019
Project Number:
Operator:
Date:
Start Time: 14:28
O2 Method: EPA 3A
Span Conc. 21.0 %
Bias Results
Standard Cal.Bias Difference Error
Gas %%%%Status
Zero 0.0 0.1 0.1 0.5 Pass
Span 12.1 12.0 -0.1 -0.5 Pass
Calibration Drift
Standard Initial*Final Difference Drift
Gas %%%%Status
Zero 0.1 0.1 0.0 0.0 Pass
Span 12.0 12.0 0.0 0.0 Pass
*Bias No. 3
CO2
Method: EPA 3A
Span Conc. 16.6 %
Bias Results
Standard Cal.Bias Difference Error
Gas %%%%Status
Zero 0.0 0.0 0.0 0.0 Pass
Span 8.6 8.4 -0.2 -1.2 Pass
Calibration Drift
Standard Initial*Final Difference Drift
Gas %%%%Status
Zero 0.0 0.0 0.0 0.0 Pass
Span 8.4 8.4 0.0 0.0 Pass
*Bias No. 3
97
BIAS AND CALIBRATION DRIFT
Number 5
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
28 Feb 2019
Project Number:
Operator:
Date:
Start Time: 07:19
O2 Method: EPA 3A
Span Conc. 21.0 %
Bias Results
Standard Cal.Bias Difference Error
Gas %%%%Status
Zero 0.0 0.0 0.0 0.0 Pass
Span 12.1 11.8 -0.3 -1.4 Pass
Calibration Drift
Standard Initial*Final Difference Drift
Gas %%%%Status
Zero 0.1 0.0 -0.1 -0.5 Pass
Span 12.0 11.8 -0.2 -1.0 Pass
*Bias No. 4
CO2
Method: EPA 3A
Span Conc. 16.6 %
Bias Results
Standard Cal.Bias Difference Error
Gas %%%%Status
Zero 0.0 0.1 0.1 0.6 Pass
Span 8.6 8.3 -0.3 -1.8 Pass
Calibration Drift
Standard Initial*Final Difference Drift
Gas %%%%Status
Zero 0.0 0.1 0.1 0.6 Pass
Span 8.4 8.3 -0.1 -0.6 Pass
*Bias No. 4
98
RUN DATA
Number 4
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
28 Feb 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
08:14 20.6 0.1
08:15 20.6 0.1
08:16 20.6 0.1
08:17 20.6 0.1
08:18 20.6 0.1
08:19 20.6 0.1
08:20 20.6 0.1
08:21 20.6 0.1
08:22 20.6 0.1
RUN 5
PORT 1
08:23 20.6 0.1
08:24 20.6 0.1
08:25 20.6 0.1
08:26 20.6 0.1
08:27 20.6 0.1
08:28 20.6 0.1
08:29 20.6 0.1
08:30 20.6 0.1
08:31 20.6 0.1
08:32 20.6 0.1
08:33 20.6 0.1
08:34 20.6 0.1
08:35 20.6 0.1
08:36 20.6 0.1
08:37 20.6 0.1
08:38 20.6 0.1
08:39 20.6 0.1
08:40 20.6 0.1
08:41 20.6 0.1
08:42 20.6 0.1
08:43 20.6 0.1
08:44 20.6 0.1
08:45 20.6 0.1
08:46 20.6 0.1
08:47 20.6 0.1
08:48 20.6 0.1
08:49 20.6 0.1
08:50 20.6 0.1
08:51 20.6 0.1
99
RUN DATA
Number 4
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
28 Feb 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
08:52 20.6 0.1
08:53 20.6 0.1
08:54 20.6 0.1
08:55 20.6 0.1
08:56 20.6 0.1
08:57 20.6 0.1
08:58 20.6 0.1
08:59 20.6 0.1
09:00 20.6 0.1
09:01 20.6 0.1
09:02 20.6 0.1
09:03 20.6 0.1
09:04 20.6 0.1
09:05 20.6 0.1
09:06 20.6 0.1
09:07 20.7 0.1
09:08 20.7 0.1
09:09 20.7 0.1
09:10 20.7 0.1
09:11 20.7 0.1
PORT CHANGE
09:12 20.7 0.1
09:13 20.7 0.1
09:14 20.7 0.1
09:15 20.7 0.1
09:16 20.6 0.1
09:17 20.6 0.1
09:18 20.6 0.1
09:19 20.6 0.1
09:20 20.6 0.1
09:21 20.6 0.1
09:22 20.6 0.1
09:23 20.6 0.1
09:24 20.6 0.1
09:25 20.6 0.1
09:26 20.6 0.1
09:27 20.6 0.1
09:28 20.6 0.1
09:29 20.6 0.1
100
RUN DATA
Number 4
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
28 Feb 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
PORT 2
09:30 20.6 0.1
09:31 20.6 0.1
09:32 20.6 0.1
09:33 20.6 0.1
09:34 20.6 0.2
09:35 20.6 0.2
09:36 20.6 0.2
09:37 20.6 0.2
09:38 20.6 0.2
09:39 20.6 0.2
09:40 20.6 0.2
09:41 20.7 0.2
09:42 20.7 0.2
09:43 20.7 0.2
09:44 20.7 0.2
09:45 20.7 0.2
09:46 20.7 0.2
09:47 20.7 0.2
09:48 20.7 0.2
09:49 20.7 0.2
09:50 20.7 0.2
09:51 20.7 0.2
09:52 20.7 0.2
09:53 20.7 0.2
09:54 20.7 0.2
09:55 20.7 0.2
09:56 20.7 0.1
09:57 20.8 0.1
09:58 20.8 0.1
09:59 20.8 0.1
10:00 20.8 0.1
10:01 20.8 0.1
10:02 20.8 0.1
10:03 20.8 0.1
10:04 20.8 0.1
10:05 20.8 0.1
10:06 20.8 0.1
10:07 20.8 0.1
10:08 20.8 0.1
101
RUN DATA
Number 4
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
28 Feb 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
10:09 20.8 0.1
10:10 20.8 0.1
10:11 20.8 0.1
10:12 20.8 0.1
10:13 20.8 0.1
10:14 20.8 0.1
10:15 20.8 0.1
10:16 20.8 0.1
10:17 20.8 0.1
10:18 20.8 0.1
Avgs 20.7 0.1
102
RUN SUMMARY
Number 4
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
28 Feb 2019
Project Number:
Operator:
Date:
O2 CO2
Method EPA 3A EPA 3A
Conc. Units %%
Time: 08:13 to 10:18
Run Averages
20.7 0.1
Pre-run Bias at 07:19
Zero Bias
Span Bias
Span Gas
0.0 0.1
11.8 8.3
12.0 8.9
Post-run Bias at 10:21
Zero Bias
Span Bias
Span Gas
0.0 0.0
12.0 8.3
12.0 8.9
Run averages corrected for the average of the pre-run and post-run bias
20.8 0.1
103
BIAS AND CALIBRATION DRIFT
Number 6
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
28 Feb 2019
Project Number:
Operator:
Date:
Start Time: 10:21
O2 Method: EPA 3A
Span Conc. 21.0 %
Bias Results
Standard Cal.Bias Difference Error
Gas %%%%Status
Zero 0.0 0.0 0.0 0.0 Pass
Span 12.1 12.0 -0.1 -0.5 Pass
Calibration Drift
Standard Initial*Final Difference Drift
Gas %%%%Status
Zero 0.0 0.0 0.0 0.0 Pass
Span 11.8 12.0 0.2 1.0 Pass
*Bias No. 5
CO2
Method: EPA 3A
Span Conc. 16.6 %
Bias Results
Standard Cal.Bias Difference Error
Gas %%%%Status
Zero 0.0 0.0 0.0 0.0 Pass
Span 8.6 8.3 -0.3 -1.8 Pass
Calibration Drift
Standard Initial*Final Difference Drift
Gas %%%%Status
Zero 0.1 0.0 -0.1 -0.6 Pass
Span 8.3 8.3 0.0 0.0 Pass
*Bias No. 5
104
RUN DATA
Number 5
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
28 Feb 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
14:12 20.6 0.1
14:13 20.6 0.1
14:14 20.6 0.1
14:15 20.6 0.1
14:16 20.6 0.1
14:17 20.6 0.1
14:18 20.6 0.1
14:19 20.6 0.1
14:20 20.6 0.1
14:21 20.6 0.1
14:22 20.6 0.1
14:23 20.6 0.1
14:24 20.6 0.1
14:25 20.6 0.1
14:26 20.6 0.1
14:27 20.6 0.1
14:28 20.6 0.1
RUN 6
PORT 1
14:29 20.6 0.1
14:30 20.5 0.2
14:31 20.5 0.4
14:32 20.5 0.2
14:33 20.6 0.2
14:34 20.6 0.1
14:35 20.6 0.1
14:36 20.6 0.1
14:37 20.6 0.1
14:38 20.6 0.1
14:39 20.6 0.1
14:40 20.6 0.1
14:41 20.6 0.1
14:42 20.6 0.1
14:43 20.6 0.1
14:44 20.6 0.1
14:45 20.6 0.1
14:46 20.6 0.1
14:47 20.6 0.1
14:48 20.6 0.1
14:49 20.6 0.1
105
RUN DATA
Number 5
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
28 Feb 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
14:50 20.6 0.1
14:51 20.6 0.1
14:52 20.6 0.1
14:53 20.6 0.1
14:54 20.6 0.1
14:55 20.6 0.1
14:56 20.6 0.1
14:57 20.6 0.1
14:58 20.6 0.1
14:59 20.6 0.1
15:00 20.6 0.1
15:01 20.6 0.1
15:02 20.6 0.1
15:03 20.6 0.1
15:04 20.6 0.1
15:05 20.6 0.1
15:06 20.6 0.1
15:07 20.6 0.1
15:08 20.6 0.1
15:09 20.6 0.1
15:10 20.6 0.1
15:11 20.6 0.1
15:12 20.6 0.1
15:13 20.7 0.1
15:14 20.7 0.1
15:15 20.7 0.1
15:16 20.7 0.1
15:17 20.7 0.1
PORT CHANGE
15:18 20.7 0.1
15:19 20.6 0.1
15:20 20.6 0.1
15:21 20.6 0.1
15:22 20.6 0.1
15:23 20.6 0.1
15:24 20.6 0.1
15:25 20.6 0.1
15:26 20.6 0.1
15:27 20.6 0.1
15:28 20.6 0.1
106
RUN DATA
Number 5
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
28 Feb 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
15:29 20.6 0.1
15:30 20.6 0.1
15:31 20.6 0.1
15:32 20.6 0.1
15:33 20.6 0.1
15:34 20.6 0.1
15:35 20.6 0.1
15:36 20.6 0.1
15:37 20.6 0.1
15:38 20.6 0.1
PORT 2
15:39 20.6 0.1
15:40 20.6 0.1
15:41 20.6 0.1
15:42 20.6 0.1
15:43 20.6 0.1
15:44 20.6 0.1
15:45 20.6 0.1
15:46 20.6 0.1
15:47 20.6 0.1
15:48 20.7 0.1
15:49 20.7 0.1
15:50 20.7 0.1
15:51 20.7 0.1
15:52 20.7 0.1
15:53 20.7 0.1
15:54 20.7 0.1
15:55 20.7 0.1
15:56 20.7 0.1
15:57 20.7 0.1
15:58 20.7 0.1
15:59 20.7 0.1
16:00 20.7 0.1
16:01 20.7 0.1
16:02 20.7 0.1
16:03 20.7 0.1
16:04 20.7 0.1
16:05 20.7 0.1
16:06 20.7 0.1
16:07 20.7 0.1
107
RUN DATA
Number 5
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
28 Feb 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
16:08 20.7 0.1
16:09 20.7 0.1
16:10 20.7 0.1
16:11 20.7 0.1
16:12 20.7 0.1
16:13 20.7 0.1
16:14 20.7 0.1
16:15 20.7 0.1
16:16 20.7 0.1
16:17 20.7 0.1
16:18 20.7 0.1
16:19 20.7 0.1
16:20 20.7 0.1
16:21 20.7 0.1
16:22 20.7 0.1
16:23 20.7 0.1
16:24 20.7 0.1
16:25 20.7 0.1
16:26 20.7 0.1
16:27 20.7 0.1
Avgs 20.6 0.1
108
RUN SUMMARY
Number 5
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
28 Feb 2019
Project Number:
Operator:
Date:
O2 CO2
Method EPA 3A EPA 3A
Conc. Units %%
Time: 14:11 to 16:27
Run Averages
20.6 0.1
Pre-run Bias at 10:21
Zero Bias
Span Bias
Span Gas
0.0 0.0
12.0 8.3
12.0 8.9
Post-run Bias at 16:31
Zero Bias
Span Bias
Span Gas
0.0 0.0
11.9 8.4
12.0 8.9
Run averages corrected for the average of the pre-run and post-run bias
20.7 0.1
109
BIAS AND CALIBRATION DRIFT
Number 7
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
28 Feb 2019
Project Number:
Operator:
Date:
Start Time: 16:31
O2 Method: EPA 3A
Span Conc. 21.0 %
Bias Results
Standard Cal.Bias Difference Error
Gas %%%%Status
Zero 0.0 0.0 0.0 0.0 Pass
Span 12.1 11.9 -0.2 -1.0 Pass
Calibration Drift
Standard Initial*Final Difference Drift
Gas %%%%Status
Zero 0.0 0.0 0.0 0.0 Pass
Span 12.0 11.9 -0.1 -0.5 Pass
*Bias No. 6
CO2
Method: EPA 3A
Span Conc. 16.6 %
Bias Results
Standard Cal.Bias Difference Error
Gas %%%%Status
Zero 0.0 0.0 0.0 0.0 Pass
Span 8.6 8.4 -0.2 -1.2 Pass
Calibration Drift
Standard Initial*Final Difference Drift
Gas %%%%Status
Zero 0.0 0.0 0.0 0.0 Pass
Span 8.3 8.4 0.1 0.6 Pass
*Bias No. 6
110
BIAS AND CALIBRATION DRIFT
Number 8
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
1 Mar 2019
Project Number:
Operator:
Date:
Start Time: 07:24
O2Method: EPA 3A
Span Conc. 21.0 %
Bias Results
Standard Cal.Bias Difference Error
Gas %%%%Status
Zero 0.0 0.0 0.0 0.0 Pass
Span 12.1 12.2 0.1 0.5 Pass
Calibration Drift
Standard Initial*Final Difference Drift
Gas %%%%Status
Zero 0.0 0.0 0.0 0.0 Pass
Span 11.9 12.2 0.3 1.4 Pass
*Bias No. 7
CO2
Method: EPA 3A
Span Conc. 16.6 %
Bias Results
Standard Cal.Bias Difference Error
Gas %%%%Status
Zero 0.0 0.0 0.0 0.0 Pass
Span 8.6 8.3 -0.3 -1.8 Pass
Calibration Drift
Standard Initial*Final Difference Drift
Gas %%%%Status
Zero 0.0 0.0 0.0 0.0 Pass
Span 8.4 8.3 -0.1 -0.6 Pass
*Bias No. 7
111
RUN DATA
Number 6
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
1 Mar 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
RUN 7
PORT 1
08:13 21.2 0.1
08:14 21.0 0.7
08:15 21.1 0.5
08:16 21.1 0.3
08:17 21.1 0.2
08:18 21.1 0.2
08:19 21.2 0.1
08:20 21.1 0.1
08:21 21.2 0.1
08:22 21.2 0.1
08:23 21.2 0.1
08:24 21.2 0.1
08:25 21.2 0.1
08:26 21.2 0.1
08:27 21.2 0.1
08:28 21.2 0.1
08:29 21.2 0.1
08:30 21.2 0.1
08:31 21.2 0.1
08:32 21.2 0.1
08:33 21.2 0.1
08:34 21.2 0.1
08:35 21.2 0.1
08:36 21.2 0.1
08:37 21.2 0.1
08:38 21.2 0.1
08:39 21.2 0.1
08:40 21.2 0.1
08:41 21.2 0.1
08:42 21.2 0.1
08:43 21.2 0.1
08:44 21.2 0.1
08:45 21.2 0.1
08:46 21.2 0.1
08:47 21.2 0.1
08:48 21.2 0.1
08:49 21.2 0.1
08:50 21.2 0.1
112
RUN DATA
Number 6
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
1 Mar 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
08:51 21.2 0.1
08:52 21.2 0.1
08:53 21.2 0.1
08:54 21.2 0.1
08:55 21.2 0.1
08:56 21.2 0.1
08:57 21.2 0.1
08:58 21.2 0.1
08:59 21.2 0.1
09:00 21.2 0.1
09:01 21.3 0.1
PORT CHANGE
PORT 2
09:20 21.2 0.1
09:21 21.2 0.1
09:22 21.2 0.1
09:23 21.2 0.2
09:24 21.2 0.2
09:25 21.2 0.2
09:26 21.2 0.2
09:27 21.2 0.2
09:28 21.2 0.2
09:29 21.2 0.2
09:30 21.2 0.2
09:31 21.3 0.2
09:32 21.3 0.2
09:33 21.3 0.2
09:34 21.3 0.2
09:35 21.3 0.2
09:36 21.3 0.2
09:37 21.3 0.2
09:38 21.3 0.2
09:39 21.3 0.2
09:40 21.3 0.2
09:41 21.3 0.2
09:42 21.3 0.1
09:43 21.3 0.1
09:44 21.3 0.1
09:45 21.3 0.1
09:46 21.3 0.1
113
RUN DATA
Number 6
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
1 Mar 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
09:47 21.3 0.1
09:48 21.3 0.1
09:49 21.3 0.1
09:50 21.3 0.1
09:51 21.3 0.1
09:52 21.3 0.1
09:53 21.3 0.1
09:54 21.3 0.1
09:55 21.3 0.1
09:56 21.3 0.1
09:57 21.3 0.1
09:58 21.3 0.1
09:59 21.3 0.1
10:00 21.3 0.1
10:01 21.3 0.1
10:02 21.3 0.1
10:03 21.3 0.1
10:04 21.3 0.1
10:05 21.3 0.1
10:06 21.3 0.1
10:07 21.3 0.1
10:08 21.3 0.1
Avgs 21.2 0.1
114
RUN SUMMARY
Number 6
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
1 Mar 2019
Project Number:
Operator:
Date:
O2 CO2
Method EPA 3A EPA 3A
Conc. Units %%
Time: 08:12 to 10:08
Run Averages
21.2 0.1
Pre-run Bias at 07:24
Zero Bias
Span Bias
Span Gas
0.0 0.0
12.2 8.3
12.0 8.9
Post-run Bias at 10:12
Zero Bias
Span Bias
Span Gas
0.0 0.0
12.2 8.4
12.0 8.9
Run averages corrected for the average of the pre-run and post-run bias
20.9 0.1
115
BIAS AND CALIBRATION DRIFT
Number 9
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
1 Mar 2019
Project Number:
Operator:
Date:
Start Time: 10:12
O2Method: EPA 3A
Span Conc. 21.0 %
Bias Results
Standard Cal.Bias Difference Error
Gas %%%%Status
Zero 0.0 0.0 0.0 0.0 Pass
Span 12.1 12.2 0.1 0.5 Pass
Calibration Drift
Standard Initial*Final Difference Drift
Gas %%%%Status
Zero 0.0 0.0 0.0 0.0 Pass
Span 12.2 12.2 0.0 0.0 Pass
*Bias No. 8
CO2
Method: EPA 3A
Span Conc. 16.6 %
Bias Results
Standard Cal.Bias Difference Error
Gas %%%%Status
Zero 0.0 0.0 0.0 0.0 Pass
Span 8.6 8.4 -0.2 -1.2 Pass
Calibration Drift
Standard Initial*Final Difference Drift
Gas %%%%Status
Zero 0.0 0.0 0.0 0.0 Pass
Span 8.3 8.4 0.1 0.6 Pass
*Bias No. 8
116
RUN DATA
Number 7
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
1 Mar 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
RUN 8
PORT 1
12:37 21.1 0.1
12:38 21.1 0.1
12:39 21.1 0.1
12:40 21.1 0.1
12:41 21.1 0.1
12:42 21.1 0.1
12:43 21.1 0.1
12:44 21.1 0.1
12:45 21.1 0.1
12:46 21.1 0.1
12:47 21.1 0.1
12:48 21.1 0.1
12:49 21.1 0.1
12:50 21.1 0.1
12:51 21.1 0.1
12:52 21.1 0.1
12:53 21.1 0.1
12:54 21.1 0.1
12:55 21.1 0.1
12:56 21.1 0.1
12:57 21.1 0.1
12:58 21.1 0.1
12:59 21.1 0.1
13:00 21.1 0.1
13:01 21.1 0.1
13:02 21.1 0.1
13:03 21.1 0.1
13:04 21.1 0.1
13:05 21.1 0.1
13:06 21.1 0.1
13:07 21.1 0.1
13:08 21.1 0.1
13:09 21.1 0.1
13:10 21.2 0.1
13:11 21.2 0.1
13:12 21.2 0.1
13:13 21.2 0.1
13:14 21.2 0.1
117
RUN DATA
Number 7
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
1 Mar 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
13:15 21.2 0.1
13:16 21.2 0.1
13:17 21.2 0.1
13:18 21.2 0.1
13:19 21.2 0.1
13:20 21.2 0.1
13:21 21.2 0.1
13:22 21.2 0.1
13:23 21.2 0.1
13:24 21.3 0.1
PORT CHANGE
PORT 2
13:45 21.1 0.1
13:46 21.1 0.1
13:47 21.1 0.1
13:48 21.1 0.1
13:49 21.1 0.1
13:50 21.1 0.1
13:51 21.1 0.1
13:52 21.1 0.1
13:53 21.1 0.1
13:54 21.1 0.1
13:55 21.1 0.1
13:56 21.2 0.1
13:57 21.2 0.1
13:58 21.2 0.1
13:59 21.2 0.1
14:00 21.2 0.1
14:01 21.2 0.1
14:02 21.2 0.1
14:03 21.2 0.1
14:04 21.2 0.1
14:05 21.2 0.1
14:06 21.3 0.1
14:07 21.2 0.1
14:08 21.2 0.1
14:09 21.2 0.1
14:10 21.2 0.1
14:11 21.2 0.1
14:12 21.2 0.1
118
RUN DATA
Number 7
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
1 Mar 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
14:13 21.2 0.1
14:14 21.2 0.1
14:15 21.2 0.1
14:16 21.2 0.1
14:17 21.2 0.1
14:18 21.2 0.1
14:19 21.3 0.1
14:20 21.3 0.1
14:21 21.3 0.1
14:22 21.3 0.1
14:23 21.3 0.1
14:24 21.3 0.1
14:25 21.2 0.1
14:26 21.2 0.1
14:27 21.2 0.1
14:28 21.2 0.1
14:29 21.2 0.1
14:30 21.2 0.1
14:31 21.2 0.1
14:32 21.2 0.1
14:33 21.2 0.1
Avgs 21.2 0.1
119
RUN SUMMARY
Number 7
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
1 Mar 2019
Project Number:
Operator:
Date:
O2 CO2
Method EPA 3A EPA 3A
Conc. Units %%
Time: 12:36 to 14:33
Run Averages
21.2 0.1
Pre-run Bias at 10:12
Zero Bias
Span Bias
Span Gas
0.0 0.0
12.2 8.4
12.0 8.9
Post-run Bias at 14:35
Zero Bias
Span Bias
Span Gas
0.0 0.0
12.1 8.3
12.0 8.9
Run averages corrected for the average of the pre-run and post-run bias
20.9 0.1
120
BIAS AND CALIBRATION DRIFT
Number 10
Client:
Location:
Source: Calibration 1
Chemours
CHEMOURS
VE North Carbon Bed/Division
15418.002.010
SD
1 Mar 2019
Project Number:
Operator:
Date:
Start Time: 14:35
O2 Method: EPA 3A
Span Conc. 21.0 %
Bias Results
Standard Cal.Bias Difference Error
Gas %%%%Status
Zero 0.0 0.0 0.0 0.0 Pass
Span 12.1 12.1 0.0 0.0 Pass
Calibration Drift
Standard Initial*Final Difference Drift
Gas %%%%Status
Zero 0.0 0.0 0.0 0.0 Pass
Span 12.2 12.1 -0.1 -0.5 Pass
*Bias No. 9
CO2
Method: EPA 3A
Span Conc. 16.6 %
Bias Results
Standard Cal.Bias Difference Error
Gas %%%%Status
Zero 0.0 0.0 0.0 0.0 Pass
Span 8.6 8.3 -0.3 -1.8 Pass
Calibration Drift
Standard Initial*Final Difference Drift
Gas %%%%Status
Zero 0.0 0.0 0.0 0.0 Pass
Span 8.4 8.3 -0.1 -0.6 Pass
*Bias No. 9
121
IASDATA\CHEMOURS\15418.002.009\CBED IN OUT REPORT FEB 2019-AMD 4/10/2019
APPENDIX C
LABORATORY ANALYTICAL REPORT
Note: The analytical report is included on the attached CD.
122






 

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04/04/2019Page 29 of 632139
IASDATA\CHEMOURS\15418.002.009\CBED IN OUT REPORT FEB 2019-AMD 4/10/2019
APPENDIX D
SAMPLE CALCULATIONS
140
SAMPLE CALCULATIONS FOR
HFPO DIMER ACID (METHOD 0010)
Client: Chemours Plant: Fayetteville, NC
Test Number: Run 1 Test Date: 2/26/2019
Test Location: CBed Inlet Test Period: 0927-1143
1. HFPO Dimer Acid concentration, lbs/dscf.
W x 2.2046 x 10-9
Conc1 = ------------------------------
Vm(std)
2713.1 x 2.2046 x 10-9
Conc1 = ------------------------------
54.721
Conc1 = 1.09E-07
Where:
W = Weight of HFPO Dimer Acid collected in sample in ug
Conc1 = HFPO Dimer Acid concentration, lbs/dscf.
2.2046x10-9 = Conversion factor from ug to lbs.
2. HFPO Dimer Acid concentration, ug/dscm.
Conc2 = W / ( Vm(std) x 0.02832)
Conc2 = 2713.1 / ( 54.721 x 0.02832 )
Conc2 =1750.6
Where:
Conc2 = HFPO Dimer Acid concentration, ug/dscm.
0.02832 = Conversion factor from cubic feet to cubic meters.
3/22/20193:58 PM 022619 CBed IN 1-3
141
3. HFPO Dimer Acid mass emission rate, lbs/hr.
MR1(Inlet)= Conc1 x Qs(std) x 60 min/hr
MR1(Inlet)= 1.09E-07 x 15187 x 60
MR1(Inlet)= 9.96E-02
Where:
MR1(Inlet)= HFPO Dimer Acid mass emission rate, lbs/hr.
4. HFPO Dimer Acid mass emission rate, g/sec.
MR2(Inlet)= MR1(Inlet) x 453.59 / 3600
MR2(Inlet)= 9.96E-02 x 453.59 /3600
MR2(Inlet)= 1.25E-02
Where:
MR2(Inlet)= HFPO Dimer Acid mass emission rate, g/sec.
453.59 = Conversion factor from pounds to grams.
3600 = Conversion factor from hours to seconds.
5. HFPO Dimer Acid Removal Efficiency, %
RE = MR1(Inlet) - MR1(Outlet)
--------------------------
MR1(Inlet)
RE = (9.96E-02) - (5.530E-04)
----------------------
9.96E-02
RE = 99.4
Where:
RE = Carbon Bed Removal Efficiency.
MR1(Inlet)= Carbon Bed Inlet HFPO Dimer Acid mass rate, lbs/hr.
MR1(Outlet)= Carbon Bed Outlet HFPO Dimer Acid mass rate, lbs/hr.
3/22/20193:58 PM 022619 CBed IN 1-3
142
EXAMPLE CALCULATIONS FOR
VOLUMETRIC FLOW AND MOISTURE AND ISOKINETICS
Client: Chemours Facility: Fayetteville, NC
Test Number: Run 1 Test Date: 2/26/19
Test Location: VEN-Carbon Bed Inlet Test Period: 0927-1143
1. Volume of dry gas sampled at standard conditions (68 deg F, 29.92 in. Hg), dscf.
delta H
17.64 x Y x Vm x ( Pb + ------------ )
13.6
Vm(std)= --------------------------------------------
(Tm + 460)
1.329
17.64 x 1.0027 x 52.809 x ( 30.29 + --------------------- )
13.6
Vm(std)= ------------------------------------------------------------ = 54.721
58.71 + 460
Where:
Vm(std) = Volume of gas sample measured by the dry gas meter,
corrected to standard conditions, dscf.
Vm = Volume of gas sample measured by the dry gas meter
at meter conditions, dcf.
Pb = Barometric Pressure, in Hg.
delt H = Average pressure drop across the orifice meter, in H2O
Tm = Average dry gas meter temperature , deg F.
Y = Dry gas meter calibration factor.
17.64 = Factor that includes ratio of standard temperature (528 deg R)
to standard pressure (29.92 in. Hg), deg R/in. Hg.
13.6 = Specific gravity of mercury.
2. Volume of water vapor in the gas sample corrected to standard conditions, scf.
Vw(std) = (0.04707 x Vwc) + (0.04715 x Wwsg)
Vw(std) = ( 0.04707 x 13.5 ) + ( 0.04715 x 11.2 ) = 1.16
Where:
Vw(std) = Volume of water vapor in the gas sample corrected to
standard conditions, scf.
Vwc = Volume of liquid condensed in impingers, ml.
Wwsg = Weight of water vapor collected in silica gel, g.
0.04707 = Factor which includes the density of water
(0.002201 lb/ml), the molecular weight of water
(18.0 lb/lb-mole), the ideal gas constant
21.85 (in. Hg) (ft3)/lb-mole)(deg R); absolute
temperature at standard conditions (528 deg R), absolute
pressure at standard conditions (29.92 in. Hg), ft3/ml.
0.04715 = Factor which includes the molecular weight of water
(18.0 lb/lb-mole), the ideal gas constant
21.85 (in. Hg) (ft3)/lb-mole)(deg R); absolute
temperature at standard conditions (528 deg R), absolute
pressure at standard conditions (29.92 in. Hg), and
453.6 g/lb, ft3/g.
3/22/20193:59 PM 022619 CBed IN 1-3
143
3. Moisture content
Vw(std)
bws = -------------------------
Vw(std) + Vm(std)
1.16
bws = ------------------------- = 0.021
1.16 + 54.721
Where:
bws = Proportion of water vapor, by volume, in the gas
stream, dimensionless.
4. Mole fraction of dry gas.
Md = 1 - bws
Md = 1 - 0.021 = 0.979
Where:
Md = Mole fraction of dry gas, dimensionless.
5. Dry molecular weight of gas stream, lb/lb-mole.
MWd = ( 0.440 x % CO2 ) + ( 0.320 x % O2 ) + ( 0.280 x (% N2 + % CO) )
MWd = ( 0.440 x 0.0 ) + ( 0.320 x 20.9 ) + (0.280 x ( 79.1 + 0.00 ))
MWd = 28.84
Where:
MWd = Dry molecular weight , lb/lb-mole.
% CO2 = Percent carbon dioxide by volume, dry basis.
% O2 = Percent oxygen by volume, dry basis.
% N2 = Percent nitrogen by volume, dry basis.
% CO = Percent carbon monoxide by volume, dry basis.
0.440 = Molecular weight of carbon dioxide, divided by 100.
0.320 = Molecular weight of oxygen, divided by 100.
0.280 = Molecular weight of nitrogen or carbon monoxide,
divided by 100.
6. Actual molecular weight of gas stream (wet basis), lb/lb-mole.
MWs = ( MWd x Md ) + ( 18 x ( 1 - Md ))
MWs = ( 28.84 x 0.979 ) +( 18 ( 1 - 0.979 )) = 28.61
Where:
MWs = Molecular weight of wet gas, lb/lb-mole.
18 = Molecular weight of water, lb/lb-mole.
3/22/20193:59 PM 022619 CBed IN 1-3
144
7. Average velocity of gas stream at actual conditions, ft/sec.
Ts (avg)
Vs =85.49 x Cp x ((delt p)1/2)avg x ( ---------------- )1/2
Ps x MWs
529
Vs = 85.49 x 0.84 x 0.72952 x ( -------------------- )^1/2 = 41.3
29.81 x 28.61
Where:
Vs = Average gas stream velocity, ft/sec.
(lb/lb-mole)(in. Hg)1/2
85.49 = Pitot tube constant, ft/sec x ------------------------------------
(deg R)(in H2O)
Cp = Pitot tube coefficient, dimensionless.
Ts = Absolute gas stream temperature, deg R = Ts, deg F + 460.
P(static)
Ps = Absolute gas stack pressure, in. Hg. = Pb + --------------
13.6
delt p = Velocity head of stack, in. H2O.
8. Average gas stream volumetric flow rate at actual conditions, wacf/min.
Qs(act) = 60 x Vs x As
Qs(act) = 60 x 41.3 x 6.31 = 15613
Where:
Qs(act) = Volumetric flow rate of wet stack gas at actual
conditions, wacf/min.
As =Cross-sectional area of stack, ft2.
60 = Conversion factor from seconds to minutes.
9. Average gas stream dry volumetric flow rate at standard conditions, dscf/min.
Ps
Qs(std) = 17.64 x Md x ----- x Qs(act)
Ts
29.81
Qs(std) = 17.64 x 0.979 x -------------------- x 15613
529.4
Qs(std) =15187
Where:
Qs(std) = Volumetric flow rate of dry stack gas at standard
conditions, dscf/min.
3/22/20193:59 PM 022619 CBed IN 1-3
145
10. Isokinetic variation calculated from intermediate values, percent.
17.327 x Ts x Vm(std)
I = -----------------------------------
Vs x O x Ps x Md x (Dn)2
17.327 x 529 x 54.721
I = -------------------------------------------------- = 93.9
41.3 x 96 x 29.81 x 0.979 x (0.215)^2
Where:
I = Percent of isokinetic sampling.
O = Total sampling time, minutes.
Dn = Diameter of nozzle, inches.
17.327 = Factor which includes standard temperature (528 deg R),
standard pressure (29.92 in. Hg), the formula for
calculating area of circle D2/4, conversion of square
feet to square inches (144), conversion of seconds
to minutes (60), and conversion to percent (100),
(in. Hg)(in2)(min)
(deg R)(ft2)(sec)
3/22/20193:59 PM 022619 CBed IN 1-3
146
IASDATA\CHEMOURS\15418.002.009\CBED IN OUT REPORT FEB 2019-AMD 4/10/2019
APPENDIX E
EQUIPMENT CALIBRATION RECORDS
147
Date: 12/4/14-12/5/14Analyzer Type: Servomex - O2Model No: 4900Serial No: 49000-652921Calibration Span: 21.09 %Pollutant: 21.09% O2 - CC418692
CO2 (30.17% CC199689)0.00 -0.01 0.00
.
NO (445 ppm CC346681)0.00 0.02 0.11
NO2 (23.78 ppm CC500749)NA NA NA
N2O (90.4 ppm CC352661)0.00 0.05 0.24
CO (461.5 ppm XC006064B)0.00 0.02 0.00
SO2 (451.2 ppm CC409079)0.00 0.05 0.23
CH4 (453.1 ppm SG901795)NA NA NA
H2 (552 ppm ALM048043)0.00 0.09 0.44
HCl (45.1 ppm CC17830)0.00 0.03 0.14
NH3 (9.69 ppm CC58181)0.00 0.01 0.03
1.20
< 2.5%
(a) The larger of the absolute values obtained for the interferent tested with and without the pollutant present was used in summing the interferences.
Chad Walker
INTERFERENCE CHECK
INTERFERENT GAS
ANALYZER RESPONSE % OF CALIBRATION
SPAN(a)
TOTAL INTERFERENCE RESPONSE
METHOD SPECIFICATION
INTERFERENT GAS RESPONSE, WITH
BACKGROUND POLLUTANT (%)INTERFERENT GAS RESPONSE (%)
148
Date: 12/4/14-12/5/14Analyzer Type: Servomex - CO2Model No: 4900Serial No: 49000-652921Calibration Span: 16.65%Pollutant: 16.65% CO2 - CC418692
CO2 (30.17% CC199689)NA NA NA
.
NO (445 ppm CC346681)0.00 0.02 0.10
NO2 (23.78 ppm CC500749)0.00 0.00 0.02
N2O (90.4 ppm CC352661)0.00 0.01 0.04
CO (461.5 ppm XC006064B)0.00 0.01 0.00
SO2 (451.2 ppm CC409079)0.00 0.11 0.64
CH4 (453.1 ppm SG901795)0.00 0.07 0.44
H2 (552 ppm ALM048043)0.00 0.04 0.22
HCl (45.1 ppm CC17830)0.10 0.06 0.60
NH3 (9.69 ppm CC58181)0.00 0.02 0.14
2.19
< 2.5%
(a) The larger of the absolute values obtained for the interferent tested with and without the pollutant present was used in summing the interferences.

Chad Walker
INTERFERENCE CHECK
INTERFERENT GAS
ANALYZER RESPONSE % OF CALIBRATION
SPAN(a)
TOTAL INTERFERENCE RESPONSE
METHOD SPECIFICATION
INTERFERENT GAS RESPONSE, WITH
BACKGROUND POLLUTANT (%)INTERFERENT GAS RESPONSE (%)
149
CERTIFICATE OF ANALYSIS
Grade of Product: EPA Protocol
Part Number: E03NI79E15A00E4 Reference Number: 82-401288926-1
Cylinder Number: CC18055 Cylinder Volume: 150.5 CF
Laboratory: 124 - Riverton (SAP) - NJ Cylinder Pressure: 2015 PSIG
PGVP Number: B52018 Valve Outlet: 590
Gas Code:CO2,O2,BALN Certification Date: Sep 04, 2018
Expiration Date:Sep 04, 2026
Certification performed in accordance with “EPA Traceability Protocol for Assay and Certification of Gaseous Calibration Standards (May 2012)” document EPA
600/R-12/531, using the assay procedures listed. Analytical Methodology does not require correction for analytical interference. This cylinder has a total analytical
uncertainty as stated below with a confidence level of 95%. There are no significant impurities which affect the use of this calibration mixture. All concentrations are on a
volume/volume basis unless otherwise noted.
Do Not Use This Cylinder below 100 psig, i.e. 0.7 megapascals.
ANALYTICAL RESULTS
Component Requested Actual Protocol Total Relative Assay
Concentration Concentration Method Uncertainty Dates
CARBON DIOXIDE 9.000 %8.864 %G1 +/- 0.7% NIST Traceable 09/04/2018
OXYGEN 12.00 %12.00 %G1 +/- 0.4% NIST Traceable 09/04/2018
NITROGEN Balance -
CALIBRATION STANDARDS
Type Lot ID Cylinder No Concentration Uncertainty Expiration Date
NTRM 13060629 CC413730 13.359 % CARBON DIOXIDE/NITROGEN +/- 0.6%May 09, 2019
ANALYTICAL EQUIPMENT
Instrument/Make/Model Analytical Principle Last Multipoint Calibration
Horiba VIA 510-CO2-19GYCXEG NDIR Aug 09, 2018
Horiba MPA 510-O2-7TWMJ041 Paramagnetic Aug 09, 2018
Triad Data Available Upon Request
Airgas Specialty GasesAirgas USA, LLC
600 Union Landing Road
Cinnaminson, NJ 08077-0000
Airgas.com
Signature on file
Approved for Release Page 1 of 82-401288926-1150
CERTIFICATE OF ANALYSIS
Grade of Product: EPA Protocol
Part Number: E03NI62E15A0224 Reference Number: 82-401044874-1
Cylinder Number: SG9169108 Cylinder Volume: 157.2 CF
Laboratory: 124 - Riverton (SAP) - NJ Cylinder Pressure: 2015 PSIG
PGVP Number: B52017 Valve Outlet: 590
Gas Code:CO2,O2,BALN Certification Date: Nov 18, 2017
Expiration Date:Nov 18, 2025
Certification performed in accordance with “EPA Traceability Protocol for Assay and Certification of Gaseous Calibration Standards (May 2012)” document EPA
600/R-12/531, using the assay procedures listed. Analytical Methodology does not require correction for analytical interference. This cylinder has a total analytical
uncertainty as stated below with a confidence level of 95%. There are no significant impurities which affect the use of this calibration mixture. All concentrations are on a
volume/volume basis unless otherwise noted.
Do Not Use This Cylinder below 100 psig, i.e. 0.7 megapascals.
ANALYTICAL RESULTS
Component Requested Actual Protocol Total Relative Assay
Concentration Concentration Method Uncertainty Dates
CARBON DIOXIDE 17.00 %16.58 %G1 +/- 0.7% NIST Traceable 11/18/2017
OXYGEN 21.00 %21.00 %G1 +/- 0.5% NIST Traceable 11/18/2017
NITROGEN Balance -
CALIBRATION STANDARDS
Type Lot ID Cylinder No Concentration Uncertainty Expiration Date
NTRM 12061336 CC360792 11.002 % CARBON DIOXIDE/NITROGEN +/- 0.6%Jan 11, 2018
NTRM 09061415 CC273526 22.53 % OXYGEN/NITROGEN +/- 0.4%Mar 08, 2019
ANALYTICAL EQUIPMENT
Instrument/Make/Model Analytical Principle Last Multipoint Calibration
Horiba VIA 510-CO2-19GYCXEG NDIR Oct 30, 2017
Horiba MPA 510-O2-7TWMJ041 Paramagnetic Oct 27, 2017
Triad Data Available Upon Request
Airgas Specialty GasesAirgas USA, LLC
600 Union Landing Road
Cinnaminson, NJ 08077-0000
Airgas.com
Signature on file
Approved for Release Page 1 of 82-401044874-1151
Pitot Tube Identification Number:
Inspection Date 2/19/19 Individual Conducting Inspection
Distance to A Plane (PA) - inches 0.46 PASS
Distance to B Plane (PB) - inches 0.46 PASS
Pitot OD (Dt) - inches 0.375
1.05 Dt < P < 1.5 Dt PA must Equal PB
Q1 and Q2 must be < 10o
B1 or B2 must be < 5o
Z must be < 0.125 inches
W must be < 0.03125 inches
X must be > 0.75 inches
Thermocouple meets
the Distance Criteria
in the adjacent figure
Impact Pressure
Opening Plane is
above the Nozzle
Entry Plane
NO
NA
NO
NA
PASS
PASS
PASS
Distance between Sample
Nozzle and Pitot (X) - inches
Thermocouple meets
the Distance Criteria
in the adjacent figure
YES
YES
PASS
NO YES
NA
0
0
Angle of B1 from
vertical A Tube-
degrees (absolute)0
0
0.8
Horizontal offset between A and
B Tubes (Z) - inches
Vertical offset between A and B
Tubes (W) - inches
0.004
0.015
PASS/FAIL
Angle of B1 from
vertical B Tube-
degrees (absolute)
PASS
PASS
PASS
P-694
ks
Angle of Q1 from vertical A Tube-
degrees (absolute)
Angle of Q2 from vertical B Tube-
degrees (absolute)
Type S Pitot Tube Inspection Data Form
Are Open Faces Aligned
Perpendicular to the Tube Axis YES NO PASS
If all Criteria PASS
Cp is equal to 0.84
Sample Probe
Type S Pitot Tube
Temperature Sensor
Dt
2 inch
Sample Probe
Temperature Sensor
Dt Type S Pitot Tube
3 inch
3/4 inch
A B
Face Opening Planes
A
B A B
Q1 Q1 Q2
B B
B
A A
A
FlowFlow
B1(+)B1(-)
B2(+ or -)
B1(+ or -)
B-Side Plane
AB
PA
PB
A-Side PlaneDt
X
Sampling D
Impact Pressure Opening Plane
Nozzle Entry Plane
W
B
A
B
A
Z
152
Pitot Tube Identification Number:
Inspection Date 2/19/19 Individual Conducting Inspection
Distance to A Plane (PA) - inches 0.453 PASS
Distance to B Plane (PB) - inches 0.453 PASS
Pitot OD (Dt) - inches 0.375
1.05 Dt < P < 1.5 Dt PA must Equal PB
Q1 and Q2 must be < 10o
B1 or B2 must be < 5o
Z must be < 0.125 inches
W must be < 0.03125 inches
X must be > 0.75 inches
Thermocouple meets
the Distance Criteria
in the adjacent figure
Impact Pressure
Opening Plane is
above the Nozzle
Entry Plane
NO
NA
NO
NA
PASS
PASS
PASS
Distance between Sample
Nozzle and Pitot (X) - inches
Thermocouple meets
the Distance Criteria
in the adjacent figure
YES
YES
PASS
NO YES
NA
0
0
Angle of B1 from
vertical A Tube-
degrees (absolute)0
0
0.87
Horizontal offset between A and
B Tubes (Z) - inches
Vertical offset between A and B
Tubes (W) - inches
0.012
0.022
PASS/FAIL
Angle of B1 from
vertical B Tube-
degrees (absolute)
PASS
PASS
PASS
P-710
ks
Angle of Q1 from vertical A Tube-
degrees (absolute)
Angle of Q2 from vertical B Tube-
degrees (absolute)
Type S Pitot Tube Inspection Data Form
Are Open Faces Aligned
Perpendicular to the Tube Axis YES NO PASS
If all Criteria PASS
Cp is equal to 0.84
Sample Probe
Type S Pitot Tube
Temperature Sensor
Dt
2 inch
Sample Probe
Temperature Sensor
Dt Type S Pitot Tube
3 inch
3/4 inch
A B
Face Opening Planes
A
B A
BQ1Q1 Q2
B B
B
A A
A
FlowFlow
B1(+)B1(-)
B2(+ or -)
B1(+ or -)
B-Side Plane
AB
PA
PB
A-Side PlaneDt
X
Sampling D
Impact Pressure Opening Plane
Nozzle Entry Plane
W
B
A
B
A
Z
153
Pitot Tube Identification Number:
Inspection Date 2/19/19 Individual Conducting Inspection
Distance to A Plane (PA) - inches 0.45 PASS
Distance to B Plane (PB) - inches 0.45 PASS
Pitot OD (Dt) - inches 0.375
1.05 Dt < P < 1.5 Dt PA must Equal PB
Q1 and Q2 must be < 10o
B1 or B2 must be < 5o
Z must be < 0.125 inches
W must be < 0.03125 inches
X must be > 0.75 inches
Thermocouple meets
the Distance Criteria
in the adjacent figure
Impact Pressure
Opening Plane is
above the Nozzle
Entry Plane
NO
NA
NO
NA
PASS
PASS
PASS
Distance between Sample
Nozzle and Pitot (X) - inches
Thermocouple meets
the Distance Criteria
in the adjacent figure
YES
YES
PASS
NO YES
NA
0
0
Angle of B1 from
vertical A Tube-
degrees (absolute)0
0
0.79
Horizontal offset between A and
B Tubes (Z) - inches
Vertical offset between A and B
Tubes (W) - inches
0.006
0.012
PASS/FAIL
Angle of B1 from
vertical B Tube-
degrees (absolute)
PASS
PASS
PASS
P-706
KS
Angle of Q1 from vertical A Tube-
degrees (absolute)
Angle of Q2 from vertical B Tube-
degrees (absolute)
Type S Pitot Tube Inspection Data Form
Are Open Faces Aligned
Perpendicular to the Tube Axis YES NO PASS
If all Criteria PASS
Cp is equal to 0.84
Sample Probe
Type S Pitot Tube
Temperature Sensor
Dt
2 inch
Sample Probe
Temperature Sensor
Dt Type S Pitot Tube
3 inch
3/4 inch
A B
Face Opening Planes
A
B
A
BQ1Q1 Q2
B B
B
A A
A
FlowFlow
B1(+)B1(-)
B2(+ or -)
B1(+ or -)
B-Side Plane
AB
PA
PB
A-Side PlaneDt
X
Sampling D
Impact Pressure Opening Plane
Nozzle Entry Plane
W
B
A
B
A
Z
154
Y Factor Calibration Check Calculation
MODIFIED METHOD 0010 TEST TRAIN
CARBON BED INLET
METER BOX NO. 28
2/26/2019 - 2/28/2019 & 3/1/2019
Run 1 Run 2 Run 3
MWd = Dry molecular weight source gas, lb/lb-mole.
0.32 = Molecular weight of oxygen, divided by 100.
0.44 = Molecular weight of carbon dioxide, divided by 100.
0.28 = Molecular weight of nitrogen or carbon monoxide, divided by 100.
% CO2 = Percent carbon dioxide by volume, dry basis.0.0 0.0 0.0
% O2 = Percent oxygen by volume, dry basis.20.9 20.9 20.9
MWd = ( 0.32 * O2 ) + ( 0.44 * CO2 ) + ( 0.28 * ( 100 - ( CO2 + O2 )))
MWd = ( 0.32 * 20.9 ) + ( 0.44 * 0 ) + ( 0.28 * ( 100 - ( 0 + 20.9 )))
MWd = ( 6.69 ) + ( 0.00 ) + ( 22.15 )
MWd = 28.84 28.84 28.84
Tma =Source Temperature, absolute(oR)
Tm = Average dry gas meter temperature , deg F.58.7 74.0 60.2
Tma = Ts + 460
Tma = 58.71 + 460
Tma = 518.71 533.96 520.17
Ps = Absolute meter pressure, inches Hg.
13.60 = Specific gravity of mercury.
delta H = Avg pressure drop across the orifice meter during sampling, in H2O 1.33 1.31 1.27
Pb = Barometric Pressure, in Hg.30.29 30.20 30.22
Pm = Pb + (delta H / 13.6)
Pm = 30.29 + ( 1.32916666666667 / 13.6)
Pm = 30.39 30.30 30.31
Yqa = dry gas meter calibration check value, dimensionless.
0.03 = (29.92/528)(0.75)2 (in. Hg/°/R) cfm2.
29.00 = dry molecular weight of air, lb/lb-mole.
Vm = Volume of gas sample measured by the dry gas meter at meter conditions, dcf.52.809 56.260 55.079
Y = Dry gas meter calibration factor (based on full calibration)1.0027 1.0027 1.0027
Delta H@ = Dry Gas meter orifice calibration coefficient, in. H2O.2.0895 2.0895 2.0895
avg SQRT Delta H =Avg SQRT press. drop across the orifice meter during sampling , in. H2O 1.1497 1.1436 1.1235
O = Total sampling time, minutes.96 96 96
Yqa = (O / Vm ) * SQRT ( 0.0319 * Tma * 29 ) / ( Delta H@ * Pm * MWd ) * avg SQRT Delta H
Yqa = ( 96.00 / 52.81 ) * SQRT ( 0.0319 * 518.71 * 29 ) / ( 2.09 * 30.39 * 28.84 ) * 1.15
Yqa = 1.818 * SQRT 479.857 / 1,831.083 * 1.15
Yqa = 1.070 1.015 1.005
Diff = Absolute difference between Yqa and Y 6.71 1.23 0.23
Diff = (( Y - Yqa ) / Y ) * 100
Diff = (( 1.0027 - 1.070 ) / 1.0027 ) * 100
Average Diff = 2.72
Allowable = 5.0
4/3/201910:30 AM 022619 CBed IN 1-3155
Y Factor Calibration Check Calculation
MODIFIED METHOD 0010 TEST TRAIN
CARBON BED OUTLET
METER BOX NO. WC22
2/26/2019 - 2/28/2019 & 3/1/2019
Run 1 Run 2 Run 3
MWd = Dry molecular weight source gas, lb/lb-mole.
0.32 = Molecular weight of oxygen, divided by 100.
0.44 = Molecular weight of carbon dioxide, divided by 100.
0.28 = Molecular weight of nitrogen or carbon monoxide, divided by 100.
% CO2 = Percent carbon dioxide by volume, dry basis.0.0 0.0 0.0
% O2 = Percent oxygen by volume, dry basis.20.9 20.9 20.9
MWd = ( 0.32 * O2 ) + ( 0.44 * CO2 ) + ( 0.28 * ( 100 - ( CO2 + O2 )))
MWd = ( 0.32 * 20.9 ) + ( 0.44 * 0 ) + ( 0.28 * ( 100 - ( 0 + 20.9 )))
MWd = ( 6.69 ) + ( 0.00 ) + ( 22.15 )
MWd = 28.84 28.84 28.84
Tma =Source Temperature, absolute(oR)
Tm = Average dry gas meter temperature , deg F.60.2 79.4 63.3
Tma = Ts + 460
Tma = 60.21 + 460
Tma = 520.21 539.38 523.25
Ps = Absolute meter pressure, inches Hg.
13.60 = Specific gravity of mercury.
delta H = Avg pressure drop across the orifice meter during sampling, in H2O 1.61 1.65 1.64
Pb = Barometric Pressure, in Hg.30.29 30.20 30.22
Pm = Pb + (delta H / 13.6)
Pm = 30.29 + ( 1.60791666666667 / 13.6)
Pm = 30.41 30.32 30.34
Yqa = dry gas meter calibration check value, dimensionless.
0.03 = (29.92/528)(0.75)2 (in. Hg/°/R) cfm2.
29.00 = dry molecular weight of air, lb/lb-mole.
Vm = Volume of gas sample measured by the dry gas meter at meter conditions, dcf.54.493 55.964 55.596
Y = Dry gas meter calibration factor (based on full calibration)1.0010 1.0010 1.0010
Delta H@ = Dry Gas meter orifice calibration coefficient, in. H2O.2.4674 2.4674 2.4674
avg SQRT Delta H =Avg SQRT press. drop across the orifice meter during sampling , in. H2O 1.2420 1.2604 1.2575
O = Total sampling time, minutes.96 96 96
Yqa = (O / Vm ) * SQRT ( 0.0319 * Tma * 29 ) / ( Delta H@ * Pm * MWd ) * avg SQRT Delta H
Yqa = ( 96.00 / 54.49 ) * SQRT ( 0.0319 * 520.21 * 29 ) / ( 2.47 * 30.41 * 28.84 ) * 1.24
Yqa = 1.762 * SQRT 481.245 / 2,163.670 * 1.24
Yqa = 1.0319 1.0398 1.0283
Diff = Absolute difference between Yqa and Y 3.09 3.88 2.73
Diff = (( Y - Yqa ) / Y ) * 100
Diff = (( 1.001 - 1.032 ) / 1.001 ) * 100
Average Diff = 3.23
Allowable = 5.0
4/3/201910:32 AM 022619 CBed OUT 1-3156
IASDATA\CHEMOURS\15418.002.009\CBED IN OUT REPORT FEB 2019-AMD 4/10/2019
APPENDIX F
LIST OF PROJECT PARTICIPANTS
157
IASDATA\CHEMOURS\15418.002.009\CBED IN OUT REPORT FEB 2019-AMD 4/10/2019
The following WESTON employees participated in this project.
Paul Meeter Senior Project Manager
Jeff O’Neill
Robert Scroggins Team Member
Jacob Little Team Member
Kris Ansley Team Member
Austin Squires Team Member
158
Team Member