2019.06.04_CCO.p8_PPA Manufacturing Process Carbon Bed Inlet and Outlet Stack Emissions Test Report

IASDATA\CHEMOURS\15418.002.012\PPA REPORT MAY 2019-AMD 6/4/2019

PPA MANUFACTURING PROCESS
CARBON BED INLET AND OUTLET STACK
EMISSIONS TEST REPORT
TEST DATES: 30 APRIL - 01 MAY 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
June 2019
W.O. No. 15418.002.012

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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 ...................................................................................4 
3. PROCESS DESCRIPTIONS ............................................................................................5 
3.1 POLYMER PROCESSING AID (PPA) AREA ......................................................5 
3.2 PROCESS OPERATIONS AND PARAMETERS .................................................5 
4. DESCRIPTION OF TEST LOCATIONS .......................................................................6 
4.1 PPA PROCESS STACK ..........................................................................................6 
4.2 PPA CARBON BED INLET ...................................................................................6 
5. SAMPLING AND ANALYTICAL METHODS .............................................................9 
5.1 STACK GAS SAMPLING PROCEDURES ...........................................................9 
5.1.1 Pre-Test Determinations ...........................................................................9 
5.2 STACK PARAMETERS .........................................................................................9 
5.2.1 EPA Method 0010.....................................................................................9 
5.2.2 EPA Method 0010 – Sample Recovery ..................................................11 
5.2.3 EPA Method 0010 – Sample Analysis ....................................................14 
5.3 GAS COMPOSITION ...........................................................................................15 
6. DETAILED TEST RESULTS AND DISCUSSION .....................................................17 

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 PPA Process Stack Test Port and Traverse Point Location ......................................... 7 
Figure 4-2 PPA Carbon Bed Inlet Test Port and Traverse Point Location .................................... 8 
Figure 5-1 EPA Method 0010 Sampling Train ............................................................................. 10 
Figure 5-2 HFPO Dimer Acid Sample Recovery Procedures for Method 0010 ......................... 13 
Figure 5-3 WESTON Sampling System ...................................................................................... 16 

IASDATA\CHEMOURS\15418.002.012\PPA REPORT MAY 2019-AMD 6/4/2019 iii
LIST OF TABLES
Title Page
Table 2-1 Summary of HFPO Dimer Acid Test Results ................................................................ 4 
Table 6-1 Summary of HFPO Dimer Acid Test Data and Test Results PPA Process Stack ....... 18 
Table 6-2 Summary of HFPO Dimer Acid Test Data and Test Results PPA Carbon Bed Inlet . 20 

IASDATA\CHEMOURS\15418.002.012\PPA REPORT MAY 2019-AMD 6/4/2019 1
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. The Chemours operating areas on the
site include the Fluoromonomers, IXM and Polymer Processing Aid (PPA) manufacturing areas,
Wastewater Treatment, and Powerhouse.
Chemours contracted Weston Solutions, Inc. (Weston) to perform HFPO Dimer Acid emission
testing on the PPA process stack (outlet) and PPA carbon bed inlet. Testing was performed on 30
April-1 May 2019 and generally followed the “Emissions 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
from the PPA process stack and PPA carbon bed inlet which are located in the PPA
process area.
 Calculate the carbon bed removal efficiency for HFPO Dimer Acid.
 Monitor and record process 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 on the PPA process stack and the PPA carbon bed inlet.
Tables 1-1 provides a summary of the test locations and the parameters that were measured along
with the sampling/analytical procedures that were followed.

IASDATA\CHEMOURS\15418.002.012\PPA REPORT MAY 2019-AMD 6/4/2019 2
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.

IASDATA\CHEMOURS\15418.002.012\PPA REPORT MAY 2019-AMD 6/4/2019 3
Table 1-1
Sampling Plan for PPA Carbon Bed
Sampling Point & Location PPA Carbon Bed
Number of Tests: 6 (3 inlet, 3 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 M3A EPA M4 in
conjunction
with M-0010
tests
Sample Extraction/ Analysis Method(s): LC/MS/MS NA6 NA NA
Sample Size > 1m3 NA NA NA NA
Total Number of Samples Collected1 6 6 3 3 6
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 105 6 3 3 6
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.

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2. SUMMARY OF TEST RESULTS
A total of three test runs were performed on the PPA process stack (outlet) and on the PPA
carbon bed inlet. Table 2-1 provides a summary of the HFPO Dimer Acid emission test results.
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 Test Results
Inlet Outlet (Process Stack) Removal
Efficiency
g/sec lb/hr g/sec lb/hr %
PPA Carbon Bed
R1 3.12E-04 2.48E-03 9.82E-06 7.80E-05 96.9
R2 3.54E-04 2.81E-03 1.13E-05 8.95E-05 96.8
R3 4.71E-04 3.74E-03 8.07E-06 6.41E-05 98.3
Average 3.79E-04 3.01E-03 9.72E-06 7.72E-05 97.3

IASDATA\CHEMOURS\15418.002.012\PPA REPORT MAY 2019-AMD 6/4/2019 5
3. PROCESS DESCRIPTIONS
The PPA area is included in the scope of this test program.
3.1 POLYMER PROCESSING AID (PPA) AREA
The PPA facility produces surfactants used to produce fluoropolymer products, such as Teflon®,
at other Chemours facilities, as well as sales to outside producers of fluoropolymers.
Process streams are vented to a caustic wet scrubber (ACD-A1), carbon bed and vented to a
process stack (AEP-A1). The process inside the building is under negative pressure and the
building air is vented to the carbon bed and the process stack (AEP-A1).
3.2 PROCESS OPERATIONS AND PARAMETERS
Source Operation/Product Batch or Continuous
PPA AF Column Reboiler/Virgin Pressure Transfers/Virgin or Purified
Continuous once it starts taking off to feed tank Batch (pressure transfers from one vessel to another – every 2 hours)
During the test program, the following parameters were monitored by Chemours and are
included in Appendix A.
 PPA Process
o Caustic Wet Scrubber (ACD-A1)
 Caustic recirculation flow rate
 Differential pressure across the packing

IASDATA\CHEMOURS\15418.002.012\PPA REPORT MAY 2019-AMD 6
4. DESCRIPTION OF TEST LOCATIONS
4.1 PPA PROCESS STACK
Two 4-inch ID test ports are in place on the 30-inch ID fiberglass stack. The ports are 12 feet
(4.8 diameters) from the nearest downstream disturbance (carbon bed outlet) and 32 feet
(12.8 diameters) from the nearest upstream disturbance (stack exit).
Per EPA Method 1, a total of 24 traverse points (12 per axis) were used for M-0010 isokinetic
sampling. See Figure 4-1 for a schematic of the test port and traverse point locations.
Note: All measurements at the test location were confirmed prior to sampling.
4.2 PPA CARBON BED INLET
Each fiberglass reinforced plastic (FRP) duct at the inlet of the PPA carbon bed is 34-inch ID.
The test ports are located a minimum of 42 inches (> 1.2 duct diameters) from the nearest
downstream disturbance and at least 57 inches (> 1.7 diameters) from the nearest upstream
disturbance. Based on EPA Method 1, a total of 24 traverse points (12 per port) were used for
HFPO Dimer Acid sampling. Figure 4-2 provides a schematic of the test port and traverse port
locations.

30 "
TRAVERSE
POINT
NUMBER
DISTANCE FROM
INSIDE NEAR
WALL (INCHES)
1
2
3
4
5
6
7
8
9
10
11
12
FIGURE 4-1
PPA PROCESS STACK TEST PORT
AND TRAVERSE POINT LOCATION
IASDATA\CHEMOURS\15418.002.012\FIGURE 4-3 PPA PROCESS STACK7
32 '
12 '
ID
FAN
DEMISTER DUCT
(DISCONNECTED)
~ 33 '
1
2
3 1/2
5 3/8
7 1/2
10 3/4
19 3/8
22 1/2
24 3/4
26 1/2
28
29
DRAWING NOT TO SCALE
34 "
TRAVERSE
POINT
NUMBER
DISTANCE FROM
INSIDE NEAR
WALL (INCHES)
1
2
3
4
5
6
7
8
9
10
11
12
FIGURE 4-2
PPA PROCESS CARBON BED INLET
TEST PORT AND TRAVERSE POINT LOCATION
IASDATA\CHEMOURS\15418.002.012\FIGURE 4-2 PPA PROCESS SCHEMATIC8
CARBON BED
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 "
42 "

IASDATA\CHEMOURS\15418.002.012\PPA REPORT MAY 2019-AMD 9
5. SAMPLING AND ANALYTICAL METHODS
5.1 STACK GAS SAMPLING PROCEDURES
The purpose of this section is to describe the stack gas emissions sampling train 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 was obtained at the 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 the test
locations. The cyclonic flow check was negative (< 20°) verifying that the sources 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 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.
9(17:$//,&(:$7(55(&,5&8/$7,213803&21'(16$7(75$3,03,1*(56,&(%$7+9$&880/,1(0$,19$/9(7(03(5$785(6(16256%<3$669$/9($,57,*+73803'5<*$60(7(525,),&(0$120(7(5&+(&.9$/9(7(03(5$785(6(1625+($7('$5($),/7(5+2/'(525,),&(6,/,&$*(/&21'(16(5;$'625%(1702'8/(621($1'7:27(03(5$785(6(16257(03(5$785(6(16259$&880*$8*(,$6'$7$?&+(02856?2?),*85(0(7+2'),*85((3$0(7+2'6$03/,1*75$,1+($7('352%(%87721+22.12==/(5(9(56(7<3(3,72778%(10 127(7+(&21'(16(50$<%(326,7,21('+25,=217$//<7+(;$'625%(1702'8/(:,//$/:$<6%(,1$9(57,&$/326,7,215,*,'%2526,/,&$7(78%,1*25)/(;,%/(6$03/(/,1(,&(:$7(55(&,5&8/$7,21&21'(16$7(75$3,03,1*(5

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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 and 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-L condensate
knockout trap. The final impinger contained 300 grams 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 the XAD-2 module 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 undergoes hydrolysis instantaneously in water in the sampling train and
during the sample recovery step and will be converted to HFPO Dimer Acid such that the
amount of HFPO Dimer Acid emissions represents 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.

IASDATA\CHEMOURS\15418.002.012\PPA REPORT MAY 2019-AMD 6/4/2019 12
A consistent procedure was employed for sample recovery:
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 remained. 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, an M-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 M-0010 sample recovery process.
,$6'$7$?&+(02856?2?),*85((3$),*85(+)32',0(5$&,'6$03/(5(&29(5<352&('85(6)250(7+2'12==/(352%($1')5217+$/)),/7(5+2/'(56$03/()5$&7,21),/7(56$03/()5$&7,21%$&.+$/)),/7(5+2/'(5&211(&7256)/(;,%/(/,1(&21'(16(56$03/()5$&7,21;$'02'8/(21(6$03/()5$&7,215(029()520,03,1*(575$,1:$6+:,7+ 0(7+$12/$0021,80+<'52;,'(6($/,1/$%(/('32/<(7+</(1(%277/(&203/(7(&8672'<)2506(&85(6$03/($1'.((3&22/:$6+:+,/(%586+,1*:,7+ 0(7+$12/$0021,80+<'52;,'(6($/(1'6:,7+*/$66&$36&29(5/$%(/&203/(7(&8672'<)2506(&85(6$03/($7$1'.((3&22/75$16)(5:$6+,1*67232/<(7+</(1(%277/(/$%(/6($/$1'0$5./,48,'/(9(/&203/(7(&8672'<)2506(&85(6$03/($1'.((3&22/6($/:$6+,1*6,1/$%(/('32/<(7+</(1(%277/(0$5./,48,'/(9(/&203/(7(&8672'<)2506(&85(6$03/($1'.((3&22/),567$1'6(&21'&21'(16$7(75$36$1',03,1*(5126$1'6$03/()5$&7,21,03,1*(5126,/,&$*(/:(,*+$1'5(&25'0($685(92/80(2)/,48,'$1'5(&25'75$16)(5:$6+,1*67232/<(7+</(1(%277/(/$%(/6($/$1'0$5./,48,'/(9(/&203/(7(&8672'<)2506(&85(6$03/($1'.((3&22/3:(,*+$1'5(&25'5(7$,1)255(*(1(5$7,21),567$1'6(&21'&21'(16$7(75$36$1',03,1*(5126$1'6$03/()5$&7,21:$6+:,7+ 0(7+$12/$0021,80+<'52;,'(75$16)(5:$6+,1*67232/<(7+</(1(%277/(/$%(/6($/$1'0$5./,48,'/(9(/&203/(7(&8672'<)2506(&85(6$03/($1'.((3&22/;$'02'8/(7:26$03/()5$&7,215(029()520,03,1*(575$,16($/(1'6:,7+*/$66&$36&29(5/$%(/&203/(7(&8672'<)2506(&85(6$03/($7$1'.((3&22/

IASDATA\CHEMOURS\15418.002.012\PPA REPORT MAY 2019-AMD 6/4/2019 14
5.2.3 EPA Method 0010 – Sample Analysis
The 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.

IASDATA\CHEMOURS\15418.002.012\PPA REPORT MAY 2019-AMD 6/4/2019 15
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.
The sample was collected at the exhaust of the Method 0010 sampling system. At the end of the
line, a tee permitted the introduction of calibration gas. The sample was drawn through a heated
Teflon® sample line to the sample conditioner. The output from the sampling system was
recorded electronically, and one-minute averages were recorded and displayed on a data logger.
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 maintains 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 ensure 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\15418.002.012\FIGURE 5-5 WESTON SAMPLING SYSTEM16

IASDATA\CHEMOURS\15418.002.012\PPA REPORT MAY 2019-AMD 6/4/2019 17
6. DETAILED TEST RESULTS AND DISCUSSION
Preliminary testing and the associated analytical results required significant sample dilution to
bring the HFPO Dimer Acid concentration within instrument calibration, therefore, sample times
and sample volumes were reduced for the formal test program. This was approved by the North
Carolina Department of Environmental Quality (NCDEQ).
Each test was a minimum of 96 minutes in duration. A total of three test runs were performed on
the PPA process stack and on the PPA carbon bed inlet.
Tables 6-1 and 6-2 provide detailed test data and test results for the PPA process stack and PPA
carbon bed inlet, 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.
TABLE 6-1
CHEMOURS - FAYETTEVILLE, NC
SUMMARY OF HFPO DIMER ACID TEST DATA AND TEST RESULTS
PPA PROCESS STACK
Test Data
Run number 1 2 3
Location PPA Stack PPA Stack PPA Stack
Date 04/30/19 04/30/19 05/01/19
Time period 1010-1201 1330-1518 0830-1017
SAMPLING DATA:
Sampling duration, min.96.0 96.0 96.0
Nozzle diameter, in.0.191 0.191 0.191
Cross sectional nozzle area, sq.ft.0.000199 0.000199 0.000199
Barometric pressure, in. Hg 30.20 30.20 30.30
Avg. orifice press. diff., in H2O 0.70 0.60 0.81
Avg. dry gas meter temp., deg F 81.5 102.3 79.6
Avg. abs. dry gas meter temp., deg. R 541 562 540
Total liquid collected by train, ml 11.9 24.3 19.4
Std. vol. of H2O vapor coll., cu.ft.0.6 1.1 0.9
Dry gas meter calibration factor 0.9944 0.9944 0.9944
Sample vol. at meter cond., dcf 43.943 41.735 47.697
Sample vol. at std. cond., dscf (1)43.066 39.377 47.071
Percent of isokinetic sampling 101.9 101.9 102.2
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.0.013 0.028 0.019
Mole fraction of dry gas 0.987 0.972 0.981
Molecular wt. of wet gas, lb/lb mole 28.70 28.53 28.63
GAS STREAM VELOCITY AND VOLUMETRIC FLOW DATA:
Static pressure, in. H2O 2.10 2.10 2.10
Absolute pressure, in. Hg 30.35 30.35 30.45
Avg. temperature, deg. F 87 89 83
Avg. absolute temperature, deg.R 547 549 543
Pitot tube coefficient 0.84 0.84 0.84
Total number of traverse points 24 24 24
Avg. gas stream velocity, ft./sec.38.2 35.6 41.4
Stack/duct cross sectional area, sq.ft.4.90 4.90 4.90
Avg. gas stream volumetric flow, wacf/min.11217 10454 12179
Avg. gas stream volumetric flow, dscf/min.10842 9911 11822
(1)Standard conditions = 68 deg. F. (20 deg. C.) and 29.92 in Hg (760 mm Hg)
5/22/2019 10:43 AM
18
043019 PPA stack
TEST DATA
Run number 1 2 3
Location PPA Stack PPA Stack PPA Stack
Date 04/30/19 04/30/19 05/01/19
Time period 1010-1201 1330-1518 0830-1017
LABORATORY REPORT DATA, ug.
HFPO Dimer Acid 2.3431 2.6870 1.9300
EMISSION RESULTS, ug/dscm.
HFPO Dimer Acid 1.92 2.41 1.45
EMISSION RESULTS, lb/dscf.
HFPO Dimer Acid 1.20E-10 1.50E-10 9.04E-11
EMISSION RESULTS, lb/hr.
HFPO Dimer Acid 7.80E-05 8.95E-05 6.41E-05
HFPO Dimer Acid (From Inlet Data)2.48E-03 2.81E-03 3.74E-03
EMISSION RESULTS, g/sec.
HFPO Dimer Acid 9.82E-06 1.13E-05 8.07E-06
Carbon Bed Removal Efficiency, %96.9 96.8 98.3
TABLE 6-1 (cont.)
CHEMOURS - FAYETTEVILLE, NC
SUMMARY OF HFPO DIMER ACID TEST DATA AND TEST RESULTS
PPA PROCESS STACK
5/22/2019 10:43 AM
19
043019 PPA stack
TABLE 6-2
CHEMOURS - FAYETTEVILLE, NC
SUMMARY OF HFPO DIMER ACID TEST DATA AND TEST RESULTS
PPA CARBON BED INLET
Test Data
Run number 1 2 3
Location PPA CB Inlet PPA CB Inlet PPA CB Inlet
Date 04/30/19 04/30/19 05/01/19
Time period 1010-1201 1330-1518 0830-1017
SAMPLING DATA:
Sampling duration, min. 96.0 96.0 96.0
Nozzle diameter, in. 0.250 0.250 0.250
Cross sectional nozzle area, sq.ft. 0.000341 0.000341 0.000341
Barometric pressure, in. Hg 30.10 30.10 30.20
Avg. orifice press. diff., in H2O 1.82 1.86 1.75
Avg. dry gas meter temp., deg F 83.4 89.8 76.2
Avg. abs. dry gas meter temp., deg. R 543 550 536
Total liquid collected by train, ml 34.6 32.5 27.6
Std. vol. of H2O vapor coll., cu.ft.1.6 1.5 1.3
Dry gas meter calibration factor 1.0005 1.0005 1.0005
Sample vol. at meter cond., dcf 63.472 65.238 62.118
Sample vol. at std. cond., dscf (1)62.324 63.326 62.008
Percent of isokinetic sampling 99.9 100.6 100.7
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 0.024 0.021
Mole fraction of dry gas 0.975 0.976 0.979
Molecular wt. of wet gas, lb/lb mole 28.56 28.58 28.61
GAS STREAM VELOCITY AND VOLUMETRIC FLOW DATA:
Static pressure, in. H2O -2.00 -2.00 -2.00
Absolute pressure, in. Hg 29.95 29.95 30.05
Avg. temperature, deg. F 78 83 75
Avg. absolute temperature, deg.R 538 543 535
Pitot tube coefficient 0.84 0.84 0.84
Total number of traverse points 24 24 24
Avg. gas stream velocity, ft./sec.33.2 33.7 32.3
Stack/duct cross sectional area, sq.ft.6.31 6.31 6.31
Avg. gas stream volumetric flow, wacf/min.12567 12772 12230
Avg. gas stream volumetric flow, dscf/min.12032 12144 11873
(1)Standard conditions = 68 deg. F. (20 deg. C.) and 29.92 in Hg (760 mm Hg)
5/22/2019 10:56 AM
20
043019 PPA CBed
TEST DATA
Run number 1 2 3
Location PPA CB Inlet PPA CB Inlet PPA CB Inlet
Date 04/30/19 04/30/19 05/01/19
Time period 1010-1201 1330-1518 0830-1017
LABORATORY REPORT DATA, ug.
HFPO Dimer Acid 97.0882 110.7296 147.6090
EMISSION RESULTS, ug/dscm.
HFPO Dimer Acid 55.00 61.74 84.05
EMISSION RESULTS, lb/dscf.
HFPO Dimer Acid 3.43E-09 3.85E-09 5.25E-09
EMISSION RESULTS, lb/hr.
HFPO Dimer Acid 2.48E-03 2.81E-03 3.74E-03
EMISSION RESULTS, g/sec.
HFPO Dimer Acid 3.12E-04 3.54E-04 4.71E-04
TABLE 6-2 (cont.)
CHEMOURS - FAYETTEVILLE, NC
SUMMARY OF HFPO DIMER ACID TEST DATA AND TEST RESULTS
PPA CARBON BED INLET
5/22/2019 10:56 AM
21
043019 PPA CBed

IASDATA\CHEMOURS\15418.002.012\PPA REPORT MAY 2019-AMD 6/4/2019
APPENDIX A
PROCESS OPERATIONS DATA

Date: 4/30/2019TimeStack TestingA/F column Feed Ratev (pounds per hour)Charging water to Hyd ‐ ventingXCharging Sulfuric acid  ‐ ventingHydrolysis ‐ Wash Tank pressure Transfer to Hydrolysis Hydrolysis ‐ Phase Settle Vap heels pressure transfer Vap cycle Venting after press tran from North/South Acid tank to HydDAF tran to Hyd ‐ venting during transferHydrolysis ‐ transfer to Waste Acid TrailerScrubber Recirculation FlowScrubber dP10:15 TO 10:5536.0 GPM37.2 GPM‐0.45 INWC‐.5 INWC1500RUN 1 1010‐1201 RUN 2 1330‐151811:00 TO 11:25800 900 1000 1100 1200 1300 1400
Date: 5/1/2019TimeStack TestingA/F column Feed Ratev (pounds per hour)Charging water to Hyd ‐ ventingCharging Sulfuric acid  ‐ ventingHydrolysis ‐ Wash Tank pressure Transfer to Hydrolysis Hydrolysis ‐ Phase Settle Vap heels pressure transfer Vap cycle Venting after press tran from North/South Acid tank to HydDAF tran to Hyd ‐ venting during transferHydrolysis ‐ transfer to Waste Acid TrailerScrubber Recirculation FlowScrubber dP37.5 GPM‐0.4 INWCRun 3 0830‐10179:30 TO 10:158:30 TO 9:458:40 TO 9:30600 700 800 900 1000 1100 1200

IASDATA\CHEMOURS\15418.002.012\PPA REPORT MAY 2019-AMD 6/4/2019
APPENDIX B
RAW AND REDUCED TEST DATA

CHEMOURS - FAYETTEVILLE, NC
INPUTS FOR HFPO DIMER ACID CALCULATIONS
PPA PROCESS STACK
Test Data
Run number 1 2 3
Location PPA Stack PPA Stack PPA Stack
Date 04/30/19 04/30/19 05/01/19
Time period 1010-1201 1330-1518 0830-1017
Operator KA/BB/NG KA/NG/BB NG/KA/BB
Inputs For Calcs.
Sq. rt. delta P 0.67054 0.62199 0.73105
Delta H 0.7004 0.6021 0.8113
Stack temp. (deg.F) 86.9 88.8 82.9
Meter temp. (deg.F) 81.5 102.3 79.6
Sample volume (act.) 43.943 41.735 47.697
Barometric press. (in.Hg) 30.20 30.20 30.30
Volume H2O imp. (ml) 3.0 11.0 8.0
Weight change sil. gel (g) 8.9 13.3 11.4
% 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.) 4.900 4.900 4.900
Sample time (min.) 96.0 96.0 96.0
Static pressure (in.H2O) 2.10 2.10 2.10
Nozzle dia. (in.) 0.191 0.191 0.191
Meter box cal. 0.9944 0.9944 0.9944
Cp of pitot tube 0.84 0.84 0.84
Traverse points 24 24 24
5/22/2019 11:01 AM 043019 PPA stack
ISOHINETIC FIELD DATA SHEET EPA Method 0010 - HFPO Diener Acid Pam L ofdclientct,e~r,ours Stack Conditions Meter Box ID ~Factor CW.O.#15418 Assumed Actual Meter Box Y K ~
Project ID Chemours °/ Moisture ~.-deter Box Del H ~,}Iflltl8l Mid-Point FinalMode/Souroe ID PPA Impfnger Vol (ml)Probe ID /Length Sample Train (ft')fkj(7
.
Samp. Loc. ID STK Silica gel (g)Probe Material Bono Leak Check @ (in Hg)~Run No.ID 1 CO2, % by Vol 3 Pftot /Thermocouple ID Pitot leak check good / no / no / noTest Method ID M0010 02, °/a by Vol ~(Pitot Coefficient 0.84 Pitot Inspection good / no / no ye / noDate ID 15APR2019 Temperature (°F)NonJe ID ;Method 3 System good yes / no yes / no yes / noSource/Location PPA Stack Meter Temp (F) NoaJe Measurements ,Temp Check Pre- est et POSt- est etSample Date ~p ~/ Static Press (In H2O) p , r',, ~4vg NoaJe Dla (in) ~Meter Box TempBaro. Press (in Hg), Area of Stack (HZ) , 1 Reference TempOperatorAmbient Temp (°F) 1 h Sample Time Pass/Fail (+/- 2°~ Pasa /Fab Pass / FaHTotal Traverse Pts ~Temp Change Response . yes / no yes / no
O a
'L .'1 ~' API ~1. Q' ~17 ~ ~ i'L ~ 3
2
~a ~,tiv ~ . ~~~o ti ~~, ab~ ~ ~-a~ ~6 c~ 5 ~s ~.,Av Delta Avg Delta H Total Volume Avg Ts Avg T Min/Max inlMax au Mau Vac Mi ax
~ Avg Sgrt Delta P Avg Sgrt Del H Comments: ~~$'y{, EPA Method 0010 from EPA SW-846
~~~~
ISOKINETIC FIELD DATA SHEET EPA Method 0010 - HFPO Diener Acid Pam ~ocNent
w.o.#
ct,enx,urs Stack Conditions
~ Assumed
Meter Box ID
Actual nnetereox v
ti~
O, ~l K Factor ~,~j~s4~a
Project ID Chemours %a Moisture ti Meter Box Del H Initial Mid-Point FinalMode/Source ID PPA Impinger Vol (ml)Prohe ID /Length (! Sample Train (ft3)p (Q 19Samp. Loc. ID STK Silica gel (g)Probe Material 8oro Leak Check @ Qn Hg)Run No.ID 2 CO2, % by Vol O Pitot /Thermocouple ID , Pitot leak check good / no / no / noTest Method ID M0010 02, % by Vol Pi of Coefficient 0.84 Pitot Inspectlon good / no J no / noDate ID 15APR2019 Temperature (°F) '~.ID I / McUwd 3 System good yes / no yes / no yes / noSource/Locatlon PPA Stack Meter Temp (F) ~ p~,~ ;.c( Noale Measurements , a . q Temp Check Pre- est et ost- est etSample Date 0 Static Press Qn H2O) Avg NoaJe Dla (in) , ~ q, Meter Box TempBaro. Press (in Hg) '2,. Area of St2ck (ftz) N Reference TempOperator 'Ambient Temp (°F) ~S Sample Time q Pass/Fail (+/- 2°~ Pasa / Fali Pess /FailTotal Traverse Pts _~ ~/ Temp Change Response ~ yes / no yes / no
1____.~ 1 { 1 1 1 1 1
n~
I~~ ~ Avg Sgrt Defta P •Av~Sq Del H Con
r~v V ~~~~ v
v2 ~`1~3 1 6fl
EPA Method 0010 from EPA SW-846
ISOKINETIC FIELD DATA SHEET EPA Method 0010 - HFPO Diener Acid Page~,or 1Client cherr,ours Stack Conditions Meter sox i~ ~
K Factor ~, s'w.o.# asa~e Assumed Actual Metereox v b.gqyljProject ID cnemours io Moisture Meter Box Del H j, q2 ~~ Initial Mid-Point FinalMode/Source ID PPA Impinger Vol (ml)~Probe ID /Length ~ 7p~Sample Traln (fl')o~a[) 6~y ~ _Samp. Loc. ID STK Silica gel (g)i Probe Material 8oro Leak Check (a~ (in Hg)1 ~~Run No.ID 3 CO2, °/ by Vol , 1 Pitot /Thermocouple ID P ]7J(a Pftot leak check good / no yes no y / noTest Method ID M0010 02, % by Vol ~Pitot Coefficient 0.84 Pitot Inspection good / no / no es 7 noDate ID 15APR2019 Temperature (°F)7 Nozzle ID ,, q McUiod 3 System goodSource/Locatlon PPA Stack Meter Temp (F) ~. No~Je Measurements 0. ql O. Q f , (~j 1 Temp Check re-Test et Post- est etSample Date Static Press (in H2O) . A~g NoaJe Dia (in) ~, ~G~ Meter Box TempBaro. Press (in Hg) Q Area of Stack (ftZ) y,~O~Reference TempOperator /[ Amb(ent Temp (°F) ~ ~ Sample Time Pass/Fail (+/- 2°~ Pass / FeU Pass /FabTotal Traverse Pts ~l~ Temp Change Response i 1 no yes I no
0¨ r~~ r .
~~~~~~~.~~~ss~m~~~~~~~~~~
~~~~~~~~ ~~~«~~1~6~~~~~~~~~~~~r~~~'~~~► ~- r ~~~~d~~t3•~~~~y'~
i.t~il!•~~~~~~~~~-1 .~5~~~~~~~~0~~~~-• ~~~~~ ~ •!1!lI~~~CJ~~ti~~~~~~~-
~~-~~ r ~iid~~r ~~~~~_
~~-~~~~~~}~~~s~~~-
~~-~~~ ~.i~3i~i SL1~~~~~-
~~L~i~'~~~~~~~~~~~~~-
yNFS•T~ =;IV t~' , ~-J I ~q.flJ~gp,' I~~"4~~'~ I b (7 I
nnau vac I ~~~~' I~'~
EPA Method 0010 from EPA SW-846
Avg Sgrt Delta P Avg 5.~ 31 ~ , 8q
Wr' v
SAMPLE RECUVERY FIELD DATA
EPA Method 0010 - HFPO Diener Acid
Client Chemours W.O. # 15418
Location/Plant Fayetteville, Nc Source &Location PPA stack
Run No. 1 Sample Date ~/~~ Recovery Date
Sample I.D. Chemours - PPA - STK - 1 - M0010 - Analyst ~~ Filter Number ~/~
Im in er
1 2 3 4 5 6 7 Imp.Total 8 Total
Contents Empry HPLC H2O HPLC H2O Silica Gel
Final ~~Q Z ~~~~
Initial ~goo goo ~soo
Gain Z ~~0`2 ~~ ~j~~Q
Impinger Color Labeled? ~
Silica Gel Condition C~ Sealed?
Run No. 2 Sample Date ~ ~~d Recovery Date ~'f
Sample I.D. Chemours - PPA - STK - 2 - M0010 - Analyst ~M~ Filter Number /~q
Im in er
1 2 3 4 5 6 7 Imp.Total 8 TotalContentsEmptyHPLC H2O HPLC H2O Silica Gel
Final ~'~~ ~~ ~3~/3 3
Initial ~100 100 ~300
Gain •--2 ~ `~~ 1 X 3.3 Z `~7i
~(~ ~ ~/ i/Impinger Color C,~^~` Labeled?
Silica Gel Condition l~a~.~. Sealed? "~
~ L~ fj!- ~~~Run No. 3 Sample Date ,~~ ii Recovery Date
Sample I.D. Chemours - PPA - STK - 3 - M0010 - Analyst ~~~ Filter Number f~
Im in er
1 2 3 4 5 6 7 Imp.Total 8 TotalContentsEmptyHPLC H2O HPLC H2O Silica GeI
Final Z ~~~~~ Y't{
Initial ~100 100 v 300
Gain ~i 2, y f 1,.x'1 f~Y.'~
~Impinger Color Labeled?
Silica Gel Condition ~ a~~ Sealed?
Check COC for Sample IDs of Media Blanks
~s
~Cvu.t~ 1 we ~o a g ~ ~Z ~ ~/i.~
CHEMOURS - FAYETTEVILLE, NC
INPUTS FOR HFPO DIMER ACID CALCULATIONS
PPA CARBON BED INLET
Test Data
Run number 1 2 3
Location PPA CB Inlet PPA CB Inlet PPA CB Inlet
Date 04/30/19 04/30/19 05/01/19
Time period 1010-1201 1330-1518 0830-1017
Operator AS/JL AS/JL AS/JL
Inputs For Calcs.
Sq. rt. delta P 0.58298 0.59008 0.57037
Delta H 1.8175 1.8579 1.7467
Stack temp. (deg.F) 77.8 82.6 74.9
Meter temp. (deg.F) 83.4 89.8 76.2
Sample volume (act.) 63.472 65.238 62.118
Barometric press. (in.Hg) 30.10 30.10 30.20
Volume H2O imp. (ml) 10.0 14.0 11.0
Weight change sil. gel (g) 24.6 18.5 16.6
% 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.) 6.310 6.310 6.310
Sample time (min.) 96.0 96.0 96.0
Static pressure (in.H2O) -2.00 -2.00 -2.00
Nozzle dia. (in.) 0.250 0.250 0.250
Meter box cal. 1.0005 1.0005 1.0005
Cp of pitot tube 0.84 0.84 0.84
Traverse points 24 24 24
5/22/2019 11:04 AM 043019 PPA CBed
ISOHINETIC FIELD DATA SHEET EPA Method 0010 - HFPO Diener Acid
client Chemours Stack Conditions Meter eox Iv
W.O.#15418 Assumed Actual Meter Box Y V p 0 S
Project ID Chemours °/ Moisture `Meter Box Del H . Z ~ (p
Mode/Source ID PPA Impinger Vol (ml)~ ~/ Probe ID /Length Sample Train (ft9)
Samp. Loc. ID Cbed Silica gel (g)Z y• (✓ Probe Material Leak Check @ (in Hg)
Run No.ID 1 CO2, °/a by Vol (~ ~/ Pitot / Thermocouple ID = Pitot leak check good
Test Method ID M0010 02, % by Vol Zp. Pitot Coefficient 0.84 Pitot Inspec8on goodDate ID
Source/LocaUon
APR2019
PPA Ca~bori Bed Inlet
Temperature (°F)
`Meter Temp ("F)
NoaJe ID ~ Method 3 System good
Page ~ of
K Factor ~ , l 7
Initial Mid-Point Final
~, .~. .
C~~mr~T~r~~~.
t~ NoaJe Measurements ,~~~ ~ ~~ 2 ~ Temp Check - ~r l se t be os - I es eSample Date ~ f 7 ~ ~ 9 Static Press (fn H2O) ' ~""~,~ - Avg NoaJe Dla (in) 2 ~~ ~ Meter Box Temp -j —~ o~
Baro. Press (in Hg) _~. l Area of Stack (ftZ) (, 31 Reference Temp ~ v, ~
Operator (.J 5,~ ~'~ ~}~Amblent Temp (°F) ` 7,j ..;Sample Time Pass/Fail (+/- 2°) Pass Fafl a /Fail
Total Traverse Pts L 1} Temp Change Response 5 / no /
0~~~
~~—~~~~~~~~r~~~—
~~~~~~~~a~~~s~a ~~~s~~~~~r~~~~~~~a ~~~Q~s~rr~~
~~~~~~~~~■~~~~t~~~~~m~~~~~~~~~~~~~~~~~~~~~~~~■~~~~~~~am~~~~~~~~~~~Q~~~~om~~~~~~~~~■~~ic~~~~o~~s~s~~~~~~~~rc~~~~~~~o~■~~~~~~~~~~t~m ~~~«~m~~~~~~~~~~~~~c~
~s~~~~~~~~~~z~
~~~d~~~
~~0n~■~..y35t l.~e~~S L3, 4~Z "l~.l~ Ava Sart ~aRa Avn Snit flal H r~,........._._.
S~Z°►~' ~ 1.3153
I ~ I m 5vac ~~
~a ~ 5
EPA Method 0010 from EPA SW-846
v~L: (~2.3~
,~
ISOKINETIC FIELD DATA SHEET
client ci,arrwurs Stack Conditions
w.o.#~ sal a Assumed
Project ID Chemours %Moisture
ModelSource ID PPA Impinger Vol (ml)
Samp. Loc. ID Coed Sllfca gel (g)
Run No.ID 2 CO2, % by Vol (~
Test Method ID M0010 02, °/ by Vol ~atq
Date ID APR2019 Temperature (°F) c~ p
Source/Locatlon PPA Carbon Bad Inlet Meter Temp ("F) k ~
Sample Date ~ ~3~~ ~q Static Press (in H2O) . Z
Bam. Press (in Hg)~D. 1
Operator 1,~~~C_ Ambient Temp(°F) ~~
EPA Method 0010 - HFPO Dimer Acid Pam r ors
Meter Box ID
Actual Meter Box Y ` ppp~K Factor t—J 1
Meter Box Del H . Zq2 Initial Mid-Point Final
ID /Length Sample Train (ft'). vp~~ ~~.~U~~Prnbe
(1~.~ Probe Material oro Leak Check Q (in Hg)' "~'_~j, "`
~D ~_.,/Pftot /Thermocouple ID ~ 'rrj ~Pkot leak check good e ! no i no ye / no
LiJ•"I ~/ Pitot Coefficient 0.84 Pitot Inspection good ye / no ye ! no / no
NoaJe ID •'~'~Method 3 System good / no es no es~ / no
Nome Measurements .2 70 , ~~ , 7 q~i Temp Check Pre-Test Se Post- est Set
TAvg Noale Dia (in) . ~~ Meter Box Temp r~~, ~
Area of Stack (ft) 3 ~ Reference Temp '~
Sample Time Pass/Fail (+/- 2°~ s I Faii !Fail
Total Traverse Pts L~ Temp Change Response 5 yes no t no
0 ~
~~-~r r ~s ~~~~~-
~~-~~I ~a ~~~~~~-
~~-~~'ll~r7/~s~~~_~ ~~~~~~-
~~~~~~~y ~~~~~~-
~~-~~~~~~~m~~--11
~~-~~~~~~~~~~v ~
~~~I~~~~~~~~~~
nvy vcne r r~vy udud n i u~ai vuiume rivg i 5~
~ ~~~s~~~ C~s.i ~~s
Avg Sgrt Delta Avg Sgrt Del H Comments:
Got ~.3y►3
~~tI~S~ I ~2J1~L'oI l'1'(/~~~I (~`6 I
nn~vac ~o'~u44l
EPA Method 0010 from EPA SW-846
X3.33
~'
ISOHINETIC FIELD DATA SHEET
CNent chemo~xs Stack Conditions
w.o.#~ 5a~ a Assumed
Project ID Chemours %Moisture —~~
Made/Source ID PPA Impinger Vol (ml)
Samp. Loc. ID Cbed Silica gel (g)
Run No.ID 3 CO2, % by Vol v
Test Method ID M0010 02, % by Vol z,>. `-j
Date 10 APR2019 Temperature (°F)S~ J
Source/LocaUon PPA Card Bad Inlet Meter Temp ("F)~~
Sample Date ~ ~/Static Press (in HZO) —7
Baro. Press (In Hg)3 c~. Z
Operator ~S/ f(_Ambient Temp (°F)~ p
EPA Method 0010 - HFPO Dimer Acid Page r ors
Meter Box ID K FaCfOfActual Meter Box Y J, n ovj 3 ' ~,
Meter Box Del H 2.2q 2( Initial Mid-Point Final
~ ✓Probe ID /Length ~. ~ V ' Sample Traln (ft9) rJ ~y
Probe Material Leak Check @ (in Hg) N
O ~/ Pitot /Thermocouple ID `2 D Pitot leak check good e / no
'LD. ~I ,/ Pitot Coefficient 0.84 Pkot Inspection good y / no
NoaJe ID ~ ~S~ Method 3 System good yes / no
Oc~p : oc7'~
""7'~
e no / no
/ no J no
ye' / no ye / no
Nome nneasurements . ~D I .2 ~ I • 2 S~ Temp Gheck Nre- I est~Et t'ost= i est Set
--'Z Avg NoaJe Dia (in)~ ~/ Meter Box Temp ~~~
Area of Stack (ftZ)~ - 3 I Reference Temp vf', l ~4 . ~
Sample Time 9ip Pass/Fall (+/- 2°)Pa !Fail as /Fail
Total Traverse Pts Z 4 ~/ Temp Change Response ~-yew/ no ~ye~ / no
1
~~-~~~~I ~~~~~~-
~~~~~~~~~~~~—!:sli~llSl,li7m
nvy uonn r r~vy va~ia n,
.33~b ~ 1. J
Avg Sgrt Delta P Avg Sgrt Del F
~5~0`~~ 1.2~~
i um~ vuwnln F~Vy 15~ AVy I ffl MINM3X MINM2X MBJC M87C V8C MINM3X ~ . ) Z.0 ~
~2.1 1`d 1`I.f►'IS ~b•ZI 12°120 ~7,~~123 ~L (o (,Z `'
nments: EPA Method 0010 from EPA SW-846
~~
SAMPLE RECOVERY FIELD DATA
EPA Method 0010 - HFPO Dimer Acid
Client
Location/Plant
Chemours
Fayetteville, NC
W.O. #
Source &Location PPA Carbon Bed Inlet
15418
Run No. 1 Sample Date Recovery Date y/ /~
Sample I.D. Chemours - PPA - Cbed - 1 - 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 ~q9`j~ (S Z! ~32 4-l~S3~-~
Initial U loo ioo ~2~"30o S~~'
Gain S -~(5 / ~Z~ C,3 9 C,
Impinger Color ('(per Labeled?
Silica Gel Condition Sealed? -~
Run No. 2 Sample Date ~j,3~//~/ Recovery Date ~~,~~?f/
Sample I.D. Chemours - PPA - Cbed - 2 - M0010 - Analyst ~ Filter Number p- /"~
Im in er
1 2 3 4 5 6 7 Imp.Total 8 Total
Contents Emp HPLC H2O HPLC H2O Silica Gel
Fina~I o ! o v u(3 ~ 1 `~3I8'~ 5~s3Z s
Initial ~100 100 v 2~'~300
Gain ~ d ~l 3 14 ~~. 5~3~ ~
Impinger Color ~~a~ Labeled?
Silica Gel Condition .5,/~fa Sealed?
Run No. 3 Sample Date ,y - ! ~ (1 Recovery Date $~" (-1 `j'
Sampie I.D. Chemours - PPA - Cbed - 3 - Moo10 - Analyst ~_ Filter N umber ~ ('~
Im in er
1 2 3 4 5 6 7 Imp.Total 8 Total
Contents Empty HPLC H2O HPLC H2O Silica Gel .,.:
~~7~~Final f2 q~l 9d'3 2 t 1 ~~(~~6
Initial (~100 100 ~ZOO 300 ~~~
Gain IZ — Z 'Z 3 i ~)K..2-r. (~
Impinger Color C~~ Labeled? ~
Silica Gel Condition 't" Sealed? ./
Check COC for Sample IDs of Media Blanks
METHODS AND ANALYZERS
Client:
Location:
Source:
Chemours
Fayetteville
PPA
15418.002.012
SR
30 Apr 2019
Project Number:
Operator:
Date:
File: C:\DATA\Chemours\April 2019\043019 Run 1 PPA.cem
Program Version: 2.1, built 19 May 2017 File Version: 2.02
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
CALIBRATION DATA
Number 1
Client:
Location:
Source:
Chemours
Fayetteville
PPA
15418.002.012
SR
30 Apr 2019
Project Number:
Operator:
Date:
Start Time: 07:24
O2 Method: EPA 3A
Calibration Type: Linear Zero and High Span
Calibration Standards
%Cylinder ID
12.1 CC157024
21.0 SG9169108
Calibration Results
Zero 7 mv
Span, 21.0 %8006 mv
Curve Coefficients
Slope Intercept
380.9 7
CO2
Method: EPA 3A
Calibration Type: Linear Zero and High Span
Calibration Standards
%Cylinder ID
9.0 CC157024
16.6 SG9169108
Calibration Results
Zero 3 mv
Span, 16.6 %8279 mv
Curve Coefficients
Slope Intercept
499.2 3
CALIBRATION ERROR DATA
Number 1
Client:
Location:
Source: Calibration 1
Chemours
Fayetteville
PPA
15418.002.012
SR
30 Apr 2019
Project Number:
Operator:
Date:
Start Time: 07:24
O2 Method: EPA 3A
Span Conc. 21.0 %
Slope 380.9 Intercept 7.0
Standard
%
Result
%
Difference
%
Error
%Status
Zero 0.0 0.0 0.0 Pass
12.1 12.1 0.0 0.0 Pass
21.0 21.0 0.0 0.0 Pass
CO2
Method: EPA 3A
Span Conc. 16.6 %
Slope 499.2 Intercept 3.0
Standard
%
Result
%
Difference
%
Error
%Status
Zero 0.0 0.0 0.0 Pass
9.0 8.7 -0.3 -1.8 Pass
16.6 16.6 0.0 0.0 Pass
BIAS
Number 1
Client:
Location:
Source: Calibration 1
Chemours
Fayetteville
PPA
15418.002.012
SR
30 Apr 2019
Project Number:
Operator:
Date:
Start Time: 07:29
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 12.1 0.1 0.5 Pass
CO2Method: EPA 3A
Span Conc. 16.6 %
Bias Results
Standard Cal.Bias Difference Error
Gas %%%%Status
Zero 0.0 0.0 0.0 0.0 Pass
Span 8.7 8.6 -0.1 -0.6 Pass
RUN DATA
Number 1
Client:
Location:
Source: Calibration 1
Chemours
Fayetteville
PPA
15418.002.012
SR
30 Apr 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
09:13 20.8 0.0
09:14 20.8 0.0
09:15 20.8 0.0
09:16 20.8 0.0
09:17 20.8 0.0
09:18 20.8 0.0
09:19 20.8 0.0
09:20 20.8 0.0
09:21 20.8 0.0
09:22 20.8 0.0
09:23 20.8 0.0
09:24 20.8 0.0
09:25 20.8 0.0
09:26 20.8 0.0
09:27 20.8 0.0
09:28 20.8 0.0
09:29 20.8 0.0
09:30 20.8 0.0
09:31 20.8 0.0
09:32 20.8 0.0
09:33 20.8 0.0
09:34 20.8 0.0
09:35 20.8 0.0
09:36 20.8 0.0
09:37 20.8 0.0
09:38 20.8 0.0
09:39 20.8 0.0
09:40 20.8 0.0
09:41 20.8 0.0
09:42 20.8 0.0
09:43 20.8 0.0
09:44 20.8 0.0
09:45 20.8 0.0
09:46 20.8 0.0
09:47 20.8 0.0
09:48 20.8 0.0
09:49 20.8 0.0
09:50 20.8 0.0
09:51 20.8 0.0
09:52 20.8 0.0
RUN DATA
Number 1
Client:
Location:
Source: Calibration 1
Chemours
Fayetteville
PPA
15418.002.012
SR
30 Apr 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
09:53 20.8 0.0
09:54 20.8 0.0
09:55 20.8 0.0
09:56 20.8 0.0
09:57 20.8 0.0
09:58 20.8 0.0
09:59 20.8 0.0
10:00 20.8 0.0
10:01 20.8 0.0
10:02 20.8 0.0
10:03 20.8 0.0
10:04 20.8 0.0
10:05 20.8 0.0
10:06 20.8 0.0
10:07 20.8 0.0
10:08 20.8 0.0
10:09 20.8 0.0
10:10 20.8 0.0
10:11 20.8 0.0
10:12 20.8 0.0
10:13 20.8 0.0
10:14 20.8 0.0
10:15 20.8 0.0
10:16 20.8 0.0
10:17 20.8 0.0
10:18 20.8 0.0
10:19 20.8 0.0
10:20 20.8 0.0
10:21 20.8 0.0
10:22 20.8 0.0
10:23 20.8 0.0
10:24 20.8 0.0
10:25 20.8 0.0
10:26 20.8 0.0
10:27 20.8 0.0
10:28 20.8 0.0
10:29 20.8 0.0
10:30 20.8 0.0
10:31 20.8 0.0
10:32 20.8 0.0
RUN DATA
Number 1
Client:
Location:
Source: Calibration 1
Chemours
Fayetteville
PPA
15418.002.012
SR
30 Apr 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
10:33 20.8 0.0
10:34 20.8 0.0
10:35 20.8 0.0
10:36 20.8 0.0
10:37 20.8 0.0
10:38 20.8 0.0
10:39 20.8 0.0
10:40 20.8 0.0
10:41 20.8 0.0
10:42 20.8 0.0
10:43 20.8 0.0
10:44 20.8 0.0
10:45 20.8 0.0
10:46 20.8 0.0
10:47 20.8 0.0
10:48 20.8 0.0
10:49 20.8 0.0
10:50 20.8 0.0
10:51 20.8 0.0
10:52 20.8 0.0
10:53 20.8 0.0
10:54 20.8 0.0
10:55 20.8 0.0
10:56 20.8 0.0
10:57 20.8 0.0
10:58 20.8 0.0
10:59 20.8 0.0
11:00 20.8 0.0
11:01 20.8 0.0
11:02 20.8 0.0
11:03 20.8 0.0
11:04 20.8 0.0
11:05 20.8 0.0
11:06 20.8 0.0
11:07 20.8 0.0
11:08 20.8 0.0
11:09 20.8 0.0
11:10 20.8 0.0
11:11 20.8 0.0
11:12 20.8 0.0
RUN DATA
Number 1
Client:
Location:
Source: Calibration 1
Chemours
Fayetteville
PPA
15418.002.012
SR
30 Apr 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
11:13 20.8 0.0
11:14 20.8 0.0
11:15 20.8 0.0
11:16 20.8 0.0
11:17 20.8 0.0
11:18 20.8 0.0
11:19 20.8 0.0
11:20 20.8 0.0
11:21 20.8 0.0
11:22 20.8 0.0
11:23 20.8 0.0
11:24 20.8 0.0
11:25 20.8 0.0
11:26 20.8 0.0
11:27 20.8 0.0
11:28 20.8 0.0
11:29 20.8 0.0
11:30 20.8 0.0
11:31 20.8 0.0
11:32 20.8 0.0
11:33 20.8 0.0
11:34 20.8 0.0
11:35 20.8 0.0
11:36 20.8 0.0
11:37 20.8 0.0
11:38 20.8 0.0
11:39 20.8 0.0
11:40 20.8 0.0
11:41 20.8 0.0
11:42 20.8 0.0
11:43 20.8 0.0
11:44 20.8 0.0
11:45 20.8 0.0
11:46 20.8 0.0
11:47 20.8 0.0
11:48 20.8 0.0
11:49 20.8 0.0
11:50 20.8 0.0
11:51 20.8 0.0
11:52 20.8 0.0
RUN DATA
Number 1
Client:
Location:
Source: Calibration 1
Chemours
Fayetteville
PPA
15418.002.012
SR
30 Apr 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
11:53 20.8 0.0
11:54 20.8 0.0
11:55 20.8 0.0
11:56 20.8 0.0
11:57 20.8 0.0
11:58 20.8 0.0
11:59 20.8 0.0
12:00 20.8 0.0
12:01 20.8 0.0
12:02 20.8 0.0
12:03 20.8 0.0
12:04 20.8 0.0
12:05 20.8 0.0
12:06 20.8 0.0
12:07 20.8 0.0
Avgs 20.8 0.0
RUN SUMMARY
Number 1
Client:
Location:
Source: Calibration 1
Chemours
Fayetteville
PPA
15418.002.012
SR
30 Apr 2019
Project Number:
Operator:
Date:
O2 CO2
Method EPA 3A EPA 3A
Conc. Units %%
Time: 09:12 to 12:07
Run Averages
20.8 0.0
Pre-run Bias at 07:29
Zero Bias
Span Bias
Span Gas
0.0 0.0
12.1 8.6
12.1 9.0
Post-run Bias at 12:09
Zero Bias
Span Bias
Span Gas
0.1 0.0
12.0 8.6
12.1 9.0
Run averages corrected for the average of the pre-run and post-run bias
20.9 0.0
BIAS AND CALIBRATION DRIFT
Number 2
Client:
Location:
Source: Calibration 1
Chemours
Fayetteville
PPA
15418.002.012
SR
30 Apr 2019
Project Number:
Operator:
Date:
Start Time: 12:09
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 12.0 12.0 0.0 0.0 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. 1
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 8.7 8.6 -0.1 -0.6 Pass
Calibration Drift
Standard Initial*Final Difference Drift
Gas %%%%Status
Zero 0.0 0.0 0.0 0.0 Pass
Span 8.6 8.6 0.0 0.0 Pass
*Bias No. 1
RUN DATA
Number 2
Client:
Location:
Source: Calibration 1
Chemours
Fayetteville
PPA
15418.002.012
SR
30 Apr 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
13:28 20.8 0.0
13:29 20.8 0.0
13:30 20.8 0.0
13:31 20.8 0.0
13:32 20.8 0.0
13:33 20.8 0.0
13:34 20.8 0.0
13:35 20.8 0.0
13:36 20.8 0.0
13:37 20.8 0.0
13:38 20.8 0.0
13:39 20.8 0.0
13:40 20.8 0.0
13:41 20.8 0.0
13:42 20.8 0.0
13:43 20.8 0.0
13:44 20.8 0.0
13:45 20.8 0.0
13:46 20.8 0.0
13:47 20.8 0.0
13:48 20.8 0.0
13:49 20.8 0.0
13:50 20.8 0.0
13:51 20.8 0.0
13:52 20.8 0.0
13:53 20.8 0.0
13:54 20.8 0.0
13:55 20.8 0.0
13:56 20.8 0.0
13:57 20.8 0.0
13:58 20.8 0.0
13:59 20.8 0.0
14:00 20.8 0.0
14:01 20.8 0.0
14:02 20.8 0.0
14:03 20.8 0.0
14:04 20.8 0.0
14:05 20.8 0.0
14:06 20.8 0.0
14:07 20.8 0.0
RUN DATA
Number 2
Client:
Location:
Source: Calibration 1
Chemours
Fayetteville
PPA
15418.002.012
SR
30 Apr 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
14:08 20.7 0.0
14:09 20.7 0.0
14:10 20.7 0.0
14:11 20.7 0.0
14:12 20.7 0.0
14:13 20.7 0.0
14:14 20.7 0.0
14:15 20.7 0.0
14:16 20.7 0.0
14:17 20.7 0.0
14:18 20.8 0.0
14:19 20.8 0.0
14:20 20.8 0.0
14:21 20.8 0.0
14:22 20.7 0.0
14:23 20.7 0.0
14:24 20.7 0.0
14:25 20.7 0.0
14:26 20.7 0.0
14:27 20.7 0.0
14:28 20.7 0.0
14:29 20.7 0.0
14:30 20.7 0.0
14:31 20.7 0.0
14:32 20.7 0.0
14:33 20.7 0.0
14:34 20.7 0.0
14:35 20.7 0.0
14:36 20.7 0.0
14:37 20.7 0.0
14:38 20.7 0.0
14:39 20.7 0.0
14:40 20.7 0.0
14:41 20.7 0.0
14:42 20.7 0.0
14:43 20.7 0.0
14:44 20.7 0.0
14:45 20.7 0.0
14:46 20.7 0.0
14:47 20.7 0.0
RUN DATA
Number 2
Client:
Location:
Source: Calibration 1
Chemours
Fayetteville
PPA
15418.002.012
SR
30 Apr 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
14:48 20.7 0.0
14:49 20.7 0.0
14:50 20.7 0.0
14:51 20.7 0.0
14:52 20.7 0.0
14:53 20.7 0.0
14:54 20.7 0.0
14:55 20.8 0.0
14:56 20.8 0.0
14:57 20.8 0.0
14:58 20.8 0.0
14:59 20.8 0.0
15:00 20.8 0.0
15:01 20.8 0.0
15:02 20.8 0.0
15:03 20.8 0.0
15:04 20.8 0.0
15:05 20.8 0.0
15:06 20.8 0.0
15:07 20.8 0.0
15:08 20.8 0.0
15:09 20.8 0.0
15:10 20.8 0.0
15:11 20.8 0.0
15:12 20.8 0.0
15:13 20.8 0.0
15:14 20.8 0.0
15:15 20.8 0.0
15:16 20.8 0.0
15:17 20.8 0.0
15:18 20.8 0.0
15:19 20.8 0.0
15:20 20.8 0.0
15:21 20.8 0.0
15:22 20.7 0.0
15:23 20.7 0.0
Avgs 20.8 0.0
RUN SUMMARY
Number 2
Client:
Location:
Source: Calibration 1
Chemours
Fayetteville
PPA
15418.002.012
SR
30 Apr 2019
Project Number:
Operator:
Date:
O2 CO2
Method EPA 3A EPA 3A
Conc. Units %%
Time: 13:27 to 15:23
Run Averages
20.8 0.0
Pre-run Bias at 12:09
Zero Bias
Span Bias
Span Gas
0.1 0.0
12.0 8.6
12.1 9.0
Post-run Bias at 15:37
Zero Bias
Span Bias
Span Gas
0.0 0.0
12.0 8.5
12.1 9.0
Run averages corrected for the average of the pre-run and post-run bias
20.9 0.0
BIAS AND CALIBRATION DRIFT
Number 3
Client:
Location:
Source: Calibration 1
Chemours
Fayetteville
PPA
15418.002.012
SR
30 Apr 2019
Project Number:
Operator:
Date:
Start Time: 15:37
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 0.1 0.0 -0.1 -0.5 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 0.0 0.0 0.0 Pass
Span 8.7 8.5 -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 8.6 8.5 -0.1 -0.6 Pass
*Bias No. 2
METHODS AND ANALYZERS
Client:
Location:
Source:
Chemours
Fayetteville
PPA
15418.002.012
SR
1 May 2019
Project Number:
Operator:
Date:
File: C:\DATA\Chemours\April 2019\050119 Run 3 PPA.cem
Program Version: 2.1, built 19 May 2017 File Version: 2.02
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
CALIBRATION DATA
Number 1
Client:
Location:
Source:
Chemours
Fayetteville
PPA
15418.002.012
SR
1 May 2019
Project Number:
Operator:
Date:
Start Time: 07:10
O2 Method: EPA 3A
Calibration Type: Linear Zero and High Span
Calibration Standards
%Cylinder ID
12.1 CC157024
21.0 SG9169108
Calibration Results
Zero 7 mv
Span, 21.0 %8004 mv
Curve Coefficients
Slope Intercept
380.8 7
CO2
Method: EPA 3A
Calibration Type: Linear Zero and High Span
Calibration Standards
%Cylinder ID
9.0 CC157024
16.6 SG9169108
Calibration Results
Zero 0 mv
Span, 16.6 %8270 mv
Curve Coefficients
Slope Intercept
498.8 0
CALIBRATION ERROR DATA
Number 1
Client:
Location:
Source: Calibration 1
Chemours
Fayetteville
PPA
15418.002.012
SR
1 May 2019
Project Number:
Operator:
Date:
Start Time: 07:10
O2 Method: EPA 3A
Span Conc. 21.0 %
Slope 380.8 Intercept 7.0
Standard
%
Result
%
Difference
%
Error
%Status
Zero 0.0 0.0 0.0 Pass
12.1 12.1 0.0 0.0 Pass
21.0 21.0 0.0 0.0 Pass
CO2
Method: EPA 3A
Span Conc. 16.6 %
Slope 498.8 Intercept 0.0
Standard
%
Result
%
Difference
%
Error
%Status
Zero 0.0 0.0 0.0 Pass
9.0 8.9 -0.1 -0.6 Pass
16.6 16.6 0.0 0.0 Pass
BIAS
Number 1
Client:
Location:
Source: Calibration 1
Chemours
Fayetteville
PPA
15418.002.012
SR
1 May 2019
Project Number:
Operator:
Date:
Start Time: 07:16
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
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
RUN DATA
Number 3
Client:
Location:
Source: Calibration 1
Chemours
Fayetteville
PPA
15418.002.012
SR
1 May 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
08:19 20.8 0.0
08:20 20.8 0.0
08:21 20.8 0.0
08:22 20.8 0.0
08:23 20.8 0.0
08:24 20.8 0.0
08:25 20.8 0.0
08:26 20.8 0.0
08:27 20.8 0.0
08:28 20.8 0.0
08:29 20.8 0.0
08:30 20.8 0.0
08:31 20.8 0.0
08:32 20.8 0.0
08:33 20.8 0.0
08:34 20.8 0.0
08:35 20.8 0.0
08:36 20.8 0.0
08:37 20.8 0.0
08:38 20.8 0.0
08:39 20.8 0.0
08:40 20.8 0.0
08:41 20.8 0.0
08:42 20.8 0.0
08:43 20.8 0.0
08:44 20.8 0.0
08:45 20.8 0.0
08:46 20.8 0.0
08:47 20.8 0.0
08:48 20.8 0.0
08:49 20.8 0.0
08:50 20.8 0.0
08:51 20.8 0.0
08:52 20.8 0.0
08:53 20.8 0.0
08:54 20.8 0.0
08:55 20.8 0.0
08:56 20.8 0.0
08:57 20.8 0.0
08:58 20.8 0.0
RUN DATA
Number 3
Client:
Location:
Source: Calibration 1
Chemours
Fayetteville
PPA
15418.002.012
SR
1 May 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
08:59 20.8 0.0
09:00 20.8 0.0
09:01 20.8 0.0
09:02 20.8 0.0
09:03 20.8 0.0
09:04 20.8 0.0
09:05 20.8 0.0
09:06 20.8 0.0
09:07 20.8 0.0
09:08 20.8 0.0
09:09 20.8 0.0
09:10 20.8 0.0
09:11 20.8 0.0
09:12 20.8 0.0
09:13 20.8 0.0
09:14 20.8 0.0
09:15 20.8 0.0
09:16 20.8 0.0
09:17 20.8 0.0
09:18 20.8 0.0
09:19 20.8 0.0
09:20 20.8 0.0
09:21 20.8 0.0
09:22 20.8 0.0
09:23 20.8 0.0
09:24 20.8 0.0
09:25 20.8 0.0
09:26 20.8 0.0
09:27 20.8 0.0
09:28 20.8 0.0
09:29 20.8 0.0
09:30 20.8 0.0
09:31 20.8 0.0
09:32 20.8 0.0
09:33 20.8 0.0
09:34 20.8 0.0
09:35 20.8 0.0
09:36 20.8 0.0
09:37 20.8 0.0
09:38 20.8 0.0
RUN DATA
Number 3
Client:
Location:
Source: Calibration 1
Chemours
Fayetteville
PPA
15418.002.012
SR
1 May 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
09:39 20.8 0.0
09:40 20.8 0.0
09:41 20.8 0.0
09:42 20.8 0.0
09:43 20.8 0.0
09:44 20.8 0.0
09:45 20.8 0.0
09:46 20.8 0.0
09:47 20.8 0.0
09:48 20.8 0.0
09:49 20.8 0.0
09:50 20.8 0.0
09:51 20.9 0.0
09:52 20.9 0.0
09:53 20.9 0.0
09:54 20.9 0.0
09:55 20.9 0.0
09:56 20.9 0.0
09:57 20.9 0.0
09:58 20.9 0.0
09:59 20.9 0.0
10:00 20.9 0.0
10:01 20.9 0.0
10:02 20.9 0.0
10:03 20.9 0.0
10:04 20.9 0.0
10:05 20.9 0.0
10:06 20.9 0.0
10:07 20.9 0.0
10:08 20.9 0.0
10:09 20.9 0.0
10:10 20.9 0.0
10:11 20.9 0.0
10:12 20.9 0.0
10:13 20.9 0.0
10:14 20.9 0.0
10:15 20.9 0.0
10:16 21.0 0.0
10:17 21.0 0.0
10:18 21.0 0.0
RUN DATA
Number 3
Client:
Location:
Source: Calibration 1
Chemours
Fayetteville
PPA
15418.002.012
SR
1 May 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
10:19 20.9 0.0
10:20 20.9 0.0
10:21 20.9 0.0
10:22 20.9 0.0
10:23 20.9 0.0
10:24 20.8 0.0
Avgs 20.8 0.0
RUN SUMMARY
Number 3
Client:
Location:
Source: Calibration 1
Chemours
Fayetteville
PPA
15418.002.012
SR
1 May 2019
Project Number:
Operator:
Date:
O2 CO2
Method EPA 3A EPA 3A
Conc. Units %%
Time: 08:18 to 10:24
Run Averages
20.8 0.0
Pre-run Bias at 07:16
Zero Bias
Span Bias
Span Gas
0.0 0.0
12.1 8.8
12.1 9.0
Post-run Bias at 10:59
Zero Bias
Span Bias
Span Gas
0.0 0.0
12.0 8.8
12.1 9.0
Run averages corrected for the average of the pre-run and post-run bias
20.8 0.0
BIAS AND CALIBRATION DRIFT
Number 2
Client:
Location:
Source: Calibration 1
Chemours
Fayetteville
PPA
15418.002.012
SR
1 May 2019
Project Number:
Operator:
Date:
Start Time: 10:59
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 12.1 12.0 -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 0.0 0.0 0.0 Pass
Span 8.9 8.8 -0.1 -0.6 Pass
Calibration Drift
Standard Initial*Final Difference Drift
Gas %%%%Status
Zero 0.0 0.0 0.0 0.0 Pass
Span 8.8 8.8 0.0 0.0 Pass
*Bias No. 1
RUN DATA
Number 0
Client:
Location:
Source: Calibration 1
Chemours
Fayetteville
PPA
15418.002.012
SR
1 May 2019
Project Number:
Operator:
Date:
O2 CO2
%%Time
Run 1 Bag Scrubber inlet
11:13:47 18.5 0.2
11:14:02 18.5 0.3
11:14:17 18.5 0.3
11:14:32 18.5 0.3
11:14:47 18.5 0.3
11:15:02 18.5 0.3
11:15:17 18.5 0.3
11:15:32 18.5 0.3
Run 3 Bag Scrubber inlet
11:18:32 19.5 0.1
11:18:47 18.7 0.1
11:19:02 18.6 0.1
11:19:17 18.6 0.2
11:19:32 18.6 0.4
11:19:47 18.6 0.5
11:20:02 18.6 0.5
11:20:17 18.7 0.5
11:20:32 18.7 0.5
11:20:47 18.7 0.5
11:21:02 18.7 0.5
11:21:17 18.7 0.5
11:21:32 18.7 0.5
11:21:47 18.7 0.5
Avgs 18.6 0.4
RUN SUMMARY
Number 0
Client:
Location:
Source: Calibration 1
Chemours
Fayetteville
PPA
15418.002.012
SR
1 May 2019
Project Number:
Operator:
Date:
O2 CO2
Method EPA 3A EPA 3A
Conc. Units %%
Time: 11:13:32 to 11:21:47
Run Averages
18.6 0.4
Pre-run Bias at 10:59
Zero Bias
Span Bias
Span Gas
0.0 0.0
12.0 8.8
12.1 9.0
No Post-run Bias
Run averages corrected for the pre-run bias
18.7 0.4

IASDATA\CHEMOURS\15418.002.012\PPA REPORT MAY 2019-AMD 6/4/2019
APPENDIX C
LABORATORY ANALYTICAL REPORT

Note: The complete analytical report is included on the attached CD.
ANALYTICAL REPORT
Job Number: 140-15200-1
Job Description: PPA Carbon Bed Outlet
Contract Number: LBIO-67048
For:
Chemours Company FC, LLC The
c/o AECOM
Sabre Building, Suite 300
4051 Ogletown Road
Newark, DE 19713
Attention: Michael Aucoin
_____________________________________________
Approved for release.
Courtney M Adkins
Project Manager I
5/16/2019 10:54 AM
Courtney M Adkins, Project Manager I
5815 Middlebrook Pike, Knoxville, TN, 37921
[phone]
[e-mail]
05/16/2019
This report may not be reproduced except in full, and with written approval from the laboratory. For questions please
contact the Project Manager at the e-mail address or telephone number listed on this page.
Eurofins TestAmerica, Knoxville
5815 Middlebrook Pike, Knoxville, TN 37921
Tel [phone] Fax [phone] www.testamericainc.com
05/16/2019Page 1 of 240
Table of Contents
Cover Title Page . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1
Data Summaries . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4
Definitions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4
Method Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5
Sample Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6
Case Narrative . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7
QC Association . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .8
Client Sample Results . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .10
Default Detection Limits . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .13
Surrogate Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .14
QC Sample Results . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .15
Chronicle . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .17
Certification Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .21
Manual Integration Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .23
Reagent Traceability . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .26
COAs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .30
Organic Sample Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 53
LCMS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .53
8321A_HFPO_Du . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .53
8321A_HFPO_Du QC Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .54
8321A_HFPO_Du Sample Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .57
Standards Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .72
8321A_HFPO_Du ICAL Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .72
8321A_HFPO_Du CCAL Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .95
Raw QC Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .101
8321A_HFPO_Du Blank Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .101
05/16/2019Page 2 of 240
Table of Contents
8321A_HFPO_Du LCS/LCSD Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .105
8321A_HFPO_Du Run Logs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .109
8321A_HFPO_Du Prep Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .111
Method DV-LC-0012 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .115
Method DV-LC-0012 QC Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .116
Method DV-LC-0012 Sample Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .123
Standards Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .160
Method DV-LC-0012 CCAL Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .160
Raw QC Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .178
Method DV-LC-0012 Tune Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .178
Method DV-LC-0012 Blank Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .183
Method DV-LC-0012 LCS/LCSD Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .201
Method DV-LC-0012 Run Logs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .213
Method DV-LC-0012 Prep Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .216
Shipping and Receiving Documents . . . . . . . . . . . . . . . . . . . . . . . . . . . 233
Client Chain of Custody . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .234
05/16/2019Page 3 of 240









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05/16/2019Page 13 of 240
ANALYTICAL REPORT
Job Number: 140-15199-1
Job Description: PPA Carbon Bed Inlet
Contract Number: LBIO-67048
For:
Chemours Company FC, LLC The
c/o AECOM
Sabre Building, Suite 300
4051 Ogletown Road
Newark, DE 19713
Attention: Michael Aucoin
_____________________________________________
Approved for release.
Courtney M Adkins
Project Manager I
5/16/2019 10:53 AM
Courtney M Adkins, Project Manager I
5815 Middlebrook Pike, Knoxville, TN, 37921
[phone]
[e-mail]
05/16/2019
This report may not be reproduced except in full, and with written approval from the laboratory. For questions please
contact the Project Manager at the e-mail address or telephone number listed on this page.
Eurofins TestAmerica, Knoxville
5815 Middlebrook Pike, Knoxville, TN 37921
Tel [phone] Fax [phone] www.testamericainc.com
05/16/2019Page 1 of 205
Table of Contents
Cover Title Page . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1
Data Summaries . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4
Definitions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4
Method Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5
Sample Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6
Case Narrative . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7
QC Association . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .8
Client Sample Results . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .10
Default Detection Limits . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .13
Surrogate Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .14
QC Sample Results . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .15
Chronicle . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .17
Certification Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .21
Manual Integration Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .23
Organic Sample Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 26
LCMS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .26
8321A_HFPO_Du . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .26
8321A_HFPO_Du QC Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .27
8321A_HFPO_Du Sample Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .30
Standards Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .45
8321A_HFPO_Du ICAL Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .45
8321A_HFPO_Du CCAL Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .68
Raw QC Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .74
8321A_HFPO_Du Blank Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .74
8321A_HFPO_Du LCS/LCSD Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .78
8321A_HFPO_Du Run Logs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .82
05/16/2019Page 2 of 205
Table of Contents
8321A_HFPO_Du Prep Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .84
Method DV-LC-0012 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .88
Method DV-LC-0012 QC Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .89
Method DV-LC-0012 Sample Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .95
Standards Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .132
Method DV-LC-0012 CCAL Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .132
Raw QC Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .147
Method DV-LC-0012 Tune Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .147
Method DV-LC-0012 Blank Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .152
Method DV-LC-0012 LCS/LCSD Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .166
Method DV-LC-0012 Run Logs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .178
Method DV-LC-0012 Prep Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .181
Shipping and Receiving Documents . . . . . . . . . . . . . . . . . . . . . . . . . . . 198
Client Chain of Custody . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .199
05/16/2019Page 3 of 205









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05/16/2019Page 13 of 205

IASDATA\CHEMOURS\15418.002.012\PPA REPORT MAY 2019-AMD 6/4/2019
APPENDIX D
SAMPLE CALCULATIONS

SAMPLE CALCULATIONS FOR
HFPO DIMER ACID (METHOD 0010)
Client: Chemours Plant: Fayetteville, NC
Test Number: Run 3 Test Date: 05/01/19
Test Location: PPA Stack Test Period: 0830-1017
1. HFPO Dimer Acid concentration, lbs/dscf.
W x 2.2046 x 10-9
Conc1 = ------------------------------
Vm(std)
1.9 x 2.2046 x 10-9
Conc1 = ------------------------------
47.071
Conc1 = 9.04E-11
Where:
W = Weight of HFPO Dimer Acid collected in sample in ug.
Conc1 = PPA Stack 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 = 1.9 / ( 47.071 x 0.02832 )
Conc2 = 1.45E+00
Where:
Conc2 = PPA Stack HFPO Dimer Acid concentration, ug/dscm.
0.02832 = Conversion factor from cubic feet to cubic meters.
6/4/20191:35 PM 043019 PPA stack
3. HFPO Dimer Acid mass emission rate, lbs/hr.
MR1(Outlet)= Conc1 x Qs(std) x 60 min/hr
MR1(Outlet)= 9.04E-11 x 11822 x 60
MR1(Outlet)= 6.41E-05
Where:
MR1(Outlet)= PPA Stack HFPO Dimer Acid mass emission rate, lbs/hr.
4. HFPO Dimer Acid mass emission rate, g/sec.
MR2(Outlet)= PMR1 x 453.59 / 3600
MR2(Outlet)= 6.41E-05 x 453.59 /3600
MR2(Outlet)= 8.07E-06
Where:
MR2(Outlet)= PPA Stack HFPO Dimer Acid mass emission rate, g/sec.
453.6 = 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 = (3.74E-03) -(6.41E-05)
---------------------------------------------
3.74E-03
RE = 98.28
Where:
RE = Carbon Bed Removal Efficiency.
MR1(Inlet)= Carbon Bed HFPO Dimer Acid mass rate, lbs/hr.
MR1(Outlet)= Scrubber Outlet HFPO Dimer Acid mass rate, lbs/hr.
6/4/20191:35 PM 043019 PPA stack
EXAMPLE CALCULATIONS FOR
VOLUMETRIC FLOW AND MOISTURE AND ISOKINETICS
Client: Chemours Facility: Fayetteville, NC
Test Number: Run 3 Test Date: 5/01/19
Test Location: PPA Stack Test Period: 0830-1017
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)
0.811
17.64 x 0.9944 x 47.697 x ( 30.30 + --------------------- )
13.6
Vm(std) = ------------------------------------------------------------ = 47.071
79.63 + 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 8.0 ) + ( 0.04715 x 11.4 ) = 0.91
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.
5/22/201911:28 AM 043019 PPA stack
3. Moisture content
Vw(std)
bws = -------------------------
Vw(std) + Vm(std)
0.91
bws = ------------------------- = 0.019
0.91 + 47.071
Where:
bws = Proportion of water vapor, by volume, in the gas
stream, dimensionless.
4. Mole fraction of dry gas.
Md = 1 - bws
Md = 1 - 0.019 = 0.981
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 0.981 ) +( 18 ( 1 - 0.981 )) = 28.63
Where:
MWs = Molecular weight of wet gas, lb/lb-mole.
18 = Molecular weight of water, lb/lb-mole.
5/22/201911:28 AM 043019 PPA stack
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
543
Vs = 85.49 x 0.84 x 0.73105 x ( -------------------- )^1/2 = 41.4
30.45 x 28.63
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 41.4 x 4.90 = 12179
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
30.45
Qs(std) = 17.64 x 0.981 x -------------------- x 12179
542.9
Qs(std) = 11822
Where:
Qs(std) = Volumetric flow rate of dry stack gas at standard
conditions, dscf/min.
5/22/201911:28 AM 043019 PPA stack
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 543 x 47.071
I = -------------------------------------------------- = 102.2
41.4 x 96 x 30.45 x 0.981 x (0.191)^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)
5/22/201911:28 AM 043019 PPA stack
SAMPLE CALCULATIONS FOR
HFPO DIMER ACID (METHOD 0010)
Client: Chemours Plant: Fayetteville, NC
Test Number: Run 3 Test Date: 05/01/19
Test Location: PPA CB Inlet Test Period: 0830-1017
1. HFPO Dimer Acid concentration, lbs/dscf.
W x 2.2046 x 10-9
Conc1 = ------------------------------
Vm(std)
147.6 x 2.2046 x 10-9
Conc1 = ------------------------------
62.008
Conc1 = 5.25E-09
Where:
W = Weight of HFPO Dimer Acid collected in sample in ug.
Conc1 = PPA Carbon Bed Inlet 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 = 147.6 / ( 62.008 x 0.02832 )
Conc2 = 8.40E+01
Where:
Conc2 = PPA Carbon Bed Inlet HFPO Dimer Acid concentration, ug/dscm.
0.02832 = Conversion factor from cubic feet to cubic meters.
6/4/20191:39 PM 043019 PPA CBed
3. HFPO Dimer Acid mass emission rate, lbs/hr.
MR1(Outlet)= Conc1 x Qs(std) x 60 min/hr
MR1(Outlet)= 5.25E-09 x 11873 x 60
MR1(Outlet)= 3.74E-03
Where:
MR1(Outlet)= PPA Carbon Bed Inlet HFPO Dimer Acid mass emission rate, lbs/hr.
4. HFPO Dimer Acid mass emission rate, g/sec.
MR2(Outlet)= PMR1 x 453.59 / 3600
MR2(Outlet)= 3.74E-03 x 453.59 /3600
MR2(Outlet)= 4.71E-04
Where:
MR2(Outlet)= PPA Carbon Bed Inlet HFPO Dimer Acid mass emission rate, g/sec.
453.6 = Conversion factor from pounds to grams.
3600 = Conversion factor from hours to seconds.
6/4/20191:39 PM 043019 PPA CBed
EXAMPLE CALCULATIONS FOR
VOLUMETRIC FLOW AND MOISTURE AND ISOKINETICS
PPA CARBON BED INLET
Client: Chemours Facility: Fayetteville, NC
Test Number: Run 3 Test Date: 5/01/19
Test Location: PPA Stack Test Period: 0830-1017
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)
1.747
17.64 x 1.0005 x 62.118 x ( 30.20 + --------------------- )
13.6
Vm(std) = ------------------------------------------------------------ = 62.008
76.21 + 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 11.0 ) + ( 0.04715 x 16.6 ) = 1.30
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.
5/22/201911:28 AM 043019 PPA CBed
3. Moisture content
Vw(std)
bws = -------------------------
Vw(std) + Vm(std)
1.30
bws = ------------------------- = 0.021
1.30 + 62.008
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.
5/22/201911:28 AM 043019 PPA CBed
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
535
Vs = 85.49 x 0.84 x 0.57037 x ( -------------------- )^1/2 = 32.3
30.05 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 32.3 x 6.31 = 12230
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
30.05
Qs(std) = 17.64 x 0.979 x -------------------- x 12230
534.9
Qs(std) = 11873
Where:
Qs(std) = Volumetric flow rate of dry stack gas at standard
conditions, dscf/min.
5/22/201911:28 AM 043019 PPA CBed
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 535 x 62.008
I = -------------------------------------------------- = 100.7
32.3 x 96 x 30.05 x 0.979 x (0.250)^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)
5/22/201911:28 AM 043019 PPA CBed

IASDATA\CHEMOURS\15418.002.012\PPA REPORT MAY 2019-AMD 6/4/2019
APPENDIX E
EQUIPMENT CALIBRATION RECORDS

Interference Check 2014.xlsO2-Servomex 4900 3/26/2019
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 (%)
Interference Check 2014.xlsCO2-Servomex 4900 3/26/2019
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 (%)
CERTIFICATE OF ANALYSIS
Grade of Product: EPA Protocol
Part Number:E03NI79E15A00E4 Reference Number:160-401424145-1
Cylinder Number:CC157024 Cylinder Volume:150.5 CF
Laboratory:124 - Plumsteadville - PA Cylinder Pressure:2015 PSIG
PGVP Number:A12019 Valve Outlet:590
Gas Code:CO2,O2,BALN Certification Date:Feb 26, 2019
Expiration Date:Feb 26, 2027
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 %9.018 %G1 +/- 0.6% NIST Traceable 02/26/2019
OXYGEN 12.00 %12.06 %G1 +/- 0.3% NIST Traceable 02/26/2019
NITROGEN Balance -
CALIBRATION STANDARDS
Type Lot ID Cylinder No Concentration Uncertainty Expiration Date
NTRM 061507 K014984 13.94 % CARBON DIOXIDE/NITROGEN 0.57%Jan 30, 2024
NTRM 16060507 CC401541 23.204 % OXYGEN/NITROGEN 0.2%Dec 24, 2021
ANALYTICAL EQUIPMENT
Instrument/Make/Model Analytical Principle Last Multipoint Calibration
HORIBA VA5011 T5V6VU9P NDIR CO2 NDIR Feb 12, 2019
SIEMENS OXYMAT 61 S01062 O2 PARAMAGNETIC Feb 18, 2019
Triad Data Available Upon Request
Airgas Specialty GasesAirgas USA, LLC
6141 Easton Road
Bldg 1
Plumsteadville, PA 18949
Airgas.com
Signature on file
Approved for Release Page 1 of 160-401424145-1
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 82-401044874-1
P-706 all in one.MOD
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
P-701 all in one.MOD
Pitot Tube Identification Number:
Inspection Date 5/30/18 Individual Conducting Inspection
Distance to A Plane (PA) - inches 0.466 PASS
Distance to B Plane (PB) - inches 0.466 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
0.89
Horizontal offset between A and
B Tubes (Z) - inches
Vertical offset between A and B
Tubes (W) - inches
0.008
0.02
PASS/FAIL
Angle of B1 from
vertical B Tube-
degrees (absolute)
PASS
PASS
PASS
P-701
SR
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
Long Cal Box 24 8_17_18
Calibrator MDW Meter Box Number 24 Ambient Temp 72
Date 17-Aug-18 Wet Test Meter Number P-2952 Temp Reference Source
Dry Gas Meter Number 17087363
Setting
in H20
(∆H)
ft3
(Vw)
ft3
(Vd)
oF
(Tw)
Outlet, oF
(Tdo)
Inlet, oF
(Tdi)
Average, oF
(Td)
Time, min
(O)Y ∆H
165.901 76.00 76.00
170.979 77.00 77.00
5.078 76.50 76.50
173.050 77.00 77.00
178.077 78.00 78.00
5.027 77.50 77.50
179.100 78.00 78.00
189.237 79.00 79.00
10.137 78.50 78.50
190.250 79.00 79.00
200.405 79.00 79.00
10.155 79.00 79.00201.439 80.00 80.00
211.615 80.00 80.00
10.176 80.00 80.00
Average 0.9944 1.9231
Vw - Gas Volume passing through the wet test meter 0 - Time of calibration run
Vd - Gas Volume passing through the dry gas meter Pb - Barometric Pressure
Tw - Temp of gas in the wet test meter
Tdi - Temp of the inlet gas of the dry gas meter
Tdo - Temp of the outlet gas of the dry gas meter
Td - Average temp of the gas in the dry gas meter

1 2 3 4 5 6
32 32 32 32 32 32.0 0.0%
212 212 212 212 212 212.0 0.0%
931 930 928 930 928 929.4 0.2%
1828 1831 1832 1828 1830 1829.8 0.1%
1 - Channel Temps must agree with +/- 5oF or 3oC
2 - Acceptable Temperature Difference less than 1.5 %
Average
Temperature
Reading
Thermocouple Simulator
(Accuracy +/- 1oF)
Temp
Difference 2
(%)
Temperature Reading from Individual Thermocouple Input 1
Channel Number
2.0320
Calibration Results
Baro Press, in
Hg ( Pb)29.68
80.0
932
1832
Reference
Temperature
Select Temperature
oC oF
212
32
1.9199
1.954413.2 0.9928
15.1 0.9948
1.0024
5.00
72.0
11.0 0.9901
78.5
79.0
Y - Ratio of accuracy of wet test
meter to dry gas meter
∆H - Pressure differential across
orifice
3.0 10.0 72.0
Temperatures
Wet Test
Meter
76.5
1.5 10.0
Long Cal and Temperature Cal Datasheet for Standard Dry Gas Meter Console
Orifice
Manometer
Wet Test
Meter Dry gas Meter
Gas Volume
1.86295.0 72.0 77.5 9.1
2.0 10.0
1.846312.8 0.9917
Dry Gas Meter
72.0
0.5 72.0
1.0
()()
()()2
Vw
O460tw
460tdPb
H0317.0H
460tw6.13
HPbVd
)460td(PbVwY


∗+∗


+∗
∆∗=∆
+∗

∆+∗
+∗∗=
()()()()()


+
+−+=460FTempferenceRe
460FTempTest460FTempferenceReDiffTempo
oo
Y Factor Calibration Check Calculation
MODIFIED METHOD 0010 TEST TRAIN
PPA STACK
METER BOX NO. 24
04/30/2019 + 05/01/2019
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.81.5 102.3 79.6
Tma = Ts + 460
Tma = 81.46 + 460
Tma = 541.46 562.29 539.63
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 0.70 0.60 0.81
Pb = Barometric Pressure, in Hg.30.20 30.20 30.30
Pm = Pb + (delta H / 13.6)
Pm = 30.2 + ( 0.700416666666667 / 13.6)
Pm = 30.25 30.24 30.36
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.43.943 41.735 47.697
Y = Dry gas meter calibration factor (based on full calibration)0.9944 0.9944 0.9944
Delta H@ = Dry Gas meter orifice calibration coefficient, in. H2O.1.9231 1.9231 1.9231
avg SQRT Delta H =Avg SQRT press. drop across the orifice meter during sampling , in. H2O 0.8229 0.7635 0.8940
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 / 43.94 ) * SQRT ( 0.0319 * 541.46 * 29 ) / ( 1.92 * 30.25 * 28.84 ) * 0.82
Yqa = 2.185 * SQRT 500.903 / 1,677.499 * 0.82
Yqa = 0.9823 0.9782 0.9798
Diff = Absolute difference between Yqa and Y 1.22 1.63 1.47
Diff = (( Y - Yqa ) / Y ) * 100
Diff = (( 0.9944 - 0.982 ) / 0.9944 ) * 100
Average Diff = 1.44
Allowable = 5.0
5/22/20191:20 PM 043019 PPA stack
Long Cal Box #23 2_11_19
Calibrator MDW Meter Box Number 23 Ambient Temp 72
Date 11-Feb-19 Wet Test Meter Number P-2952 Temp Reference Source
Dry Gas Meter Number 17087349
Setting
in H20
(∆H)
ft3
(Vw)
ft3
(Vd)
oF
(Tw)
Outlet, oF
(Tdo)
Inlet, oF
(Tdi)
Average, oF
(Td)
Time, min
(O)Y ∆H
531.257 73.00 73.00
536.085 73.00 73.00
4.828 73.00 73.00
537.085 73.00 73.00
542.070 74.00 74.00
4.985 73.50 73.50
543.080 76.00 76.00
553.215 76.00 76.00
10.135 76.00 76.00
554.221 77.00 77.00
564.420 77.00 77.00
10.199 77.00 77.00
565.462 77.00 77.00
575.635 77.00 77.00
10.173 77.00 77.00
Average 1.0005 2.2926
Vw - Gas Volume passing through the wet test meter 0 - Time of calibration run
Vd - Gas Volume passing through the dry gas meter Pb - Barometric Pressure
Tw - Temp of gas in the wet test meter
Tdi - Temp of the inlet gas of the dry gas meter
Tdo - Temp of the outlet gas of the dry gas meter
Td - Average temp of the gas in the dry gas meter

1 2 3 4 5 6
32 32 32 32 33 32.2 0.0%
212 213 213 212 213 212.6 -0.1%
931 932 931 932 933 931.8 0.0%
1831 1833 1833 1832 1833 1832.4 0.0%
1 - Channel Temps must agree with +/- 5oF or 3oC
2 - Acceptable Temperature Difference less than 1.5 %
Average
Temperature
Reading
Thermocouple Simulator
(Accuracy +/- 1oF)
Temp
Difference 2
(%)
Temperature Reading from Individual Thermocouple Input 1
Channel Number
2.3416
Calibration Results
Baro Press, in
Hg ( Pb)30.7
77.0
932
1832
Reference
Temperature
Select Temperature
oC oF
212
32
12.0 0.9871
2.3083
2.384114.8 0.9850
16.8 0.9905
3.0 10.0 72.0
2.0 10.0 72.0
72.0
2.1493
1.0 5.0 72.0 73.5 10.2 1.0034
76.0
Y - Ratio of accuracy of wet test
meter to dry gas meter
∆H - Pressure differential across
orifice
Dry Gas Meter
Temperatures
Wet Test
Meter
2.2797
73.0 14.0 1.036372.0
77.0
Long Cal and Temperature Cal Datasheet for Standard Dry Gas Meter Console
Orifice
Manometer
Wet Test
Meter Dry gas Meter
Gas Volume
5.00.5
1.5 10.0
()()
()()2
Vw
O460tw
460tdPb
H0317.0H
460tw6.13
HPbVd
)460td(PbVwY


∗+∗


+∗
∆∗=∆
+∗

∆+∗
+∗∗=
()()()()()


+
+−+=460FTempferenceRe
460FTempTest460FTempferenceReDiffTempo
oo
Y Factor Calibration Check Calculation
MODIFIED METHOD 0010 TEST TRAIN
PPA STACK
METER BOX NO. 23
04/30/2019 + 05/01/2019
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.83.4 89.8 76.2
Tma = Ts + 460
Tma = 83.42 + 460
Tma = 543.42 549.75 536.21
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 1.82 1.86 1.75
Pb = Barometric Pressure, in Hg.30.10 30.10 30.20
Pm = Pb + (delta H / 13.6)
Pm = 30.1 + ( 1.8175 / 13.6)
Pm = 30.23 30.24 30.33
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.63.472 65.238 62.118
Y = Dry gas meter calibration factor (based on full calibration)1.0005 1.0005 1.0005
Delta H@ = Dry Gas meter orifice calibration coefficient, in. H2O.2.2926 2.2926 2.2926
avg SQRT Delta H =Avg SQRT press. drop across the orifice meter during sampling , in. H2O 1.3254 1.3413 1.2969
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 / 63.47 ) * SQRT ( 0.0319 * 543.42 * 29 ) / ( 2.29 * 30.23 * 28.84 ) * 1.33
Yqa = 1.512 * SQRT 502.715 / 1,998.488 * 1.33
Yqa = 1.0054 0.9955 0.9969
Diff = Absolute difference between Yqa and Y 0.49 0.50 0.36
Diff = (( Y - Yqa ) / Y ) * 100
Diff = (( 1.0005 - 1.005 ) / 1.0005 ) * 100
Average Diff = 0.45
Allowable = 5.0
5/22/20191:05 PM 043019 PPA CBed

IASDATA\CHEMOURS\15418.002.012\PPA REPORT MAY 2019-AMD 6/4/2019
APPENDIX F
LIST OF PROJECT PARTICIPANTS

IASDATA\CHEMOURS\15418.002.012\PPA REPORT MAY 2019-AMD 6/4/2019
The following Weston employees participated in this project:
Paul Meeter Senior Project Manager
Jacob Little Team Member
Nicholas Guarino Team Member
Austin Squires Team Member
Kris Ansley Team Member
Brandon Berger Team Member