DAQ-2024-010906

1

DAQC-1017-24
Site ID 10129 (B4)

MEMORANDUM

TO: STACK TEST FILE – WASATCH INTEGRATED WASTE MANAGEMENT
DISTRICT – Davis Landfill

THROUGH: Harold Burge, Major Source Compliance Section Manager

FROM: Paul Morris, Environmental Scientist

DATE: October 7, 2024

SUBJECT: Location: 1997 East 3500 North, Layton, Davis County, UT
Contact: Nathan Rich – 801-614-5600
Tester: Kleinfelder, Inc. Amit Nair – 801-261-3336
Source: Municipal Waste Landfill
FRS ID #: UT0000004901100033
Permit# : Title V operating permit 1100033004, revised September 18, 2024
Subject: Review of Pretest Protocol dated October 3, 2024

On October 3, 2024, the DAQ received a protocol for testing of the Wasatch Integrated Waste
Management District’s Municipal Waste County Landfill in Layton, UT. The test will be performed the
week of November 5, 2024, to determine compliance with limits in accordance with Conditions II.B.3.c,
II.B.3.d, and II.B.3.e.

PROTOCOL CONDITIONS:

1. RM 3A used to determine dry molecular weight of the gas stream: OK
2. RM 7E used to determine NOx emissions: OK
3. RM 10 used to determine CO emissions: OK
4. RM 25a used to determine NMOC landfill gas emissions: OK

DEVIATIONS: None reported.

CONCLUSION: The protocol appears to be acceptable.

RECOMMENDATION: Send protocol review and test date confirmation notice.

ATTACHMENTS: Pretest protocol dated October 3, 2024

6 , 3
waste management district
WASATCH
October 3,2024
Bryce Bird, Director
Utah Division of Air Quality
P.O. Box 144820
Salt Lake City, Utah 84114-4820
RE: 2024 Compliance Stack Testing Protocol, Davis Landfill
Dear Mr. Bird:
Wasatch Integrated Waste Management District (Wasatch) operates the Davis Landfill in
accordance with Operating Permit #l 100033004 and Approval Order (AO) DAQE-
AN101290026-22.
Wasatch is required to conduct an annual stack test on one landfill gas fired Spark Ignited -
Internal Combustion Engine (SI-ICE) at the Davis Landfill. This Stack Test will be performed by
DeNovo Global Technologies, Inc. (DeNovo) in accordance with the attached work plan and test
protocol. The onsite sampling is currently scheduled at the Davis Landfill for November 5,2024.
Source testing described in this protocol will include the annual compliance testing on unit E- I
for the emissions NOX, CO, NMVOC, and the diluent 02. Sampling and analysis will be tested
according to USEPA 40 CFR part63, subpart ZZZZ,40 CFR part 60, subpart A, and part 60,
Appendix A.
Please review the attached work plan and test protocol. Do not hesitate to contact me if you have
any questions or concerns regarding the test protocol or to schedule a Pre-test Meeting.
Sincerely,
Wasatch Integrated Waste Management District@L
Nathan Rich, P.E.
Executive Director
Cc: Preston Lee
attachment
1997 East 3500 North I Layton, Utah 84040
(801) 614-s600 | fax [phone]
UfnH OrPrrF.TMENT OF
E N \/ I RQlluENrlag],latllY
C,IVISION OF A!R OI]ALITY
OENOVO
WASATCH INTEGRATED WASTE
MANGAEMENT DISTRICT
SOURCE TESTING PROTOCOL
52s0.10.01
DAVIS LANDFILL
LAYTON, UTAH
AO : DAQE-AN I 01290026-22
October 3,2024
Prepared for:
Davis Landfill
C/O ENERGYneering Solutions, lnc
15820 Barclay Drive
Sisters, OR.97759
i
Il@
vtxshs L47 1) Clients - Acritr I:NL:RGYneenng Sohtions - 5250 5 )50 l0 - l)aris ('oilnry' Inndlll, t fl"1'r14t 5250 10 01 Da|is lnn.$ll 1'rtocol.Lkrx
Wasotch lntegrated Woste Monagement District, Dovis Londfill 2024 Periodic Test Protocol PN.5250.10.01
Table of Contents
EQUIPMENT AND PROCEDURES............... ..........................3
APPENDIX A. SAMPLE TRAIN DRAWING ..............
APPENDIX B - EPA TEST METHODS....
Wosatch tntegrated Woste Monogement District, Dovis Londfill 2024 Periodic Test Protocol PN.5250.10.01
PREFACE
DeNovo Global Technologies, lnc. (DeNovo) has been contracted to conduct the 2024 Periodic
Performance Test Series (PPT) on one landfill gas fired Spark lgnited - lnternal Combustion Engine
(Sl-lCE) at the Wasatch lntegrated Waste Management District (WIWMD) Gas-to-Energy power
generation facility in Layton, UT. Specifically, testing will be performed to document compliance
with the facility source Approval Order (AO) number DAQE-AN10129O026-22 following
applicable EPA, NSPS, and Utah Department of Environmental Quality, Division of Air Quality
(UDAa) regulations along with 40 CFR part 60, sections 60.8, 60.11, 60.4245 (subpart JJJJ),
following the General Provisions under 560.8 and specific requirements of 60.754(d) using 40 CFR
Part 60, Appendix A Test Methods 3A, 7E, LO, 19 and 25a with a methane cutter, for the
determination of Oz, NOx, CO, NMVOC mass emissions and defines engine load requirements for
landfill gas fired Spark lgnited lnternal Combustion Engine (Sl-lCE) operations. Report will be in
accordance with 560.8 and 560.4244for compliance stack test reports. This document defines
the proposed protocol for the test series.
GENERAL INFORMATION
DeNovo Global Technologies, lnc. (DeNovo) has been contracted to perform the source testing
for one Sl-lCE unit associated with plant operations as mandated by UDAQApprovalOrder, state,
and federal regulations. Source testing described in this protocol will include the annual
compliance testing on unit E-1 for the emissions NOx, CO, NMVOC, and the diluent Oz. The
operating limits for the listed units below are governed by UDAQ.
Plant and Process Description
WIWND operates a landfill gas-to-energy operation which is located at L997 East 3500 North,
Layton, Utah 84040, Davis County. The LFGE facility reroutes the methane gas collection system
from the plant flare to a gas recovery plant which is composed of a landfill gas treatment facility
and one (!) 2,233 hp Caterpillar 3520C Engine/Generator sets. The collected landfill gas is pre-
treated to remove moisture and particulate prior to being fed the engine. The pre-treatment
technology utilizes compression, filtering, and de-watering, thus qualifying under 40 CFR Part
60.752(b) (2) (iii). The technology satisfies the facility's obligation under NSPS subpart WWW and
NESHAP for gas which is processed.
Test Source Information
EP.
No.
DESCR!PTION NOx co NMVOC Maximum
Operation
E-1
Caterpillar G3520C
2,233 BHP lean burn
lC-Reciprocating engine
2.46 Lb.lhr
0.5 g/hp-hr
12.31Lb./hr
2.5 g/hp-hr
4.33 Lb./hr
0.88 g/hp-hr
8760 hours/year
Wosotch lntegroted Woste Monogement District, Dovis Londfill 2024 PeriodicTest Protocol
Testing Summary
PN.5250.10.01
Site Information
Wasatch lntegrated Waste Management District, 1997 East 3500 North, Layton, Utah
84O4O, Davis County - UTM: L2,X: 42!500 m Easting, Y: 4550700 m Northing.
Governing Regulations
IDAQ Approval Order number DAQE-AN10L290O26-22 dated August L2,2022.
Facility Contact Information
M Jesse Simonsen
Wasatch lntegrated Waste Management District
Landfill Manager
1997 East 3500 North
Layton, Utah 84040
[e-mail]
(801)614-s62a@)
Testing Organization
DeNovo Global Technologies, lnc
Louis M. Esposito
17902 East Strack Drive
Spring, Texas 77379
(281) 2s1-0399 ext. 14
Test Schedule
The current test schedule is set for November 05th ,2024, beginning at 10:00 am.
Wosotch lntegrated Woste Monagement District, Davis Londfill 2024 Periodic Test Protocol PN. 5250.10.01
Equipment and Procedures
The unit will be tested according to USEPA 40 CFR part 63, subpart ZZZZ,40 CFR part 60,
subpart A, and part 60, Appendix A.
Sampling and Analytical Protocol
The following tables present specific methods which will be utilized to perform the test
series:
EPA Method 3A
Sampling of the Sl-lCE exhaust gas for Oz & COz will be performed as outlined by the
procedures in EPA Method 34, in 40 CFR, Part 60, Appendix A. There are no modifications
to this method.
EPA Method 7E
Sampling of the Sl-lCE exhaust gas for NOx concentrations will be performed as outlined
by the procedures in EPA Method 7E, 40 CFR, Part 60, Appendix A. There are no
modifications to this method.
EPA Method 10
Sampling of the Sl-lCE exhaust gas for CO will be performed as outlined by the procedures
in EPA Method 10, in 40 CFR, Part 60, Appendix A. There are no modifications to this
method.
EPA Method 19
Determination of the Sl-lCE unit for mass emissions will be performed as outlined by the
procedures in EPA Method 19 in 40 CFR, Part 60, Appendix A using Oz as the measured
diluent. There are no modifications to this method.
EPA Method 25A
Sampling of the Sl-lCE unit for NMVOC concentrations will be performed as outlined by
the procedures in EPA Method 25A with use of a methane cutter, in 40 CFR, Part 60,
Appendix A. There are no modifications to this method.
Fuel Flow Determination
Fuel flow will be provided by plant personnel using the calibrated in line fuelflow meter
that measures landfill gas flow to the unit being tested. A calibration certificate will be
provided as part of the final report.
TEST
SERIES
SAMPLING
FREQUENCY
SAMPTING
METHODS
ANATYTICAL
PARAMETER RM RANGE ANATYTICAL METHOD
Caterpillar
G3520C
3 X 60 Minute
Samples
(Full Load)
EPA - 34
EPA - 7E
EPA - 10
EPA _ 19
EPA _ 25A
Oz
NOx
CO
Mass emissions
NMVOC
10 (%\
1s0 (ppm)
1000 (ppm)
N/A
s00(ppm)
Paramagnetic
Chem ilum inescent
IR
N/A
FID w/methane cutter
Wosatch lntegroted Waste Monogement District, Dovis Londfill 2024 Periodic Test Protocol PN.52s0.10.01
RM Instrumentation
The compounds to be calibrated are Oxides of Nitrogen (NOx), Carbon Monoxide (CO),
Non-Methane Volatile Organic Compounds (NMVOC's) and Oxygen (Oz). The NOx analysis
will be performed using a California Analytical Model 601 Chemiluminescent analyzer.
The CO analysis will be performed using a California Analytical Model 600 NDIR analyzer.
The Oz analysis will be performed using a California Analytical Model 600 Paramagnetic
analyzer. The NMVOC analysis will be performed using a California Analytical Model
6O0M-HFID Flame lonization Detector analyzer equipped with a methane cutter.
RM Calibration Procedure
The NOx, CO, and Oz and NMVOC analyzers will be calibrated using EPA protocol gas
mixtures. The sensitivity of the analyzers is less than L% of the range and response time
is typically less than one minute, depending on the length of heated line used. The
analyzers will be zeroed with ultra-pure nitrogen, followed by a mid and high range
calibration standard, corresponding to approximately 40 % - 60 % and tOO % of the
analyzer full span value. The calibration range for each component will vary dependent
on the unit specifics.
A system bias check will be performed before and after each test run using the mid-range
gas mixture through the entire sampling system to check for line contamination and leaks.
Calibration correction factors will be determined and used to correct the raw RM
concentrations.
RM Sampling Procedure
The Sl-lCE exhaust gas stream will be sampled and measured according to the
requirements and procedures of EPA Reference Methods 1,2, and 7E. Samples will be
drawn from a single point at 50% of the respective stack diameter. From the stacks, the
samples are transferred through a heated line to the mobile laboratory. Upon entering
the lab, the NMVOC sample is routed directly through a sample pump to the FID analyzer
for analysis. For NOx, CO, and Oz the sample stream first passed through a one-micron
filter assembly to remove particulate and then through a Universal Analyzer Model 9010
chiller the system to remove moisture. The dried sample is then distributed via a manifold
and independent control flow to the various analyzers. Sample concentrations are
recorded 8 times each second using Dasylab data acquisition software and averaged at
one-minute intervals. The data is saved to a personal computer and test runs are averaged
and corrected for bias and drift. There are no modifications to this method.
RM Sampling Locations
As currently configured, the flue gas samples present in the exhaust stacks will be checked
for cyclonic flow and Oz stratification. A 3-point sampling plan at 1,6.7%,SOYo, and 833%
of the stack diameter will be utilized according to the requirements and procedures of
applicable EPA Reference Methods.
Wosotch lntegroted Woste Manogement District, Dovis Londfill 2024 Periodic Test Protocol PN. 5250.10.01
Operational Parameters
During testing, the unit will be tested at full load condition in accordance with UDAQ
guidelines. Plant personnel will be responsible for gathering operations data necessary for
determining load conditions.
Fuel Analysis
A fuel composition analysis shall be supplied by WIWMD for use in determination of fuel
heating values and fuel specific F-factor for use in the flow and emission calculations.
Possible Complications
No complications are expected for this test series. Should it become necessary to change
the testing schedule, the UDAQ regional and/or State office will be notified as soon as
practicable.
The test crew will consist of Messrs. Abraham Lara and Tony Wells. Mr. Louis M.
Esposito will be the overall project manager who has over 34 years of emissions testing
experience as well as airlwater/waste permitting.
Wosatch lntegrated Waste Monagement District, Dovls Landfill 2024 PeriodicTest Protocol PN.5250.10.01
APPENDIX A . SAMPLE TRAIN DRAWING
-t
E.
tJ)=E.FFa^ul
F
Qr
ll-dE+
Ir
f
t

r
u
l
g
l

(E
l
Y
r
{
Li
EH
i*E*
Ii
l
i
l
l
i
l
t
o
ICE
doT:
-88A
Af
;
€
ll
.

I
r'
\o
I
S
Ee
IL
I
-f
r
R
E-
-
5I
e
i
H*
i
k*
\.
8
iE
i
IS
iioo
_
aE
E.5ae.FFU)H
lr
t
T_
_
_
_
_
_
_
_
L
_
_
_
_
_
l
_
_
_
_
_
_
L
_
_
_
_
_
r
tN
n

il
o
l
3
l

Gl
v
S
H
LI
FH?zE*
1i
l
i
l
i
l
i
l
Ii
l
i
l

ti
l

to
Ii
l
i
l
l
t
i
l
o
Ii
l
i
l
i
l
i
l
O
il
i
l
t
I
I
i
l
O
a,Id4
Ao-
IE
ioaon;
xo
o
oo8B
€
i
FI
-g
t
g
Ee
!
(,
.
:
o
2
l
:f
r
s
BH
$
5
Ei
i
Eu
r
LT
:
f,
3
e
ta
,
\N
O
-o
t
*
R;
'E
,

-
N
a<a
ao
Br
N
!iE(
L
3h
hntiItEIt:(tINE
Wosotch lntegroted Woste Monogement District, Dovis Londfill 2024 PeriodicTest Protocol PN.5250.10.01
APPENDIX B. EPA TEST METHODS
METHOD 3A
DETERM!NATION OF OXYGEN AND CARBON
DIOXIDE CONCENTRATIONS IN EMISSIONS
FROM STATIONARY SOURCES (!NSTRUMENTAL
ANALYZER PROCEDURE)
Revision 0
LzlLL(20L3 DENOVO
1.0 Scope and Application
What is Method 34?
Method 34 is a procedure for measuring oxygen (Oz) and carbon dioxide (CO2) in stationary source
emissions using a continuous instrumental analyzer. Quality assurance and quality control
requirements are included to assure that you, the tester, collect data of known quality. You must
document your adherence to these specific requirements for equipment, supplies, sample collection
and analysis, calculations, and data analysis.
This method does not completely describe all equipment, supplies, and sampling and analytical
procedures you will need but refers to other methods for some of the details. Therefore, to obtain
reliable results, you should also have a thorough knowledge of these additional test methods which
are found in appendix A to this part:
(a) Method 1-Sample and Velocity Traverses for Stationary Sources.
(b) Method 3-Gas Analysis for the Determination of Molecular Weight.
(c) Method 4-Determination of Moisture Content in Stack Gases.
(d) Method 7E-Determination of Nitrogen Oxides Emissions from Stationary Sources (lnstrumental
Analyzer Procedure).
1.1 Analytes. What does this method determine? This method measures the concentration of oxygen
and carbon dioxide.
Analyte CAS No.Sensitivity
Oxygen (Oz)778244-7 Typically <2% of Calibration Span.
Carbon dioxide (COz)124-38-9 Typically <2% of Calibration Span.
1.2 Applicability. When is this method required? The use of Method 34 may be required by specific
New Source Performance Standards, Clean Air Marketing rules, State lmplementation Plans and
permits, where measurements of Oz and COz concentrations in stationary source emissions must
be made, either to determine compliance with an applicable emission standard or to conduct
performance testing of a continuous emission monitoring system (CEMS). Other regulations may
also require the use of Method 34.
1.3 Data Quality Objectives. How good must my collected data be? Refer to Section 1.3 of Method 7E.
2.0 Summary of Method
ln this method, you continuously or intermittently sample the effluent gas and convey the sample to
an analyzer that measures the concentration of Oz or COz. You must meet the performance
requirements of this method to validate your data.
3.0 Definitions
Refer to Section 3.0 of MethodTEfor the applicable definitions.
4.0 lnterferences IReserved]
5.0 Safety
METHOD 3A
DETERMINATION OF OXYGEN AND CARBON
DIOXIDE CONCENTRATIONS IN EMISSIONS
FROM STATTONARY SOURCES (l NSTRU MENTAT
ANALYZER PROCEDURE)
Revision 0
t2lLL|20L3 DENOVO
Refer to Section 5.0 of Method 7E.
5.0 Equipment and Supplies
Figure 7E-1 in Method 7E is a schematic diagram of an acceptable measurement system.
6.1 What do I need for the measurement system? The components of the measurement system are
described (as applicable) in Sections 6.1 and 5.2 of Method 7E, except that the analyzer described
in Section 6.2 of this method must be used instead of the analyzer described in Method 7E. You
must follow the noted specifications in Section 5.1 of Method 7E except that the requirements
to use stainless steel, Teflon, or non-reactive glass filters do not apply. Also, a heated sample line
is not required to transport dry gases or for systems that measure the Oz or COz concentration
on a dry basis, provided that the system is not also being used to concurrently measure SO2
and/or NOx.
6.2 What analyzer must I use? You must use an analyzer that continuously measures 02 or COz in the
gas stream and meets the specifications in Section 13.0.
7.0 Reagents and Standards
T.l Calibration Gas. What calibration gasses do I need? Refer to Section 7.L of Method 7E for the
calibration gas requirements. Example calibration gas mixtures are listed below. Precleaned or
scrubbed air may be used for the Oz high-calibration gas provided it does not contain other gases
that interfere with the Oz measurement.
(a) COz in nitrogen (Nz).
(b) COz in air.
(c) COz/SOz gas mixture in N2.
(d) Oz/SOz gas mixture in Nz.
(el Oz/COz/SOz gas mixture in Nz.
(f) 692/NOx gas mixture in N2.
(e) COz/SOz/NOx 8as mixture in Nz.
The tests for analyzer calibration error and system bias require high-, mid-, and low-level gases.
7.2 lnterference Check. What reagents do I need forthe interference check? Potential interferences
may vary among available analyzers. Table 7E-3 of Method 7E lists a number of gases that should
be considered in conducting the interference test.
8.0 Sample Collection, Preservation, Storage, and Transport
8.1 Sampling Site and Sampling Points. You must follow the procedures of Section 8.1 of Method 7E
to determine the appropriate sampling points, unless you are using Method 3A only to determine
the stack gas molecular weight and for no other purpose. In that case, you may use single-point
integrated sampling as described in Section 8.2.1of Method 3. lf the stratification test provisions
in Section 8.7.2 of Method 7E are used to reduce the number of required sampling points, the
alternative acceptance criterion for 3-point sampling will be + 0.5 percent COz or Oz, and the
alternative acceptance criterion for single-point sampling will be + 0.3 percent COz or Oz. ln that
case, you may use single-point integrated sampling as described in Section 8.2.1of Method 3.
METHOD 3A
DETERMINATION OF OXYGEN AND CARBON
DIOXIDE CONCENTRATIONS !N EMISSIONS
FROM STATTONARY SOURCES (t NSTRUMENTAL
ANALYZER PROCEDURE)
Revision 0
LzlLLl2OL3 r)ENOVO
8.2 lnitial Measurement System Performance Tests. You must follow the procedures in Section 8.2 of
Method 7E.lf a dilution-type measurement system is used, the special considerations in Section
8.3 of Method 7E apply.
8.3 lnterference Check. The Oz or COz analyzer must be documented to show that interference effects
to not exceed 2.5 percent of the calibration span. The interference test in Section8.2.7 of Method
7E is a procedure that may be used to show this. The effects of all potential interferences at the
concentrations encountered during testing must be addressed and documented. This testing and
documentation may be done by the instrument manufacturer.
8.4 Sample Collection. You must follow the procedures in Section 8.4 of Method 7E.
8.5 Post-Run System Bias Check and Drift Assessment. You must follow the procedures in Section 8.5
of Method 7E.
9.0 Quality Control
Follow quality control procedures in Section 9.0 of Method 7E.
10.0 Calibration and Standardization
Follow the procedures for calibration and standardization in Section 10.0 of Method 7E.
11".0 Analytica I Procedu res
Because sample collection and analysis are performed together (see Section 8), additional discussion
of the analytical procedure is not necessary.
12.0 Calculations and Data Analysis
You must follow the applicable procedures for calculations and data analysis in Section 12.0 of Method
7E, substituting percent Oz and percent COz for ppmv of NOx as appropriate.
L3.0 Method Performance
The specifications forthe applicable performance checks are the same as in Section 13.0 of Method
7E except for the alternative specifications for system bias, drift, and calibration error. ln these
alternative specifications, replace the term "0.5 ppmv" with the term "0.5 percent Oz" ot "0.5 percent
COz" (as applicable).
14.0 Pollution Prevention IReserved]
15.0 Waste Management IReserved]
16.0 Alternative Procedures IReserved]
17.0 References
L7.L"EPA Traceability Protocol for Assay and Certification of Gaseous Calibration Standards"
September 1997 as amended, EPA-500/R-97/t27.
18.0 Tables, Diagrams, Flowcharts, and Validation Data
Refer to Section 18.0 of Method 7E.
METHOD 7E
DETERMTNAfloN oF NTTRoGEN oxtDEs I Revision 0 I DENOVEMrssroNsFRoMsrATtoNARysouRcEs I tzlttlzotg I - r\\-
(l NSTRUMENTAL ANALYZER PROCEDURE)
L.0 Scope and Application
What is Method 7E?
Method 7E is a procedure for measuring nitrogen oxides (NOx) in stationary source emissions using a
continuous instrumental analyzer. Quality assurance and quality control requirements are included
to assure that you, the tester, collect data of known quality. You must document your adherence to
these specific requirements for equipment, supplies, sample collection and analysis, calculations, and
data analysis. This method does not completely describe all equipment, supplies, and sampling and
analytical procedures you will need but refers to other methods for some of the details. Therefore, to
obtain reliable results, you should also have a thorough knowledge of these additionaltest methods
which are found in appendix A to this part:
(a) Method 1-sample and Velocity Traverses for Stationary Sources.
(b) Method 4-Determination of Moisture Content in Stack Gases.
1.1Analytes. What does this method determine? This method measures the concentration of
nitrogen oxides as NOz.
Analyte CAS No.Sensitivity
Nitric oxide (NO)roto243-9 Typically <2% oI
Nitrogen dioxide (NOz)L0L02444 Calibration Span.
1.2 Applicability. When is this method required? The use of Method 7E may be required by specific
New Source Performance Standards, Clean Air Marketing rules, State lmplementation Plans, and
permits where measurement of NOx concentrations in stationary source emissions is required,
either to determine compliance with an applicable emissions standard or to conduct
performance testing of a continuous monitoring system (CEMS). Other regulations may also
require the use of Method 7E.
1.3 Data Quality Objectives (DaO). How good must my collected data be? Method 7E is designed to
provide high-quality data for determining compliance with Federal and State emission standards
and for relative accuracy testing of CEMS. ln these and other applications, the principal objective
is to ensure the accuracy of the data at the actual emission levels encountered. To meet this
objective, the use of EPA traceability protocol calibration gases and measurement system
performance tests are required.
1.4 Data Quality Assessment for Low Emitters. ls performance relief granted when testing low-
emission units? Yes. For low-emitting sources, there are alternative performance specifications
for analyzer calibration error, system bias, drift, and response time. Also, the alternative dynamic
spiking procedure in Section 16 may provide performance relief for certain low-emitting units.
2,0 Summary of Method
ln this method, a sample of the effluent gas is continuously sampled and conveyed to the analyzer for
measuring the concentration of NOx. You may measure NO and NO2 separately or simultaneously
together but, for the purposes of this method, NOx is the sum of NO and NOz. You must meet the
performance requirements of this method to validate your data.
METHOD 7E
DETERMINATION OF NITROGEN OXIDES i:::::: I DENOVO
EMTSSTONS FROM STATTONARY SOURCES I L2lLLlzOLs
(r NSTRUMENTAL ANALYZER PROCEDU RE)
3.0 Definitions
3.1. Analyzer Calibration Error, for non-dilution systems, means the difference between the
manufacturer certified concentration of a calibration gas and the measured concentration of the
same gas when it is introduced into the analyzer in direct calibration mode.
3.2 Calibration Curve means the relationship between an analyzer's response to the injection of a
series of calibration gases and the actual concentrations ofthose gases.
3.3 Calibration Gas means the gas mixture containing NOx at a known concentration and produced
and certified in accordance with "EPA Traceability Protocol for Assay and Certification of Gaseous
Calibration Standards," September 1997, as amended August 25, 7999, EPA-600/R-97172L or
more recent updates. The tests for analyzer calibration error, drift, and system bias require the
use of calibration gas prepared according to this protocol. lf a zero gas is used for the low-level
gas, it must meet the requirements under the definition for "zero air material" in 40 CFR72.2 in
place of being prepared by the traceability protocol.
3.3.1 Low-Level Gas means a calibration gas with a concentration that is less than 20 percent of
the calibration span and may be a zero gas.
3.3.2 Mid-LevelGas means a calibration gas with a concentration that is 40 to 50 percent of the
calibration span.
3.3.3 High-Level Gas means a calibration gas with a concentration that is equalto the calibration
span.
3.4 Calibration Span means the upper limit of the analyzer's calibration that is set by the choice of
high-level calibration gas. No valid run average concentration may exceed the calibration span.
To the extent practicable, the measured emissions should be between 20 to 100 percent of the
selected calibration span. This may not be practicable in some cases of low-concentration
measurements or testing for compliance with an emission limit when emissions are substantially
less than the limit. ln such cases, calibration spans that are practicable to achieving the data
quality objectives without being excessively high should be chosen.
3.5 Centroidal Area means the central area of the stack or duct that is no greater than 1 percent of
the stack or duct cross section. This area has the same geometric shape as the stack or duct.
3.6 Converter Efficiency Gas means a calibration gas with a known NO or NOz concentration and of
Traceability Protocol quality.
3.7 Data Recorder means the equipment that permanently records the concentrations reported by
the analyzer.
3.8 Direct Calibration Mode means introducing the calibration gases directly into the analyzer (or into
the assembled measurement system at a point downstream of all sample conditioning
equipment) according to manufacturer's recommended calibration procedure. This mode of
calibration applies to non-dilution-type measurement systems.
3.9 Drift means the difference between the pre- and post-run system bias (or system calibration error)
checks at a specific calibration gas concentration level (i.e. low-, mid- or high-).
3.L0 Gas Analyzer means the equipment that senses the gas being measured and generates an output
proportional to its concentration.
METHOD 7E
DETERMINATION OF NITROGEN OXIDES
EMISSIONS FROM STATIONARY SOURCES
(r NSTRUMENTAL ANALYZER PROCEDURE)
Revision 0
Lzlttl2OL3 DEI{OVO
3.11 lnterference Check means the test to detect analyzer responses to compounds other than the
compound of interest, usually a gas present in the measured gas stream, that is not adequately
accounted for in the calibration procedure and may cause measurement bias.
3.12 Low-Concentration Analyzer means any analyzerthat operates with a calibration span of 20 ppm
NOx or lower. Each analyzer model used routinely to measure low NOx concentrations must pass
a manufacturer's stability test (MST). An MST subjects the analyzer to a range of line voltages
and temperatures that reflect potential field conditions to demonstrate its stability following
procedures similar to those provided in 40 CFR 53.23. Ambient-level analyzers are exempt from
the MST requirements of Section 16.3. A copy of this information must be included in each test
report. Table 7E-5 lists the criteria to be met.
3.L3 Measurement System means all of the equipment used to determine the NOx concentration. The
measurement system comprises six major subsystems: Sample acquisition, sample transport,
sample conditioning, calibration gas manifold, gas analyzer, and data recorder.
3.14 Response Time means the time it takes the measurement system to respond to a change in gas
concentration occurring at the sampling point when the system is operating normally at its target
sample flow rate or dilution ratio.
3.15 Run means a series of gas samples taken successively from the stack or duct. A test normally
consists of a specific number of runs.
3.1-6 System Bias means the difference between a calibration gas measured in direct calibration mode
and in system calibration mode. System bias is determined before and after each run at the low-
and mid- or high-concentration levels. For dilution-type systems, pre- and post-run system
calibration error is measured rather than system bias.
3.17 System Calibration Error applies to dilution-type systems and means the difference between the
measured concentration of low-, mid-, or high-level calibration gas and the certified
concentration for each gas when introduced in system calibration mode. For dilution-type
systems, a 3-point system calibration error test is conducted in lieu of the analyzer calibration
error test, and 2-point system calibration error tests are conducted in lieu of system bias tests.
3.L8 System Calibration Mode means introducing the calibration gases into the measurement system
at the probe, upstream of the filter and all sample conditioning components.
3.19 Test refers to the series of runs required by the applicable regulation.
4.0 lnterferences
Note that interferences may vary among instruments and that instrument-specific interferences must
be evaluated through the interference test.
5.0 Safety
What safety measures should I consider when using this method? This method may require you to
work with hazardous materials and in hazardous conditions. We encourage you to establish safety
procedures before using the method. Among other precautions, you should become familiar with the
safety recommendations in the gas analyzer user's manual. Occupational Safety and Health
Administration (OSHA) regulations concerning cylinder and noxious gases may apply. Nitric oxide and
NOz are toxic and dangerous gases. Nitric oxide is immediately converted to NOz upon reaction with
METHOD 7E
DETERMINATION OF NITROGEN OXIDES
EMISSIONS FROM STATIONARY SOURCES
(rNSTRU MENTAT ANALYZER PROCEDURE)
Revision 0
LzltLl20L3 DEI\IOVO
air. Nitrogen dioxide is a highly poisonous and insidious gas. lnflammation of the lungs from exposure
may cause only slight pain or pass unnoticed, but the resulting edema several days later may cause
death. A concentration of 100 ppm is dangerous for even a short exposure, and 200 ppm may be fatal.
Calibration gases must be handled with utmost care and with adequate ventilation. Emission-level
exposure to these gases should be avoided.
6.0 Equipment and Supplies
The performance criteria in this method will be met or exceeded if you are properly using equipment
designed for this application.
6.1 What do I need for the measurement system? You may use any equipment and supplies meeting
the following specifications.
(1) Sampling system components that are not evaluated in the system bias or system calibration
error test must be glass, Teflon, or stainless steel. Other materials are potentially acceptable,
subject to approval by the Administrator.
(2) The interference, calibration error, and system bias criteria must be met.
(3) Sample flow rate must be maintained within 10 percent of the flow rate at which the system
response time was measured.
(4) All system components (excluding sample conditioning components, if used) must maintain
the sample temperature above the moisture dew point.
Section 5.2 provides example equipment specifications for a NOx measurement system. Figure
7E-1 is a diagram of an example dry basis measurement system that is likely to meet the method
requirements and is provided as guidance. For wet-basis systems, you may use alternative
equipment and supplies as needed (some of which are described in Section 6.2), provided that
the measurement system meets the applicable performance specifications of this method.
6.2 Measurement System Components
6.2.1 Sample Probe. Glass, stainless steel, or other approved material, of sufficient length to
traverse the sample points.
5.2.2 Particulate Filter. An in-stack or out-of-stack filter. The filter must be made of material that
is non-reactive to the gas being sampled. The filter media for out-of-stack filters must be
included in the system bias test. The particulate filter requirement may be waived in
applications where no significant particulate matter is expected (e.g,, for emission testing
of a combustion turbine firing natural gas).
6.2.3 Sample Line. The sample line from the probe to the conditioning system/sample pump
should be made of Teflon or other material that does not absorb or otherwise alter the
sample gas. For a dry-basis measurement system (as shown in Figure 7E-1), the
temperature of the sample line must be maintained at a sufficiently high level to prevent
condensation before the sample conditioning components. For wet-basis measurement
systems, the temperature of the sample line must be maintained at a sufficiently high level
to prevent condensation before the analyzer.
METHOD 7E
DETERMINATION OF NITROGEN OXIDES
EMISSIONS FROM STATIONARY SOURCES
(rNSTRU MENTAT ANALYZER PROCEDU RE)
Revision 0
L2lLLl20L3 DENOVO
6.2.4 Conditioning Equipment. For dry basis measurements, a condenser, dryer or other suitable
device is required to remove moisture continuously from the sample gas. Any equipment
needed to heat the probe or sample line to avoid condensation prior to the sample
conditioning component is also required.
For wet basis systems, you must keep the sample above its dew point either by: (1) Heating
the sample line and all sample transport components up to the inlet of the analyzer (and,
for hot-wet extractive systems, also heating the analyzer) or (2) by diluting the sample prior
to analysis using a dilution probe system. The components required to do either of the above
are considered to be conditioning equipment.
6.2.5 Sampling Pump. For systems similar to the one shown in Figure 7E-L, a leak-free pump is
needed to pull the sample gas through the system at a flow rate sufficient to minimize the
response time of the measurement system. The pump may be constructed of any material
that is non-reactive to the gas being sampled. For dilution-type measurement systems, an
ejector pump (eductor) is used to create a vacuum that draws the sample through a critical
orifice at a constant rate.
6.2.6 Calibration Gas Manifold. Prepare a system to allow the introduction of calibration gases
either directly to the gas analyzer in direct calibration mode or into the measurement
system, at the probe, in system calibration mode, or both, depending upon the type of
system used. ln system calibration mode, the system should be able to flood the sampling
probe and vent excess gas. Alternatively, calibration gases may be introduced at the
calibration valve following the probe. Maintain a constant pressure in the gas manifold. For
in-stack dilution-type systems, a gas dilution subsystem is required to transport large
volumes of purified air to the sample probe and a probe controller is needed to maintain
the proper dilution ratio.
6.2.7 Sample Gas Manifold. For the type of system shown in Figure 7E-1, the sample gas manifold
diverts a portion of the sample to the analyzer, delivering the remainder to the by-pass
discharge vent. The manifold should also be able to introduce calibration gases directly to
the analyzer (except for dilution-type systems). The manifold must be made of materialthat
is non-reactive to the gas sampled or the calibration gas and be configured to safely
discharge the bypass gas.
6.2.8 NOx Analyzer. An instrument that continuously measures NOx in the gas stream and meets
the applicable specifications in Section 13.0. An analyzerthat operates on the principle of
chemiluminescence with an NOu to NO converter is one example of an analyzer that has
been used successfully in the past. Analyzers operating on other principles may also be used
provided the performance criteria in Section 13.0 are met.
6.2.8.1 Dual Range Analyzers. For certain applications, a wide range of gas concentrations
may be encountered, necessitating the use of two measurement ranges. Dual-range
analyzers are readily available for these applications. These analyzers are often
equipped with automated range-switching capability, so that when readings exceed
METHOD 7E
DETERMINATION OF NITROGEN OXIDES
EMISSIONS FROM STATIONARY SOURCES
(TNSTRUMENTAL ANATYZER PROCEDURE)
Revision 0
LzlLL|20L3 DENOVO
the full-scale of the low measurement range, they are recorded on the high range. As
an alternative to using a dual-range analyzer, you may use two segments of a single,
large measurement scale to serve as the low and high ranges. ln all cases, when two
ranges are used, you must quality-assure both ranges using the proper sets of
calibration gases. You must also meet the interference, calibration error, system bias,
and drift checks. However, we caution that when you use two segments of a large
measurement scale for dual range purposes, it may be difficult to meet the
performance specifications on the low range due to signal=to-noise ratio
considerations.
6.2.8.2 Low Concentration Analyzer. When an analyzer is routinely calibrated with a
calibration span of 20 ppmv or less, the manufacturer's stability test (MST) is required.
See Table 7E-5 f or test parameters.
6.2.9 Data Recording. A strip chart recorder, computerized data acquisition system, digital
recorder, or data logger for recording measurement data may be used.
7.0 Reagents and Standards
7.1 Calibration Gas. What calibration gases do I need? Your calibration gas must be NO in Nz and
certified (or recertified) within an uncertainty of 2.0 percent in accordance with "EPA Traceability
Protocol for Assay and Certification of Gaseous Calibration Standards" September 1997, as
amended August 25,1999, EPA-600/R-97/t21. Blended gases meetingtheTraceability Protocol
are allowed if the additional gas components are shown not to interfere with the analysis. lf a
zero gas is used for the low-level gas, it must meet the requirements under the definition for
"zero ait material" in 40 CFR 12.2.The calibration gas must not be used after its expiration date.
Except for applications under part 75 of this chapter, it is acceptable to prepare calibration gas
mixtures from EPA Traceability Protocol gases in accordance with Method 205 in appendix M to
part 51 of this chapter. For part 75 applications, the use of Method 205 is subject to the approval
of the Administrator. The goal and recommendation for selecting calibration gases is to bracket
the sample concentrations. The following calibration gas concentrations are required:
7.1.1 High-Level Gas. This concentration sets the calibration span and results in measurements
being 20 to 100 percent ofthe calibration span.
7.1.2 Mid-Level Gas. 40 to 60 percent of the calibration span.
7.1.3 Low-Level Gas. Less than 20 percent of the calibration span.
7.1.4 Converter Efficiency Gas. What reagents do I need for the converter efficiency test? The
converter efficiency gas is a manufacturer-certified gas with a concentration sufficient to
show NOz conversion at the concentrations encountered in the source. A test gas
concentration in the 40 to 50 ppm range is suggested, but other concentrations may be
more appropriate to specific sources. For the test described in Section 8,2.4.1, NOz is
required. For the alternative converter efficiency tests in Section 16.2, NO is required.
7.2 lnterference Check. What reagents do I need for the interference check? Use the appropriate test
gases listed in Table 7E-3 or others not listed that can potentially interfere (as indicated by the
METHOD 7E
DETERMINATION OF NITROGEN OXIDES
EMISSIONS FROM STATIONARY SOURCES
(r NsrRU MENTAL ANALYZER PROCEDURE)
Revision 0
L2lLtl20L3 DENOVO
test facility type, instrument manufacturer, etc.) to conduct the interference check. These gases
should be manufacturer certified but do not have to be prepared by the EPA traceability protocol.
8.0 Sample Collection, Preservation, Storage, and Transport
Em ission Test Procedu re
Since you are allowed to choose different options to comply with some of the performance criteria, it
is your responsibility to identify the specific options you have chosen, to document that the
performance criteria for that option have been met, and to identify any deviations from the method.
8.1 What sampling site and sampling points do lselect?
8.L.1 Unless otherwise specified in an applicable regulation or by the Administrator, when this
method is used to determine compliance with an emission standard, conduct a stratification
test as described in Section 8.1.2 to determine the sampling traverse points to be used. For
performance testing of continuous emission monitoring systems, follow the sampling site
selection and traverse point layout procedures described in the appropriate performance
specification or applicable regulation (e.g., Performance Specification 2 in appendix B to this
part).
8.1.2 Determination of Stratification. Perform a stratification test at each test site to determine
the appropriate number of sample traverse points. lf testing for multiple pollutants or
diluents at the same site, a stratification test using only one pollutant or diluent satisfies this
requirement. A stratification test is not required for small stacks that are less than 4 inches
in diameter. To test for stratification, use a probe of appropriate length to measure the NOx
(or pollutant of interest) c.oncentration at twelve traverse points located according to Table
1-1 or Table 1-2 of Method 1. Alternatively, you may measure at three points on a line
passing through the centroidal area. Space the three points at L6.7,50.0, and 83.3 percent
of the measurement line. Sample for a minimum of twice the system response time (see
Section 8.2.6) at each traverse point. Calculate the individual point and mean NOx
concentrations. lf the concentration at each traverse point differs from the mean
concentration for all traverse points by no more than: (a) +5.0 percent of the mean
concentration; or (b) 10.5 ppm (whichever is less restrictive), the gas stream is considered
unstratified and you may collect samples from a single point that most closely matches the
mean. lf the 5.0 percent or 0.5 ppm criterion is not met, but the concentration at each
traverse point differs from the mean concentration for all traverse points by no more than:
(a) 110,0 percent of the mean; or (b) 11.0 ppm (whichever is less restrictive), the gas stream
is considered to be minimally stratified, and you may take samples from three points. Space
the three points atL6.7,50.0, and 83.3 percent of the measurement line. Alternatively, if a
twelve-point stratification test was performed and the emissions were shown to be
minimally stratified (all points within 110.0 percent of their mean or within 11.0 ppm), and
if the stack diameter (or equivalent diameter, for a rectangular stack or duct) is greater than
2.4 meters (7.8 ft), then you may use 3-point sampling and locate the three points along the
measurement line exhibiting the highest average concentration during the stratification
METHOD 7E
DETERMINATION OF NITROGEN OXIDES
EMISS!ONS FROM STATIONARY SOURCES
(r NSTRUMENTAL ANALYZER PROCEDU RE)
Revision 0
LzlLLlzOLs DENOVO
test, at 0.4, 1.0 and 2.0 meters from the stack or duct wall. lf the gas stream is found to be
stratified because the 10.0 percent or L.0 ppm criterion for a 3-point test is not met, locate
twelve traverse points for the test in accordance with Table 1-1 or Table 1-2 of Method 1.
8.2 lnitial Measurement System Performance Tests. What initial performance criteria must my system
meet before I begin collecting samples? Before measuring emissions, perform the following
procedures:
(a) Calibration gas verification,
(b) Measurement system preparation,
(c) Calibration error test,
(d) NOz to NO conversion efficiency test, if applicable,
(e) System bias check,
(f) System response time test, and
(g) lnterference check
8.2.1 Calibration Gas Verification. How must lverify the concentrations of my calibration gases?
Obtain a certificate from the gas manufacturer documenting the quality of the gas. Confirm
that the manufacturer certification is complete and current. Ensure that your calibration gas
certifications have not expired. This documentation should be available on-site for
inspection. To the extent practicable, select a high-level gas concentration that will result in
the measured emissions being between 20 and 100 percent of the calibration span.
8.2.2 Measurement System Preparation. How do I prepare my measurement system? Assemble,
prepare, and precondition the measurement system according to your standard operating
procedure. Adjust the system to achieve the correct sampling rate or dilution ratio (as
applicable).
8.2.3 Calibration ErrorTest. How do I confirm my analyzer calibration is correct? After you have
assembled, prepared and calibrated your sampling system and analyzer, you must conduct
a 3-point analyzer calibration error test (or a 3-point system calibration error test for dilution
systems) before the first run and again after any failed system bias test (or 2-point system
calibration error test for dilution systems) or failed drift test. lntroduce the low-, mid-, and
high-level calibration gases sequentially. For non-dilution-type measurement systems,
introduce the gases in direct calibration mode. For dilution-type measurement systems,
introduce the gases in system calibration mode.
(1) For non-dilution systems, you may adjust the system to maintain the correct flow rate
at the analyzer during the test, but you may not make adjustments for any other
purpose. For dilution systems, you must operate the measurement system at the
appropriate dilution ratio during all system calibration error checks, and may make only
the adjustments necessary to maintain the proper ratio.
(2) Record the analyzer's response to each calibration gas on a form similar to Table 7E-1.
For each calibration gas, calculate the analyzer calibration error using Equation 7E- 1 in
Section 12.2 or the system calibration error using Equation 7E-3 in Section 12.4 (as
applicable). The calibration error specification in Section 13.1- must be met for the low-
METHOD 7E
DETERMINATION OF NITROGEN OX!DES
EMISSIONS FROM STATIONARY SOURCES
(TNSTRUMENTAL ANALYZER PROCEDURE)
Revision 0
L2ltLlzOLs DENOVO
, mid-, and high-level gases. lf the calibration error specification is not met, take
corrective action and repeat the test until an acceptable 3-point calibration is achieved.
8.2.4 NOz to NO Conversion Efficiency Test. Before or after each field test, you must conduct an
NOz to NO conversion efficiency test if your system converts NOz to NO before analyzing for
NOx. You may risk testing multiple facilities before performing this test provided you pass
this test at the conclusion of the final facility test. A failed final conversion efficiency test in
this case will invalidate alltests performed subsequent to the test in which the converter
efficiency test was passed. Follow the procedures in Section 8.2.4.L, or 8.2.4.2. lf desired,
the converter efficiency factor derived from this test may be used to correct the test results
for converter efficiency if the NOz fraction in the measured test gas is known. Use Equation
7E-8 in Section 12.8 for this correction.
8.2.4.1Introduce NOz converter efficiency gas to the analyzer in direct calibration mode and
record the NOx concentration displayed by the analyzer. Calculate the converter
efficiency using Equation 7E-7 in Section !2.7. The specification for converter
efficiency in Section 13.5 must be met. The user is cautioned that state-of-the-art NOz
calibration gases may have limited shelf lives, and this could affect the ability to pass
the 90-percent conversion efficiency requirement.
8.2.4.2 Alternatively, either of the procedures for determining conversion efficiency using NO
in Section 1,6.2 may be used.
8.2.5 lnitial System Bias and System Calibration Error Checks. Before sampling begins, determine
whether the high-level or mid-level calibration gas best approximates the emissions and use
it as the upscale gas. lntroduce the upscale gas at the probe upstream of all sample
conditioning components in system calibration mode. Record the time it takes for the
measured concentration to increase to a value that is within 95 percent or 0.5 ppm
(whichever is less restrictive) of the certified gas concentration. Continue to observe the gas
concentration reading until it has reached a final, stable value. Record this value on a form
similar to Table 7E-2.
(1) Next, introduce the low-level gas in system calibration mode and record the time
required for the concentration response to decrease to a value that is within 5.0 percent
or 0.5 ppm (whichever is less restrictive) of the certified low-range gas concentration. lf
the low-level gas is a zero gas, use the procedures described above and observe the
change in concentration until the response is 0.5 ppm or 5.0 percent of the upscale gas
concentration (whichever is less restrictive).
(2) Continue to observe the low-level gas reading until it has reached a final, stable value
and record the result on a form similar to Table 7E-2. Operate the measurement system
at the normal sampling rate during all system bias checks. Make only the adjustments
necessary to achieve proper calibration gas flow rates at the analyzer.
(3) From these data, calculate the measurement system response time (see Section 8.2.6)
and then calculate the initial system bias using Equation 7E-2 in Section 12.3. For
dilution systems, calculate the system calibration error in lieu of system bias using
METHOD 7E
DETERMINATION OF NITROGEN OXIDES
EMISSIONS FROM STATIONARY SOURCES
(I NSTRUMENTAL ANALYZER PROCEDURE)
Revision 0
L2lLL{aOL3 DENOVO
equation 7E-3 in Section 12.4. See Section L3.2for acceptable performance criteria for
system bias and system calibration error. lf the initial system bias (or system calibration
error) specification is not met, take corrective action. Then, you must repeat the
applicable calibration errortest from Section 8.2.3 and the initial system bias (or 2-point
system calibration error) check until acceptable results are achieved, after which you
may begin sampling.
(Note: For dilution-type systems, data from the 3-point system calibration error test
described in Section 8.2.3 may be used to meet the initial 2-point system calibration error
test requirement of this section, if the calibration gases were injected as described in this
section, and if response time data were recorded).
8.2.5 Measurement System Response Time. As described in section 8.2.5, you must determine
the measurement system response time during the initial system bias (or 2-point system
calibration error) check. Observe the times required to achieve 95 percent of a stable
response for both the low-level and upscale gases. The longer interval is the response time.
8.2.7 lnterference Check. Conduct an interference response test of the gas analyzer prior to its
initial use in the field. lf you have multiple analyzers of the same make and model, you need
only perform this alternative interference check on one analyzer. You may also meet the
interference check requirement if the instrument manufacturer performs this or similar
check on the same make and model of analyzer that you use and provides you with
documented results.
(1) You may introduce the appropriate interference test gases (that are potentially
encountered during a test, see examples in Table 7E-3) into the analyzer separately or
as mixtures. Test the analyzer with the interference gas alone at the highest
concentration expected at a test source and again with the interference gas and NOx at
a representative NOx test concentration. For analyzers measuring NOx greater than 20
ppm, use a calibration gas with an NOx concentration of 80 to 100 ppm and set this
concentration equal to the calibration span. For analyzers measuring less than 20 ppm
NOx, select an NO concentration for the calibration span that reflects the emission levels
at the sources to be tested, and perform the interference check at that level. Measure
the total interference response of the analyzer to these gases in ppmv. Record the
responses and determine the interference using Table 7E-4. The specification in Section
13.4 must be met.
(2) A copy of this data, including the date completed and signed certification, must be
available for inspection at the test site and included with each test report. This
interference test is valid for the life of the instrument unless major analytical
components (e.g., the detector) are replaced with different model parts. lf major
components are replaced with different model parts, the interference gas check must
be repeated before returning the analyzerto service. lf major components are replaced,
the interference gas check must be repeated before returning the analyzer to service.
METHOD 7E
DETERMINATION OF NITRO6EN OXIDES
EMISSIONS FROM STATIONARY SOURCES
(! NSTRUMENTAL ANALYZER PROCEDURE)
Revision 0
LzlLLlzOLs DENOVO
The tester must ensure that any specific technology, equipment, or procedures that are
intended to remove interference effects are operating properly during testing.
8.3 Dilution-Type Systems-Special Considerations. When a dilution-type measurement system is
used, there are three important considerations that must be taken into account to ensure the
quality of the emissions data. First, the critical orifice size and dilution ratio must be selected
properly so that the sample dew point will be below the sample line and analyzer temperatures.
Second, a high-quality, accurate probe controller must be used to maintain the dilution ratio
during the test. The probe controller should be capable of monitoring the dilution air pressure,
eductor vacuum, and sample flow rates. Third, differences between the molecular weight of
calibration gas mixtures and the stack gas molecular weight must be addressed because these
can affect the dilution ratio and introduce measurement bias.
8.4 Sample Collection.
(1) Position the probe at the first sampling point. Purge the system for at least two times the
response time before recording any data. Then, traverse all required sampling points,
sampling at each pointforan equal length of time and maintainingthe appropriate sample
flow rate or dilution ratio (as applicable). You must record at least one valid data point per
minute during the test run.
(2) Each time the probe is removed from the stack and replaced, you must recondition the
sampling system for at least two times the system response time prior to your next recording.
lf the average of any run exceeds the calibration span value, that run is invalid.
(3) You may satisfy the multipoint traverse requirement by sampling sequentially using a single-
hole probe or a multi-hole probe designed to sample at the prescribed points with a flow
within 10 percent of mean flow rate. Notwithstanding, for applications under part 75 of this
chapter, the use of multi-hole probes is subject to the approval of the Administrator.
8.5 Post-Run System Bias Check and Drift Assessment.
How do I confirm that each sample I collect is valid? After each run, repeat the system bias check
or 2-point system calibration error check (for dilution systems) to validate the run. Do not make
adjustments to the measurement system (other than to maintain the target sampling rate or
dilution ratio) between the end of the run and the completion of the post-run system bias or
system calibration error check. Note that for all post-run system bias or 2-point system
calibration error checks, you may inject the low-level gas first and the upscale gas last, or vice-
versa. You may risk sampling for multiple runs before performing the post-run bias or system
calibration error check provided you pass this test at the conclusion of the group of runs. A failed
finaltest in this case will invalidate all runs subsequent to the last passed test.
(1) lf you do not pass the post-run system bias (or system calibration error) check, then the run
is invalid. You must diagnose and fix the problem and pass another calibration error test
(Section 8.2.3) and system bias (or 2-point system calibration error) check (Section 8.2.5)
before repeating the run. Record the system bias (or system calibration error) results on a
form similar to Table 7E-2.
METHOD 7E
DETERMINATION OF NITROGEN OXIDES
EMISSIONS FROM STATIONARY SOURCES
(r NSTRU MENTAT ANALYZER pROCEDURE)
Revision 0
L2lLtl2OL3 DENOVO
(2) After each run, calculate the low-level and upscale drift, using Equation 1E-4in Section 12.5.
lf the post-run low- and upscale bias (or 2-point system calibration error) checks are passed,
but the low-or upscale drift exceeds the specification in Section 13.3, the run data are valid,
but a 3-point calibration error test and a system bias (or 2-point system calibration error)
check must be performed and passed before any more test runs are done.
(3) For dilution systems, data from a 3-point system calibration error test may be used to meet
the pre-run 2-point system calibration error requirement for the first run in a test sequence.
Also, the post-run bias (or 2-point calibration error) check data may be used as the pre-run
data for the next run in the test sequence at the discretion of the tester.
8.5 Alternative lnterference and System Bias Checks (Dynamic Spike Procedure). lf I want to use the
dynamic spike procedure to validate my data, what procedure should I follow? Except for
applications under part 75 of this chapter, you may use the dynamic spiking procedure and
requirements provided in Section 16.L during each test as an alternative to the interference
check and the pre- and post-run system bias checks. The calibration error test is still required
under this option. Use of the dynamic spiking procedure for Part 75 applications is subject to the
approval of the Administrator.
8.7 Moisture correction. You must determine the moisture content of the flue gas and correct the
measured gas concentrations to a dry basis using Method 4 or other appropriate methods,
subject to the approval of the Administrator, when the moisture basis (wet or dry) of the
measurements made with this method is different from the moisture basis of either: (1) the
applicable emissions limit; or (2) the CEMS being evaluated for relative accuracy. Moisture
correction is also required if the applicable limit is in lb/mm Btu and the moisture basis of the
Method 7E NOx analyzer is different from the moisture basis of the Method 34 diluent gas (COz
or Oz) analyzer.
9.0 Quality Control
What quality control measures must I take?
The following table is a summary of the mandatory, suggested, and alternative quality assurance and
quality control measures and the associated frequency and acceptance criteria. All of the QC data,
along with the sample run data, must be documented and included in the test report.
Summary Table of qA/aC
Status Process or elemenl QA/QC specification Acceptance criteria Checking frequency
S ldentify Data User Regulatory Agency or other
primary end user of data
lefore designing
:est.
S Analyzer Design {nalyzer resolution
rr sensitivity < 2.O% of full-scale range Vlanufacturer design
M
nterference gas
:heck
lum of responses 32.5o/o of
:a libration spa n Alternatively,
;um of responses:
METHOD 7E
ffil:3,xffI13x,:lx+li[fl],""11?::, lfft'i]ill, lDENOVO
(I NSTRUMENTAL ANALYZER PROCEDURE)
Status Process or elemenl qA/qC specification Acceptance criteria Checking frequency
0.5 ppmv for calibration
pans of 5 to 10 ppmv
( 0.2 ppmv for calibration
;pans < 5 ppmv
lee Table 7E-3
M Calibration Gases
l-racea bi lity protocol
,G1, G2)
/alid certificate required
Jncertainty <2.0% of tag value
M ligh-levelgas qual to the calibration span iach test.
M Vlid-level gas lOto 60% of calibration span iach test,
M -ow-level gas < 20% of calibration span ach test.
S
Data Recorder
Design
)ata resolution < O.5% of full-scale range Vlanufacturer design.
S Sample Extraction )robe material iS or quartz if stack > 500 'F :ast test.
M Sample Extraction
)robe, filter and
;ample line
:emperature
:or dry-basis analyzers, keep
;ample above the dew point by
reating, prior to sample
:onditioning
:ach run.
:or wet-basis analyzers, keep
;ample above dew point at all
:imes, by heating or dilution
S Sample Extraction lalibration valve
naterial JS ach test.
S Sample Extraction iample pump
naterial nert to sample constituents :ach test.
S Sample Extraction Vlanifolding material nert to sample constituents ach test.
S Moisture Removal :quipment efficiency < 5% target com pound removal /erified through
;ystem bias check.
S
Particulate
Removal
:ilter inertness )ass system bias check ach bias check.
M
Analyzer &
Calibration Gas
Performance
\nalyzer calibration
-.rror (of 3-point
;ystem calibration
:rror for dilution
;ystems)
il/ithin 12.0 percent of the
:alibration span of the analyzer
'or the low-, mid-, and high-
evel calibration gases
]efore initial run and
lfter a failed system
:ias test or drift test.
\lternative specification: ( 0.5
rpmv absolute difference
M System
Performance
iystem bias (or pre-
lnd post-run 2-point
;ystem calibration
-'rror for dilution
,Systems)
//ithin !5.0% of the analyzer
:alibration span for low-scale
lnd upscale calibration gases
lefore and after eacl
'un.
METHOD 7E
DETERM!NAT!ON OF NITROGEN OXIDES
EMISSIONS FROM STATIONARY SOURCES
(TNSTRUMENTAL ANALYZER PROCEDURE)
Revision 0
LzlLLlzOts DENOVO
Status Process or elemenl AA/qC specification Acceptance criteria Checking frequency
Alternative specification: < 0.5
cpmv absolute difference
M System
Performance
iystem response
:ime
)etermines minimum sampling
:ime per point
)uring initial
;ampling system bias
est.
M System
Performance )rift
< 3.0% of calibration span for
ow-leveland mid- or high-level
lases
\fter each test run.
\lternative specification: < 0.5
rpmv absolute difference
M System
Performance
\,lOz-NO conversion
-,fficiency
z 90% of certified test gas
:oncentration
3efore or after each
lest.
M System
Performance
)urge time z 2 times system response time
3efore starting the
rirst run and when
crobe is removed
trom and re-inserted
nto the stack.
M System
Performance
Vlinimum sample
:ime at each point
'wo times the system response
ime iach sample point.
M System
Performance
itable sample flow
'ate (surrogate for
naintaining system
'esponse time)
/Uithin 10% of flow rate
:sta blished du ring system
"esponse time check
iach run.
M Sample Point
Selection itratification test \ll points within:)rior to first run.
L5% of mean for 1-point
;ampling
LlO% of mean for 3-point
\lternatively, all points within:
i0.5 ppm of mean for 1-point
;ampling
t1.0 ppm of mean for 3-point
;ampling
A
Multiple sample
points
simultaneously
\lo. of openings in
:robe
Vlulti-hole probe with verifiable
:onstant flow through all holes
ruithin 10% of mean flow rate
,requires Administrative
lpproval for Part 75)
iach run.
M Data Recording :requency < 1 minute average )uring run.
S Data Parameters iample
:oncentration range
\ll 1-minute averages within
:alibration span
iach run.
METHOD 7E
DETERMINATION OF NITROGEN OXIDES
EMISSIONS FROM STATIONARY SOURCES
(t NSTRUMENTAT ANALYZER PROCEDURE)
Revision 0
LzlLtl2ot3 DENOVO
Status Process or elemenl qA/QC specification Acceptance criteria Checking frequency
M Date Parameters
\verage
:oncentration for the
'un
lun average S calibration span ach run.
S = Suggest.
M = Mandatory.
A = Alternative.
Agency.
10.0 Calibration and Standardization
What measurement system calibrations are required?
(L) The initial 3-point calibration error test as described in Section 8.2.3 and the system bias (or
system calibration error) checks described in Section 8.2.5 are required and must meet the
specifications in Section 13 before you start the test. Make all necessary adjustments to calibrate
the gas analyzer and data recorder. Then, after the test commences, the system bias or system
calibration error checks described in Section 8.5 are required before and after each run. Your
analyzer must be calibrated for all species of NOx that it detects. Analyzers that measure NO and
NOz separately without using a converter must be calibrated with both NO and NOz.
(2) You must include a copy of the manufacturer's certification of the calibration gases used in the
testing as part of the test report. This certification must include the 13 documentation
requirements in the EPA Traceability Protocol For Assay and Certification of Gaseous Calibration
Standards, September L997, as amended August 25,1999. When Method 205 is used to produce
diluted calibration gases, you must document that the specifications for the gas dilution system
are met forthe test. You must also include the date of the most recent dilution system calibration
against flow standards and the name of the person or manufacturer who carried out the
calibration in the test report.
11.0 Analytica I Procedu res
Because sample collection and analysis are performed together (see Section 8), additional discussion
of the analytical procedure is not necessary.
12.0 Calculations and Data Analysis
You must follow the procedures for calculations and data analysis listed in this section.
12.1 Nomenclature. The terms used in the equations are defined as follows:
ACE = Analyzer calibration error, percent of calibration span.
Bws = Moisture content of sample gas as measured by Method 4 or other approved method,
percent/100.
Ce,e = Average unadjusted gas concentration indicated by data recorder for the test run,
ppmv.
Co = Pollutant concentration adjusted to dry conditions, ppmv.
Coi, = Measured concentration of a calibration gas (low, mid, or high) when introduced in
direct calibration mode, ppmv.
Cea, = Average effluent gas concentration adjusted for bias, ppmv.
METHOD 7E
DETERMINATION OF NITROGEN OXIDES
EMISSIONS FROM STATIONARY SOURCES
(I NSTRUMENTAL ANALYZER PROCEDURE)
Revision 0
L2ltLl20L3 DENOVO
CM = Average of initial and final system calibration bias (or 2-point system calibration error)
check responses for the upscale calibration gas, ppmv.
Cur = Actual concentration of the upscale calibration gas, ppmv.
CNati,e = NOx concentration in the stack gas as calculated in Section 12.6, ppmv.
Co = Average of the initial and final system calibration bias (or 2-point system calibration
error) check responses from the low-level (or zero) calibration gas, ppmv.
Cor = Actual concentration of the low-level calibration gas, ppmv.
Cs = Measured concentration of a calibration gas (low, mid, or high) when introduced in
system calibration mode, ppmv.
Css = Concentration of NOx measured in the spiked sample, ppmv.
Cspik" = Concentration of NOx in the undiluted spike gas, ppmv.
Cc.r. = Calculated concentration of NOx in the spike gas diluted in the sample, ppmv.
Cv = Manufacturer certified concentration of a calibration gas (low, mid, or high), ppmv.
Cw = Pollutant concentration measured under moist sample conditions, wet basis, ppmv.
CS = Calibration span, ppmv.
D = Drift assessment, percent of calibration span.
DF = Dilution system dilution factor or spike gas dilution factor, dimensionless.
Effruoz - Nozto NO converter efficiency, percent.
NOxco, = The NOx concentration corrected for the converter efficiency, ppmv.
NOxrin,r = The final NOx concentration observed during the converter efficiency test in
Section 76.2.2, ppmv.
NOxpe,r = The highest NOx concentration observed during the converter efficiency test in
Section'J,6.2.2, ppmv.
Qspike = Flow rate of spike gas introduced in system calibration mode, L/min.
Qrot,r = Total sample flow rate during the spike test, L/min.
R = Spike recovery, percent.
SB = System bias, percent of calibration span.
SBi = prs-tr. system bias, percent of calibration span.
SBnnar = Post-run system bias, percent of calibration span.
SCE = System calibration error, percent of calibration span.
SCE; = p;"-rrn system calibration error, percent of calibration span.
SCEp;n31 = Post-run system calibration error, percent of calibration span.
12.2 Analyzer Calibration Error. For non-dilution systems, use Equation 7E-1to calculate the analyzer
calibration error for the low-, mid-, and high-level calibration gases.
ACE :c'i': c' x 1oo Eq.7E - LL)
12.3 System Bias. For non-dilution systems, use Equation 7E-2to calculate the system bias separately
for the low-level and upscale calibration gases.
C" - Cn,-sB-
-x100
Eq.7E-2
C5
METHOD 7E
DETERMINAT!ON OF NITROGEN OXIDES
EMISSIONS FROM STATIONARY SOURCES
(I NSTRUMENTAL ANALYZER PROCEDURE)
Revision 0
LzlLL|20L3 DENOVO
L2.4 System Calibration Error. Use Equation 7E-3 to calculate the system calibration error for dilution
systems. Equation 7E-3 applies to both the initial 3-point system calibration error test and the
subsequent 2-point calibration error checks between test runs. ln this equation, the term "C,"
refers to the diluted calibration gas concentration measured by the analyzer.
SCE =
(CrxDF)-C,x 100 Eq.7E - 3
CS
LD-t-Bws Eq.7E - l0
12.11Calculated Spike Gas Concentration and Spike Recoveryforthe Example Alternative Dynamic
Spiking Procedure in Section 16.1.3. Use EquationTE-LL to determine the calculated spike gas
concentration. Use Equation 7E-12 to calculate the spike recovery.
1-2.5 Drift Assessment. Use Equation lE4lo separately calculate the low-level and upscale drift over
each test run. For dilution systems, replace "SBrinrr" and "SBi" with "SCEFinar" and "SCEi",
respectively, to calculate and evaluate drift.
D : lsBsnor - sBil Eq.7E - 4
12.6 Effluent Gas Concentration. For each test run, calculate Ca,g, the arithmetic average of all valid
NOx concentration values (e.9., 1-minute averages). Then adjust the value of Ca,e for bias using
Equation 7E-5a if you use a non-zero gas as your low-levelcalibration gas, or Equation 7E-5b if
you use a zero gas as your low-level calibration gas.
cco, = (co,n - ,ilW * cut Eq.zE - sa
cco,: (coun - ciPi Eq.TE - sb
LM_Lo
12.7 NOz-NO Conversion Efficiency. lf the NOx converter efficiency test described in Section 8.2.4.1-
is performed, calculate the efficiency using Equation 7E-7.
Ef f,oz =+x 100 Eq.7E - 7
Ly
12.8 NOz-NO Conversion Efficiency Correction. lf desired, calculate the total NOx concentration with
a correction for converter efficiency using Equation 7E-8.
Noxco,, = No * ry#x 100 Eq.7E - B
12.9 Alternative NOz Converter Efficiency. lf the alternative procedure of Section L6.2.2 is used,
determine the NOx concentration decrease from NOxp"ur after the minimum 30-minute test
interval using Equation 7E-9. This decrease from NOxpear must meet the requirement in Section
13.5 for the converter to be acceptable.
o/oDecrease =Y9W*x 1oo Eq.zE - 9
12.10 Moisture Correction. Use Equation 7E-10 if your measurements need to be corrected to a dry
basis.
CW
METHOD 7E
DETERMINATION OF NITROGEN OX!DES
EMISSIONS FROM STATIONARY SOURCES
(r NSTRUMENTAL ANALYZER PROCEDURE)
Revision 0
LzlLLlzOts DENOVO
^ CtrrxeQspuce
Qrotal
R_DF(Css - Cr,totiu") * Lxotir"x L00 Eq.7E - 1,2Cspl*
13.0 Method Performance
13.1 Calibration Error. This specification is applicable to both the analyzer calibration error and the 3-
point system calibration error tests described in Section 8.2.3. At each calibration gas level (low,
mid, and high)the calibration error must either be within + 2.0 percent of the calibration span.
Alternatively, the results are acceptable if lCai, - C, I or IC, - Cu | (as applicable) is <0.5 ppmv.
13.2 System Bias. This specification is applicable to both the system bias and 2-point system
calibration errortests described in Section 8.2.5 and 8.5. The pre- and post-run system bias (or
system calibration error) must be within + 5.0 percent of the calibration span for the low-level
and upscale calibration gases. Alternatively, the results are acceptable if lC, - Coi, I is t 0.5 ppmv
or if lC' - C, I is I 0.5 ppmv (as applicable).
13.3 Drift. For each run, the low-level and upscale drift must be less than or equal to 3.0 percent of
the calibration span. The drift is also acceptable if the pre- and post-run bias (or the pre- and
post-run system calibration error) responses do not differ by more than 0.5 ppmv at each gas
concentration (i.e. I C, post-rrn - C, p,"-,rn I < 0.5 ppmv).
13.4 lnterference Check. The total interference response (i.e., the sum of the interference responses
of all tested gaseous components) must not be greater than 2.50 percent of the calibration span
for the analyzer tested. ln summing the interferences, use the larger of the absolute values
obtained for the interferent tested with and without the pollutant present. The results are also
acceptable if the sum of the responses does not exceed 0.5 ppmv for a calibration span of 5 to
10 ppmv, or 0.2 ppmv for a calibration span < 5 ppmv.
L3.5 NOz to NO Conversion Efficiency Test (as applicable). The NOz to NO conversion efficiency,
calculated according to Equation 7E-7, must be greater than or equal to 90 percent. The
alternative conversion efficiency check, described in Section L6.2.2 and calculated according to
Equation 7E-9, must not result in a decreasefrom Noxp""1 by morethan 2.0 percent.
L3.6 Alternative Dynamic Spike Procedure. Recoveries of both pre-test spikes and post-test spikes
must be within 100 t 10 percent. lf the absolute difference between the calculated spike value
and measured spike value is equal to or less than 0.20 ppmv, then the requirements of the ADSC
are met.
14.0 Pollution Prevention IReserved]
15.0 Waste Management IReserved]
16.0 Alternative Procedures
16.1 Dynamic Spike Procedure. Except for applications under part 75 of this chapter, you may use a
dynamic spiking procedure to validate your test data for a specific test matrix in place of the
interference check and pre- and post-run system bias checks. For part 75 applications, use ofthis
procedure is subject to the approval of the Administrator. Best results are obtained for this
procedure when source emissions are steady and not varying. Fluctuating emissions may render
METHOD 7E
DETERMINATION OF NITROGEN OXIDES
EMISSIONS FROM STATIONARY SOURCES
(r NSTRUMENTAT ANALYZER PROCEDURE)
Revision 0
LzlLtl2OL3 DENOVO
this alternative procedure difficult to pass. To use this alternative, you must meet the following
requirements.
16.1.1 Procedure Documentation. You must detail the procedure you followed in the test report,
including how the spike was measured, added, verified during the run, and calculated after
the test.
16.7.2 Spiking Procedure Requirements. The spikes must be prepared from EPA Traceability
Protocol gases. Your procedure must be designed to spike field samples at two target levels
both before and after the test. Your target spike levels should bracket the average sample
NOx concentrations. The higher target concentration must be less than the calibration span.
You must collect at least 5 data points for each target concentration. The spiking procedure
must be performed before the first run and repeated after the last run of the test program.
16.1.3 Example Spiking Procedure. Determine the NO concentration needed to generate
concentrations that are 50 and 150 percent of the anticipated NOx concentration in the
stack at the total sampling flow rate while keeping the spike flow rate at or below 10 percent
of this total. Use a mass flow meter (accurate within 2.0 percent)to generate these NO spike
gas concentrations at a constant flow rate. Use Equation 7E-Lt in Section L2.tL to
determine the calculated spike concentration in the collected sample.
(1) Prepare the measurement system and conduct the analyzer calibration error test as
described in Sections 8.2.2and 8.2.3. Following the sampling procedures in Section 8.1,
determine the stack NOx concentration and use this concentration as the average stack
concentration (C.,e) for the first spike level, or if desired, for both pre-test spike levels.
lntroduce the first levelspike gas into the system in system calibration mode and begin
sample collection. Wait for at least two times the system response time before
measuring the spiked sample concentration. Then record at least five successive L-
minute averages of the spiked sample gas. Monitor the spike gas flow rate and maintain
at the determined addition rate. Average the five 1-minute averages and determine the
spike recovery using Equation 7E-L2. Repeat this procedure forthe other pre-test spike
level. The recovery at each level must be within the limits in Section 13.6 before
proceeding with the test.
(2) Conduct the number of runs required for the test. Then repeat the above procedure for
the post-test spike evaluation. The last run of the test may serve as the average stack
concentration forthe post-test spike test calculations. The results ofthe post-test spikes
must meet the limits in Section 13.6.
16.2 Alternative NOz to NO Conversion Efficiency Procedures. You may use either of the following
procedures to determine converter efficiency in place of the procedure in Section 8.2.4.1,.
1.6.2.L The procedure for determining conversion efficiency using NO in 40 CFR 86.123-78.
t6.2.2Tedlar Bag Procedure. Perform the analyzer calibration error test to document the
calibration (both NO and NOx modes, as applicable). Fill a Tedlar bag approximately half full
with either ambient air, pure oxygen, or an oxygen standard gas with at least 19.5 percent
by volume oxygen content. Fill the remainder of the bag with mid- to high-level NO in Nz (or
METHOD 7E
DETERMINATION OF NITROGEN OXIDES
EMISSIONS FROM STATIONARY SOURCES
(I NSTRUMENTAL ANALYZER PROCEDURE)
Revision 0
LzltLl20L3 DEI{OVO
other appropriate concentration) calibration gas. (Note that the concentration of the NO
standard should be sufficiently high enough for the diluted concentration to be easily and
accurately measured on the scale used. The size of the bag should be large enough to
accommodate the procedure and time required.)
(1.) lmmediately attach the bag to the inlet of the NOx analyzer (or external converter if
used). ln the case of a dilution-system, introduce the gas at a point upstream of the
dilution assembly. Measurethe NOxconcentrationfora period of 30 minutes.lf the NOx
concentration drops more than 2 percent absolute from the peak value observed, then
the NOz converter has failed to meet the criteria of this test. Take corrective action. The
highest NOx value observed is considered to be NOxp"ur. The final NOx value observed is
considered to be NOxnnrr.
(2) [Reserved]
16.3 Manufacturer's Stability Test, A manufacturer's stability test is required for all analyzers that
routinely measure emissions below 20 ppmv and is optional but recommended for other
analyzers. This test evaluates each analyzer model by subjecting it to the tests listed in Table 7E-
5 following procedures similar to those in 40 CFR 53.23 for thermal stability and insensitivity to
supply voltage variations. lf the analyzer will be used under temperature conditions that are
outside the test conditions in Table B-4 of Part 53.23, alternative test temperatures that better
reflect the analyzer field environment should be used. Alternative procedures or documentation
that establish the analyzer's stability over the appropriate line voltages and temperatures are
acceptable.
17.0 References
17.L "EPA Traceability Protocol for Assay and Certification of Gaseous Calibration Standards"
September 1997 as amended, EPA-600/R-971t21.
18.0 Tables, Diagrams, Flowcharts, and Validation Data
METHOD 10
DETERMINATION OF CARBON MONOXIDE
EMISSIONS FROM STATIONARY SOURCES
(r NSTRUMENTAL ANATYZER PROCEDURE)
Revision 0
L2lLLl20L3 DEI.{0V0
1-.0 Scope and Application
What is Method 10?
Method 10 is a procedure for measuring carbon monoxide (CO) in stationary source emissions using
a continuous instrumental analyzer. Quality assurance and quality control requirements are included
to assure that you, the tester, collect data of known quality. You must document your adherence to
these specific requirements for equipment, supplies, sample collection and analysis, calculations, and
data analysis.
This method does not completely describe all equipment, supplies, and sampling and analytical
procedures you will need but refers to other methods for some of the details. Therefore, to obtain
reliable results, you should also have a thorough knowledge of these additional test methods which
are found in appendix A to this part:
(a) Method 1-Sample and Velocity Traverses for Stationary Sources.
(b) Method 4-Determination of Moisture Content in Stack Gases.
(c) Method 7E-Determination of Nitrogen Oxides Emissions from Stationary Sources (lnstrumental
Analyzer Procedure).
1.1 Analytes. What does this method determine? This method measures the concentration of carbon
monoxide.
Analyte CAS No.Sensitivitv
CO 630-08-0 Tvpicallv <2% of Calibration Span
1.2 Applicability. When is this method required? The use of Method 10 may be required by specific
New Source Performance Standards, State lmplementation Plans, and permits where CO
concentrations in stationary source emissions must be measured, either to determine
compliance with an applicable emission standard or to conduct performance testing of a
continuous emission monitoring system (CEMS). Other regulations may also require the use of
Method 10.
L.3 Data Quality Objectives. Referto Section 1.3 of Method 7E.
2.0 Summary of Method
ln this method, you continuously or intermittently sample the effluent gas and convey the sample to
an analyzer that measures the concentration of CO. You must meet the performance requirements of
this method to validate your data.
3.0 Definitions
Refer to Section 3.0 of Method 7E for the applicable definitions.
4.0 lnterferences
Substances having a strong absorption of infrared energy may interfere to some extent in some
analyzers. lnstrumental correction may be used to compensate for the interference. You may also use
silica gel and ascarite traps to eliminate the interferences. lf this option is used, correct the measured
gas volume for the carbon dioxide (COz) removed in the trap.
5.0 Safety
METHOD 10
DETERMINATION OF CARBON MONOXIDE
EMISSIONS FROM STATIONARY SOURCES
(TNSTRUMENTAL ANALYZER PROCEDURE)
Revision 0
LzlLLl2OLs DENOVO
Refer to Section 5.0 of Method 7E.
5.0 Equipment and Supplies
What do I need for the measurement system?
6.1 Continuous Sampling. Figure 7E-L of Method 7E is a schematic diagram of an acceptable
measurement system. The components are the same as those in Sections 6.1 and 6.2 of Method
7E, except that the CO analyzer described in Section 6.2 of this method must be used instead of
the analyzer described in Section 5.2 of Method 7E. You must follow the noted specifications in
Section 6.1 of Method 7E except that the requirements to use stainless steel, Teflon, or non-
reactive glass filters do not apply. Also, a heated sample line is not required to transport dry gases
or for systems that measure the CO concentration on a dry basis.
6.2 lntegrated Sampling.
6.2.1 Air-Cooled Condenser or Equivalent. To remove any excess moisture.
6.2.2 Valve. Needle valve, or equivalent, to adjust flow rate.
6.2.3 Pump. Leak-free diaphragm type, or equivalent, to transport gas.
6.2.4 Rate Meter. Rotameter, or equivalent, to measure a flow range from 0 to 1.0 liter per minute
(0.035 cfm).
6.2.5 Flexible Bag. Tedlar, or equivalent, with a capacity of 60 to 90 liters (2 to 3 ft3). Leak-test the
bag in the laboratory before using by evacuating with a pump followed by a dry gas meter.
When the evacuation is complete, there should be no flow through the meter.
6.3 What analyzer must I use? You must use an instrument that continuously measures CO in the gas
stream and meets the specifications in Section 13.0. The dual-range analyzer provisions in
Section 6.2.8.L of Method 7E apply.
7.0 Reagents and Standards
T.l Calibration Gas. What calibration gases do I need? Refer to Section 7.L of Method 7E for the
ca libration gas requirements.
7.2 lnterference Check. What additional reagents do I need for the interference check? Use the
appropriate test gases listed in Table 7E-3 of Method 7E (i.e., potential interferents, as identified
by the instrument manufacturer) to conduct the interference check.
8.0 Sample Collection, Preservation, Storage, and Transport Emission Test Procedure
8.1 Sampling Site and Sampling Points. You must follow Section 8.1of Method 7E.
8.2 lnitial Measurement System Performance Tests. You must follow the procedures in Section 8.2 of
Method 7E.lf a dilution-type measurement system is used, the specialconsiderations in Section
8.3 of Method 7E also apply.
8.3 lnterference Check. You must follow the procedures of Section 8.2.7 of Method 7E.
8.4 Sample Collection.
8.4.1 Continuous Sampling. You must follow the procedures of Section 8.4 of Method 7E.
8.4.2 lntegrated Sampling. Evacuate the flexible bag. Set up the equipment as shown in Figure 10-
1 with the bag disconnected. Place the probe in the stack and purge the sampling line.
Connect the bag, making sure that all connections are leak-free. Sample at a rate
proportional to the stack velocity. lf needed, the COz content of the gas may be determined
METHOD 10
DETERMINATION OF CARBON MONOXIDE
EMISSIONS FROM STATIONARY SOURCES
(r NSTRUMENTAT ANALYZER PROCEDURE)
Revision 0
L2lLrlzot3 DENOVO
by using the Method 3 integrated sample procedures, or by weighing an ascarite COz
removal tube used and computing COz concentration from the gas volume sampled and the
weight gain of the tube. Data may be recorded on a form similar to Table 10-1.
8.5 Post-Run System Bias Check, Drift Assessment, and Alternative Dynamic Spike Procedure. You
must follow the procedures in Sections 8.5 and 8.6 of Method 7E.
9.0 Quality Control
Follow the quality control procedures in Section 9.0 of Method 7E.
10.0 Calibration and Standardization
Follow the procedures for calibration and standardization in Section 10.0 of Method 7E.
11.0 Analytical Procedures
Because sample collection and analysis are performed together (see Section 8), additional discussion
of the analytical procedure is not necessary.
L2.0 Calculations and Data Analysis
You must follow the procedures for calculations and data analysis in Section 12.0 of Method 7E, as
applicable, substituting CO for NOx as applicable.
12.1 Concentration Correction for COz Removal. Correct the CO concentration for COz removal (if
applicable) using Eq. 10-1.
Ct s = Cco rtort(7 - Fcor) 8q.10 - 1,
Where:
Ca,g = 4vsrate gas concentration for the test run, ppm.
Cco stack = Average unadjusted stack gas CO concentration indicated by the data recorder for
the test run, ppmv.
Fcoz = Volume fraction of COz in the sample, i.e., percent COz from Orsat analysis divided by
100.
13.0 Method Performance
The specifications for analyzer calibration error, system bias, drift, interference check, and alternative
dynamic spike procedure are the same as in Section 13.0 of Method 7E.
14.0 Pollution Prevention IReserved]
15.0 Waste Management IReserved]
16.0 Alternative Procedu res
The dynamic spike procedure and the manufacturer stability test are the same as in Sections 16.L and
15.3 of Method 7E
17.0 References
1-1.'J. "EPA Traceability Protocol for Assay and Certification of Gaseous Calibration Standards"
September 1997 as amended, EPA-6A0{R-97lLzL
18.0 Tables, Diagrams, Flowcharts, and Validation Data
METHOD 19
DETERMINATION OF SUTFUR DIOXIDE
REMOVAL EFF!CIENCY AND PARTICULATE
MATTER, SULFUR DIOXIDE, AND NITROGEN
OXIDE EMISSION RATES
Revision 0
L2ILL|aOL3 DEI\IOVO
L.0 Scope and Application
1.L Analytes. This method provides data reduction procedures relating to the following pollutants,
but does not include any sample collection or analysis procedures.
Analwe CAS No.Sensitivity
Nitrogen oxides (NOx), includine
Nitric oxide (NO)10102-43-9 N/A
Nitrogen dioxide (NOz)70702-44-O
Particulate matter (PM)None assiened N/A
Sulfur dioxide (SOz)7499-09-0s N/A
1.2 Applicability. Where specified by an applicable subpart of the regulations, this method is
applicable for the determination of (a) PM, SO2, and NOx emission rates; (b) sulfur removal
efficiencies of fuel pretreatment and SOz control devices; and (c) overall reduction of potential
SOz emissions.
2.0 Summary of Method.
2.1 Emission Rates. Oxygen (Oz) or carbon dioxide (COz) concentrations and appropriate F factors
(ratios of combustion gas volumes to heat inputs) are used to calculate pollutant emission rates
from pollutant concentrations.
2.2 Sulfur Reduction Efficiency and SOu Removal Efficiency. An overall SOz emission reduction
efficiency is computed from the efficiency of fuel pretreatment systems, where applicable, and
the efficiency of SOz control devices.
2.2.LThe sulfur removal efficiency of a fuel pretreatment system is determined by fuel sampling
and analysis of the sulfur and heat contents of the fuel before and after the pretreatment
system.
2.2.2fhe SOz removal efficiency of a control device is determined by measuring the SOz rates
before and after the control device.
2.2.2.7 The inlet rates to SOz control systems (or, when SOz control systems are not used, SOz
emission rates to the atmosphere) are determined by fuel sampling and analysis.
3.0 Definitions. IReserved]
4.0 lnterferences. IReserved]
5.0 Safety. IReserved]
6.0 Equipment and Supplies. IReserved]
7.0 Reagents and Standards. IReserved]
8.0 Sample Collection, Preservation, Storage, and Transport. IReserved]
9.0 Quality Control, IReserved]
10.0 Calibration and Standardization. IReserved]
11.0 Analytica I Procedures. IReserved]
12.0 Data Analysis and Calculations.
l2.L Nomenclature.
B*a = Moisture fraction of ambient air, percent.
METHOD 19
DETERMINATION OF SULFUR D!OX!DE
REMOVAL EFFIC! ENCY AND PARTICULATE
MATTER, SULFUR DIOXIDE, AND NITROGEN
OXIDE EM!SS!ON RATES
Revision 0
LzlLLlzOLs DENOVO
B*, = Moisture fraction of effluent gas, percent.
%C = Concentration of carbon from an ultimate analysis of fuel, weight percent.
Co = Pollutant concentration, dry basis, ng/scm (lb/scf).
%oCOza,%oCOz* = Concentration of carbon dioxide on a dry and wet basis, respectively,
percent.
C* = Pollutant concentration, wet basis, ng/scm (lb/scf).
D = Number of sampling periods during the performance test period.
E = Pollutant emission rate, ngf ) (lb/million Btu).
E, = Average pollutant rate for the specified performance test period, nCl (lb/million Btu).
Ero, Eri = Average pollutant rate of the control device, outlet and inlet, respectively, for
the performance test period, ng/J (lb/million Btu).
Eui = Pollutant rate from the steam generating unit, ng/J (lb/million Btu)
Euo = Pollutant emission rate from the steam generating unit, ngfl (lb/million Btu).
Eci = Pollutant rate in combined effluent, nC/J (lb/million Btu).
E.o = Pollutant emission rate in combined effluent, ng/J (lb/million Btu).
Eo = Average pollutant rate for each sampling period (e.g.,24-hr Method 68 sample or 24-
hrfuelsample) orforeach fuel lot (e.g., amount of fuel bunkered), ng! (lb/million
Btu).
Eai = Average inlet SOz rate for each sampling period d, ng/) (lb/million Btu)
Ee = Pollutant rate from gas turbine, ne/J (lb/million Btu).
Eru = Daily geometric average pollutant rale, ng/J (lbs/million Btu) or ppm corrected to 7
percent Oz.
Eio,Eii = Matched pair hourly arithmetic average pollutant rate, outlet and inlet,
respectively, ng/J (lb/million Btu) or ppm corrected to 7 percent 02.
Er, = Hourly average pollutant, ngiJ (lb/million Btu).
E6; = Hourly arithmetic average pollutant rate for hour "j," nC/J (lb/million Btu) or ppm
corrected to 7 percent 02.
EXP = Natural logarithmic base (2.718) raised to the value enclosed by brackets.
Fd, F*, F. = Volumes of combustion components per unit of heat content, scm/J
(scf/million Btu).
GCV = Gross calorific value of the fuel consistent with the ultimate analysis, kJ/ke (Btu/lb).
GCVp, GCV, = Gross calorific value for the product and raw fuel lots, respectively, dry basis,
kJlke (Btu/lb).
%H = Concentration of hydrogen from an ultimate analysis of fuel, weight percent.
H = Total number of operating hours for which pollutant rates are determined in the
performance test period.
Hu = Heat input rate to the steam generating unit from fuels fired in the steam generating
unit, J/hr (million Btu/hr).
METHOD 19
DETERMINATION OF SULFUR DIOXIDE
REMOVAL EFFICIENCY AND PARTICULATE
MAfiER, SULFUR D!OXIDE, AND NITROGEN
OXIDE EMISSION RATES
Revision 0
LzlLLl20L3 DEI\IOVO
Hc = Heat input rate to gas turbine from all fuels fired in the gas turbine, J/hr (million
Btu/hr).
%oHzO= Concentration of water from an ultimate analysis of fuel, weight percent.
Hr=Total numbersof hoursintheperformancetestperiod (e.9.,720 hoursfor30-day
performa nce test period).
K = Conversion factor, lOs (W/J)/(%) [106 Btu/million Btu].
K. = (9.57 scmlke)/% l(L.s3 scf /lb)l%l.
K.. = (2.0 scmlke)l% [(0.321 scf llb)/'/"].
K16= (22.7 scmlke)l% 18.64 scf llb)1"/"1.
(6* = (34.74 scm/ke)/% l(s.st scf /tbl/%l.
Kn = (0.86 scm/kg)/o/" l(o.1,a sct/lbl/%).
Ko = (2.85 scmlke\l% l@.46 scf llb\/o/"|.
6, = (3.54 scm/kgl/o/o l(0.57 scf /lb)/%|.
6* = (1.30 scm/kc)/%l(0.21scf /lbl/%|.
ln = Natural log of indicated value.
Lo, L, = Weight of the product and raw fuel lots, respectively, metric ton (ton).
%N = Concentration of nitrogen from an u ltimate analysis of fuel, weight percent.
N = Number of fuel lots during the averaging period.
n = Number of fuels being burned in combination.
na = Number of operating hours of the affected facility within the performance test period
for each Eo determined.
nt = Total number of hourly averages for which paired inlet and outlet pollutant rates are
available within the 24-hr midnight to midnight daily period.
%O = Concentration of oxygen from an ultimate analysis of fuel, weight percent.
%oOza, %oO2* = Concentration of oxygen on a dry and wet basis, respectively, percent.
P, = Potential SOz emissions, percent.
%R1 = $6, removal efficiency from fuel pretreatment, percent.
%R, = 59, removal efficiency of the control device, percent.
o/oRg" = Daily geometric average percent reduction.
%Ro - Overall SOz reduction, percent.
%S = Sulfur content of as-fired fuel lot, dry basis, weight percent.
S" = Standard deviation of the hourly average pollutant rates for each performance test
period, nelJ (lb/million Btu).
%St = f6n."ntration of sulfur from an ultimate analysis of fuel, weight percent.
Si = Standard deviation of the hourly average inlet pollutant rates for each performance
test period, ngl (lb/million Btu).
So = Standard deviation of the hourly average emission rates for each performance test
period, nelJ (lblmillion Btu).
METHOD 19
DETERMINATION OF SULFUR DIOXIDE
REMOVAL EFFICIENCY AND PARTICULATE
MATTER, SULFUR DIOXIDE, AND NITROGEN
OX!DE EMISSION RATES
Revision 0
LzlLLl20L3 DENOVO
yosp, yos, = Sulfur content of the product and raw fuel lots respectively, dry basis, weight
percent.
to.ss = Values shown in Table 19-3 for the indicated number of data points n.
Xr = Fraction of total heat input from each type of fuel k.
12.2 Emission Rates of PM, SOz, and NOx. Select from the following sections the applicable procedure
to compute the PM, SOz, or NOx emission rate (E) in ngl (lb/million Btu). The pollutant
concentration must be in ng/scm (lb/scf) and the F factor must be in scmfl (scf/million Btu). lf
the pollutant concentration (C) is not in the appropriate units, use Table 19-1 in Section 17.0 to
make the proper conversion. An F factor is the ratio of the gas volume of the products of
combustion to the heat content of the fuel. The dry F factor (Fo) includes all components of
combustion less water, the wet F factor (F*) includes all components of combustion, and the
carbon F factor (F.) includes only carbon dioxide.
NOTE: Since F* factors include water resulting only from the combustion of hydrogen in the fuel,
the procedures using F*factors are not applicableforcomputing E from steam generating units
with wet scrubbers or with other processes that add water (e.g., steam injection).
L2.2.t Oxygen-Based F Factor, Dry Basis. When measurements are on a dry basis for both O (%Oza)
and pollutant (Co) concentrations, use the following equation:
20.9
E : caFa @g - "/ro,)
Eq'79 - |
L2.2.2 Oxygen-Based F Factor, Wet Basis. When measurements are on a wet basis for both Oz
(o/oO2*) and pollutant (C*) concentrations, use either of the following:
L2.2.2.L lf the moisture fraction of ambient air (B*,) is measured:
lnstead of actual measurement, B*" may be estimated according to the procedure
below.
20.9
E = C*F*120.9(7-B*o)-o/oo2*f
8q.L9 - 2
NOTE: The estimates are selected to ensure that negative errors will not be larger than
-1.5 percent. However, positive errors, or over-estimation of emissions by as much as
5 percent may be introduced depending upon the geographic location of the facility
and the associated range of ambient moisture.
12.2.2.1.7 B*u = 0.027. This value may be used at any location at all times.
12.2.2.t.2 B*. = Highest monthly average of B*, that occurred within the previous
calendar year at the nearest Weather Service Station. This value shall be
determined annually and may be used as an estimate for the entire current
calendar year.
!2.2.2.L.3 B*. = Highest daily average of B*. that occurred within a calendar month at the
nearest Weather Service Station, calculated from the data from the past 3 years.
METHOD 19
DETERM!NATION OF SULFUR DIOXIDE
REMOVAT EFFIC!ENCY AND PARTICULATE
MATTER, SUTFUR DIOXIDE, AND NITROGEN
OXIDE EMISSION RATES
Revision 0
L2lLLlzOLs DENOVO
This value shall be computed for each month and may be used as an estimate
for the current respective calendar month.
L2.2.2.2|f the moisture fraction (B*,) of the effluent gas is measured:
20.9
E = C*Fa
120.9 (1, - B-.,) - o/oo2*l Eq.19 - 3
12.2.3 Oxygen-Based F Factor, Dry/Wet Basis.
12.2.3.LWhen the pollutant concentration is measured on a wet basis (C*) and Oz
concentration is measured on a dry basis (%Oza), use the following equation:
E_(cwFi(20.e)
Eq.79 - 4
('1. - Bw)(20.9 - o/oo2a)
t2.2.3.2When the pollutant concentration is measured on a dry basis (Ca) and the Oz
concentration is measured on a wet basis (%Oz*), use the following equation:
cdFd20.9 8q.19 - 5
1.2.2.4 Carbon Dioxide-Based F Factor, Dry Basis. When measurements are on a dry basis for both
COz (%COza) and pollutant (Co) concentrations, use the following equation:
100E = CaFc or*o* Eq.19 - 6
!2.2.5 Carbon Dioxide-Based F Factor, Wet Basis. When measurements are on a wet basis for
both COz (%COz*) and pollutant (C,) concentrations, use the following equation:
100
E = C*F,q75; Eq.]9 - 7
t2.2.6 Carbon Dioxide-Based F Factor, Dry/Wet Basis.
t2.2.6.LWhen the pollutant concentration is measured on a wet basis (C*) and COu
concentration is measured on a dry basis (%COza), use the following equation:
E_crF, 100 Eq.79 - B(1 - B.,r) o/oC02a
L2.2.6.2When the pollutant concentration is measured on a dry basis (Co) and COz
concentration is measured on a wet basis (%COz*), use the following equation:
100
E = CaFr(l - Br,rzr) o/ocor* Eq.19 - 9
12.2.7 Direct-Fired Reheat Fuel Burning. The effect of direct-fired reheat fuel burning (for the
purpose of raising the temperature of the exhaust effluent from wet scrubbers to above the
moisture dew-point) on emission rates will be less than 1.0 percent and, therefore, may be
ignored.
12.2.8 Combined Cycle-Gas Turbine Systems. For gas turbine-steam generator combined cycle
systems, determine the emissions from the steam generating unit orthe percent reduction
in potential SOz emissions as follows:
12.2.8.1. Compute the emission rate from the steam generating unit using the following
equation:
METHOD 19
DETERM!NATION OF SULFUR DIOXIDE
REMOVAT EFFIC! ENCY AND PARTICUTATE
MATTER, SUTFUR DIOXIDE, AND NITROGEN
OXIDE EMISSION RATES
Revision 0
LalLLl20L3 DEI{OVO
Ebo: ,," *H(8,. - En) Eq.t9 - ro
12.2.8.1.1Use the test methods and procedures section of 40 CFR Part 60, Subpart GG to
obtain E.o and Es. Do not use F* factors for determining E, or E.o. lf an SOz control
device is used, measure E.o after the control device.
12.2.8.1..2 Suitable methods shall be used to determine the heat input rates to the steam
generating units (Hu) and the gas turbine (Hr).
12,2.8.2|f a control device is used, compute the percent of potential SOz emissions (P.) using
the following equations:
Eni: Eci +ffG,, - en) Eq.1.e - tt
Ps = 1oo U -'#) Eq.Le - 1-Z
NOTE: Use the test methods and procedures section of Subpart GG to obtain Eci ?nd
Er. Do not use F* factors for determining E, or E.;.
12.3 F Factors. Use an average F factor according to Section 12.3.1or determine an applicable F factor
according to Section 12.3.2.|f combined fuels are fired, prorate the applicable F factors using the
procedure in Section 723.3.
12.3.I Average F Factors. Average F factors (Fo, F*, or F.)from Table 19-2 in Section 17.0 may be
used.
1,2.3.2 Determined F Factors. lf the fuel burned is not listed in Table L9-2 or if the owner or
operator chooses to determine an F factor rather than use the values in Table 1,9-2, use the
procedure below:
I2.3.2.1, Equations. Use the equations below, as appropriate, to compute the F factors:
Fd-K (K1ao/oH * Kro/oC I Kro/oS I Kno/oN - Kol/oo)Eq.l9 - 13
GCV
Fa:K(K1*o/oH * Kro/oC * Kro/oS I Kno/oN - Koo/oo * K-o/oH2O)Eq.l9 - 14
GCV*
K ( K..o/oC\
F, = -=;;i- Eq.1e - 1,5
NOTE: Omit the %HzO term in the equations for F* if %oH and %O include the
unavailable hydrogen and oxygen in the form of HzO.)
12.3.2.2 Use applicable sampling procedures in Section 72.5.2.7 or 72.5.2.2 to obtain samples
for analyses.
METHOD 19
DETERMINATION OF SUTFUR DIOXIDE
REMOVAL EFFICIENCY AN D PARTICULATE
MATTER, SULFUR DIOXIDE, AND NITROGEN
OXIDE EMISSION RATES
Revision 0
L2ltLlzOLs DEI\IOVO
12.3.2.3 Use ASTM D 3176-74 or 89 (all cited ASTM standards are incorporated by reference-
see $60.17) for ultimate analysis of the fuel.
12.3.?.4 Use applicable methods in Section 12.5.2.Lor 12.5.2.2 to determine the heat content
of solid or liquid fuels. For gaseous fuels, use ASTM D 1826-77 or 94 (incorporated by
reference-see $50.17)to determine the heat content.
L2.3.3 F Factors for Combination of Fuels. lf combinations of fuels are burned, use the following
equations, as applicable unless othenauise specified in an applicable subpart:
,":;(x*Fa) Eq.1.e - t6
k=r
Fw-Eq.19 - 1.7
12.4 Determination of Average Pollutant *.,:;:
L2.4.1, Average Pollutant Rates from Hourly Values. When hourly average pollutant rates (Er,),
inlet or outlet, are obtained (e.g., CEMS values), compute the average pollutant rate (E") for
the performance test period (e.g., 30 days) specified in the applicable regulation using the
following equation:
1 +E"=ELEni Eq.t9-1.9
j=t
12.4.2 Average Pollutant Rates from Other than Hourly Averages. When pollutant rates are
determined from measured values representing longer than L-hour periods (e.g., daily fuel
sampling and analyses or Method 68 values), or when pollutant rates are determined from
combinations of L-hour and longer than 1-hour periods (e.g., CEMS and Method 58 values),
compute the average pollutant rate (E,) for the performance test period (e.g., 30 days)
specified in the applicable regulation using the following equation:
2?=.,(nnE,),Eo=-# 8q.19-20
L j=t ILd j
12.4.3 Daily Geometric Average Pollutant Rates from Hourly Values. The geometric average
pollutant rate (Eea) is computed using the following equation:
Eso =,*f[r,,(r^,)l] Eq.1.e - 21.
12.5 Determination of Overall Reduction in Potential Sulfur Dioxide Emission.
F
/(xxF*x)
k=7
4:I(x*F,*) Eq.te-t8
METHOD 19
DETERMINATION OF SULFUR DIOXIDE
REMOVAL EFFICIENCY AND PART!CULATE
MATTER, SULFUR DIOXIDE, AND NITROGEN
OXIDE EM!SS!ON RATES
Revision 0
tzlLtl20t3 ,DENOVO
72.5.1Overall Percent Reduction. Compute the overall percent SOz reduction (%Ro) using the
following equation:
o/oRo: roo [r o - (,.0 -ffi)(r o -{lff)] Eq.1.e -22
L2.5.2 Pretreatment Removal Efficiency (Optional). Compute the SOz removal efficiency from fuel
pretreatment (%Rr) for the averaging period (e.g., 90 days) as specified in the applicable
regulation using the following equation:
Eq.19 - 23
NOTE: ln calculating %Rr, include %S and GCV values for all fuel lots that are not pretreated
and are used during the averaging period.
12.5.2.1. Solid Fossil (lncluding Waste) Fuel-Sampling and Ana lysis.
NOTE: For the purposes of this method, raw fuel (coal or oil) is the fuel delivered to
the desulfurization (pretreatment) facility. For oil, the input oil to the oil
desulfurization process (e.g., hydrotreatment) is considered to be the raw fuel.
12.5.2.L.L Sample lncrement Collection. Use ASTM D 2234-76, 96, 97a, or 98
(incorporated by reference-see 560.17), Type l, Conditions A, B, or C, and
systematic spacing. As used in this method, systematic spacing is intended to
include evenly spaced increments in time or increments based on equal weights
of coal passing the collection area. As a minimum, determine the number and
weight of increments required per gross sample representing each coal lot
according to Table 2 or Paragraph 7.L.5.2 of ASTM D 2234. Collect one Bross
sample for each lot of raw coal and one gross sample for each lot of product coal.
12.5.2.L.2 ASTM Lot Size. For the purpose of Section !2.5.2 (fuel pretreatment), the lot
size of product coal is the weight of product coalfrom one type of raw coal. The
lot size of raw coal is the weight of raw coal used to produce one lot of product
coal. Typically, the lot size is the weight of coal processed in a L-day (24-hour)
period. lf more than one type of coal is treated and produced in 1 day, then gross
samples must be collected and analyzed for each type of coal. A coal lot size
equaling the 90-day quarterly fuel quantity for a steam generating unit may be
used if representative sampling can be conducted for each raw coal and product
coal.
NOTE: Alternative definitions of lot sizes may be used, subject to prior approval
of the Administrator.
12.5.2.L.3 Gross Sample Analysis. Use ASTM D 2013-72 or 86 to prepare the sample,
ASTM D 3177-75 or 89 or ASTM D 4239-85,94, or 97 to determine sulfur content
METHOD 19
DETERMINATION OF SULFUR DIOXIDE
REMOVAL EFFIC! ENCY AND PARTICULATE
MATTER, SULFUR DIOXIDE, AND NITROGEN
OXIDE EMISSION RATES
Revision 0
LzlLL{20L3 DENOVO
(%S), ASTM D 3t73-73 or 87 to determine moisture content, and ASTM D 2015-
77 (Reapproved 1978) or 96, D 3286-85 or 95, or D 5865-98 or L0 to determine
gross calorific value (GCV) (all standards cited are incorporated by reference-see
S60.17 for acceptable versions of the standards) on a dry basis for each gross
sample.
12.5.2.2 Liquid Fossil Fuel-Sampling and Analysis. See Note under Section 12.5.2.1,.
12.5.2.2.1Sample Collection. Follow the procedures for continuous sampling in ASTM D
270 or D 4177-95 (incorporated by reference-see 560.17) for each gross sample
from each fuel lot.
12.5.2.2.2 Lot Size. For the purpose of Section 12.5.2 (fuel pretreatment), the lot size of a
product oil is the weight of product oil from one pretreatment facility and
intended as one shipment (ship load, barge load, etc.). The lot size of raw oil is
the weight of each crude liquid fuel type used to produce a lot of product oil.
NOTE: Alternative definitions of lot sizes may be used, subject to prior approval
of the Administrator.
72.5.2.2.3 Sample Analysis. Use ASTM D L29-64,78, or 95, ASTM D 1552-83 or 95, or
ASTM D 4057-81 or 95 to determine the sulfur content (%S) and ASTM D 240-76
or 92 (all standards cited are incorporated by reference-see 560.17) to
determine the GCV of each gross sample. These values may be assumed to be on
a dry basis. The owner or operator of an affected facility may elect to determine
the GCV by sampling the oil combusted on the first steam generating unit
operating day of each calendar month and then using the lowest GCV value of
the three GCV values per quarter for the GCV of all oil combusted in that calendar
quarter.
72.5.2.3 Use appropriate procedures, subject to the approval of the Administrator, to
determine the fraction of total mass input derived from each type of fuel.
12.5.3 Control Device Removal Efficiency. Compute the percent removal efficiency (%Rs) of the
control device using the following equation:
o/oRo = roo (r.o - k) Eq.Le - 24Y \ Eoi/
12.5.3.L Use continuous emission monitoring systems or test methods, as appropriate, to
determine the outlet SOz rates and, if appropriate, the inlet SOz rates. The rates may
be determined as hourly (Er) or other sampling period averages (Ea). Then, compute
the average pollutant rates for the performance test period (E.o and E.i) using the
procedures in Section 12.4.
12.5.3.2 As an alternative, as-fired fuelsampling and analysis may be used to determine inlet
SOz rates as follows:
12.5.3.2.1. Compute the average inlet SOz rate (Eoi) for each sampling period using the
following equation:
METHOD 19
DETERMINATION OF SULFUR DIOXIDE
REMOVAL EFF!C!ENCY AND PART!CULATE
MATTER, SULFUR DIOXIDE, AND NITROGEN
OXIDE EMISSION RATES
Revision 0
LzlLtl2Ot3 OENOVO
so,: KH Eq'te-25
Where:
K:2"'*(wx?) G*^)
[z'roo(d)(#*)Gna))
After calculating Eoi, use the procedures in Section 12.41o determine the average
inlet SOz rate for the performance test period (E.i).
L2.5.3.2.2Collect the fuel samples from a location in the fuel handling system that
provides a sample representative of the fuel bunkered or consumed during a
steam generating unit operating day. For the purpose of as-fired fuel sampling
under Section 12.5.3.2 or Section 12.6, the lot size for coal is the weight of coal
bunkered or consumed during each steam generating unit operating day. The lot
size for oil is the weight of oil supplied to the "day" tank or consumed during
each steam generating unit operating day. For reporting and calculation
purposes, the gross sample shall be identified with the calendar day on which
sampling began. For steam generating unit operating days when a coal-fired
steam generating unit is operated without coal being added to the bunkers, the
coal analysis from the previous "as bunkered" coal sample shall be used until
coal is bunkered again. For steam generating unit operating days when an oil-
fired steam generating unit is operated without oil being added to the oil "day"
tank, the oil analysis from the previous day shall be used until the "day" tank is
filled again. Alternative definitions of fuel lot size may be used, subject to prior
approval of the Administrator.
12.5.3.2.3 Use ASTM procedures specified in Section 12.5.2.Lor !2.5.2.21o determine %S
and GCV.
ly Values. The geometric average
equation:
II Eq.L9 - 26
l
NOTE: The calculation includes only paired data sets (hourly average)forthe inlet and outlet
pollutant measurements.
1.2.6 Sulfur Retention Credit for Compliance Fuel. lf fuel sampling and analysis procedures in Section
12.5.2.L are being used to determine average SOz emission rates (Err) to the atmosphere from a
coal-fired steam generating unit when there is no SO2 control device, the following equation may
be used to adjust the emission rate for sulfur retention credits (no credits are allowed for oil-
fired systems) (Eai) for each sampling period using the following equation:
METHOD 19
DETERMINATION OF SULFUR D!OX!DE
REMOVAL EFFICIENCY AND PARTICULATE
MATTER, SULFUR DIOXIDE, AND NITROGEN
OXIDE EMISSION RATES
Revision 0
L2lLLlzOts DENOVO
Eat = o.97KH Eq.L9 - 27
GDV
Where:
K=2"rc'(w)(7) (h)
lz'rcn(-q;)(,n-L,,,*nrrux6ar)]
After calculating Eoi, use the procedures in Section t2.4.2 to determine the average SOz emission
rate to the atmosphere for the performance test period (E,o).
12.7 Determination of Compliance When Minimum Data Requirement ls Not Met.
12.7.L Adjusted Emission Rates and ControlDevice RemovalEfficiency. When the minimum data
requirement is not met, the Administrator may use the following adjusted emission rates or
control device removal efficiencies to determine compliance with the applicable standards.
12.7.1,.t Emission Rate. Compliance with the emission rate standard may be determined by
using the lower confidence limit of the emission rate (E,o') as follows:
Eio: Eao - to.ssso 8q.79 - 28
12.7.t.2 Control Device Removal Efficiency. Compliance with the overall emission reduction
(%R") may be determined by using the lower confidence limit of the emission rate
(Euo') and the upper confidence limit of the inlet pollutant rate (Eai') in calculating the
control device removal efficiency (%Rr) as follows:
o/oRn : roo (r.o -'*) Eq.re - ze
Eii = Eri * to.sss, Eq'19 - 30
12.7.2 Standard Deviation of Hourly Average Pollutant Rates. Compute the standard deviation (Su)
of the hourly average pollutant rates using the following equation:
Eq.l9 - 3L
Equation 19-19 through 19-31 may be used to compute the standard deviation for both the
outlet (S") and, if applicable, inlet (Si) pollutant rates.
13.0 Method Performance. IReserved]
14.0 Pollution Prevention. IReserved]
L5.0 Waste Management. IReservedj
16.0 References. IReserved]
17.0 Tables, Diagrams, Flowcharts, and Validation Data.
L'l=r(rni- c,)'
METHOD 19
DETERMINATION OF SULFUR DIOXIDE
REMOVAL EFFIC!ENCY AND PARTICULATE
MATTER, SULFUR DIOXIDE, AND NITROGEN
OXIDE EMISSION RATES
Revision 0
LzlLLl2OL3 OENOVO
From To Multiply by
g/scm ng/scm 10e
ms/scm nglscm 1,06
lblscf ng/scm 1.502 x 1013
00m SOz ns/scm 2.66 x 106
ppm NOx nslscm 1.91"2 x l-06
ppm SOz lblscf 1.550 x 10'7
ppm NOx lblscf t,194 x tO'7
Table 19-1-Conversion Factors for Concentration
Fuel Tvoe
Fa F*F.
dscm/J dscf/105 Btu wscm/J wscf/106 Btu scm/scf/105 Btu
Coal:
Anthracite2 2.7Lx1O7 10,L00 2.83 x 10-7 10,540 0.530 x 10 7 1,97O
Bituminous2 2.63 xtO'7 9,780 2,86 x !O'7 10,640 0.484 x 107 1",800
Lienite 2.65 x 10 7 9,850 3.21x1O7 11,950 0.513 x 10 7 1,910
oi13 2.47 xLOT 9,1_90 2.77 x 107 10,320 0.383 x 10 7 L,420
Gas:
Natural 2.34 x LO7 8,770 2.85 x 10 7 10,610 0.287 xLO'7 1,040
Propane 2.34 x LO-l 8,710 2.74 x 1O'1 1,0,200 O.32Lx LO7 1,190
Butane 2.34 x LO7 8,770 2.79 x tO7 l-0,390 0.337 x 10 ?1,25O
Wood 2.48 x LOl 9,240 0.492x lO'7 1,830
Wood Bark 2.58 x 10-7 9,600 0.51"6 x 10-7 !,92O
Municipal 2,57 x]-;O'7 9,570 0.488 x 10-7 t,820
Solid Waste
Table 19-2-F Factors for Various Fuelsl
lDetermined at standard conditions: 20 "C (58 'F) and 760 mm He (29.92 in Hg)
2As classified according to ASTM D 388.
3Crude, residual, or distillate.
Table 19-3-Values for T6.e5.
lThe values of this table are corrected for n-L degrees of freedom. Use n equal to the number (H) of
hourly average data points.
nl to.gs n1 to.gs n1 to.gs
2 5.31 8 1.89 22-26 L.77
3 2.42 9 1.86 27-3L L.70
4 2.35 10 1.83 32-5L 1.58
5 2.L3 11 1.81 52-9t 1.67
6 2.O2 12-16 1.77 92-1.5t 1.66
7 1.94 17-27 1.73 l-52 or more 1.55
METHOD 25A
DETERMINATION OF TOTAL GASEOUS
ORGANIC CONCENTRATION USING A FLAME
IONIZATION ANALYZER
Revision 0
L2lLLlzOLs DEI{OVO
1.0 Scope and Application.
L.1Analytes.
Analyte CAS No.Sensitivitv
Total Orga nic Com pou nds N/A < 2% of span.
1.2 Applicability. This method is applicable for the determination of total gaseous organic
concentration of vapors consisting primarily of alkanes, alkenes, and/or arenes (aromatic
hydrocarbons). The concentration is expressed in terms of propane (or other appropriate organic
calibration gas) or in terms of carbon.
1.3 Data Quality Objectives. Adherence to the requirements of this method willenhance the quality
of the data obtained from air pollutant sampling methods.
2.0 Summary of Method.
2.1- A gas sample is extracted from the source through a heated sample line and glass fiber filter to a
flame ionization analyzer (FlA). Results are reported as volume concentration equivalents of the
calibration gas or as carbon equivalents.
3.0 Definitions.
3.1 Calibration drift means the difference in the measurement system response to a mid-level
calibration gas before and after a stated period of operation during which no unscheduled
maintenance, repair, or adjustment took place.
3.2 Calibration error means the difference between the gas concentration indicated by the
measurement system and the know concentration of the calibration gas.
3.3 Calibration gas means a known concentration of a gas in an appropriate diluentgas.
3.4 Measurement system means the total equipment required for the determination of the gas
concentration. The system consists of the following major subsystems:
3.4.1 Sample interface means that portion of a system used for one or more of the following:
sample acquisition, sample transportation, sample conditioning, or protection of the
analyzer(s)from the effects of the stack effluent.
3.4.2 Organic analyzer means that portion of the measurement system that senses the gas to be
measured and generates an output proportional to its concentration.
3.5 Response time means the time intervalfrom a step change in pollutant concentration at the inlet
to the emission measurement system to the time at which 95 percent of the corresponding final
value is reached as displayed on the recorder.
3.6 Span Value means the upper limit of a gas concentration measurement range that is specified for
affected source categories in the applicable part of the regulations. The span value is established
in the applicable regulation and is usually 1.5 to 2.5 times the applicable emission limit. lf no span
value is provided, use a span value equivalent to 1.5 to 2.5 times the expected concentration. For
convenience, the span value should correspond to 100 percent ofthe recorderscale.
3.7 Zero drift means the difference in the measurement system response to a zero level calibration
gas before or after a stated period of operation during which no unscheduled maintenance,
repair, or adjustment took place.
4.0 I nterferences. IReserved]
METHOD 25A
DETERMINAT!ON OF TOTAL GASEOUS
ORGANIC CONCENTRATION USING A FLAME
IONIZATION ANALYZER
Revision 0
LzlLtl2013 DEI{OVO
5.0 Safety.
5.1- Disclaimer. This method may involve hazardous materials, operations, and equipment. This test
method may not address all of the safety problems associated with its use. lt is the responsibility
of the user of this test method to establish appropriate safety and health practices and determine
the applicability of regulatory limitations prior to performing this test method. The analyzer users
manual should be consulted for specific precautions to be taken with regard to the analytical
proced u re.
5.2 Explosive Atmosphere. This method is often applied in highly explosive areas. Caution and care
should be exercised in choice of equipment and installation.
6.0 Equipment and Supplies
5.1 Measurement System. Any measurement system fortotal organic concentration that meets the
specifications of this method. A schematic of an acceptable measurement system is shown in
Figure 25A-1. All sampling components leading to the analyzer shall be heated > 110"C (22O"F)
throughout the sampling period, unless safety reasons are cited (Section 5.2) The essential
components of the measurement system are described below:
6.1.L Organic Concentration Analyzer. A flame ionization analyzer (FlA) capable of meeting or
exceeding the specifications of this method. The flame ionization detector block shall be
heated >120'C (250'F).
6.1.2 Sample Probe. Stainless steel, or equivalent, three-hole rake type, Sample holes shall be 4
mm (0.L6-in.) in diameter or smaller and located al t6.7,50, and 83.3 percent of the
equivalent stack diameter. Alternatively, a single opening probe may be used so that a gas
sample is collected from the centrally located 10 percent area of the stack cross-section.
6.L.3 Heated Sample Line. Stainless steel or Teflon@ tubing to transport the sample gas to the
analyzer. The sample line should be heated (>110 'C) to prevent any condensation.
6.1.4 Calibration Valve Assembly. A three-way valve assembly to direct the zero and calibration
gases to the analyzers is recommended. Other methods, such as quick-connect lines, to
route calibration gas to the analyzers are applicable.
5.1,.5 Particulate Filter. An in-stack or an out-of-stack glass fiber filter is recommended if exhaust
gas particulate loading is significant. An out-of-stackfiltershould be heated to prevent any
condensation.
6.1..6 Recorder. A strip-chart recorder, analog computer, or digital recorder for recording
measurement data. The minimum data recording requirement is one measurement value
per minute.
7.0 Reagents and Standards.
7.1 Calibration Gases. The calibration gases for the gas analyzer shall be propane in air or propane in
nitrogen. Alternatively, organic compounds other than propane can be used; the appropriate
corrections for response factor must be made. Calibration gases shall be prepared in accordance
with the procedure listed in Citation 2 of Section 16. Additionally, the manufacturer of the
cylinder should provide a recommended shelf life for each calibration gas cylinder over which the
concentration does not change more than + 2 percent from the certified value. For calibration
METHOD 25A
DETERMINATION OF TOTAL GASEOUS
ORGANIC CONCENTRATION USING A FLAME
IONIZATION ANALYZER
Revision 0
LzlLLl20ts DENOVO
gas values not generally available (i.e., organics between 1 and 10 percent by volume),
alternative methods for preparing calibration gas mixtures, such as dilution systems (Test
Method 2O5,40 CFR Part 5L, Appendix M), may be used with prior approval of the Administrator.
7.1-.1 Fuel. A 40 percent Hz/60 percent N2 gas mixture is recommended to avoid an oxygen
synergism effect that reportedly occurs when oxygen concentration varies significantly from
a mean value.
7.t.2Zero Gas. High purity air with less than 0.1 part per million by volume (ppmv) of organic
material (propane or carbon equivalent) or less than 0.1 percent of the span value,
whichever is greater.
7.1.3 Low-level Calibration Gas. An organic calibration gas with a concentration equivalent to 25
to 35 percent of the applicable span value.
7.1.4 Mid-level Calibration Gas. An organic calibration gas with a concentration equivalent to 45
to 55 percent of the applicable span value.
7.1.5 High-level Calibration Gas. An organic calibration gas with a concentration equivalent to 80
to 90 percent of the applicable span value.
8.0 Sample Collection, Preservation, Storage, and Transport.
8. L Selection of Sampling Site. The location of the sam pling site is generally specified by the applicable
regulation or purpose of the test (i.e., exhaust stack, inlet line, etc.). The sample port shall be
located to meet the testing requirements of Method 1.
8.2 Location of Sample Probe. lnstall the sample probe so that the probe is centrally located in the
stack, pipe, or duct and is sealed tightly at the stack port connection.
8.3 Measurement System Preparation. Prior to the emission test, assemble the measurement system
by following the manufacturer's written instructions for preparing sample interface and the
organic analyzer. Make the system operable (Section 10.1).
8.4 Calibration Error Test. lmmediately prior to the test series (within 2 hours of the start of the test),
introduce zero gas and high-level calibration gas at the calibration valve assembly. Adjust the
analyzer output to the appropriate levels, if necessary. Calculate the predicted response for the
low-level and mid-level gases based on a linear response line between the zero and high-level
response. Then introduce low-level and mid-level calibration gases successively to the
measurement system. Record the analyzer responses for low-level and mid-level calibration
gases and determine the differences between the measurement system responses and the
predicted responses. These differences must be less than 5 percent of the respective calibration
gas value. lf not, the measurement system is not acceptable and must be replaced or repaired
prior to testing. No adjustments to the measurement system shall be conducted after the
calibration and before the drift check (Section 8.5.2). lf adjustments are necessary before the
completion of the test series, perform the drift checks prior to the required adjustments and
repeat the calibration following the adjustments. lf multiple electronic ranges are to be used,
each additional range must be checked with a mid-level calibration gas to verify the
mu ltiplication factor.
METHOD 25A
DETERMINAT!ON OF TOTAL GASEOUS
ORGANIC CONCENTRATION US!NG A FLAME
IONIZATION ANALYZER
Revision 0
LzlLLl2OL3 DEI{OVO
8.5 Response Time Test. lntroduce zero gas into the measurement system at the calibration valve
assembly. When the system output has stabilized, switch quickly to the high-level calibration gas.
Record the time from the concentration change to the measu rement system response equ ivalent
to 95 percent of the step change. Repeat the test three times and average the results.
8.6 Emission Measurement Test Procedure.
8.6.L Organic Measurement. Begin sampling at the start of the test period, recording time and
any required process information as appropriate. ln particulate, note on the recording chart,
periods of process interruption or cyclic operation.
8.6.2 Drift Determination. lmmediately following the completion of the test period and hourly
during the test period, reintroduce the zero and mid-level calibration gases, one at a time,
to the measurement system at the calibration valve assembly. (Make no adjustments to the
measurement system until both the zero and calibration drift checks are made.) Record the
analyzer response. lf the drift values exceed the specified limits, invalidate the test results
preceding the check and repeat the test following corrections to the measurement system.
Alternatively, recalibrate the test measurement system as in Section 8.4 and report the
results using both sets of calibration data (i.e., data determined priorto the test period and
data determined following the test period).
NOTE: Note on the recording chart periods of process interruption or cyclic operation.
9.0 Quality Control
Method Section Qualitv Control Measure Effect
8.4 Zero and calibration drift tests.Ensures that bias introduced by drift in the
measurement system output during the run
is no greaterthan 3 percent ofspan.
10.0 Calibration and Standardization.
10.1 FIA equipment can be calibrated for almost any range of total organic concentrations. For high
concentrations of organics (> 1.0 percent by volume as propane), modifications to most
commonly available analyzers are necessary. One accepted method of equipment modification
is to decrease the size of the sample to the analyzer through the use of a smaller diameter sample
capillary. Direct and continuous measurement of organic concentration is a necessary
consideration when determining any modification design.
L1.0 Analytical Procedure.
The sample collection and analysis are concurrent for this method (see Section 8.0).
12.0 Calculations and Data Analysis.
12.1 Determine the average organic concentration in terms of ppmv as propane or other calibration
gas. The average shall be determined by integration of the output recording over the period
specified in the applicable regulation. lf results are required in terms of ppmv as carbon, adjust
measured concentrations using Equation 25A-1.
Cr: KC^"o, Eq.25A - 1,
Where:
METHOD 25A
DETERMINATION OF TOTAL GASEOUS i::?}::: I DENOVOoRGANrc coNcENTRATToN usrNc A FLAME I LzlLLl2oL3
IONIZATION ANALYZER
C. = Organic concentration as carbon, ppmv.
Cr"ur= Organic concentration as measured, ppmv.
K = Carbon equivalent correction factor.
= 2 for etha ne.
= 3 for propane.
= 4 for butane.
= Appropriate response factor for other organic calibration gases.
13.0 Method Performance.
13.L Measurement System Performance Specifications.
13.1-.1 Zero Drift. Less than t3 percent of the span value.
13.1.2 Calibration Drift. Less than +3 percent of span value.
13.1.3 Calibration Error. Less than +5 percent of the calibration gas value.
14.0 Pollution Prevention. IReserved]
15.0 Waste Management. IReserved]
l-6.0 References.
15.1 Measurement of Volatile Organic Compounds-Guideline Series. U.S. Environmental Protection
Agency. Research Triangle Park, NC. Publication No. EPA-450/2-78-04L. June 1978. p.46-54.
16.2 EPA Traceability Protocol for Assay and Certification of Gaseous Calibration Standards. U.S.
Environmental Protection Agency, Quality Assurance and Technical Support Division. Research
Triangle Park, N.C. September 1993.
15.3 Gasoline Vapor Emission Laboratory Evaluation-Part 2. U.S. Environmental Protection Agency,
Office of Air Quality Planning and Standards. Research Triangle Park, NC. EMB Report No. 75-
GAS-5. August 1975. '
17.0 Tables, Diagrams, Flowcharts, and Validation Data.