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southeast (from west to east). The area 
is defined as that airspace upward from 700 feet above the surface within the area bounded by a line beginning at lat. 58°27′33″ N, long. 134°37′40″ W, to lat. 
58°13′13″ N, long. 134°11′51″ W, to lat. 
58°05′59″ N, long. 134°21′04″ W, to lat. 
58°10′51″ N, long. 134°59′18″ W, to lat. 
58°23′41″ N, long. 135°31′13″ W, to lat. 
58°32′22″ N, long. 135°18′32″ W, to lat. 
58°27′17″ N, long. 135°01′27″ W, thence 
to the point of beginning. This modification reduces the airspace area to only that area necessary to contain IFR operations as they transition between the airport and en route environments. Also, Class E airspace extending upward from 1,200 feet above the surface designated for Juneau International Airport is removed since this airspace is wholly contained within the Southeast Alaska Class E en route airspace, and duplication is not necessary. 
This action also makes an editorial 
change to the Class D airspace legal description replacing Airport/Facility Directory with Chart Supplement. 
Regulatory Notices and Analyses 
The FAA has determined that this 
regulation only involves an established 
body of technical regulations for which 
frequent and routine amendments are necessary to keep them operationally current, is non-controversial and unlikely to result in adverse or negative comments. It, therefore: (1) Is not a ‘‘significant regulatory action’’ under Executive Order 12866; (2) is not a ‘‘significant rule’’ under DOT Regulatory Policies and Procedures (44 FR 11034; February 26, 1979); and (3) does not warrant preparation of a Regulatory Evaluation as the anticipated impact is so minimal. Since this is a routine matter that only affects air traffic procedures and air navigation, it is certified that this rule, when promulgated, will not have a significant economic impact on a substantial number of small entities under the criteria of the Regulatory Flexibility Act. 
Environmental Review 
The FAA has determined that this 
action qualifies for categorical exclusion 
under the National Environmental Policy Act in accordance with FAA Order 1050.1F, ‘‘Environmental Impacts: Policies and Procedures,’’ paragraph 5–6.5a. This airspace action is not expected to cause any potentially significant environmental impacts, and no extraordinary circumstances exist that warrant preparation of an environmental assessment. Lists of Subjects in 14 CFR Part 71 
Airspace, Incorporation by reference, 
Navigation (air). 
Adoption of the Amendment 
In consideration of the foregoing, the 
Federal Aviation Administration 
amends 14 CFR part 71 as follows: 
PART 71 —DESIGNATION OF CLASS 
A, B, C, D, AND E AIRSPACE AREAS; AIR TRAFFIC SERVICE ROUTES; AND REPORTING POINTS 
■1. The authority citation for part 71 
continues to read as follows: 
Authority: 49 U.S.C. 106(f), 106(g); 40103, 
40113, 40120; E.O. 10854, 24 FR 9565, 3 CFR, 
1959–1963 Comp., p. 389. 
§ 71.1 [Amended] 
■2. The incorporation by reference in 
14 CFR 71.1 of FAA Order 7400.11C, 
Airspace Designations and Reporting Points, dated August 13, 2018, and effective September 15, 2018, is amended as follows: 
Paragraph 5000 Class D Airspace. 
* * * * * 
AAL AK D Juneau, AK [Amended] 
Juneau International Airport, AK 
(Lat. 58°21′17″ N, long. 134°34′42″ W) 
That airspace extending upward from the 
surface to and including 2,500 feet MSL 
within a 3-mile radius of Juneau International Airport, and within 2.5 miles each side of the 271° bearing from the airport 
extending from the 3-mile radius to 5.2 miles west of the airport, and within 1 mile southwest and 2.6 miles northeast of the airport 135° bearing extending from the 
airport 3-mile radius to 5 miles southeast of the airport, excluding that airspace below 2,000 feet MSL within the area bounded by a line beginning at lat. 58°19′35″ N, long. 
134°24′31″ W, to lat. 58°19′02″ N, long. 
134°25′33″ W, to lat. 58°20′16″ N, long. 
134°27′28″ W, to lat. 58°20′34″ N, long. 
134°26′22″ W, thence to the point of 
beginning. This Class D airspace area is effective during the specific dates and times established in advance by a Notice to Airmen. The effective date and time will thereafter be continuously published in the Chart Supplement. 
Paragraph 6002 Class E Airspace Areas 
Designated as Surface Areas. 
* * * * * 
AAL AK E2 Juneau, AK [Amended] 
Juneau International Airport, AK 
(Lat. 58°21′17″ N, long. 134°34′42″ W) 
That airspace extending upward from the 
surface within a 3-mile radius of Juneau 
International Airport, and within 2.5 miles each side of the 271° bearing from the airport 
extending from the 3-mile radius to 5.2 miles west of the airport, and within 1 mile southwest and 2.6 miles northeast of the airport 135° bearing extending from the airport 3-mile radius to 5 miles southeast of the airport, excluding that airspace below 2,000 feet MSL within the area bounded by a line beginning at lat. 58°19′35″ N, long. 
134°24′31″ W, to lat. 58°19′02″ N, long. 
134°25′33″ W, to lat. 58°20′16″ N, long. 
134°27′28″ W, to lat. 58°20′34″ N, long. 
134°26′22″ W, thence to the point of 
beginning. This Class E airspace area is effective during the specific dates and times established in advance by a Notice to Airmen. The effective date and time will thereafter be continuously published in the Chart Supplement. 
Paragraph 6004 Class E Airspace 
Designated as an Extension to a Class D or Class E Surface Area. 
* * * * * 
AAL AK E4 Juneau, AK [Removed] 
Paragraph 6005 Class E Airspace Areas 
Extending Upward From 700 Feet or More Above the Surface of the Earth. 
* * * * * 
AAL AK E5 Juneau, AK [Amended] 
Juneau International Airport, AK 
(Lat. 58°21′17″ N, long. 134°34′42″ W) 
That airspace upward from 700 feet above 
the surface within the area bounded by a line 
beginning at lat. 58°27′33″ N, long. 
134°37′40″ W, to lat. 58°13′13″ N, long. 
134°11′51″ W, to lat. 58°05′59″ N, long. 
134°21′04″ W, to lat. 58°10′51″ N, long. 
134°59′18″ W, to lat. 58°23′41″ N, long. 
135°31′13″ W, to lat. 58°32′22″ N, long. 
135°18′32″ W, to lat. 58°27′17″ N, long. 
135°01′27″ W, thence to the point of 
beginning. 
Issued in Seattle, Washington, on 
November 1, 2018. 
Shawn M. Kozica, Manager, Operations Support Group, Western 
Service Center. 
[FR Doc. 2018–24721 Filed 11–13–18; 8:45 am] 
BILLING CODE 4910–13–P 
ENVIRONMENTAL PROTECTION 
AGENCY 
40 CFR Parts 51, 60, and 63 
[EPA–HQ–OAR–2016–0510; FRL–9986–42– 
OAR] 
RIN 2060–AS95 
Testing Regulations for Air Emission 
Sources 
AGENCY : Environmental Protection 
Agency (EPA). 
ACTION : Final rule. 
SUMMARY : This action amends certain 
existing testing regulations to reflect corrections, updates, and the addition of alternative equipment and methods for source testing of emissions. These revisions will improve the quality of data and provide flexibility in the use of 
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approved alternative procedures. The 
revisions do not impose any new substantive requirements on source owners or operators. 
DATES : The final rule is effective on 
January 14, 2019. The incorporation by reference materials listed in the rule are approved by the Director of the Federal Register as of January 14, 2019. 
ADDRESSES : The EPA has established a 
docket for this action under Docket ID No. EPA–HQ–OAR–2016–0510. All documents in the docket are listed on the http://www.regulations.gov website. 
Although listed in the index, some information is not publicly available, e.g., confidential business information 
or other information whose disclosure is restricted by statute. Certain other material, such as copyrighted material, is not placed on the internet and will be publicly available only in hard copy. Publicly available docket materials are available electronically through http://www.regulations.gov. 
FOR FURTHER INFORMATION CONTACT : Ms. 
Lula H. Melton, Office of Air Quality Planning and Standards, Air Quality Assessment Division (E143–02), Environmental Protection Agency, Research Triangle Park, NC 27711; telephone number: (919) 541–2910; fax number: (919) 541–0516; email address: melton.lula@epa.gov. 
SUPPLEMENTARY INFORMATION : The 
supplementary information in this preamble is organized as follows: 
Table of Contents 
I. General Information 
A. Does this action apply to me? 
B. What action is the agency taking? C. Judicial Review 
II. Background III. Summary of Amendments 
A. Method 201A of Appendix M of Part 51 B. Method 204 of Appendix M of Part 51 C. Method 205 of Appendix M of Part 51 D. General Provisions (Subpart A) of Part 
60 
E. Fossil-Fuel-Fired Steam Generators 
(Subpart D) Part 60 
F. Electric Utility Steam Generating Units 
(Subpart Da) Part 60 
G. Industrial-Commercial-Institutional 
Steam Generating Units (Subpart Db) Part 60 
H. Small Industrial-Commercial- 
Institutional Steam Generating Units (Subpart Dc) Part 60 
I. Municipal Waste Combustors for Which 
Construction is Commenced After December 20, 1989 and on or Before September 20, 1994 (Subpart Ea) Part 60 
J. Glass Manufacturing Plants (Subpart CC) 
Part 60 
K. New Residential Wood Heaters, New 
Residential Hydronic Heaters and 
Forced-Air Furnaces (Subpart QQQQ) Part 60 
L. Method 2B of Appendix A–1 of Part 60 M. Method 5 of Appendix A–3 of Part 60 
N. Method 5B of Appendix A–3 of Part 60 O. Method 5I of Appendix A–3 of Part 60 P. Method 7 of Appendix A–4 of Part 60 Q. Method 8 of Appendix A–4 of Part 60 R. Method 18 of Appendix A–6 of Part 60 S. Method 22 of Appendix A–7 of Part 60 T. Method 26 of Appendix A–8 of Part 60 U. Method 26A of Appendix A–8 of Part 
60 
V. Test Method 28WHH of Appendix A–8 
of Part 60 
W. Performance Specification 1 of 
Appendix B of Part 60 
X. Performance Specification 2 of 
Appendix B of Part 60 
Y. Performance Specification 3 of 
Appendix B of Part 60 
Z. Performance Specification 11 of 
Appendix B of Part 60 
AA. Performance Specification 15 of 
Appendix B of Part 60 
BB. Performance Specification 18 of 
Appendix B of Part 60 
CC. Procedure 1 of Appendix F of Part 60 DD. General Provisions (Subpart A) Part 63 EE. Wool Fiberglass Manufacturing 
(Subpart NNN) Part 63 
FF. Major Sources: Industrial, Commercial, 
and Institutional Boilers and Process Heaters (Subpart DDDDD) Part 63 
GG. Coal- and Oil-Fired Electric Utility 
Steam Generating Units (Subpart UUUUU) Part 63 
HH. Method 303 of Appendix A of Part 63 
II. Method 308 of Appendix A of Part 63 JJ. Method 320 of Appendix A of Part 63 KK. Method 323 of Appendix A of Part 63 LL. Method 325A of Appendix A of Part 63 MM. Method 325B of Appendix A of Part 
63 
IV. Public Comments on the Proposed Rule V. Statutory and Executive Order Reviews 
A. Executive Order 12866: Regulatory 
Planning and Review and Executive Order 13563: Improving Regulation and Regulatory Review 
B. Executive Order 13771: Reducing 
Regulations and Controlling Regulatory Costs 
C. Paperwork Reduction Act (PRA) D. Regulatory Flexibility Act (RFA) E. Unfunded Mandates Reform Act 
(UMRA) 
F. Executive Order 13132: Federalism G. Executive Order 13175: Consultation 
and Coordination with Indian Tribal Governments 
H. Executive Order 13045: Protection of 
Children from Environmental Health Risks and Safety Risks 
I. Executive Order 13211: Actions 
Concerning Regulations That Significantly Affect Energy Supply, Distribution or Use 
J. National Technology Transfer and 
Advancement Act (NTTAA) and 1 CFR part 51 
K. Executive Order 12898: Federal Actions 
to Address Environmental Justice in Minority Populations and Low-Income Populations 
L. Congressional Review Act (CRA) I. General Information 
A. Does this action apply to me? 
The revisions promulgated in this 
final rule apply to industries that are 
subject to the current provisions of 40 Code of Federal Regulations (CFR) parts 51, 60, and 63. We did not list all of the specific affected industries or their North American Industry Classification System (NAICS) codes herein since there are many affected sources in numerous NAICS categories. If you have any questions regarding the applicability of this action to a particular entity, consult either the air permitting authority for the entity or your EPA Regional representative as listed in 40 CFR 63.13. 
B. What action is the agency taking? 
We are promulgating corrections and 
updates to regulations for source testing 
of emissions. More specifically, we are correcting typographical and technical errors, updating obsolete testing procedures, adding approved testing alternatives, and clarifying testing requirements. 
C. Judicial Review 
Under section 307(b)(1) of the Clean 
Air Act (CAA), judicial review of this 
final rule is available by filing a petition for review in the United States Court of Appeals for the District of Columbia Circuit by January 14, 2019. Under section 307(d)(7)(B) of the CAA, only an 
objection to this final rule that was raised with reasonable specificity during the period for public comment can be raised during judicial review. Moreover, under section 307(b)(2) of the CAA, the requirements that are the subject of this final rule may not be challenged later in civil or criminal proceedings brought by the EPA to enforce these requirements. 
II. Background 
The revisions to testing regulations for 
air emission sources were proposed in 
the Federal Register on January 26, 
2018 (83 FR 3636). The public comment period ended March 27, 2018, and 83 comment letters were received from the public; 23 of the comment letters were relevant, and the other 60 comment letters were considered beyond the scope of the proposed rule. This final rule was developed based on public comments that the agency received on the proposed rule. 
III. Summary of Amendments A. Method 201A of Appendix M of Part 
51 
In Method 201A, in section 12.5, the 
denominator of equation 24 is corrected 
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as proposed; the proposed c′ pin the 
denominator is changed to C p′ to be 
consistent with the nomenclature in 
section 12.1. The c pin the numerator is 
changed to C palso to be consistent with 
the nomenclature in section 12.1. 
B. Method 204 of Appendix M of Part 
51 
In Method 204, in section 8.2, the 
statement regarding equation 204–2 is corrected to ‘‘The NEAR must be ≤0.05,’’ as proposed. 
C. Method 205 of Appendix M of Part 
51 
In Method 205, section 2.1.1 is 
revised to allow the use of National Institute of Standards and Technology (NIST)-traceable transfer standards to calibrate the gas dilution system as proposed. The agency continues to believe that these standards are widely available and provide the accuracy necessary to perform the calibration. Section 2.1.1 is also revised as proposed to require testers to report the results of the calibration of the dilution system to enable the regulatory authority to review this information. 
D. General Provisions (Subpart A) of 
Part 60 
In the General Provisions of part 60, 
§ 60.17(h) is revised as proposed to add ASTM D6216–12 to the list of incorporations by reference and to re- number the remaining consensus standards that are incorporated by reference in alpha-numeric order. 
E. Fossil-Fuel-Fired Steam Generators 
(Subpart D) Part 60 
In a change from proposal, the 
allowed filter temperature in § 60.46(b)(2)(i) is not revised. Based on comments we received on the proposed revisions, we are deferring finalizing the proposed revisions of the temperature tolerances of probe and filter holder heating systems as part of this rulemaking. We will continue to review supporting information and data we received on the proposed rule and may propose either revisions or similar requirements as part of future rulemakings. 
F. Electric Utility Steam Generating 
Units (Subpart Da) Part 60 
In a change from proposal, the 
allowed filter temperature in § 60.50Da (b)(1)(ii)(A) is not revised. Based on comments we received on the proposed revisions, we are deferring finalizing the proposed revisions of the temperature tolerances of probe and filter holder heating systems as part of this rulemaking. We will continue to review supporting information and data we received on the proposed rule and may propose either revisions or similar requirements as part of future rulemakings. 
G. Industrial-Commercial-Institutional 
Steam Generating Units (Subpart Db) Part 60 
In a change from proposal, the 
allowed filter temperature in § 60.46b(d)(4) is not revised. Based on comments we received on the proposed revisions, we are deferring finalizing the proposed revisions of the temperature tolerances of probe and filter holder heating systems as part of this rulemaking. We will continue to review supporting information and data we received on the proposed rule and may propose either revisions or similar requirements as part of future rulemakings. 
H. Small Industrial-Commercial- 
Institutional Steam Generating Units (Subpart Dc) Part 60 
In a change from proposal, the 
allowed filter temperature in § 60.45c(a)(5) is not revised. Based on comments we received on the proposed revisions, we are deferring finalizing the proposed revisions of the temperature tolerances of probe and filter holder heating systems as part of this rulemaking. We will continue to review supporting information and data we received on the proposed rule and may propose either revisions or similar requirements as part of future rulemakings. 
I. Municipal Waste Combustors for 
Which Construction is Commenced After December 20, 1989 and on or Before September 20, 1994 (Subpart Ea) Part 60 
In a change from proposal, the 
allowed filter temperature in § 60.58a(b)(3) is not revised. Based on comments we received on the proposed revisions, we are deferring finalizing the proposed revisions of the temperature tolerances of probe and filter holder heating systems as part of this rulemaking. We will continue to review supporting information and data we received on the proposed rule and may propose either revisions or similar requirements as part of future rulemakings. 
J. Glass Manufacturing Plants (Subpart 
CC) Part 60 
In a change from proposal, the 
allowed filter temperatures in §§ 60.293(f) and 60.296(d)(2) are not revised. Based on comments we received on the proposed revisions, we are deferring finalizing the proposed revisions of the temperature tolerances of probe and filter holder heating systems as part of this rulemaking. We will continue to review supporting information and data we received on the proposed rule and may propose either revisions or similar requirements as part of future rulemakings. 
K. New Residential Wood Heaters, New 
Residential Hydronic Heaters and Forced-Air Furnaces (Subpart QQQQ) Part 60 
In subpart QQQQ, in Method 28WHH, 
in section 13.5.1, equation 8 is corrected as proposed. 
L. Method 2B of Appendix A–1 of Part 
60 
In Method 2B, in section 12.1, the 
definition of ambient carbon dioxide concentration is revised as proposed. The agency continues to believe that the global monthly mean (CO
2)a 
concentration varies over time. Also, a website link is added to the definition as specified at proposal. 
M. Method 5 of Appendix A–3 of Part 
60 
In a change from proposal, allowed 
filter temperatures in Method 5, sections 2.0, 6.1.1.2, 6.1.1.6, 6.1.1.7, and 8.5 are not revised. Based on comments we received on the proposed revisions, we are deferring finalizing the proposed revisions of the temperature tolerances of probe and filter holder heating systems as part of this rulemaking. We will continue to review supporting information and data we received on the proposed rule and may propose either revisions or similar requirements as part of future rulemakings. 
Section 6.1.1.9 is revised as proposed 
to allow the use of a single temperature sensor in lieu of two temperature sensors on the dry gas meter as allowed by Technical Information Document 19 (TID–19) and the approved broadly applicable alternative, ALT–117 (see https://www.epa.gov/emc). Consistent with our response to the comment regarding allowing flexibility for the weighing container in section 11.2.1, Method 5B, the first sentence in section 11.2.1, Method 5 is revised similarly. 
N. Method 5B of Appendix A–3 of Part 
60 
In a change from proposal, the 
allowed filter temperatures in Method 5B, sections 2.0, 6.1, and 8.2 are not revised. Based on comments we received on the proposed revisions, we are deferring finalizing the proposed revisions of the temperature tolerances of probe and filter holder heating 
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systems as part of this rulemaking. We 
will continue to review supporting information and data we received on the proposed rule and may propose either revisions or similar requirements as part of future rulemakings. 
Section 11.0 is revised as proposed to 
replace the reference to Method 5, section 11.0 with specific analytical procedures and to report the results using Figure 5B–1 for complete data review. Section 17.0 is revised as proposed to delete the word ‘‘Reserved’’ from the title, and Figure 5B–1 (Analytical Data Sheet) is added. 
O. Method 5I of Appendix A–3 of Part 
60 
In a change from proposal, Method 5I, 
sections 2.1 and 8.5.2.2 are not revised to tighten the allowed filter temperatures. Based on comments we received on the proposed revisions, we are deferring finalizing the proposed revisions of the temperature tolerances of probe and filter holder heating systems as part of this rulemaking. We will continue to review supporting information and data we received on the proposed rule and may propose either revisions or similar requirements as part of future rulemakings. 
P. Method 7 of Appendix A–4 of Part 60 
In Method 7, sections 10.1.2 and 11.3 
reference erroneous sections; the correct 
section is inserted, as proposed. The proposed referenced section 10.1.1.2 is changed to 10.1.1 to include procedures in both sections 10.1.1.1 and 10.1.1.2. 
Q. Method 8 of Appendix A–4 of Part 60 
As proposed, Method 8, sections 
6.1.1.1 through 6.1.1.4 are renumbered 
to 6.1.1.2 through 6.1.1.5; a new section 6.1.1.1 is added to clarify the requirements that apply to the probe nozzle; and, in response to comments, Figure 8–1 (Sulfuric Acid Sampling Train) is corrected by: (1) Modifying the impinger graphics to make it consistent with the text in section 6.1.1.4 and (2) revising the proposed label S-Type Pitot Tube to Type S Pitot Tube for consistency. The proposed first sentence in section 6.1.1.1 is revised to ‘‘Borosilicate or quartz glass with a sharp, tapered leading edge and coupled to the probe liner using a polytetrafluoroethylene (PTFE) or glass- lined union (e.g., fused silica, Silico, or 
equivalent).’’ Based on a public comment that recommended adding Silco coated stainless steel unions as an option for Teflon unions, and for consistency with other test methods, we have replaced Teflon with the generic option polytetrafluoroethylene (PTFE). R. Method 18 of Appendix A–6 of Part 
60 
In Method 18, in section 13.1, the 
erroneous paragraph (c) designation is re-designated as (b), as proposed. 
S. Method 22 of Appendix A–7 of Part 
60 
In Method 22, sections 11.2.1 and 
11.2.2 are revised as proposed to allow digital photography to be used for a subset of the recordkeeping requirements. As proposed, section 11.2.3 is added to specify the requirements for digital photographic records. In response to comments on the proposal, the next to the last sentence in section 11.2.3 regarding photographs that must be taken within 15 minutes of the observation period is revised from the proposal, and another sentence is added to provide clarity. The revised and new sentences read: ‘‘The photograph(s) representing the environmental conditions including the sky conditions and the position of the sun relative to the observer and the emission point must be taken within a reasonable time of the observation (i.e., 15 minutes). When observations are taken from exactly the same observation point on a routine basis (e.g., daily) and 
as long as there are no modifications to the units depicted, only a single photograph each day is necessary to document the observer’s location relative to the emissions source, the process unit being observed, and the location of potential and actual emission points.’’ The agency notes that ALT–109 (see https://www.epa.gov/ emc) is the associated broadly applicable alternative that allows the use of digital photographs for specific recordkeeping requirements. 
T. Method 26 of Appendix A–8 of Part 
60 
As proposed, Method 26, section 6.2.2 
is revised to allow the use of glass sample storage containers as an option to allow flexibility and to be consistent with Method 26A. The proposed title of section 6.2.2, ‘‘Storage Bottles,’’ is changed to ‘‘Storage Containers’’ to be consistent with the language in section 6.2.2. 
U. Method 26A of Appendix A–8 of Part 
60 
As proposed, in Method 26A, section 
6.2.1 is revised to remove the language regarding sample storage containers. In 
response to comments on our proposal, we have determined that high-density polyethylene is an acceptable material for sample storage containers in addition to the currently allowed glass. Therefore, in a new section 6.2.4., we have specified that both high-density polyethylene and glass are acceptable sample storage containers. 
V. Test Method 28WHH of Appendix A– 
8 of Part 60 
In Test Method 28WHH, equation 8 in 
section 13.5.1 is corrected, as proposed. 
W. Performance Specification 1 of 
Appendix B of Part 60 
As proposed, in Performance 
Specification 1, references to ASTM D6216–98 (in sections 2.1, 3.1, 6.1, 8.1(1), 8.1(3)(ii), 8.2(1), 8.2(2), 8.2(3), 9.0, 12.1, 13.0, 13.1, 13.2, and 16.0 paragraph 8) are replaced with ASTM D6216–12. As noted at proposal, if the initial certification of the continuous opacity monitoring system (COMS) has already occurred using D6216–98, D6216–03, or D6216–07, it will not be necessary to recertify using D6216–12. In response to comments on our decision to add ASTM D6216 to the list of consensus standards, the April 1998 publication date for ASTM D6216 in paragraph 8 in section 16.0 is replaced with October 2012, the ASTM D6216–12 publication date. In response to comments, for consistency with section 2.1, and for purposes of clarification, the note at the end of section 2.1 is added to section 13.0. 
X. Performance Specification 2 of 
Appendix B of Part 60 
In Performance Specification 2, 
section 13.2 is replaced with a table that indicates the relative accuracy performance specifications, as proposed. Given that the equals to (=) signs were erroneously omitted from several of the < and > values during publication of the table in the proposed rule, these values have been corrected. 
Y. Performance Specification 3 of 
Appendix B of Part 60 
In Performance Specification 3, the 
two sentences in section 12.0 that read, ‘‘Calculate the arithmetic difference between the RM and the CEMS output for each run. The average difference of the nine (or more) data sets constitute the RA.’’ are deleted, as proposed; these two sentences are no longer necessary since equations 3–1 and 3–2 would be moved from section 13.2 to section 12.0. The sentence, ‘‘Calculate the RA using equations 3–1 and 3–2.’’ is added to the beginning of section 12.0. 
Z. Performance Specification 11 of 
Appendix B of Part 60 
In Performance Specification 11, 
section 13.1, the word ‘‘average’’ erroneously exists in the second sentence and is deleted, as proposed. 
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AA. Performance Specification 15 of 
Appendix B of Part 60 
As proposed, in Performance 
Specification 15, section 13.0 is added as ‘‘Method Performance [Reserved].’’ 
BB. Performance Specification 18 of 
Appendix B of Part 60 
As proposed, in Performance 
Specification 18, in section 11.8.7, the last sentence is revised to clarify the duration of the drift check. In Table 1, the erroneous acronym ‘‘NO
2’’ is 
replaced with ‘‘NO,’’ as proposed. In the appendix of Performance Specification 18, the inadvertently omitted reserved section 12.0 is added, as proposed. 
CC. Procedure 1 of Appendix F of Part 
60 
As proposed, in Procedure 1, in 
section 5.1.2 (1), the sentence immediately following the table that reads, ‘‘Challenge the CEMS three times at each audit point, and use the average of the three responses in determining accuracy.’’ is replaced with, ‘‘Introduce each of the audit gases, three times each for a total of six challenges. Introduce the gases in such a manner that the entire CEMS is challenged. Do not introduce the same gas concentration twice in succession.’’ In order to obtain six distinct readings during the cylinder gas audit (CGA), the same gas must not be introduced twice in succession, and this revised language accurately reflects this standard scientific practice. As also proposed, in section 5.1.2 (3), the reference to EPA’s traceability protocol for gaseous calibration standards is updated, and the language regarding the use of EPA Method 205 for dilution of audit gases is clarified. 
DD. General Provisions (Subpart A) of 
Part 63 
Sections 63.7(g)(2), 63.7(g)(2)(v), and 
63.8(e)(5)(i) of the General Provisions (subpart A) of part 63 are revised, as proposed, to require the reporting of specific test data for continuous monitoring system performance evaluation tests and ongoing quality assurance (QA) tests. These data elements are required regardless of the format of the report, i.e., electronic or 
paper. These modifications will ensure that performance evaluation and QA test reporting include all data necessary for the compliance authority to assess and assure the quality of the reported data and that the reported information 
describes and identifies the specific unit covered by the evaluation test report. In response to comment, we specified the level of reporting needed for continuous parameter monitoring systems (CPMS) versus other continuous monitoring systems including continuous emission monitoring systems (CEMS), COMS, and predictive emissions monitoring systems (PEMS). 
EE. Wool Fiberglass Manufacturing 
(Subpart NNN) Part 63 
In a change from proposal, the 
allowed filter temperature in § 63.1385(a)(5) is not revised. Based on comments we received on the proposed revisions, we are deferring finalizing proposed revisions of the temperature tolerances of probe and filter holder heating systems as part of this rulemaking. We will continue to review supporting information and data we received on the proposed rule and may propose either revisions or similar requirements as part of future rulemakings. 
FF. Major Sources: Industrial, 
Commercial, and Institutional Boilers and Process Heaters (Subpart DDDDD) Part 63 
As proposed, in Table 6 of subpart 
DDDDD, row 1.f. is revised to allow the use of EPA SW–846–7471B (for liquid samples) in addition to EPA SW–846– 7470A for measuring mercury to allow for compliance flexibility. 
GG. Coal- and Oil-Fired Electric Utility 
Steam Generating Units (Subpart UUUUU) Part 63 
In a change from proposal, the 
allowed filter temperature in § 63.10010(h)(7)(i)(1) is not revised. Based on comments we received on the proposed revisions, we are deferring finalizing proposed revisions of the temperature tolerances of probe and filter holder heating systems as part of this rulemaking. We will continue to review supporting information and data we received on the proposed rule and may propose either revisions or similar requirements as part of future rulemakings. 
As proposed, in Table 5, Method 5I is 
specified as a test method option because, as explained at proposal, Method 5I is designed for low particulate matter (PM) application. 
HH. Method 303 of Appendix A of Part 
63 
In Method 303, section 12.4, equation 
303–3 is corrected, as proposed, by inserting ‘‘where y = ’’ in front of the equation. 
II. Method 308 of Appendix A of Part 63 
As proposed, in Method 308, 
deionized distilled water replaces the 
aqueous n-proponal solution; the affected sections are 2.0, 7.2.2, 7.2.3.3, and 11.3.2. Section 7.2.2, which defines the aqueous n-proponal solution, is 
removed, as proposed. In section 7.2.3.3, the erroneous ‘‘four’’ is replaced as proposed, with ‘‘three’’ in the sentence that reads ‘‘Pipette 5, 15, and 25 ml of this standard, respectively into four 50-ml volumetric flasks.’’ Section 8.1.2 is revised, as proposed, to require a leak check prior to the sampling run (in addition to after the sampling run) for QA purposes; as explained at proposal, requiring a leak check prior to the sampling run would potentially save time and money. In section 9.1, methanol spike recovery check is added as a quality control (QC) measure in Table 9.1, as proposed. In section 12.1, variables used in equations 308–4 and 308–5 are added and section 12.5, which includes equations 308–4 and 308–5, is added, as proposed. In section 
13.0, the title ‘‘Reserved’’ is replaced with ‘‘Method Performance’’ and QA requirements would be added to be consistent with other methods, as proposed. The erroneous proposed paragraph (a) of section 13.0 is replaced, as proposed, with ‘‘Calibration standards must meet the requirements in section 10.2.1 or 10.2.2 as applicable.’’ 
JJ. Method 320 of Appendix A of Part 63 
In section 8.2.2.4, the denominator in 
equation 2 is corrected from P
SSto P S, 
as proposed. In section 9.2.3, the word 
‘‘where’’ in the statement, ‘‘Calculate the dilution ratio using the tracer gas as follows: where:’’ is deleted, as proposed. Also in section 9.2.3, the inadvertently superscripted ‘‘dir’’ on the definition of spike is subscripted, as proposed. 
KK. Method 323 of Appendix A of Part 
63 
In Method 323, section 12.9, the 
denominator in equation 323–8 is corrected, as proposed. 
LL. Method 325A of Appendix A of Part 
63 
In Method 325A, section 8.2.1.3 is 
revised, as proposed, to clarify that only one extra sampling site is required near known sources of volatile organic compounds (VOCs) when the source is located both within 50 meters of the boundary and between two monitors. Based on a public comment we received on the proposed regulatory text, wording changes have been made to the language in section 8.2.1.3. As proposed, the label under Figure 8.1 is corrected from ‘‘Refinery (20% angle)’’ to ‘‘Refinery (20° angle).’’ Section 8.2.3.2 
is revised, as proposed, to include facilities with a monitoring perimeter length equal to 7,315 meters (24,000 feet). Section 8.2.3.3 is added, as 
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proposed, to provide clarification and 
an equivalent procedure in Option 2 (linear distance between sites) for site locations that parallel section 8.2.2.2.4 in Option 1 (radial distance between sites). In response to comments, section 8.4.3 is added to address worker safety during extenuating circumstances. 
MM. Method 325B of Appendix A of 
Part 63 
In Method 325B, section 9.3.2 is 
revised, as proposed, to correct an error in the number of field blank samples required for a sampling period and to provide consistency with the sample analysis required in Method 325B. In sections 9.13 and 11.3.2.5, the erroneous reference to section 10.6.3 is corrected to 10.0, as proposed. Also in section 11.3.2.5, the erroneous reference to section 10.9.5 is corrected to 9.13, as proposed. Section 12.2.2 is revised, as proposed, to correct the calculation of target compound concentrations at standard conditions, and the erroneous reference to U
stdin the note in section 
12.2.2 is revised to U NTP. Sections 12.2.3 
and 12.2.4 are deleted, as proposed, 
because the equations for target concentrations are incorrect. Table 17– 1 is revised, as proposed, to add inadvertently omitted QC criteria from section 9.3.3. 
IV. Public Comments on the Proposed 
Rule 
Eighty-three (83) comment letters 
were received from the public; 23 of the comment letters were relevant, and the other 60 comment letters were considered as beyond the scope of the proposed rule. The public comments and the agency’s responses are summarized in the Response to Comments document located in the docket for this rule. See the 
ADDRESSES  
section of this preamble. 
A summary of the relevant portions of 
significant comments that we received on the proposal and agency responses are presented below. 
Comment: Three commenters 
provided comments on our proposed revisions to the General Provisions (Subpart A) of Part 63. One commenter stated that the proposed revisions impose new requirements on CMS performance evaluations and QA testing for types of monitors not previously subject to such requirements. Another commenter remarked that the proposed revisions to various requirements in Part 63 revisions were vague. Yet another commenter remarked that the proposed revisions to § 63.8(e)(5) would shorten the CMS performance evaluation reporting period for CMS associated with performance tests. Response: We disagree with the 
comment that the proposed changes to 
§ 63.8(e)(5)(i) would impose new requirements given that at proposal, the agency had explained that they were intended to clarify and codify data elements and reporting requirements that are already routinely requested by the Administrator’s delegated authorities. With regard to § 63.8(e)(5), in a change from proposal, we have retained the existing requirement that allows for the simultaneous submission of the report of a CMS performance evaluation with results of performance testing required under 40 CFR 63.7. We also edited the final rule language for 40 CFR 63.7(g)(2)(v) to improve clarity and to eliminate confusion. 
Comment: Fifteen commenters 
provided comments arguing against the proposal to tighten the filter temperature tolerance in 40 CFR 60.46(b)(2)(i); 60.50Da(b)(1)(ii)(A); 60.45c(a)(5); 60.58a(b)(3); 60.293(f); 60.296(d)(2); 63.1385(a)(5); and sections 2.0, 6.1.1.2, 6.1.1.6, 6.1.1.7 and 8.5 of Method 5, Appendix A–3 of Part 60. They cited issues that included: weather (e.g., ambient temperature fluctuations 
and windy conditions); costs; lack of justification and data for the revision; inconsistent language (e.g., the use of 
‘‘shall’’ vs. ‘‘may’’ and proposed revisions to temperature tolerance in Methods 5, 5B, and 5I but not in Methods 5D, 5E, and 5F); and safety risks. Nine commenters remarked that ambient conditions (cold climates, wind gusts, etc.) can cause temperature fluctuations that are difficult to manage. More specifically, one commenter stated that the reduced allowable temperature range would be problematic during testing in cold, windy ambient conditions that are persistent in the winter months in northern climates because the time required for temperature recovery after a component change in these conditions could add hours and possibly days to testing programs. One commenter remarked that the proposed ±5 °C is unattainable 
for sources in cold or windy climates. 
Eight commenters stated that 
alteration or replacement of equipment components would likely be necessary to achieve the proposed temperature tolerances resulting in additional costs. One commenter noted potential equipment improvements, such as increased probe sheath tubing diameter to make room for added insulation around every probe heater; re-design of filter heating ovens; improved sealing and insulation of the openings at the inlet and outlet of filter heating ovens; 
and/or for sources with high stack temperatures, more frequent use of air- cooled or water-cooled probes. One 
commenter remarked that this revision would force cold weather stack testers to replace or retrofit equipment with higher power heating devices and possibly more refined control devices which would be costly. One commenter remarked that this revision will most likely require air sampling equipment suppliers to redesign sample probes by either increasing sheath diameter, altering the placement or increasing the number of thermocouples used to control the probe heating system, and/ or increasing the insulation around the sample liner. The commenter added that an increase in the diameter of the probe sheath would have a cascading effect either requiring test companies to purchase new sample hot boxes or retrofit existing sample hot boxes to accommodate the increased probe sheath diameter. 
Seven commenters stated that neither 
information nor data was provided to support, justify, or quantify the claimed increased precision of filterable PM measurements, and a few of these commenters noted that the Electric Power Research Institute (EPRI) paper that the EPA used as the basis for tightening the filter temperature tolerance was from a comparison of results measured at four coal-fired power plants. 
One commenter requested that the 
statement in § 60.50Da(b)(1)(ii)(A), ‘‘The probe and filter holder heating system in the sampling train may be set to provide an average gas temperature of no greater than 160 ±5 °C (320 ±9 °F),’’ 
be changed to, ‘‘The probe and filter holder heating system in the sampling train shall be set to provide an average gas temperature of 160 ±5 °C (320 
±9°F),’’ because they believe that this 
was the agency’s intent. Similarly, another commenter requested that the statement in § 60.296(d)(2), ‘‘The probe and filter holder heating system may be set to provide a gas temperature no greater than 177 ±5 °C (320 ±9 °F),’’ be 
changed to, ‘‘The probe and filter holder heating system shall be set to provide an average gas temperature 160 ±5 °C (320 
±9°F),’’ because they believe that this 
was the agency’s intent. One commenter also recommended changing the sentence in Method 5B to, ‘‘The 
collected sample is then heated in an oven at 160 °C (320 °F) for 6 hours . . . 
,’’ to, ‘‘The collected sample is then heated in an oven at 160 ±5 °C (320 
±9°F) for 6 hours . . .,’’ to be internally 
consistent. 
Three commenters noted that if the 
temperature tolerances are changed in Method 5, methods that reference Method 5 (namely Method 5D, section 
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2.1; Method 5E, section 2.0; and Method 
5F, section 2.0) would also need to be revised. 
Three commenters remarked that 
tightening the filter temperature tolerance conflicts with the assertion that the proposed rule will improve the quality of data but will not impose new substantive requirements. Two of the three commenters further remarked that the proposed rule does not meet the requirements of Executive Order 13771 nor the Paperwork Reduction Act (PRA). 
Three commenters acknowledged that 
an improvement in measurement precision could benefit the data quality in limited situations, such as the Mercury and Air Toxics Standards (MATS). 
Four commenters remarked that if the 
proposed revisions to the temperature tolerances lead to a measurable change in reported PM emissions, sources that were previously in compliance with their emission standards may become non-compliant; one commenter added that the opposite situation may occur. One commenter stated that the proposed revision may have the unintended consequence of redefining the filterable PM being measured leading to either higher or lower PM measurements as compared to sampling runs conducted with wider tolerances. 
Two commenters mentioned that this 
revision could result in a potential 
safety risk. One of the commenters remarked that the added weight and handling difficulties associated with air- or water-cooled probes (if necessary to control the probe temperature) can increase safety risks to testing personnel, and the other commenter remarked that the proposed requirements may require the use of encapsulated probes which are heavy and cumbersome resulting in hazards. 
Response: In response to these 
comments and in a change from proposal, we are deferring finalizing proposed revisions of the temperature tolerances of probe and filter holder heating systems as part of this rulemaking. We will continue to review supporting information and data we received on the proposed rule and may propose either revisions or similar requirements as part of future rulemakings. 
V. Statutory and Executive Order 
Reviews 
Additional information about these 
statutes and Executive Orders can be found at http://www2.epa.gov/laws- regulations/laws-and-executive-orders. A. Executive Order 12866: Regulatory 
Planning and Review and Executive Order 13563: Improving Regulation and Regulatory Review 
This action is not a significant 
regulatory action and was, therefore, not 
submitted to the Office of Management and Budget (OMB) for review. 
B. Executive Order 13771: Reducing 
Regulations and Controlling Regulatory Costs 
This action is considered an 
Executive Order 13771 deregulatory action. This final rule provides meaningful burden reduction by allowing regulated facilities the flexibility to use newly-approved alternative procedures for compliance demonstration purposes, which may result in lower labor costs for some facilities (e.g., allowing digital 
photography in lieu of manual documentation in EPA Method 22); lower compliance testing costs (e.g., additional sample storage container options now allowed by Method 26); reducing the likelihood of re-testing (e.g., revised QA requirements in 
Method 308); and expediting data processing (e.g., simplified calculations 
in Method 325B). 
C. Paperwork Reduction Act (PRA) 
This action does not impose an 
information collection burden under the 
PRA. The revisions do not substantively revise the existing information collection requirements but simply corrects, updates, and clarifies performance testing and continuous monitoring requirements. 
D. Regulatory Flexibility Act (RFA) 
I certify that this action will not have 
a significant economic impact on a 
substantial number of small entities under the RFA. In making this determination, the impact of concern is any significant adverse economic impact on small entities. An agency may certify that a rule will not have a significant economic impact on a substantial number of small entities if the rule relieves regulatory burden, has no net burden or otherwise has a positive economic effect on the small entities subject to the rule. This action will not impose emission measurement requirements beyond those specified in the current regulations, nor does it 
change any emission standard. We have, therefore, concluded that this action will have no net regulatory burden for all directly regulated small entities. E. Unfunded Mandates Reform Act 
(UMRA) 
This action does not contain any 
unfunded mandate as described in UMRA, 2 U.S.C. 1531–1538, and does not significantly or uniquely affect small governments. The action imposes no enforceable duty on any state, local or tribal governments or the private sector. 
F. Executive Order 13132: Federalism 
This action does not have federalism 
implications. It will not have substantial 
direct effects on the states, on the relationship between the national government and the states, or on the distribution of power and 
responsibilities among the various levels of government. 
G. Executive Order 13175: Consultation 
and Coordination With Indian Tribal Governments 
This action does not have tribal 
implications, as specified in Executive Order 13175. This action simply corrects and updates existing testing regulations. Thus, Executive Order 13175 does not apply to this action. 
H. Executive Order 13045: Protection of 
Children From Environmental Health Risks and Safety Risks 
The EPA interprets Executive Order 
13045 as applying only to those regulatory actions that concern environmental health or safety risks that the EPA has reason to believe may disproportionately affect children, per the definition of ‘‘covered regulatory action’’ in section 2–202 of the Executive Order. This action is not subject to Executive Order 13045 because it does not concern an environmental health risk or safety risk. 
I. Executive Order 13211: Actions 
Concerning Regulations That Significantly Affect Energy Supply, Distribution or Use 
This action is not subject to Executive 
Order 13211, because it is not a significant regulatory action under Executive Order 12866. 
J. National Technology Transfer and 
Advancement Act (NTTAA) and 1 CFR part 51 
This action involves technical 
standards. The EPA used ASTM D6216– 12 for continuous opacity monitors in Performance Specification 1. The ASTM D6216–12 standard covers the procedure for certifying continuous opacity monitors and includes design and performance specifications, test procedures, and QA requirements to ensure that continuous opacity monitors meet minimum design and calibration 
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requirements necessary, in part, for 
accurate opacity monitoring measurements in regulatory environmental opacity monitoring applications subject to 10 percent or higher opacity standards. 
The ASTM D6216–12 standard was 
developed and adopted by the American Society for Testing and Materials (ASTM). The standard may be obtained from http://www.astm.org or from the 
ASTM at 100 Barr Harbor Drive, P.O. Box C700, West Conshohocken, PA 19428–2959. 
K. Executive Order 12898: Federal 
Actions To Address Environmental Justice in Minority Populations and Low-Income Populations 
The EPA believes that this action is 
not subject to Executive Order 12898 (59 FR 7629, February 16, 1994) because it does not establish an environmental health or safety standard. This action is a technical correction to previously promulgated regulatory actions and does not have an impact on human 
health or the environment. 
L. Congressional Review Act (CRA) 
This action is subject to the CRA, and 
the EPA will submit a rule report to each house of the Congress and to the 
Comptroller General of the United States. This action is not a ‘‘major rule’’ as defined by 5 U.S.C. 804(2). 
List of Subjects 40 CFR Part 51 
Environmental protection, Air 
pollution control, Performance 
specifications, Test methods and procedures. 
40 CFR Part 60 
Environmental protection, Air 
pollution control, Incorporation by 
reference, Performance specifications, Test methods and procedures. 
40 CFR Part 63 
Environmental protection, Air 
pollution control, Incorporation by 
reference, Performance specifications, Test methods and procedures. 
Dated: November 5, 2018. 
Andrew R. Wheeler, 
Acting Administrator. 
For the reasons stated in the 
preamble, the Environmental Protection 
Agency amends title 40, chapter I of the Code of Federal Regulations as follows: PART 51—REQUIREMENTS FOR 
PREPARATION, ADOPTION, AND SUBMITTAL OF IMPLEMENTATION PLANS 
■1. The authority citation for part 51 
continues to read as follows: 
Authority: 23 U.S.C. 101; 42 U.S.C. 7401– 
7671q. 
■2. Amend appendix M to part 51 as 
follows: 
■a. Revise section 12.5, equation 24, in 
Method 201A. 
■b. Revise the last sentence in section 
8.2 in Method 204. 
■c. Revise section 2.1.1 in Method 205. 
The revisions read as follows: 
Appendix M to Part 51—Recommended Test Methods for State Implementation Plans 
* * * * * 
Method 201A—Determination of PM 10and 
PM 2.5Emissions From Stationary Sources 
(Constant Sampling Rate Procedure) 
* * * * * 
12.5 * * * 
* * * * * 
Method 204—Criteria for and Verification of 
a Permanent or Temporary Total Enclosure 
* * * * * 
8.2 * * * 
The NEAR must be ≤0.05. 
* * * * * 
Method 205—Verification of Gas Dilution 
Systems for Field Instrument Calibrations 
* * * * * 
2.1.1 The gas dilution system shall be 
recalibrated once per calendar year using 
NIST-traceable flow standards with an uncertainty ≤0.25 percent. You shall report 
the results of the calibration by the person or manufacturer who carried out the calibration whenever the dilution system is used, listing the date of the most recent calibration, the due date for the next calibration, calibration point, reference flow device (ID, S/N), and acceptance criteria. Follow the manufacturer’s instructions for the operation and use of the gas dilution system. A copy of the manufacturer’s instructions for the operation of the instrument, as well as the most recent calibration documentation, shall be made available for inspection at the test site. 
* * * * * 
PART 60—STANDARDS OF 
PERFORMANCE FOR NEW STATIONARY SOURCES 
■3. The authority citation for part 60 
continues to read as follows: 
Authority: 42 U.S.C. 7401 et seq. 
■4. In § 60.17, revise paragraph (h)(177) 
to read as follows: 
§ 60.17 Incorporations by reference. 
* * * * * 
(h) * * * 
(177) ASTM D6216–12, Standard 
Practice for Opacity Monitor 
Manufacturers to Certify Conformance 
with Design and Performance Specifications, approved October 1, 2012; IBR approved for appendix B to part 60. 
* * * * * ■5. In Appendix A–1 to part 60, revise 
‘‘(CO 2)a’’ in section 12.1 in Method 2B 
to read as follows: 
Appendix A–1 to Part 60—Test 
Methods 1 through 2F 
* * * * * 
Method 2B—Determination of Exhaust Gas 
Volume Flow Rate From Gasoline Vapor Incinerators 
* * * * * 
12.1 * * * (CO
2)a= Ambient carbon dioxide 
concentration, ppm (if not measured during the test period, may be assumed to equal the global monthly mean CO
2concentration 
posted at http://www.esrl.noaa.gov/gmd/ ccgg/trends/global.html#global_ data). 
* * * * * 
■6. In appendix A–3 to part 60: 
■a. Revise sections 6.1.1.9 and 11.2.1 in 
Method 5. 
■b. Revise section 11.0 in Method 5B. 
■c. Add section 17.0 in Method 5B. 
The revisions and addition read as 
follows: 
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Appendix A–3 to Part 60—Test 
Methods 4 through 5I 
* * * * * 
Method 5—Determination of Particulate 
Matter Emissions From Stationary Sources 
* * * * * 
6.1.1.9 Metering System. Vacuum gauge, 
leak-free pump, calibrated temperature 
sensors, dry gas meter (DGM) capable of measuring volume to within 2 percent, and related equipment, as shown in Figure 5–1. Other metering systems capable of maintaining sampling rates within 10 percent of isokinetic and of determining sample volumes to within 2 percent may be used, subject to the approval of the Administrator. When the metering system is used in conjunction with a pitot tube, the system shall allow periodic checks of isokinetic rates. The average DGM temperature for use in the calculations of section 12.0 may be obtained by averaging the two temperature sensors located at the inlet and outlet of the DGM as shown in Figure 5–3 or alternatively from a single temperature sensor located at the immediate outlet of the DGM or the plenum of the DGM. 
* * * * * 
11.2.1 Container No. 1. Leave the 
contents in the shipping container or transfer 
the filter and any loose PM from the sample container to a tared weighing container. Desiccate for 24 hours in a desiccator containing anhydrous calcium sulfate. Weigh to a constant weight, and report the results to the nearest 0.1 mg. For the purposes of this section, the term ‘‘constant weight’’ means a difference of no more than 0.5 mg or 1 percent of total weight less tare weight, whichever is greater, between two consecutive weighings, with no less than 6 
hours of desiccation time between weighings. Alternatively, the sample may be oven dried at 104 °C (220 °F) for 2 to 3 hours, cooled in 
the desiccator, and weighed to a constant weight, unless otherwise specified by the Administrator. The sample may be oven dried at 104 °C (220 °F) for 2 to 3 hours. Once 
the sample has cooled, weigh the sample, and use this weight as a final weight. 
* * * * * 
Method 5B-Determination of Nonsulfuric 
Acid Particulate Matter Emissions From Stationary Sources 
* * * * * 
11.0 Analytical Procedure 
11.1 Record and report the data required 
on a sheet such as the one shown in Figure 
5B–1. 
11.2 Handle each sample container as 
follows: 
11.2.1 Container No. 1. Leave the 
contents in the shipping container or transfer the filter and any loose PM from the sample container to a tared non-reactive oven-proof container. Oven dry the filter sample at a temperature of 160 ±5 °C (320 ±9 °F) for 6 
hours. Cool in a desiccator for 2 hours, and weigh to constant weight. Report the results to the nearest 0.1 mg. For the purposes of this section, the term ‘‘constant weight’’ means a difference of no more than 0.5 mg or 1 percent of total weight less tare weight, whichever is greater, between two consecutive weighings, with no less than 6 hours of desiccation time between weighings. 
11.2.2 Container No. 2. Note the level of 
liquid in the container, and confirm on the analysis sheet whether leakage occurred during transport. If a noticeable amount of leakage has occurred, either void the sample 
or use methods, subject to the approval of the Administrator, to correct the final results. Measure the liquid in this container either volumetrically to ±1 ml or gravimetrically to ±0.5 g. Transfer the contents to a tared 250 ml beaker, and evaporate to dryness at ambient temperature and pressure. Then oven dry the probe sample at a temperature of 160 ±5 °C (320 ±9 °F) for 6 hours. Cool in 
a desiccator for 2 hours, and weigh to constant weight. Report the results to the nearest 0.1 mg. 
11.2.3 Container No. 3. Weigh the spent 
silica gel (or silica gel plus impinger) to the nearest 0.5 g using a balance. This step may be conducted in the field. 
11.2.4 Acetone Blank Container. Measure 
the acetone in this container either volumetrically or gravimetrically. Transfer the acetone to a tared 250 ml beaker, and evaporate to dryness at ambient temperature and pressure. Desiccate for 24 hours, and weigh to a constant weight. Report the results to the nearest 0.1 mg. 
Note: The contents of Container No. 2 as 
well as the acetone blank container may be evaporated at temperatures higher than ambient. If evaporation is done at an elevated temperature, the temperature must be below the boiling point of the solvent; also, to prevent ‘‘bumping,’’ the evaporation process must be closely supervised, and the contents of the beaker must be swirled occasionally to maintain an even temperature. Use extreme care, as acetone is highly flammable and has 
a low flash point. 
* * * * * 
17.0 Tables, Diagrams, Flowcharts, and 
Validation Data 
Container number Weight of particulate collected, mg 
Final weight Tare weight Weight gain 
1. 
2. 
Total: 
Less acetone blank 
Weight of particulate matter 
Volume of liquid water collected 
Impinger volume, Silica gel weight, 
ml g 
Final 
Initial 
Liquid collected 
Total volume collected g* ml 
* Convert weight of water to volume by dividing total weight increase by density of water (1 g/ml). 
Figure 5B–1. Analytical Data Sheet 
* * * * * 
■7. In appendix A–4 to part 60: 
■a. Revise sections 10.1.2 and 11.3 in 
Method 7. ■b. Redesignate sections 6.1.1.1 
through 6.1.1.4 as sections 6.1.1.2 
through 6.1.1.5 in Method 8. 
■c. Add a new section 6.1.1.1 in 
Method 8. 
■d. Revise Figure 8–1 in Method 8. The revisions and addition read as 
follows: 
Appendix A–4 to Part 60—Test 
Methods 6 Through 10B 
* * * * * 
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Method 7—Determination of Nitrogen Oxide 
Emissions From Stationary Sources 
* * * * * 
10.1.2 Determination of 
Spectrophotometer Calibration Factor K c. 
Add 0 ml, 2.0 ml, 4.0 ml, 6.0 ml, and 8.0 ml 
of the KNO 3working standard solution (1 ml 
= 100 mg NO 2) to a series of five 50-ml 
volumetric flasks. To each flask, add 25 ml of absorbing solution and 10 ml water. Add 1 N NaOH to each flask until the pH is between 9 and 12 (about 25 to 35 drops). Dilute to the mark with water. Mix thoroughly, and pipette a 25-ml aliquot of each solution into a separate porcelain 
evaporating dish. Beginning with the evaporation step, follow the analysis procedure of section 11.2 until the solution has been transferred to the 100-ml volumetric flask and diluted to the mark. Measure the absorbance of each solution at the optimum wavelength as determined in section 10.1.1. This calibration procedure must be repeated on each day that samples are analyzed. 
Calculate the spectrophotometer calibration factor as shown in section 12.2. 
* * * * * 
11.3 Sample Analysis. Mix the contents 
of the flask thoroughly, and measure the absorbance at the optimum wavelength used for the standards (section 10.1.1), using the 
blank solution as a zero reference. Dilute the sample and the blank with equal volumes of water if the absorbance exceeds A
4, the 
absorbance of the 400-mg NO 2standard (see 
section 10.1.3). 
* * * * * 
Method 8—Determination of Sulfuric Acid and Sulfur Dioxide Emissions From Stationary Sources 
* * * * * 
6.1.1.1 Probe Nozzle. Borosilicate or 
quartz glass with a sharp, tapered leading edge and coupled to the probe liner using a polytetrafluoroethylene (PTFE) or glass-lined union (e.g., fused silica, Slico, or equivalent). 
When the stack temperature exceeds 210 °C 
(410 °F), a leak-free ground glass fitting or 
other leak free, non-contaminating fitting must be used to couple the nozzle to the probe liner. It is also acceptable to use a one- piece glass nozzle/liner assembly. The angle of the taper shall be ≤30°, and the taper shall be on the outside to preserve a constant internal diameter. The probe nozzle shall be of the button-hook or elbow design, unless otherwise specified by the Administrator. Other materials of construction may be used, subject to the approval of the Administrator. 
A range of nozzle sizes suitable for isokinetic sampling should be available. Typical nozzle sizes range from 0.32 to 1.27 cm (
1⁄8to 1⁄2in) 
inside diameter (ID) in increments of 0.16 cm (
1⁄16in). Larger nozzles sizes are also 
available if higher volume sampling trains are used. 
* * * * * 
17.0 * * * 
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* * * * * 
Appendix A–6 to Part 60—[Amended] 
■8. In Appendix A–6 to part 60, 
redesignate paragraph (c) as paragraph 
(b) in section 13.1 in Method 18. 
■9. In appendix A–7 to part 60: 
■a. Revise sections 11.2.1 and 11.2.2 in 
Method 22. 
■b. Add section 11.2.3 in Method 22. 
The revisions and addition read as 
follows: 
Appendix A–7 to Part 60—Test 
Methods 19 Through 25E 
* * * * * 
Method 22—Visual Determination of 
Fugitive Emissions From Material Sources and Smoke Emissions From Flares 
* * * * * 
11.2.1 Outdoor Location. Record the 
following information on the field data sheet 
(Figure 22–1): Company name, industry, process unit, observer’s name, observer’s affiliation, and date. Record also the estimated wind speed, wind direction, and sky condition. Sketch the process unit being observed, and note the observer location relative to the source and the sun. Indicate the potential and actual emission points on the sketch. Alternatively, digital photography as described in section 11.2.3 may be used for a subset of the recordkeeping requirements of this section. 
11.2.2 Indoor Location. Record the 
following information on the field data sheet (Figure 22–2): Company name, industry, process unit, observer’s name, observer’s affiliation, and date. Record as appropriate the type, location, and intensity of lighting on the data sheet. Sketch the process unit being observed, and note the observer 
location relative to the source. Indicate the potential and actual fugitive emission points on the sketch. Alternatively, digital photography as described in section 11.2.3 may be used for a subset of the recordkeeping requirements of this section. 
11.2.3 Digital Photographic Records. 
Digital photographs, annotated or unaltered, 
may be used to record and report sky conditions, observer’s location relative to the source, observer’s location relative to the sun, process unit being observed, potential emission points and actual emission points for the requirements in sections 11.2.1 and 11.2.2. The image must have the proper lighting, field of view and depth of field to properly distinguish the sky condition (if applicable), process unit, potential emission point and actual emission point. At least one digital photograph must be from the point of the view of the observer. The photograph(s) representing the environmental conditions including the sky conditions and the position of the sun relative to the observer and the emission point must be taken within a reasonable time of the observation (i.e., 15 
minutes). When observations are taken from exactly the same observation point on a routine basis (i.e., daily) and as long as there 
are no modifications to the units depicted, only a single photograph each is necessary to document the observer’s location relative to the emissions source, the process unit being observed, and the location of potential and actual emission points. Any photographs altered or annotated must be retained in an unaltered format for recordkeeping purposes. 
* * * * * 
■10. In appendix A–8 to part 60: 
■a. Revise section 6.2.2 in Method 26. 
■b. Revise section 6.2.1 in Method 26A. 
■c. Add section 6.2.4 in Method 26A. ■d. Revise equation 8 in section 13.5.1 
in Test Method 28WHH. 
The revisions and additions read as 
follows: 
Appendix A–8 to Part 60—Test 
Methods 26 Through 30B 
* * * * * 
Method 26—Determination of Hydrogen 
Halide and Halogen Emissions From Stationary Sources Non-Isokinetic Method 
* * * * * 
6.2.2 Storage Containers. 100- or 250-ml, 
high-density polyethylene or glass sample 
storage containers with Teflon screw cap liners to store impinger samples. 
* * * * * 
Method 26A—Determination of Hydrogen 
Halide and Halogen Emissions From Stationary Sources Isokinetic Method 
* * * * * 
6.2.1 Probe-Liner and Probe-Nozzle 
Brushes, Wash Bottles, Petri Dishes, 
Graduated Cylinder and/or Balance, and Rubber Policeman. Same as Method 5, sections 6.2.1, 6.2.2, 6.2.4, 6.2.5, and 6.2.7. 
* * * * * 
6.2.4 Sample Storage Containers. High- 
density polyethylene or glass sample storage containers with Teflon screw cap liners to store impinger samples. 
* * * * * 
Test Method 28WHH for Measurement of 
Particulate Emissions and Heating Efficiency of Wood-Fired Hydronic Heating Appliances 
* * * * * 
13.5.1 * * * 
* * * * * 
■11. In appendix B to part 60: 
■a. Add the following entries to the list 
of Performance Specifications in 
numeric order: 
■i. Performance Specification 12B— 
Specifications and Test Procedures for Monitoring Total Vapor Phase Mercury Emissions From Stationary Sources Using A Sorbent Trap Monitoring System 
■ii. Performance Specification 17 
[Reserved] 
■iii. Performance Specification 18— 
Performance Specifications and Test Procedures for Gaseous Hydrogen Chloride (HCl) Continuous Emission Monitoring Systems at Stationary Sources 
■iv. PS–18—Appendix A Standard 
Addition Procedures 
■b. In Performance Specification 1, 
remove ‘‘D 6216–98’’ wherever it appears and add in its place ‘‘D6216– 12’’, and revise section 2.1, the introductory text of section 13.0, sections 13.1 and 13.2, and paragraph 8. of section 16.0. 
■c. In Performance Specification 2, 
revise section 13.2. 
■d. In Performance Specification 3, 
revise sections 12.0 and 13.2. 
■e. In Performance Specification 11, 
revise section 13.1. 
■f. In Performance Specification 15, 
add reserved section 13.0. 
■g. In Performance Specification 18, 
revise section 11.8.7 and table 1 in section 17.0, and add reserved section 12.0 to PS–18. 
The revisions and additions read as 
follows: 
Appendix B to Part 60—Performance 
Specifications 
* * * * * Performance Specification 1—Specifications 
and Test Procedures for Continuous Opacity Monitoring Systems in Stationary Sources 
* * * * * 
2.1 ASTM D6216–12 (incorporated by 
reference, see § 60.17) is the reference for 
design specifications, manufacturer’s performance specifications, and test procedures. The opacity monitor manufacturer must periodically select and test an opacity monitor, that is representative of a group of monitors produced during a specified period or lot, for conformance with the design specifications in ASTM D6216–12. The opacity monitor manufacturer must test each opacity monitor for conformance with the manufacturer’s performance specifications in ASTM D6216–12. Note: If the initial certification of the opacity monitor occurred before November 14, 2018 using D6216–98, D6216–03, or D6216–07, it is not necessary to recertify using D6216–12. 
* * * * * 
13.0 What Specifications Does a COMS 
Have to Meet for Certification? 
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A COMS must meet the following design, 
manufacturer’s performance, and field audit 
performance specifications: 
Note: If the initial certification of the 
opacity monitor occurred before November 14, 2018 using D6216–98, D6216–03, or D6216–07, it is not necessary to recertify using D6216–12.A. COMS must meet the following design, manufacturer’s performance, and field audit performance specifications. 13.1 Design Specifications. The opacity 
monitoring equipment must comply with the 
design specifications of ASTM D6216–12. 
13.2 Manufacturer’s Performance 
Specifications. The opacity monitor must comply with the manufacturer’s performance specifications of ASTM D6216–12. 
* * * * * 
16.0 * * * 8. ASTM D6216–12: Standard Practice for 
Opacity Monitor Manufacturers to Certify Conformance with Design and Performance 
Specifications. ASTM. October 2012. 
* * * * * 
Performance Specification 2—Specifications 
and Test Procedures for SO 2and NO X 
Continuous Emission Monitoring Systems in Stationary Sources 
* * * * * 
13.2 Relative Accuracy Performance 
Specification. 
Calculate . . . RA criteria 
(%) 
If average emissions during the RATA are ≥50% of emission 
standard.Use Eq. 2–6, with RM in the denominator ............................. ≤20.0 
If average emissions during the RATA are <50% of emission 
standard.Use Eq. 2–6, emission standard in the denominator ............. ≤10.0 
For SO 2emission standards ≤130 but ≥86 ng/J (0.30 and 
0.20 lb/million Btu).Use Eq. 2–6, emission standard in the denominator ............. ≤15.0 
For SO 2emission standards <86 ng/J (0.20 lb/million Btu) .... Use Eq. 2–6, emission standard in the denominator ............. ≤20.0 
* * * * * Performance Specification 3—Specifications and Test Procedures for O
2and CO 2 
Continuous Emission Monitoring Systems in Stationary Sources 
* * * * * 12.0 Calculations and Data Analysis 
Calculate the RA using equations 3–1 and 
3–2. Summarize the results on a data sheet similar to that shown in Figure 2.2 of PS2. 
* * * * * 
13.2 CEMS Relative Accuracy 
Performance Specification. The RA of the CEMS must be no greater than 20.0 percent of the mean value of the reference method (RM) data when calculated using equation 3–1. The results are also acceptable if the result of Equation 3–2 is less than or equal to 1.0 percent O
2(or CO 2). 
* * * * * Performance Specification 11— 
Specifications and Test Procedures for Particulate Matter Continuous Emission Monitoring Systems at Stationary Sources 
* * * * * 
13.1 What is the 7-day drift check 
performance specification? Your daily PM 
CEMS internal drift checks must demonstrate that the daily drift of your PM CEMS does not deviate from the value of the reference light, optical filter, Beta attenuation signal, or other technology-suitable reference standard by more than 2 percent of the response range. If your CEMS includes diluent and/or 
auxiliary monitors (for temperature, pressure, 
and/or moisture) that are employed as a necessary part of this performance specification, you must determine the calibration drift separately for each ancillary monitor in terms of its respective output (see the appropriate performance specification for the diluent CEMS specification). None of the calibration drifts may exceed their individual specification. 
* * * * * 
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Performance Specification 15—Performance 
Specification for Extractive FTIR Continuous Emissions Monitor Systems in Stationary Sources 
* * * * * 
13.0 Method Performance [Reserved] 
* * * * * 
Performance Specification 18—Performance Specifications and Test Procedures for Gaseous Hydrogen Chloride (HCl) Continuous Emission Monitoring Systems at Stationary Sources 
* * * * * 
11.8.7 The zero-level and mid-level CD 
for each day must be less than 5.0 percent of 
the span value as specified in section 13.2 of this PS. You must meet this criterion for 7 consecutive operating days. 
* * * * * 
17.0 * * * TABLE 1—I NTERFERENCE TESTGAS 
CONCENTRATIONS  
Potential 
interferent gas1 Approximate concentration 
(balance N 2) 
CO 2................... 15% ± 1% CO 2.2 
CO .................... 100 ± 20 ppm. 
CH2O ................ 20 ± 5 ppm. 
CH4................... 100 ± 20 ppm. 
NH3................... 10 ± 5 ppm (extractive 
CEMS only). 
NO .................... 250 ± 50 ppm. 
SO2................... 200 ± 20 ppm. 
O2..................... 3% ± 1% O 2.2 
H2O ................... 10% ± 1% H 2O.2 
N2...................... Balance.2 
1Any of these specific gases can be tested 
at a lower level if the manufacturer has pro-
vided reliable means for limiting or scrubbing that gas to a specified level in CEMS field in-stallations. 
2Gases for short path IP cell interference 
tests cannot be added above 100 percent stack equivalent concentration. Add these gases at the indicated percentages to make up the remaining cell volume. * * * * * 
PS–18 Appendix A Standard 
Addition Procedures 
* * * * * 
12.0 [Reserved] 
* * * * * 
■12. Revise sections 5.1.2(1) and (3) in 
Procedure 1 of appendix F to part 60 to 
read as follows: 
Appendix F to Part 60—Quality 
Assurance Procedures 
Procedure 1—Quality Assurance 
Requirements for Gas Continuous Emission Monitoring Systems Used For Compliance Determination 
* * * * * 
5.1.2 * * * 
(1) Challenge the CEMS (both pollutant 
and diluent portions of the CEMS, if applicable) with an audit gas of known concentration at two points within the following ranges: 
Audit point Audit range 
Pollutant monitors Diluent monitors for— 
CO
2 O 2 
1 ................................. 20 to 30% of span value .............................. 5 to 8% by volume ....................................... 4 to 6% by volume. 
2 ................................. 50 to 60% of span value .............................. 10 to 14% by volume ................................... 8 to 12% by volume. 
Introduce each of the audit gases, three 
times each for a total of six challenges. Introduce the gases in such a manner that the entire CEMS is challenged. Do not introduce the same gas concentration twice in succession. 
Use of separate audit gas cylinder for audit 
points 1 and 2. Do not dilute gas from audit cylinder when challenging the CEMS. 
The monitor should be challenged at each 
audit point for a sufficient period of time to assure adsorption-desorption of the CEMS sample transport surfaces has stabilized. 
* * * * * 
(3) Use Certified Reference Materials 
(CRM’s) (See Citation 1) audit gases that have been certified by comparison to National Institute of Standards and Technology (NIST) Standard Reference Materials (SRM’s) or EPA Protocol Gases following the most recent edition of the EPA Traceability Protocol for Assay and Certification of Gaseous Calibration Standards (See Citation 2). Procedures for preparation of CRM’s are described in Citation 1. Procedures for preparation of EPA Protocol Gases are described in Citation 2. In the case that a suitable audit gas level is not commercially available, Method 205 (See Citation 3) may be used to dilute CRM’s or EPA Protocol Gases to the needed level. The difference between the actual concentration of the audit gas and the concentration indicated by the monitor is used to assess the accuracy of the CEMS. 
* * * * * PART 63—NATIONAL EMISSION 
STANDARDS FOR HAZARDOUS AIR POLLUTANTS FOR SOURCE CATEGORIES 
■13. The authority citation for part 63 
continues to read as follows: 
Authority: 42 U.S.C. 7401 et seq. 
■14. In § 63.7, revise paragraphs (g)(2) 
introductory text and (g)(2)(v) to read as follows: 
§ 63.7 Performance testing requirements. 
* * * * * 
(g) * * * 
(2) Contents of a performance test, 
CMS performance evaluation, or CMS 
quality assurance test report (electronic or paper submitted copy). Unless otherwise specified in a relevant standard, test method, CMS performance specification, or quality assurance requirement for a CMS, or as otherwise approved by the Administrator in writing, the report shall include the elements identified in paragraphs (g)(2)(i) through (vi) of this section. 
* * * * * 
(v) Where a test method, CEMS, 
PEMS, or COMS performance 
specification, or on-going quality assurance requirement for a CEMS, PEMS, or COMS requires you record or report, the following shall be included in your report: Record of preparation of standards, record of calibrations, raw data sheets for field sampling, raw data sheets for field and laboratory analyses, chain-of-custody documentation, and example calculations for reported results. 
* * * * * 
■15. In § 63.8, revise paragraph (e)(5)(i) 
to read as follows: 
§ 63.8 Monitoring requirements. 
* * * * * 
(e) * * * 
(5) * * * (i) The owner or operator 
shall furnish the Administrator a copy 
of a written report of the results of the performance evaluation containing the information specified in § 63.7(g)(2)(i) through (vi) simultaneously with the results of the performance test required under § 63.7 or within 60 days of completion of the performance evaluation, unless otherwise specified in a relevant standard. 
* * * * * 
■16. Revise Table 6 to Subpart DDDDD 
of part 63 to read as follows: 
Table 6 to Subpart DDDDD of Part 63— 
Fuel Analysis Requirements 
As stated in § 63.7521, you must 
comply with the following requirements 
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for fuel analysis testing for existing, new 
or reconstructed affected sources. However, equivalent methods (as defined in § 63.7575) may be used in 
lieu of the prescribed methods at the discretion of the source owner or operator: 
To conduct a fuel analysis for the 
following pollutant . . . You must . . . Using . . . 
1. Mercury ....................................... a. Collect fuel samples .................. Procedure in § 63.7521(c) or ASTM D519 2a, or ASTM D7430a, or 
ASTM D6883a, or ASTM D2234/D2234Ma(for coal) or EPA 1631 
or EPA 1631E or ASTM D6323a(for solid), or EPA 821–R–01–013 
(for liquid or solid), or ASTM D4177a(for liquid), or ASTM D4057a 
(for liquid), or equivalent. 
b. Composite fuel samples ............ Procedure in § 63.7521(d) or equivalent. 
c. Prepare composited fuel sam-
ples.EPA SW–846–3050Ba(for solid samples), ASTM D2013/D2013Ma 
(for coal), ASTM D5198a(for biomass), or EPA 3050a(for solid 
fuel), or EPA 821–R–01–013a(for liquid or solid), or equivalent. 
d. Determine heat content of the 
fuel type.ASTM D5865a(for coal) or ASTM E711a(for biomass), or ASTM 
D5864afor liquids and other solids, or ASTM D240aor equivalent. 
e. Determine moisture content of 
the fuel type.ASTM D3173a, ASTM E871a, or ASTM D5864a, or ASTM D240a, or 
ASTM D95a(for liquid fuels), or ASTM D4006a(for liquid fuels), or 
equivalent. 
f. Measure mercury concentration 
in fuel sample.ASTM D6722a(for coal), EPA SW–846–7471Baor EPA 1631 or EPA 
1631Ea(for solid samples), or EPA SW–846–7470Aaor EPA SW– 
846–7471Ba(for liquid samples), or EPA 821–R–01–013a(for liq-
uid or solid), or equivalent. 
g. Convert concentration into units 
of pounds of mercury per 
MMBtu of heat content.For fuel mixtures use Equation 8 in § 63.7530. 
2. HCl .............................................. a. Collect fuel samples .................. Procedure in § 63.7521(c) or ASTM D 5192a, or ASTM D7430a, or 
ASTM D6883a, or ASTM D2234/D2234Ma(for coal) or ASTM 
D6323a(for coal or biomass), ASTM D4177a(for liquid fuels) or 
ASTM D4057a(for liquid fuels), or equivalent. 
b. Composite fuel samples ............ Procedure in § 63.7521(d) or equivalent. 
c. Prepare composited fuel sam-
ples.EPA SW–846–3050Ba(for solid samples), ASTM D2013/D2013Ma 
(for coal), or ASTM D5198a(for biomass), or EPA 3050aor equiva-
lent. 
d. Determine heat content of the 
fuel type.ASTM D5865a(for coal) or ASTM E711a(for biomass), ASTM 
D5864a, ASTM D240aor equivalent. 
e. Determine moisture content of 
the fuel type.ASTM D3173aor ASTM E871a, or D5864a, or ASTM D240a, or 
ASTM D95a(for liquid fuels), or ASTM D4006a(for liquid fuels), or 
equivalent. 
f. Measure chlorine concentration 
in fuel sample.EPA SW–846–9250a, ASTM D6721a, ASTM D4208a(for coal), or 
EPA SW–846–5050aor ASTM E776a(for solid fuel), or EPA SW– 
846–9056aor SW–846–9076a(for solids or liquids) or equivalent. 
g. Convert concentrations into 
units of pounds of HCl per MMBtu of heat content.For fuel mixtures use Equation 7 in § 63.7530 and convert from chlo-
rine to HCl by multiplying by 1.028. 
3. Mercury Fuel Specification for 
other gas 1 fuels.a. Measure mercury concentration 
in the fuel sample and convert to units of micrograms per cubic meter, or.Method 30B (M30B) at 40 CFR part 60, appendix A–8 of this chapter 
or ASTM D5954
a, ASTM D6350a, ISO 6978–1:2003(E)a, or ISO 
6978–2:2003(E)a, or EPA–1631aor equivalent. 
b. Measure mercury concentration 
in the exhaust gas when firing only the other gas 1 fuel is fired in the boiler or process heater.Method 29, 30A, or 30B (M29, M30A, or M30B) at 40 CFR part 60, 
appendix A–8 of this chapter or Method 101A or Method 102 at 40 CFR part 61, appendix B of this chapter, or ASTM Method D6784
a 
or equivalent. 
4. TSM ............................................. a. Collect fuel samples .................. Procedure in § 63.7521(c) or ASTM D5 192a, or ASTM D7430a, or 
ASTM D6883a, or ASTM D2234/D2234Ma(for coal) or ASTM 
D6323a(for coal or biomass), or ASTM D4177a, (for liquid fuels), 
or ASTM D4057a(for liquid fuels), or equivalent. 
b. Composite fuel samples ............ Procedure in § 63.7521(d) or equivalent. 
c. Prepare composited fuel sam-
ples.EPA SW–846–3050Ba(for solid samples), ASTM D2013/D2013Ma 
(for coal), ASTM D5198aor TAPPI T266a(for biomass), or EPA 
3050aor equivalent. 
d. Determine heat content of the 
fuel type.ASTM D5865a(for coal) or ASTM E711a(for biomass), or ASTM 
D5864afor liquids and other solids, or ASTM D240aor equivalent. 
e. Determine moisture content of 
the fuel type.ASTM D3173aor ASTM E871a, or D5864a, or ASTM D240a, or 
ASTM D95a(for liquid fuels), or ASTM D4006a(for liquid fuels), or 
ASTM D4177a(for liquid fuels) or ASTM D4057a(for liquid fuels), 
or equivalent. 
f. Measure TSM concentration in 
fuel sample.ASTM D3683a, or ASTM D4606a, or ASTM D6357aor EPA 200.8aor 
EPA SW–846–6020a, or EPA SW–846–6020Aa, or EPA SW–846– 
6010Ca, EPA 7060aor EPA 7060Aa(for arsenic only), or EPA 
SW–846–7740a(for selenium only). 
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1Regarding emissions data collected during 
periods of startup or shutdown, see §§ 63.10020(b) 
and (c) and 63.10021(h). To conduct a fuel analysis for the 
following pollutant . . . You must . . . Using . . . 
g. Convert concentrations into 
units of pounds of TSM per 
MMBtu of heat content.For fuel mixtures use Equation 9 in § 63.7530. 
aIncorporated by reference, see § 63.14. 
* * * * * 
■17. Revise Table 5 to Subpart UUUUU 
of part 63 to read as follows: Table 5 to Subpart UUUUU of Part 63— 
Performance Testing Requirements 
As stated in § 63.10007, you must 
comply with the following requirements for performance testing for existing, new 
or reconstructed affected sources:1 
To conduct a performance test 
for the following pollutant...  Using...  You must perform the following activities, as applicable to your input- or output- based emission limit...  Using...
2 
1. Filterable Particulate matter 
(PM).Emissions Testing ... a. Select sampling ports location and the 
number of traverse points.Method 1 at appendix A–1 to part 60 of 
this chapter. 
b. Determine velocity and volumetric flow- 
rate of the stack gas.Method 2, 2A, 2C, 2F, 2G or 2H at ap-
pendix A–1 or A–2 to part 60 of this 
chapter. 
c. Determine oxygen and carbon dioxide 
concentrations of the stack gas.Method 3A or 3B at appendix A–2 to part 
60 of this chapter, or ANSI/ASME PTC 19.10–1981.
3 
d. Measure the moisture content of the 
stack gas.Method 4 at appendix A–3 to part 60 of 
this chapter. 
e. Measure the filterable PM concentration Methods 5 and 5I at appendix A–3 to part 
60 of this chapter. 
For positive pressure fabric filters, Method 
5D at appendix A–3 to part 60 of this chapter for filterable PM emissions. 
Note that the Method 5 or 5I front half 
temperature shall be 160° ±14 °C (320° 
±25 °F). 
f. Convert emissions concentration to lb/ 
MMBtu or lb/MWh emissions rates.Method 19 F-factor methodology at ap-
pendix A–7 to part 60 of this chapter, or calculate using mass emissions rate and gross output data (see § 63.10007(e)). 
OR OR 
PM CEMS ................ a. Install, certify, operate, and maintain 
the PM CEMS.Performance Specification 11 at appendix 
B to part 60 of this chapter and Proce-dure 2 at appendix F to part 60 of this chapter. 
b. Install, certify, operate, and maintain 
the diluent gas, flow rate, and/or mois-ture monitoring systems.Part 75 of this chapter and § 63.10010(a), 
(b), (c), and (d). 
c. Convert hourly emissions concentra-
tions to 30 boiler operating day rolling average lb/MMBtu or lb/MWh emissions rates.Method 19 F-factor methodology at ap-
pendix A–7 to part 60 of this chapter, or calculate using mass emissions rate and gross output data (see § 63.10007(e)). 
2. Total or individual non-Hg 
HAP metals.Emissions Testing ... a. Select sampling ports location and the 
number of traverse points.Method 1 at appendix A–1 to part 60 of 
this chapter. 
b. Determine velocity and volumetric flow- 
rate of the stack gas.Method 2, 2A, 2C, 2F, 2G or 2H at ap-
pendix A–1 or A–2 to part 60 of this chapter. 
c. Determine oxygen and carbon dioxide 
concentrations of the stack gas.Method 3A or 3B at appendix A–2 to part 
60 of this chapter, or ANSI/ASME PTC 19.10–1981.
3 
d. Measure the moisture content of the 
stack gas.Method 4 at appendix A–3 to part 60 of 
this chapter. 
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To conduct a performance test 
for the following pollutant...  Using...  You must perform the following activities, as applicable to your input- or output- based emission limit...  Using...
2 
e. Measure the HAP metals emissions 
concentrations and determine each indi-
vidual HAP metals emissions con-centration, as well as the total filterable HAP metals emissions concentration and total HAP metals emissions con-centration.Method 29 at appendix A–8 to part 60 of 
this chapter. For liquid oil-fired units, Hg is included in HAP metals and you may use Method 29, Method 30B at appen-dix A–8 to part 60 of this chapter; for Method 29, you must report the front half and back half results separately. When using Method 29, report metals matrix spike and recovery levels. 
f. Convert emissions concentrations (indi-
vidual HAP metals, total filterable HAP metals, and total HAP metals) to lb/ MMBtu or lb/MWh emissions rates.Method 19 F-factor methodology at ap-
pendix A–7 to part 60 of this chapter, or calculate using mass emissions rate and gross output data (see § 63.10007(e)). 
3. Hydrogen chloride (HCl) and 
hydrogen fluoride (HF).Emissions Testing ... a. Select sampling ports location and the 
number of traverse points.Method 1 at appendix A–1 to part 60 of 
this chapter. 
b. Determine velocity and volumetric flow- 
rate of the stack gas.Method 2, 2A, 2C, 2F, 2G or 2H at ap-
pendix A–1 or A–2 to part 60 of this chapter. 
c. Determine oxygen and carbon dioxide 
concentrations of the stack gas.Method 3A or 3B at appendix A–2 to part 
60 of this chapter, or ANSI/ASME PTC 19.10–1981.
3 
d. Measure the moisture content of the 
stack gas.Method 4 at appendix A–3 to part 60 of 
this chapter. 
e. Measure the HCl and HF emissions 
concentrations.Method 26 or Method 26A at appendix A– 
8 to part 60 of this chapter or Method 320 at appendix A to part 63 of this chapter or ASTM D6348–03
3with 
(1) the following conditions when using 
ASTM D6348–03: 
(A) The test plan preparation and imple-
mentation in the Annexes to ASTM D6348–03, Sections A1 through A8 are mandatory; 
(B) For ASTM D6348–03 Annex A5 
(Analyte Spiking Technique), the per-cent (%) R must be determined for each target analyte (see Equation A5.5); 
(C) For the ASTM D6348–03 test data to 
be acceptable for a target analyte, %R must be 70% ≥R ≤130%; and 
3.e.1(D) The %R value for each 
compound must be reported in the test report and all field measurements 
corrected with the calculated %R value for that compound using the following equation: 
and 
To conduct a performance test 
for the following pollutant...  (cont’d) Using...  (cont’d) You must perform the following activities, as applicable to your input- or output- based emission limit...  (cont’d) Using...
2(cont’d) 
(2) spiking levels nominally no greater 
than two times the level corresponding 
to the applicable emission limit. 
Method 26A must be used if there are en-
trained water droplets in the exhaust stream. 
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To conduct a performance test 
for the following pollutant...  (cont’d) Using...  (cont’d) You must perform the following activities, as applicable to your input- or output- based emission limit...  (cont’d) Using...
2(cont’d) 
f. Convert emissions concentration to lb/ 
MMBtu or lb/MWh emissions rates.Method 19 F-factor methodology at ap-
pendix A–7 to part 60 of this chapter, or 
calculate using mass emissions rate and gross output data (see § 63.10007(e)). 
OR OR 
HCl and/or HF 
CEMS.a. Install, certify, operate, and maintain 
the HCl or HF CEMS.Appendix B of this subpart. 
b. Install, certify, operate, and maintain 
the diluent gas, flow rate, and/or mois-ture monitoring systems.Part 75 of this chapter and § 63.10010(a), 
(b), (c), and (d). 
c. Convert hourly emissions concentra-
tions to 30 boiler operating day rolling average lb/MMBtu or lb/MWh emissions rates.Method 19 F-factor methodology at ap-
pendix A–7 to part 60 of this chapter, or calculate using mass emissions rate and gross output data (see § 63.10007(e)). 
4. Mercury (Hg) ......................... Emissions Testing ... a. Select sampling ports location and the 
number of traverse points.Method 1 at appendix A–1 to part 60 of 
this chapter or Method 30B at Appendix A–8 for Method 30B point selection. 
b. Determine velocity and volumetric flow- 
rate of the stack gas.Method 2, 2A, 2C, 2F, 2G or 2H at ap-
pendix A–1 or A–2 to part 60 of this chapter. 
c. Determine oxygen and carbon dioxide 
concentrations of the stack gas.Method 3A or 3B at appendix A–1 to part 
60 of this chapter, or ANSI/ASME PTC 19.10–1981.
3 
d. Measure the moisture content of the 
stack gas.Method 4 at appendix A–3 to part 60 of 
this chapter. 
e. Measure the Hg emission concentration Method 30B at appendix A–8 to part 60 of 
this chapter, ASTM D6784,3or Method 
29 at appendix A–8 to part 60 of this chapter; for Method 29, you must report the front half and back half results sep-arately. 
f. Convert emissions concentration to lb/ 
TBtu or lb/GWh emission rates.Method 19 F-factor methodology at ap-
pendix A–7 to part 60 of this chapter, or calculate using mass emissions rate and gross output data (see § 63.10007(e)). 
OR OR 
Hg CEMS ................ a. Install, certify, operate, and maintain 
the CEMS.Sections 3.2.1 and 5.1 of appendix A of 
this subpart. 
b. Install, certify, operate, and maintain 
the diluent gas, flow rate, and/or mois-ture monitoring systems.Part 75 of this chapter and § 63.10010(a), 
(b), (c), and (d). 
c. Convert hourly emissions concentra-
tions to 30 boiler operating day rolling average lb/TBtu or lb/GWh emissions rates.Section 6 of appendix A to this subpart. 
OR OR 
Sorbent trap moni-
toring system.a. Install, certify, operate, and maintain 
the sorbent trap monitoring system.Sections 3.2.2 and 5.2 of appendix A to 
this subpart. 
b. Install, operate, and maintain the dil-
uent gas, flow rate, and/or moisture monitoring systems.Part 75 of this chapter and § 63.10010(a), 
(b), (c), and (d). 
c. Convert emissions concentrations to 30 
boiler operating day rolling average lb/ TBtu or lb/GWh emissions rates.Section 6 of appendix A to this subpart. 
OR OR 
LEE testing .............. a. Select sampling ports location and the 
number of traverse points.Single point located at the 10% centroidal 
area of the duct at a port location per Method 1 at appendix A–1 to part 60 of this chapter or Method 30B at Appendix A–8 for Method 30B point selection. 
b. Determine velocity and volumetric flow- 
rate of the stack gas.Method 2, 2A, 2C, 2F, 2G, or 2H at ap-
pendix A–1 or A–2 to part 60 of this chapter or flow monitoring system cer-tified per appendix A of this subpart. 
c. Determine oxygen and carbon dioxide 
concentrations of the stack gas.Method 3A or 3B at appendix A–1 to part 
60 of this chapter, or ANSI/ASME PTC 19.10–1981,
3or diluent gas monitoring 
systems certified according to part 75 of this chapter. 
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2See Tables 1 and 2 to this subpart for required 
sample volumes and/or sampling run times. 3Incorporated by reference, see § 63.14. To conduct a performance test 
for the following pollutant...  (cont’d) Using...  (cont’d) You must perform the following activities, as applicable to your input- or output- based emission limit...  (cont’d) Using...
2(cont’d) 
d. Measure the moisture content of the 
stack gas.Method 4 at appendix A–3 to part 60 of 
this chapter, or moisture monitoring sys-
tems certified according to part 75 of this chapter. 
e. Measure the Hg emission concentration Method 30B at appendix A–8 to part 60 of 
this chapter; perform a 30 operating day test, with a maximum of 10 operating days per run (i.e., per pair of sorbent 
traps) or sorbent trap monitoring system or Hg CEMS certified per appendix A of this subpart. 
f. Convert emissions concentrations from 
the LEE test to lb/TBtu or lb/GWh emis-sions rates.Method 19 F-factor methodology at ap-
pendix A–7 to part 60 of this chapter, or calculate using mass emissions rate and gross output data (see § 63.10007(e)). 
g. Convert average lb/TBtu or lb/GWh Hg 
emission rate to lb/year, if you are at-tempting to meet the 29.0 lb/year threshold.Potential maximum annual heat input in 
TBtu or potential maximum electricity generated in GWh. 
5. Sulfur dioxide (SO 2) .............. SO 2CEMS .............. a. Install, certify, operate, and maintain 
the CEMS.Part 75 of this chapter and § 63.10010(a) 
and (f). 
b. Install, operate, and maintain the dil-
uent gas, flow rate, and/or moisture monitoring systems.Part 75 of this chapter and § 63.10010(a), 
(b), (c), and (d). 
c. Convert hourly emissions concentra-
tions to 30 boiler operating day rolling average lb/MMBtu or lb/MWh emissions rates.Method 19 F-factor methodology at ap-
pendix A–7 to part 60 of this chapter, or calculate using mass emissions rate and gross output data (see § 63.10007(e)). 
■18. In appendix A to Part 63: 
■a. Revise section 12.4 in Method 303. 
■b. Revise section 2.0 in Method 308. 
■c. Remove and reserve section 7.2.2 in 
Method 308. 
■d. Revise sections 7.2.3.3, 8.1.2, 9.1, 
11.3.2, and 12.1 in Method 308. 
■e. Add sections 12.5 and 13.0 in 
Method 308. 
■f. Revise sections 8.2.2.4 and 9.2.3 in 
Method 320. 
■g. Revise section 12.9 in Method 323. ■h. Revise section 8.2.1.3, Figure 8.1. 
and section 8.2.3.2 in Method 325A. 
■i. Add sections 8.2.3.3 and 8.4.3 in 
Method 325A. 
■j. Revise sections 9.3.2, 9.13, 11.3.2.5, 
and 12.2.2 in Method 325B. 
■k. Remove sections 12.2.3 and 12.2.4 
in Method 325B. 
■l. Revise table 17.1 in Method 325B. 
The revisions and additions read as 
follows: Appendix A to Part 63—Test Methods 
* * * * * 
Method 303—Determination of Visible 
Emissions From By-Product Coke Oven Batteries 
* * * * * 
12.4 Average Duration of VE from 
Charging Operations. Use Equation 303–3 to calculate the daily 30-day rolling log average of seconds of visible emissions from the charging operation for each battery using these current day’s observations and the 29 previous valid daily sets of observations. 
* * * * * 
Method 308—Procedure for Determination of Methanol Emission From Stationary Sources 
* * * * * 
2.0 Summary of Method 
A gas sample is extracted from the 
sampling point in the stack. The methanol is 
collected in deionized distilled water and adsorbed on silica gel. The sample is returned to the laboratory where the 
methanol in the water fraction is separated from other organic compounds with a gas chromatograph (GC) and is then measured by a flame ionization detector (FID). The fraction adsorbed on silica gel is extracted with deionized distilled water and is then separated and measured by GC/FID. 
* * * * * 7.2.2 [Reserved] 
* * * * * 
7.2.3.3 Methanol Standards for Adsorbent 
Tube Samples. Prepare a series of methanol 
standards by first pipetting 10 ml of the methanol working standard into a 100-ml volumetric flask and diluting the contents to exactly 100 ml with deionized distilled water. This standard will contain 10 mg/ml of methanol. Pipette 5, 15, and 25 ml of this 
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standard, respectively, into three 50-ml 
volumetric flasks. Dilute each solution to 50 ml with deionized distilled water. These standards will have 1, 3, and 5 mg/ml of 
methanol, respectively. Transfer all four standards into 40-ml glass vials capped with Teflon
®-lined septa and store under 
refrigeration. Discard any excess solution. 
* * * * * 8.1.2 Leak Check. A leak check before 
and after the sampling run is mandatory. The 
leak-check procedure is as follows: 
Temporarily attach a suitable (e.g., 0- to 40- 
ml/min) rotameter to the outlet of the DGM, and place a vacuum gauge at or near the probe inlet. Plug the probe inlet, pull a vacuum of at least 250 mm (10 inch) Hg or the highest vacuum experienced during the 
sampling run, and note the flow rate as indicated by the rotameter. A leakage rate in 
excess of 2 percent of the average sampling rate is acceptable. 
Note: Carefully release the probe inlet plug 
before turning off the pump. 
* * * * * 
9.1 Miscellaneous Quality Control 
Measures. The following quality control 
measures are required: 
Section Quality control measure Effect 
8.1.2, 8.1.3, 10.1 .................. Sampling equipment leak check and calibration ............ Ensures accurate measurement of sample volume. 
10.2 ...................................... GC calibration ................................................................. Ensures precision of GC analysis. 
13.0 ...................................... Methanol spike recovery check ...................................... Verifies all metha nol in stack gas is being captured in 
impinge/adsorbent tube setup. 
* * * * * 
11.3.2 Desorption of Samples. Add 3 ml 
of deionized distilled water to each of the 
stoppered vials and shake or vibrate the vials for 30 minutes. 
* * * * * 
12.1 Nomenclature. 
Caf= Concentration of methanol in the front 
of the adsorbent tube, mg/ml. 
Cab= Concentration of methanol in the back 
of the adsorbent tube, mg/ml. 
Ci= Concentration of methanol in the 
impinger portion of the sample train, mg/ml. 
E = Mass emission rate of methanol, mg/hr 
(lb/hr). 
m
s= Total mass of compound measured in 
impinger and on adsorbent with spiked 
train (mg). mu= Total mass of compound measured in 
impinger and on adsorbent with unspiked 
train (mg). 
mv= Mass per volume of spiked compound 
measured (mg/L). 
Mtot= Total mass of methanol collected in 
the sample train, mg. 
Pbar= Barometric pressure at the exit orifice 
of the DGM, mm Hg (in. Hg). 
Pstd= Standard absolute pressure, 760 mm Hg 
(29.92 in. Hg). 
Qstd= Dry volumetric stack gas flow rate 
corrected to standard conditions, dscm/hr 
(dscf/hr). 
R = fraction of spiked compound recovered s = theoretical concentration (ppm) of spiked 
target compound 
T
m= Average DGM absolute temperature, 
degrees K (°R). Tstd= Standard absolute temperature, 293 
degrees K (528 °R). 
Vaf= Volume of front half adsorbent sample, 
ml. 
Vab= Volume of back half adsorbent sample, 
ml. 
Vi= Volume of impinger sample, ml. 
Vm= Dry gas volume as measured by the 
DGM, dry cubic meters (dcm), dry cubic 
feet (dcf). 
Vm(std)= Dry gas volume measured by the 
DGM, corrected to standard conditions, dry standard cubic meters (dscm), dry standard cubic feet (dscf). 
* * * * * 
12.5 Recovery Fraction (R) 
13.0 Method Performance 
Since a potential sample may contain a 
variety of compounds from various sources, a specific precision limit for the analysis of field samples is impractical. Precision in the range of 5 to 10 percent relative standard deviation (RSD) is typical for gas 
chromatographic techniques, but an experienced GC operator with a reliable instrument can readily achieve 5 percent RSD. For this method, the following combined GC/operator values are required. 
(a) Precision. Calibration standards must 
meet the requirements in section 10.2.1 or 10.2.2 as applicable. 
(b) Recovery. After developing an 
appropriate sampling and analytical system for the pollutants of interest, conduct the following spike recovery procedure at each sampling point where the method is being 
applied. 
i. Methanol Spike. Set up two identical 
sampling trains. Collocate the two sampling probes in the stack. The probes shall be placed in the same horizontal plane, where the first probe tip is 2.5 cm from the outside 
edge of the other. One of the sampling trains shall be designated the spiked train and the other the unspiked train. Spike methanol into the impinger, and onto the adsorbent tube in the spiked train prior to sampling. The total mass of methanol shall be 40 to 60 percent of the mass expected to be collected with the unspiked train. Sample the stack gas into the two trains simultaneously. Analyze the impingers and adsorbents from the two trains utilizing identical analytical procedures and instrumentation. Determine the fraction of spiked methanol recovered (R) by combining 
the amount recovered in the impinger and in the adsorbent tube, using the equations in section 12.5. Recovery values must fall in the range: 0.70 ≤ R ≤ 1.30. Report the R value in 
the test report. 
ii. [Reserved] 
* * * * * 
Method 320—Measurement of Vapor Phase 
Organic and Inorganic Emissions By Extractive Fourier Transform Infrared (FTIR) Spectroscopy 
* * * * * 
8.2.2.4 Determine the percent leak 
volume %V Lfor the signal integration time 
tSSand for DP max, i.e., the larger of DP vor DPp, 
as follows: 
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Where: 50 = 100% divided by the leak-check time of 
2 minutes. 
* * * * * 9.2.3 Calculate the dilution ratio using 
the tracer gas as follows: 
DF = Dilution factor of the spike gas; this 
value shall be ≥10. 
SF6(dir)= SF 6(or tracer gas) concentration 
measured directly in undiluted spike 
gas. 
SF6(spk)= Diluted SF 6(or tracer gas) 
concentration measured in a spiked sample. Spike
dir= Concentration of the analyte in the 
spike standard measured by filling the 
FTIR cell directly. 
CS = Expected concentration of the spiked 
samples. 
Unspike = Native concentration of analytes 
in unspiked samples. 
* * * * * Method 323—Measurment of Formaldehyde 
Emissions From Natural Gas-Fired Stationary Sources-Acetyl Acetone Derivitization Method 
* * * * * 
12.9 Formaldehyde Concentration 
Corrected to 15% Oxygen 
* * * * * 
Method 325A—Volatile Organic Compounds From Fugitive and Area Sources: Sampler Deployment and VOC Sample Collection 
* * * * * 
8.2.1.3 An extra sampler must be placed 
near known sources of VOCs if potential 
emission sources are within 50 meters (162 feet) of the boundary and the source or 
sources are located between two monitors. Measure the distance (x) between the two 
monitors and place another monitor approximately halfway between (x/2 ±10 percent) the two monitors. Only one extra sampler is required between two monitors to account for known sources of VOCs. For 
example, in Figure 8.1, the facility added three additional monitors (i.e., light shaded 
sampler locations), and in Figure 8.2, the 
facility added two additional monitors to provide sufficient coverage of all area sources. 
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Figure 8.1. Facility with a Regular Shape 
Between 750 and 1,500 Acres in Area 
* * * * * 
8.2.3.2 For facilities with a monitoring 
perimeter length greater than or equal to 
7,315 meters (24,000 feet), sampling locations are spaced 610 ± 76 meters (2,000 ± 250 feet) 
apart. 
8.2.3.3 Unless otherwise specified in an 
applicable regulation, permit or other 
requirement, for small disconnected subareas with known sources within 50 meters (162 feet) of the monitoring perimeter, sampling points need not be placed closer than 152 meters (500 feet) apart as long as a minimum of 3 monitoring locations are used for each subarea. 
* * * * * 
8.4.3 When extenuating circumstances do 
not permit safe deployment or retrieval of passive samplers (e.g., extreme weather, 
power failure), sampler placement or retrieval earlier or later than the prescribed schedule is allowed but must occur as soon 
as safe access to sampling sites is possible. 
* * * * * 
Method 325B—Volatile Organic Compounds 
From Fugitive and Area Sources: Sampler Preparation and Analysis 
* * * * * 
9.3.2 Field blanks must be shipped to the 
monitoring site with the sampling tubes and 
must be stored at the sampling location throughout the monitoring exercise. The field blanks must be installed under a protective hood/cover at the sampling location, but the long-term storage caps must remain in place throughout the monitoring period (see Method 325A). The field blanks are then shipped back to the laboratory in the same container as the sampled tubes. Collect at least two field blank samples per sampling 
period to ensure sample integrity associated with shipment, collection, and storage. 
* * * * * 
9.13 Routine CCV at the Start of a 
Sequence. Run CCV before each sequence of analyses and after every tenth sample to 
ensure that the previous multi-level 
calibration (see section 10.0) is still valid. 
* * * * * 
11.3.2.5 Whenever the thermal 
desorption—GC/MS analytical method is changed or major equipment maintenance is performed, you must conduct a new five- level calibration (see section 10.0). System calibration remains valid as long as results from subsequent CCV are within 30 percent of the most recent 5-point calibration (see section 9.13). Include relevant CCV data in the supporting information in the data report for each set of samples. 
* * * * * 
12.2.2 Determine the equivalent 
concentrations of compounds in atmospheres as follows. Correct target compound concentrations determined at the sampling site temperature and atmospheric pressure to standard conditions (25 °C and 760 mm mercury) using Equation 12.5. 
Where: 
mmeas= The mass of the compound as 
measured in the sorbent tube (mg). 
t = The exposure time (minutes). 
tss= The average temperature during the 
collection period at the sampling 
site (K). 
UNTP= The method defined diffusive 
uptake rate (sampling rate) (mL/ min). Note: Diffusive uptake rates (U
NTP) for 
common VOCs, using carbon sorbents 
packed into sorbent tubes of the dimensions specified in section 6.1, are listed in Table 12.1. Adjust analytical conditions to keep expected sampled masses within range (see sections 11.3.1.3 to 11.3.1.5). Best possible method detection limits are typically in the order of 0.1 ppb for 1,3-butadiene and 0.05 ppb for volatile aromatics such as benzene for 14-day monitoring. However, actual detection limits will depend upon the analytical conditions selected. 
* * * * * 
TABLE 17.1—S UMMARY OF GC/MS A NALYSIS QUALITY CONTROL PROCEDURES  
Parameter Frequency Acceptance criteria Corrective action 
Bromofluorobenzene Instrument 
Tune Performance Check.Dailyaprior to sample analysis .... Evaluation criteria presented in 
Section 9.5 and Table 9.2.(1) Retune and or 
(2) Perform Maintenance. 
Five point calibration bracketing 
the expected sample concentra-tion.Following any major change, re-
pair or maintenance or if daily CCV does not meet method re-quirements. Recalibration not to exceed three months.(1) Percent Deviation (%DEV) of 
response factors ±30%.
(2) Relative Retention Times 
(RRTs) for target peaks ±0.06 units from mean RRT.(1) Repeat calibration sample 
analysis. 
(2) Repeat linearity check. (3) Prepare new calibration stand-
ards as necessary and repeat analysis. 
Calibration Verification (CCV Sec-
ond source calibration verification check).Following the calibration curve ..... The response factor ±30% DEV 
from calibration curve average response factor.(1) Repeat calibration check. (2) Repeat calibration curve. 
Laboratory Blank Analysis ............. Dailyafollowing bromofluoro ben-
zene and calibration check; prior to sample analysis.(1) ≤0.2 ppbv per analyte or ≤3 
times the LOD, whichever is greater.
(2) Internal Standard (IS) area re-
sponse ±40% and IS Retention 
Time (RT) ±0.33 min. of most recent calibration check.(1) Repeat analysis with new 
blank tube. 
(2) Check system for leaks, con-
tamination. 
(3) Analyze additional blank. 
Blank Sorbent Tube Certification ... One tube analyzed for each batch 
of tubes cleaned or 10 percent of tubes whichever is greater.<0.2 ppbv per VOC targeted com-
pound or 3 times the LOD, whichever is greater.Re-clean all tubes in batch and 
reanalyze. 
Samples—Internal Standards ........ All samples ................................... IS area response ±40% and IS 
RT ±0.33 min. of most recent 
calibration validation.Flag Data for possible invalida-
tion. 
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1IQ (intelligence quotient) is a score created by 
dividing a person’s mental age score, obtained by 
administering an intelligence test, by the person’s chronological age, both expressed in terms of years and months. ‘‘Glossary of Important Assessment and Measurement Terms,’’ Philadelphia, PA: National Council on Measurement in Education. 2016. 
243 FR 46246 (October 5, 1978). 373 FR 66964 (November 12, 2008) (‘‘lead 
NAAQS rule’’). 
479 FR 52205. 
5For an exact description of the Hayden Lead 
NAA, see 40 CFR 81.303. 
6Letter dated March 3, 2017, from Timothy S. 
Franquist, Director, Air Quality Division, ADEQ, to 
Alexis Strauss, Acting Regional Administrator, EPA Region IX. TABLE 17.1—S UMMARY OF GC/MS A NALYSIS QUALITY CONTROL PROCEDURES —Continued 
Parameter Frequency Acceptance criteria Corrective action 
Field Blanks ................................... Two per sampling period .............. No greater than one-third of the 
measured target analyte or 
compliance limit.Flag Data for possible invalidation 
due to high blank bias. 
aEvery 24 hours. 
* * * * * 
[FR Doc. 2018–24747 Filed 11–13–18; 8:45 am] 
BILLING CODE 6560–50–P 
ENVIRONMENTAL PROTECTION 
AGENCY 
40 CFR Part 52 
[EPA–R09–OAR–2018–0222; FRL–9986–31– 
Region 9] 
Approval of Arizona Air Plan; Hayden 
Lead Nonattainment Area Plan for the 2008 Lead Standard 
AGENCY : Environmental Protection 
Agency (EPA). 
ACTION : Final rule. 
SUMMARY : The Environmental Protection 
Agency (EPA) is approving a state implementation plan (SIP) revision submitted by the State of Arizona to meet Clean Air Act (CAA or ‘‘Act’’) requirements applicable to the Hayden lead nonattainment area (‘‘Hayden Lead NAA’’). The EPA is approving the base year emissions inventory, the attainment demonstration, the control strategy, including reasonably available control technology and reasonably available control measures demonstrations, the reasonable further progress demonstration, and the contingency measure as meeting the requirements of the CAA and the EPA’s implementing regulations for the 2008 lead national ambient air quality standard (NAAQS). We also find that the State has demonstrated that the Arizona SIP meets the new source review (NSR) requirements of CAA section 172(c)(5) for the Hayden Lead NAA. 
DATES : This final rule is effective on 
December 14, 2018. 
ADDRESSES : The EPA has established a 
docket for this action under Docket ID No. EPA–R09–OAR–2018–0222. All documents in the docket are listed on the https://www.regulations.gov 
website. Although listed in the index, some information is not publicly available, e.g., Confidential Business 
Information (CBI) or other information whose disclosure is restricted by statute. Certain other material, such as copyrighted material, is not placed on the internet and will be publicly 
available only in hard copy form. Publicly available docket materials are available through https://www.regulations.gov, or please contact 
the person identified in the 
FOR FURTHER  
INFORMATION CONTACT section for 
additional availability information. 
FOR FURTHER INFORMATION CONTACT : 
Ginger Vagenas, EPA Region IX, 415– 972–3964, Vagenas.Ginger@epa.gov. 
SUPPLEMENTARY INFORMATION : 
Throughout this document, the terms ‘‘we,’’ ‘‘us,’’ and ‘‘our’’ mean the EPA. 
Table of Contents 
I. Background 
II. Proposed Action and Public Comment III. Final Action IV. Statutory and Executive Order Reviews 
I. Background 
Lead is generally emitted in the form 
of particles that are deposited in water, soil, and dust. People may be exposed to lead by inhaling it or by ingesting lead-contaminated food, water, soil, or dust. Once in the body, lead is quickly absorbed into the bloodstream and can result in a broad range of adverse health effects including damage to the central nervous system, cardiovascular function, kidneys, immune system, and red blood cells. Children are particularly vulnerable to lead exposure, in part because they are more likely to ingest lead and in part because their still-developing bodies are more sensitive to the effects of lead. The harmful effects to children’s developing nervous systems (including their brains) arising from lead exposure may include IQ
1loss, poor academic achievement, 
long-term learning disabilities, and an increased risk of delinquent behavior. 
The EPA first established a lead 
standard in 1978 at 1.5 micrograms per meter cubed (mg/m
3) as a quarterly 
average.2Based on new health and 
scientific data, the EPA revised the federal lead standard to 0.15 mg/m
3and revised the averaging time for the standard on October 15, 2008.
3A 
violation of the standard occurs when ambient lead concentrations exceed 0.15 
mg/m
3averaged over a 3-month rolling 
period. 
Following the promulgation of a new 
or revised NAAQS, the EPA is required by the CAA to designate areas throughout the United States as attaining or not attaining the NAAQS. This process is set forth in section 107(d)(1) of the Act. After initially being designated unclassifiable due to insufficient monitoring data, the Hayden area was redesignated nonattainment on September 3, 2014, effective October 3, 2014.
45The 
designation of the Hayden area as nonattainment for the 2008 lead NAAQS triggered requirements under section 191(a) of the CAA requiring Arizona to submit a SIP revision with a plan to attain the standard as expeditiously as practicable, but no later than October 3, 2019. 
The Arizona Department of 
Environmental Quality (ADEQ) is the air quality agency that develops SIP revisions for the Hayden area. The SIP revision for the Hayden Lead NAA, entitled ‘‘SIP Revision: Hayden Lead Nonattainment Area’’ (‘‘2017 Hayden Lead Plan’’ or ‘‘Plan’’) was adopted by ADEQ on March 3, 2017, and submitted to the EPA on the same day.
6The Plan 
includes a 2012 base year emissions inventory, a demonstration that controls required under the Plan are sufficient to bring the area into attainment of the 2008 lead NAAQS, an analysis that demonstrates reasonably available control measures/reasonably available control technology (RACM/RACT) levels of control are required to be implemented, a demonstration that the Plan provides for reasonable further progress (RFP) towards attainment, and a contingency measure that will be implemented if the area fails to make 
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