BEFORE THE ILLINOIS POLLUTION CONTROL BOARD
IN THE MATTER OF:
NITROGEN OXIDES EMISSIONS FROM
VARIOUS SOURCE CATEGORIES:
AMENDMENTS TO
35 ILL. ADM. CODE
PARTS 211 AND 217
)
)
)
)
)
)
R08-19
(Rulemaking - Air)
NOTICE
TO:
John Therriault
Assistant Clerk
Illinois Pollution Control Board
James
R.
Thompson Center
100 West Randolph St., Suite 11-500
Chicago, IL 60601
SEE
ATTACHED SERVICE LIST
PLEASE
TAKE NOTICE that I have today filed with the Office of the Clerk of the
Illinois Pollution Control Board the
FIRST-NOTICE COMMENTS OF THE ILLINOIS
ENVIRONMENTAL PROTECTION AGENCY, a copy of which is herewith served upon you.
DATED: July
6,2009
1021 North Grand Avenue East
P.
o.
Box 19276
Springfield, IL 62794-9276
2171782-5544
ILLINOIS ENVIRONMENTAL
PROTES1J~N
AGENCY
_
BY:~~
Gina Roccaforte
Assistant Counsel
Division
of Legal Counsel
THIS FILING IS SUBMITTED
ON
RECYCLED PAPER
Electronic Filing - Received, Clerk's Office, July 6, 2009
* * * * * * PC # 17 * * * * * *
BEFORE THE ILLINOIS POLLUTION CONTROL BOARD
IN THE MATTER OF:
NITROGEN OXIDES EMISSIONS FROM
VARIOUS SOURCE CATEGORIES:
AMENDMENTS TO 35 ILL. ADM. CODE
PARTS
211 AND 217
)
)
)
)
)
)
R08-19
(Rulemaking - Air)
FIRST-NOTICE
COMMENTS OF THE ILLINOIS ENVIRONMENTAL
PROTECTION AGENCY
NOW COMES the Illinois Environmental Protection Agency ("Illinois EPA"), by its
attorneys, and respectfully submits its comments on the first notice published on May
22,2009,
in the above rulemaking proceeding.
See,
33
Ill.
Reg. 6896 and 6921. The Illinois EPA
recognizes and appreciates the expedited efforts of the Illinois Pollution Control Board ("Board")
in this rulemaking proposal to amend 35 Ill. Adm. Code Parts 211 and 217 to control the
emissions
of nitrogen oxides ("NO;') from certain major stationary sources in areas designated
as nonattainment with respect to National Ambient Air Quality Standards.
These comments
of the Illinois EPA address proposed clarifications and corrections to
the first-notice pUblication
of the proposed amendments and respond to the first-notice comments
filed by ArcelorMittal
USA, Inc., with the Board on July 1, 2009.
Clarifications and Corrections
The lllinois EPA recommends the following clarifications and corrections:
1.
Under 35 Ill. Adm. Code 211.3100, amend the definition of "industrial boiler" by striking
the reference to
"cogeneration units" to read as follows:
Section
211.3100
Industrial Boiler
"Industrial boiler" means, for purposes of Part 217, an enclosed vessel in which water is
heated and circulated either as hot water or as steam for heating or for power, or both.
This term does not include a heat recovery steam generator that captures waste heat from
a combustion turbine and boilers serving a generator that has a nameplate capacity
greater than
25 MWe and produces electricity for sale, if such boilers meet the
applicability criteria under Subpart M
of Part 217.
Electronic Filing - Received, Clerk's Office, July 6, 2009
* * * * * * PC # 17 * * * * * *
(See, Board's May 7,2009 opinion and order,
Amendments to
35
Ill. Adm. Code 217,
Nitrogen Oxides Emissions, and
35
Ill. Adm. Code
211, ROS-19, slip op. at 26.)
2.
Under 35 Ill. Adm. Code 217.1 04, to update an incorporation by reference, amend
subsection
(1) to read as follows:
n
40 CFR 60, Appendix A, Methods
I,
2, 3, and 4 (200S);
3.
Under 35 Ill. Adm. Code 217.104, to update incorporations by reference, amend
subsections
(0) and (P) and add subsections (q) and (r) to read as follows:
Q}
Alternative Control Techniques Document--NO, Emissions from Glass
Manufacturing,
EPA-4531R-94-037,
U. S. Environmental Protection Agency,
Office of Air and Radiation, Office of Air Ouality Planning and Standards,
Research Triangle
Park, N. C. 27711, June 1994;
Alternative Control Techniques Document--NO, Emissions from Iron and
Steel
Mills,
EPA-4531R-94-065.
U. S. Environmental Protection Agency, Office of Air
and Radiation, Office of Air Quality Planning and Standards, Research Triangle
Park, N. C. 27711, September 1994;
ill
40 CFR 60 and 75 (200S); and
rl
40 CFR 60, Appendix B, Performance Specification 16, 74 FR 12575 (March 25,
2009).
(A copy
of 40 CFR 60, Appendix B, Performance Specification 16, 74 FR 12575 (March
25,2009) is attached.)
4.
Amend the heading of Subpart D of Part 217 by deleting the reference to "Industrial
Boilers"
and adding ''NO, General Requirements" to read as follows:
SUBPART D: NO, GENERAL REQUIREMENTS
5.
Under 35
III.
Adm. Code 217.154, for clarification purposes, amend subsections (a) and
(b) to add references to
"emissions limitations under" an applicable Subpart and to add
the exclusion for a
"predictive emission monitoring system, or combustion tuning" to
read as follows:
il
Performance testing of NO x emissions for emission units constructed on or before
July
1, 2011, and subject to emissions limitations under Subpart E, F, G, H. or I of
this Part must be conducted in accordance with Section 217.157 ofthis SUbpart.
Except as provided for under Section 217.157(a)(4) and (e)(l), this subsection
does not apply to owners and operators
of emission units demonstrating
2
Electronic Filing - Received, Clerk's Office, July 6, 2009
* * * * * * PC # 17 * * * * * *
compliance through a continuous emissions monitoring system, predictive
emission monitoring system, or combustion tuning.
hl
Performance testing of NO, emissions for emission units for which construction
or modification occurs after July 1, 2011, and that are subject to emissions
limitations under Subpart
E, F, G,
H,
or I of this Part must be conducted within 60
days of achieving maximum operating rate but no later than 180 days after initial
startup
of the new or modified emission unit, in accordance with Section 217.157
of this Subpart. Except as provided for under Section 217.157(a)(4) and (e)(l),
this subsection does not apply to owners and operators
of emission units
demonstrating compliance through a continuous emissions monitoring system,
predictive emission monitoring system,
or combustion tuning.
6.
Under 35
Ill.
Adm. Code 217.158, subsection (a), the reference to "Section
217.150(a)(l)(A) or
(BY'
should read as "Section 217 . 150(a)(l )(A)(i) or
(ii)."
7.
Under 35 Ill. Adm. Code 217.158, amend subsection (a)(2)(C) to read as follows:
g
Units that are required to meet emission limits or control requirements for
NO~
provided for in an enforceable order, unless such order allows for emissions
averaging.
In the case of petroleum refineries, this subsection does not prohibit
including industrial boilers
or process heaters, or both, in an emissions averaging
plan where an enforceable order does not prohibit the reductions made under such
order from also being used for compliance with any rules
or regulations designed
to address regional haze or the non-attainment status
of any area.
8.
Under 35 Ill. Adm. Code 217.158, subsection (g), the reference to "Section
217. 150(a)(l)(A) or (B)" should read as "Section 217 .150(a)(l)(A)(i) or
(ii)."
9.
Under 35
Ill.
Adm. Code 217.158, add subsection
(j)
to read as follows:
il
The owner or operator of an emission unit located at a petroleum refinery who is
demonstrating compliance with an applicable Subpart through an emissions
averaging plan under this Section may exclude from the calculation demonstrating
compliance those time periods when
NO~
pollution control equipment that
controls one or more emission units included
in the emissions averaging plan is
shut down for a maintenance turnaround, provided that such owner
or operator
notify the Agency in writing at least
30 days in advance of the shutdown ofthe
NQx pollution control equipment for the maintenance turnaround and the
shutdown
of the NO, pollution control equipment does not exceed 45 days per
ozone season or calendar year, and except for those emission units vented to the
NQ"
pollution control equipment undergoing the maintenance turnaround, NO
x
pollution control equipment, if any, continues to operate on all other emission
units operating during the maintenance turnaround.
3
Electronic Filing - Received, Clerk's Office, July 6, 2009
* * * * * * PC # 17 * * * * * *
10.
Under 35
Ill.
Adm. Code 217.160, amend subsection (b) by striking the references to
"cogeneration units" and adding reference to boilers that "meet the applicability criteria
under Subpart M
of Part 217" to read as follows:
hl
The provisions of this Subpart do not apply to boilers serving a generator that has
a nameplate capacity greater than
25 MWe and produces electricity for sale, if
such boilers meet the applicability criteria under Subpart M of Part 217.
(See, Board's
May 7,2009 opinion and order,
Amendments to
35
Ill. Adm. Code 217,
Nitrogen
Oxides Emissions, and
35
Ill. Adm. Code
211, ROS-19, slip op. at 45-46.)
II.
Under 35
Ill.
Adm. Code 217.164, amend the first paragraph to read as follows:
Except as provided for under Section 217.152, on and after January
I,
2012, no person
shall cause or allow emissions
of NO x into the atmosphere from any industrial boiler to
exceed the following limitations.
Compliance must be demonstrated with the applicable
emissions limitation on an ozone season and annual basis.
12.
Under 35 Ill. Adm.
Code 217.164, subsection (e), amend the denominator in the equation
to read as follows:
(Btu NC
+
Btu coc
+
Btu RFC)
(See, Board's May 7, 2009 opinion and order,
Amendments to
35
Ill. Adm. Code 217,
Nitrogen
Oxides Emissions, and
35
Ill. Adm. Code
211, ROS-19, slip op. at 9S.)
13.
Under 35
Ill.
Adm. Code 217.1S4, amend the first paragraph to read as follows:
Except as provided for under Section 217.152, on and after January
I,
2012, no person
shall cause or allow emissions
of NO x into the atmosphere from any process heater to
exceed the following limitations. Compliance must be demonstrated with the applicable
emissions limitation on an ozone season and annual basis.
14.
Under 35 Ill. Adm.
Code 217.204, due to the special characteristics of glass melting
furnaces and further discussions with Saint-Gobain
Containers, Inc., amend subsection
(b) to read as follows:
hl
The emissions during glass melting furnace startup (not to exceed 70 days) or
furnace idling (operation at Jess than 35%
of furnace capacity) shall be excluded
from calculations for the purpose
of demonstrating compliance with the seasonal
and annual emissions limitations under this Section, provided that such owner or
operator, at all times, including periods
of startup and idling, to the extent
practicable, maintain and operate any affected emission unit including associated
air pollution control equipment in a manner consistent with good air pollution
4
Electronic Filing - Received, Clerk's Office, July 6, 2009
* * * * * * PC # 17 * * * * * *
control practice for minimizing emissions. The owner or operator of a glass
melting furnace must maintain records that include the date, time, and duration
of
any startup or idling in the operation of such glass melting furnace.
15.
Under 35 Ill. Adm. Code 217.244, amend subsection (b) by correcting the emissions
limitations to read
as follows:
hl
On and after January 1, 2012, no person shall cause or allow emissions of NO x
into the atmosphere from any reverberatory furnace or crucible furnace used in
aluminum melting to exceed the following limitations. Compliance must
be
demonstrated with the applicable emissions limitation on an ozone season and
annual basis.
Emission
Unit Type
NO
x
Emissions
Limitation
(lb/mmBtu)
-------------------------------------------------------------------------------------------------------
12
Reverberatory furnace
Crucible furnace
(See, Board's
May 7,2009 opinion and order,
Amendments to
35
Ill. Adm. Code 217,
Nitrogen Oxides Emissions, and
35
Ill. Adm. Code
211, R08-19, slip op. at 105.)
16.
Amend 35
Ill.
Adm. Code 217.340 by adding reference to any "fossil" fuel-fired
stationary boiler serying
"at any time" a generator to read as follows:
Notwithstanding Subpart V
or W of this Part, the provisions of Subpart D of this Part and
this Subpart apply to any fossil fuel-fired stationary boiler serving at any time a generator
that has a nameplate capacity greater than 25 MWe and produces electricity for sale,
excluding any units listed
in Appendix D of this Part, located at sources subject to this
Subpart pursuant to Section 217.150.
(See, Board's
May 7,2009 opinion and order,
Amendments to 35111. Adm. Code 217,
Nitrogen Oxides Emissions, and
35
Ill. Adm. Code
211, R08-19, slip op. at 55-56.)
17.
In light ofR09-10,
Amendments to
35
Ill. Adm. Code
225:
Control of Emissions From
Large Combustion
Sources (Mercury Monitoring),
under 35 Ill. Adm. Code 217.342,
amend subsection (b) to read
as follows:
hl
Notwithstanding Section 217.340, the provisions of this Subpart do not apply to a
coal-fired stationary boiler that commenced operation before January
1, 2008, that
is complying with Part 225.Subpart B through the multi-pollutant standard or the
combined pollutant standard.
5
Electronic Filing - Received, Clerk's Office, July 6, 2009
* * * * * * PC # 17 * * * * * *
18.
Amend Appendix H of Part 217 to read as follows:
Section
217.APPENDIX H: Compliance Dates for Certain Emission Units at Petroleum
Refineries
ExxonMobil
Oil Corporation (Facility ID 197800AAA)
Point
Emission Unit Description
Compliance Date
0019
Crude Vacuum Heater
(13-B-2)
December 31,2014
0038 Alky Iso-Stritmer Reboiler (7-B-1}
December 31,2014
0033
CHD Charge Heater (3-B-l)
December 31,2014
0034
CHD Stripper Reboiler (3-B-2)
December
31,2014
0021
Coker East Charge Heater (16-B-IA)
December 31, 2014
0021
Coker East Charge Heater (16-B-IB)
December 31,2014
0018
Crude Atmospheric Heater
(J -B-IA)
December 31, 2014
0018
Crude Atmospheric Heater
(l-B-IB)
December 31, 2014
ConocoPhillips Company Wood RiYer Refinery (Facility ID 119090AAA)
Point
Emission Unit Description
Compliance Date
0017
BEUHM-l
December 31,2012
0018
BEUHM-2
December 31,2012
0004
CR-l Feed Preheat, H-l
December 31,2012
0005
CR-ll st Interreactor Heater, H-2
December 31,2012
0009
CR-1
3'0 interreactor Heater, H-7
December 31,2012
0091
CR-3 Charge Heater
December 31,2012
0092
CR-3 1
st Reheat Heater, H-5
December 31,2012
0082
Boiler
17
December 31,2012
0080
Boiler 15
December 31,2012
0073
Alky HM-2 Heater
December 31, 2012
0662
VF-4 Charge Heater, H-28
December 31, 2012
0664
DU-4 Charge Heater, H-24
December 31, 2014
0617
DCU Charge Heater, H-20
December 31, 2014
0014
HCU Fractionator Reboil, H-3
December 31, 2016
0024
DU-1 Primary Heater South, F-301
December 31,2016
0025
DU-1
Second~
Heater North, F-302
December 31, 2016
0081 Boiler 16
December 31, 2016
0083
Boiler
18
December 31,2016
0095
DHT Charge Heater
December 31,2016
0028
DU-2 Lube Crude Heater, F-200
December 31,2016
0029
DU-2 Mixed Crude Heater West, F-202
December 31, 2016
0030
DU-2
Mixed Crude Heater East, F -203
December 31,2016
0084
CR-2 North Heater
December 31,2016
0661
CR-2 South Heater
December 31,2016
6
Electronic Filing - Received, Clerk's Office, July 6, 2009
* * * * * * PC # 17 * * * * * *
ArcelorMittal USA, Inc.
In its first notice comments filed on July I, 2009, with the Board, ArcelorMittal USA,
Inc., ("ArcelorMittal") contends that the Illinois EPA failed to provide technical or economical
justification for the proposed revised emissions limitation and to demonstrate that such revised
emissions limitation was based upon Reasonably Available Control Technology
("RACT").
See,
First Notice Public Comments
for the Illinois Pollution Control Board Submitted By
ArcelorMittal
USA, Inc., filed July
1,
2009.
The Illinois EPA's Technical Support Document
("TSD") provides detailed performance and cost information that demonstrates that the proposed
emissions limitations contained
in the rulemaking proposal are feasible technologically and
economically. And, as further set forth in the Illinois
EPA's TSD, the NO, control technologies
identified for reheat, annealing and galvanizing furnaces at iron and steel plants are reasonably
available, technically feasible, and cost effective, even recognizing the tunnel design
of
ArcelorMittal's reheat furnace.
After reviewing the Illinois
EPA's summary of NO
x
emissions limitations from reheat
furnaces at other sources that was used as the basis for amending the emissions limitation for
recuperative reheat furnaces combusting natural gas, ArcelorMittal attempts to distinguish itself
from the sources surveyed. Arce10rMittal indicates that the
NO, emissions limitation for Beta
Steel Corporation's natural gas-fired reheat furnace slab 2 of 0.0147
Ib/mmBtu
was the original
permit limit based on manufacturer's estimates, whereas the current permit limit is 0.77
Ib/mmBtu.
See, First Notice Public Comments for the Illinois Pollution Control Board
Submitted
By ArcelorMittal USA, Inc., filed July
1,
2009, Paragraph
2. The permit limit that
ArcelorMittal cites
to is actually 0.077
Ib/mmBtu,
which is more stringent than the emissions
limitation proposed
by the Illinois EPA. Arce10rMittal states that the Nucor Steel facility,
Tuscaloosa, Alabama, and the V &M
Star facility in Mahoning County, Ohio, are not similar to
7
Electronic Filing - Received, Clerk's Office, July 6, 2009
* * * * * * PC # 17 * * * * * *
ArcelorMittal's Riverdale facility, and that two of the facilities, New Steel International,
Haverhill,
Ohio, and Minnesota Steel Industries LLC, Itasca County, Minnesota, have not been
constructed to date. Emissions limitations set forth in construction permits are enforceable
limits, and the actions
ofthese states to require such emission limits support the Illinois EPA's
proposal as technologically feasible for this type of reheat furnace.
ArcelorMittal again cites to its economic analysis that provides the estimated cost
effectiveness for burner changes based upon the next-generation ultra low
NO
x
burners currently
available.
See, Post-Hearing Comments for the Illinois Environmental Protection Agency
Submitted
By ArcelorMittal USA, Inc., filed March
23,
2009, Exhibit A.
In the Illinois EPA's
opinion, the economic analysis provided by ArcelorMittal is flawed and should not be relied
upon as evidence that the proposed emission limits are beyond RACT from an economic
perspective.
It is important to point out that the burners, Series 1430, now in use at
ArcelorMittal's Riverdale facility were designed in the 1980s and are not considered an
"advanced NO
x
control technology" as ArcelorMittal claims. ArcelorMittal's estimated cost
effectiveness for burner modifications is $22,895 per ton
of NO x removed under Scenario 1 for
the
1500 Series burners and $39,472 per ton of NO x removed under Scenario 2 for the 1550
Series
burners. The calculation for the annualized cost per ton of NO
x
removed based on
changing burners under either scenario assumes only a 5-year equipment life. Clearly the
expected equipment life is much greater than five years,
as the existing burners in
ArcelorMittal's furnace are about 20 years old. A more reasonable economic equipment life is
15 or 20 years. By using umeasonably low equipment life in the economic analysis,
ArcelorMittal has overstated the annualized costs
of installing and maintaining the controls
needed to comply with the Illinois EPA's proposal. In addition, the interest rate
of 10% is high,
as is the contingency at 20%. Again, by overstating these costs, ArcelorMittal has overstated the
8
Electronic Filing - Received, Clerk's Office, July 6, 2009
* * * * * * PC # 17 * * * * * *
costs, on an annual basis, of meeting the Illinois EPA's proposal. ArcelorMittal's economic
analysis should not be relied upon
as evidence that the proposed emission limits are beyond
RACT.
ArcelorMittal requests that the Board revisit the proposed rule and for second notice
,
allow a source to be exempt from the proposed NO, emissions limitations upon an adequate
demonstration that additional
NO, controls would be economically unreasonable. Essentially,
ArcelorMittal is requesting a case-by-case RACT analysis, and the proposal does not include for
case-by-case RACT determinations. The
illinois EPA opposes the inclusion of such options in
this proposal. The Board's regulations include regulatory relief mechanisms from environmental
regulations under certain circumstances, and the Illinois
EPA acknowledges that sources may
initiate proceedings for such relief.
DATED: July 6,2009
1021 North Grand Avenue East
P. O. Box 19276
Springfield, IL 62794-9276
217/782-5544
9
Respectfully submitted,
ILLINOIS ENVIRONMENTAL
PROTEytT
O.N AGENCY
• --1£. "'. ,,--
By:.
~
Gina Roccaforte
Assistant Counsel
Division
of Legal Counsel
THIS FILING
IS SUBMITTED
ON RECYCLED PAPER
Electronic Filing - Received, Clerk's Office, July 6, 2009
* * * * * * PC # 17 * * * * * *
Federal Register/Vol. 74, No. 56/Wednesday, March 25, 2009/Rules and Regulations
12575
EPA-ApPROVED SOURCE-SPECIFIC REQUIREMENTS
Source name
Pennitlorder or registration nurn-
State effec-
EPA approval date
40
CFR
part 52
ber
tive date
citation
Reynolds
Consumer
Company.
Products Registration No. 50534
10/1/08 03/25/09 ........................................ .
52.2420(d)(12)
*
•
•
•
*
IFR Doc. Eg...<;663 Filed 3-24-<)9; 8:45 am]
BILL.ING CODE
656o-~
ENVIRONMENTAL PROTECTION
AGENCY
40 CFR Parts 60 and 63
[EPA-H~AR-2003-0074;
FRL-ll785-41
RIN
206D-AG21
Performance Specification 16 for
Predictive Emissions Monitoring
Systems and Amendments
to Testing
and Monitoring Provisions
AGENCY: Environmental Protection
Agency (EPA).
ACTION: Final rule.
SUMMARY:
EPA is taking final action to
promulgate Performance Specification
(PS) 16 for predictive emissions
monitoring systems (PEMS).
Performance Specification 16 provides
testing
requirements for assessing the
acceptability of PEMS when they are
initially installed. Currently,
there are
no Federal rules requiring the
USe
of
PEMS; however. some sources have
obtained Administrator approval to use
PEMS as alternatives to continuous
emissions monitoring systems (CEMS).
Other sources may desire to use PEMS
in cases where initial and operational
costs
are less than CEMS and process
optimization for emissions control may
be desirable. Performance Specification
16 will
apply to any PEMS required in
future rules in 40 CFR Parts 60, 61, or
63, and in cases where a source
petitions the Administrator and receives
approval to use a PEMS in lieu of
another emissions monitoring system
required under the regulation. We are
also finalizing minor technical
amendments.
DATES:
This final rule is effective on
April 24, 2009.
ADDRESSES: EPA has established a
docket for
this action under Docket ID
No. EPA-HQ-OAR-2003-{)074. All
documents in the docket are listed on
the
http://www.regulations.govWeb
[Insert page number where the
document begins].
site. Although listed in the index, some
information is not publicly available,
e.g.,
CBl 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 either electronically through
http://www.regu/ations.govorinhard
copy at the Performance Specification
16 for
Predictive Emission Monitoring
Systems Docket, Docket
ID
No. EPA-
OAR-2003-{)074, EPA Docket Center,
EPA/DC, EPA West, Room 3334,
1301
Constitution
Ave.,
NW., Washington,
DC. This Docket Facility is open from
8;30 a.m. to 4:30 p.m. Monday through
Friday excluding legal holidays. The
docket telephone number is (202) 566-
1742. The Public Reading Room is open
from 8:30 a.m. to 4:30 p.m., Monday
through Friday, excluding legal
holidays.
The telephone number for the
Public Reading Room is (202) 566-1744.
FOR FURTHER INFORMATION CONTACT:
Mr.
Foston
Curtis, Air Quality Assessment
Division,
Office of Air Quality Planning
and Standards (E143-{)2),
Environmental Protection Agency,
Research Triangle
Park, North Carolina
27711; telephone number (919) 541-
1063; fax number (919) 541-0516; e-
mail address:
curtis.joston@epa.gov.
SUPPLEMENTARY INFORMATION:
Table of Contents
I.
Does This Action Apply to Me!'
n.
Where Can
I
Obtain a Copy of This
Action?
III.
Background
IV. This Action
A. PS-16
B. Method 24 of Appendix A-7 of Part 60
C. Performance Specification 11 of
Appendix B of Part 60
D. Procodures 1 and 2 of Appendix
F
of
Pert 60
E. Method 303 of Appendix A of Part 63
V. Public Comments on the Proposed Rule
A.
Parameter Operating Level Terminology
B.
PS--16 Applicability to Market-Based
Programs
C. PS--16 and the Older Draft Performance
Specifications on the EPA Web site
D. PEMS Relative Accwacy Stringency vs
CEMS Stringency
E. Alternative Limits for Low Emitters
F. Statistical Tests
G. Use of Portable Analyzers for the
Relative Accuracy Audit
H. Potential Overlap Between PS-16 and
PS-17
I.
Reduced Relative Accuracy Audit
Frequency for Good Performance
VI.
Judicial Review
VII.
Statutory and Executive Order Reviews
A. Executive Order 12866: Regulatory
Planning and Review
B. Paperwork Reduction Act
C. Regulatory Flexibility Act
D. Unfunded Mandates Refonn Act
E. Executive Order 13132: Federalism
F. Executive
Order 13175: Consultation
and Coordination
with
Indian Tribal
Governments
G. Executive Order 13045: Protcction of
Children from Environmantal Health
Risks
and Safety Risks
H.
Executive Order 13211: Actions that
Significantly Affect Energy Supply.
Distribution, or Use
I.
National Technology Transfer and
Advancement Act
J. Executive Order 12898: Fadoral Actions
to
Address Environmental Justice in
Minority Populations and
Low~Income
Populations
K.
CongresSional Review Act
I.
Does This Action Apply to Me?
Predictive
emission monitoring
systems
are not currently required in
any Federal rule. However, they may be
used under certain New Source
Performance Standards (NSPS) to
predict nitrogen oxides emissions from
small industrial, commercial, and
institutional steam generating units. In
some cases,
PEMS have been approved
as alternatives to CEMS for the initial
30-day compliance test at these
facilities. Various State and Local
regulations
are incorporating PEMS as
an emissions monitoring tool. The major
entities that are potentially affected by
Performance Specification 16 and the
amendments to the subparts Bre
included in the following tables.
Performance Specification 16 will
neither apply to existing PEMS nor
those covered under Subpart E of 40
CFRparl 75.
Regulated Entities. Categories
and
entities potentially affected include the
following:
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I
Vol. 74, No, 56
I
Wednesday, March 25, 2009/Rules and Regulations
TABLE 1-MAJOR ENTITIES POTENTIALLY AFFECTED BY THIS ACTION: PERFORMANCE SPECIFICATION 16
Category
Industry ..................................... " ...•••........ ___ ................................................................ , ..••....
Industry
................ " ...•.................................. _ ...........••.•.... " .... ___ ........•••.. ,., .......................... .
a
North American Industry classification system.
NAICsa
Examples of regulated entities
333611 Stationary Gas Turbines.
332410 Industrial, Commercial, Institu-
tional Steam Generating Units.
TABLE 2-MAJOR ENTITIES POTENTIALLY AFFECTED BY THIS ACTION: AMENDMENTS TO PERFORMANCE SPECIFICATION 11
AND PROCEDURES 1 AND 2, ApPENDIX F, PART 60
Category
NAICS'
Examples of regulated entities
Industry ......................................... _ .. "", ........ , ....................... " ............ , ............................................. .
Industry " ......... ,", ....... " ........... , ......... " ......... " ....................... , ........... ,', ........ , ................................... .
a North American
Industry Classsification System.
333298 Portland Cement Manufacturing.
562211 Hazardous Waste Incinerators.
TABLE 3-MAJOR ENTITIES POTENTIALLY AFFECTED BY THIS ACTION: AMENDMENTS TO METHOD 24, ApPENDIX A, PART
60
Category
Industry ........................................... , ................................................................... " ........ , .... ..
Industry ............................................................................................................................... ..
Industry ................
. .................. ..
Industry ....................................................................... , ...................................................... .
Industry ............................................................... " ........................................................ , .... ..
Industry ................................................................................................................ , ............. ..
Industry ............... " ........................................................................................................... ..
Industry ............... ,', ................................................... "., ........................................ , ........... .
Industry ..............................................................................................................................
..
Industry ............ " ................... , ............................................ , ........... " .................................. ..
Industry ..... ,", ......................................................................................................... .
Industry ..... ,", .................................................. , ........................ " .......................................... ,
Industry ...... " ................................................... ,., ..................... , ........................................... ,
Industry ................................................ " ......................................................... ,', .................. .
Industry ................................................................................................................................ .
Industry ................................................................................................................................ .
Industry ........................................... ,", ...................................................... ,.,, ..................... ..
Industry ............. ,"', ...... ,." ......................................... , ..... , ...................................... ,", ....... " ..
Industry ............. "."., ...... " ........................................ "."., ...................................... ,,", ......... .
Industry ................
" ............................................ , ........ , .................................... " .................. .
Industry ................... , ....................................................... , ................................. ,""', .... , ....... .
Industry ............................................................ ,', ............................................. , ................ ..
Industry ........... "., ...... " ........................................ ,', ........ " ................................ , .. , ....... .
a
North Amencan Industry classificatllon System.
NAICS'
326211
323111
334613
326199
332812
337124
336111
323111
322222
421620
335931
332812
33641
Examples of regulated entities
Rubber Tire Manufacturing.
Flexible
Vinyl and Urethane Coating and
Printing,
Magnetic
Tape Coating Facilities.
Surface Coaling of Plastic Parts for Busi-
ness MachInes.
Polymeric Coating
of Supporting Sub-
strates FacilitIes.
Surface
Coating of Metal Fumiture.
Automobile and
Ught
Duty
Truck Surface
Coating.
Graphic Arts Industry: Publication Roto-
gravure Printing.
Pressure
Sensitive Tape and Label Sur-
face Coating Operations.
Industrial
Surface Coating: Large Appli-
ances.
Metal Coil
Surface Coaling.
Beverage Can Surface Coating.
Aerospace.
Boat and
Ship Manufacturing and Repair
Surface Coating.
Fabric Printing, Coating. and Dyeing.
Leather Finishing.
Miscellaneous Coating Manufacturing.
Miscellaneous
Metal Parts and Products.
Paper and
Other Web Surface Coating.
Plastic Parts Surface Coating.
Printing and Publishing
Surface Coating.
Wood Building Products.
Wood Furniture.
TABLE 4-MAJOR ENTITIES POTENTIALLY AFFECTED BY THIS ACTION: AMENDMENT TO METHOD 303, ApPENDIX A, PART
63
Category
Industry .................. ,", •. " .. , .... .
aNorth American
Industry classsification System.
These tables are not intended to be
exhaustive. but rather to provide a guide
for readers regarding entities likely to be
affected by these actions, These tables
list examples of the types of entities
EPA is
now aware could potentially be
affected by these final actions. Other
types
of entities not listed could also be
affected.
If
you have any questions
regarding the applicability of this action
NAICS'
Examples of regulated entities
33111111
Coke
Ovens.
to a particular entity. consult the person
listed
in the preceding
FOR FURTHER
INFORMATION CONTACT
section.
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12577
II. Where Can I Obtain a Copy of This
Action?
In addition to
being available in the
docket. an electronic copy of this rule
will also be available on the Worldwide
Web
(www)
through the Technology
Transfer Network (TTN). Following the
Administrator's signature, a copy of the
final rule will be placed on the TTN's
policy
and guidance page for newly
proposed or promulgated rules at
http://www.epa.govlttn!oarpg.
The TIN
provides information and technology
exchange in various areas of air
pollution control.
III. Background
Performance Specification 16 and the
amendments to PS-l1. Procedures 1
and 2, Method 24, and Method 303 were
proposed in the Federal Register on
August 8, 2005 with a public comment
period that ended October 7, 2005. A
public commenter asked that the
comment period be reopened to allow
for additional time to prepare their
response since they were a leading
vendor of PEMS and were significantly
impacted by the rule. We reopened the
comment period for two weeks, from
November 2-16, 2005. A total of 42
comment letters were received on the
proposed rule. Most comment letters
pertained to
PS--16 and contained
multiple comments. We have compiled
and responded to the public comments
and made appropriate changes to the
rule based on the comments.
IV.
This Action
A.
PS-16
This action finalizes PS-16 for PEMS.
This performance specification was
originally proposed by EPA on August
8,2005
(70 FR 45608). Performance
Specification 16 establishes procedures
that
must be used to determine whether
a PEMS is acceptable for use in
demonstrating compliance with
applicable requirements. Predictive
emission monitoring systems predict
source
emissions indirectly using
process parameters instead of measuring
them directly.
Additionally, the following
amendments are made to the noted
testing and monitoring provisions.
B.
Method
24
of Appendix A-7 of Part
60
Method 24, part 60, Appendix A-7 is
used to determine the contents and
properties of surface coatings under
NSPS applications. Method 24 currently
references ASTM D2369 as the method
for determining volatiles content. The
American Society for Testing and
Materials has recommended that ASTM
D6419 be allowed as an alternative to
D2369 in this case. We have amended
Method 24 to cite this optional method.
C.
Perfonnance Specification
11
of
Appendix B of Part 60
The publication on January 12, 2004
ofPS-11 for Appendix B and Procedure
2
for part 60, Appendix
F
contained
technical and typographical errors
and
unclear instructions. We have revised
the definition of confidence interval half
range to clarify the language, replacing
the word "pairs" with "sets" to avoid
possible confusion regarding the use of
paired sampling trains, corrected errors
in Equations 11-22, 11-27, and 11-37,
corrected the procedures in paragraphs
(4) and (5) of section 12.3 for
determining confidence and tolerance
interval
half ranges for the exponential
and power correlation models, and
added a note following paragraph (5)(v)
concerning the application of
correlation equations to calculate
particulate matter
(PM) concentrations
using the response data from an
operating PM CEMS. We have also
renumbered some equations and
references for clarification, consistency,
and accuracy.
D. Procedures
1
and
2
of Appendix
F
of
Part 60
In Procedure 1 of Appendix F of part
60, we revised obsolete language that
describes
the standard reference
material that is required,
and in
Procedure 2, we added a needed
equation for calculating an absolute
correlation audit based
on the
applicable standard.
E. Method 303 of Appendix A of
Port 63
In Method 303 of Appendix A to part
63, a statement on varying the time of
day runs are taken that was deleted by
mistake in a recent amendment of the
method has been added.
V. Public Comments on the Proposed
Rule
A more detailed summary of the
public comments and our responses can
be
fowld in the Summary of Public
Comments and Responses document,
which is available from several sourCes
(see
ADDRESSES
section). The major
public comments are summarized by
subject as follows:
A. Parameter Operating Level
Terminology
Several commenters suggested we
revise the key parameter operating level
used for the relative accuracy (RA) test
from
"nonnal" to "mid."
It
was noted
that some units nonnally operate in the
high or
low levels and that a revised
listing of mid level would ensure that
the intended three levels would be
evaluated. We agree with the
commenters and changed
the reference
from
"normal" to "mid."
B.
PS-16 Applicability
to
Market-Based
Programs
Several comrnenters objected to
applying PS-16 to PEMS that are used
in a market-based program. They noted
that market-based PEMS are already
covered
in Subpart
E
of 40 CFR part 75
and those requirements are different
from proposed P8-16. This was deemed
confusing from an applicability
standpoint, especially for those PEMS
that have already been approved under
part 75. Other commenters stated that
they did not understand why
performance specifications for market.
based monitoring
were being added to
40 CFR part 60 since part 60 does not
address marketing regulations.
Some
commenters asked whether PS-16
would apply to PEMS already in use.
We have dropped the proposed
applicability
ofPS-16 to market-based
PEMS and agree that part 75 is the better
place to address market-based
PEMS.
Requirements for PEMS used in the part
75 market-based program are already
addressed in Subpart E of part 75, and
we do not believe the more stringent
requirements
given there for market-
based PEMS are warranted for
compliance monitoring under 40 CFR
parts 60, 61, and 63. We note in the final
rule that PS-16 applies only to PEMS
that are installed after the effective date
oftoday's action and to those used to
comply with requirements in 40 CFR
parts 60, 61, or 63.
C.
PS-16 and the Older Draft
Performance Specifications on the EPA
Web Site
A
number of commenters asked that
the draft
"Example Specifications and
Test Procedures for Predictive Emission
Monitoring Systems" on the EPA Web
site be adopted as PS-16 instead of the
proposed provisions. They note that
these specifications have been used in
the past to approve prospective PEMS
and felt the same guidelines should be
used in the future. One commenter
thought a departure from the draft
requirements would result in a demise
in PEMS use due to the increased costs
of initial certification and ongoing
maintenance.
The "Example Specifications and Test
Procedures for Predictive Emission
Monitoring Systems" was a guidance
document to give PEMS users and
regulators a general idea
of what could
be expected of PEMS in light of the
limited performance data available at
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that time.
It
was primarily based on the
existing requirements in PS-2 for CEMS
and not on extensive research. The
document was offered on the EMC Web
site
until the Agency could develop and
finalize
PS-1B.
Since then, we have
acquired relative accuracy test
audit
(RATA) data from a number of PEMS
over time. and our understanding of
their capabilities has increased. This
data is presented in the docket and gives
a better indication of PEMS performance
than what is reflected in the guidance
document (see EPA-OAR-2003--o074-
0002,0003,
and 0004 dacket entries).
This data confirms that the performance
levels
set in PS-16 are achievable by the
vast majority of PEMS in the data pool
and are more reflecti
VB
of the
technology's capabilities. We disagree
with the commenter that the new
requirements in PS-16 will result in the
demise ofPEMS due to increased cost
for initial certification
and ongoing
maintenance.
D. PEMS Relative Accuracy Stringency
vs. CEMS Stringency
Some commenters objected to the 10
percent relative accuracy limit for PEMS
in PS-16 considering that the
corresponding performance
specifications for
CEMS that are used
for the same purposes have a 20 percent
relative accuracy limit. They note that
previous approvals of PEMS were based
on the 20 percent criterion in the draft
Web site performance specifications.
Tbey also argued that the added
stringency of having to certify at a level
twice as accurate as a GEMS under the
same compliance conditions was not
warranted.
The 20 percent relative accuracy limit
was set for
CEMS in the 1970's and
reflects the performance capabilities of
systems at that time. State-of-the-art
CEMS are capable of much better
performance as
can be seen by their
success under the tighter part 75 rules
where a 10 percent relative accuracy is
required. We have obtained
perfonnance data on a number of
installed PEMS currently in use
(see
EPA-HQ-OAR-2003--o074--o002,0003,
and 0004 docket entries), and the data
show an overwhelming majority of the
PEMS are capable of meeting a 10
percent criterion on a repeated basis.
We believe
the quality of emissions data
should parallel the increased
capabilities of newer technologies, not
the capabilities of older, outdated
systems. Therefore, the 10 percent
relative accuracy
limit for PEMS is
retained in this final rule.
E. Alternative Limits for
Low
Emitters
Several commenters asked that
alternative relative accuracy limits be
allowed for low-emitting sources. They
were concerned that the 10 percent
relative accuracy limit would be
problematic for low-emitters because
the error in the reference method
measurement plays a significant part in
the accuracy determination at low
concentrations. One commenter noted
that many permits set emission limits
just above
the typical emission level of
the source. This results in low-emitting
sources running
in the 75-95 percent of
the emission standard range. The
proposed alternative limits would only
be
of use when the unit is operating
either below 25 or below 10 percent of
the emission standard. They thought it
would be more practical to base
alternative criteria on the measured
concentration ranges instead of the
emission standard. Two commenters
suggested scaling the relative accuracy
requirement such that 10 percent would
be the limit for measurements over 100
ppm, 20 percent for measurements
between 10 and 100 ppm, and within 2
ppm for measurements under 10 ppm.
We understand the commenters'
concerns and think their suggestion for
alternative criteria for low emitters
is a
practical idea. We have added the
suggested alternative criteria for
concentrations between
10 and 100 ppm
(20 percent RA) and below 10 ppm
(±
2 ppm difference between PEMS and
reference method).
F. Statistical Tests
One commenter thought the relative
accuracy requirements are, in some
cases, too severe and would prevent (1)
even most CEMS from certifying using
standard reference method testing
and
(2) all but the most sophisticated PEMS
from passing certification. Two
cornmenters proposed using daily zero
and span calibration checks and
quarterly linearity checks as alternatives
to the statistical tests and quarterly
relative accuracy audits (RAA). Others
recommended longer sampling times to
obtain the needed data for the relative
accuracy statistical tests similar to the
40 CFR part 75, Subpart E requirements.
Several commenters stated that they
anticipated difficulty in meeting the 0.8
r-correlation requirement in tests where
process v8!'iations are small. One
commenter recommended the proposed
waiver of the correlation test be made
permanent if the data are determined to
be either auto-correlated or if the signal-
to-noise ratio of the data is less than 4.
We do
not believe the relative
accuracy requirements are so severe as
to prevent most GEMS or PEMS from
certifying using standard reference
method testing. Most PEMS are not
amenable to daily zero and span checks
or quarterly linearity checks of their
sensors. The suggested long-term
relative accuracy evaluation
of PEMS
similar to the requirements of Subpart E
of part 75 would render PEMS use
economically impractical under parts
60, 61, and 63. Evaluation times similar
to those currently required
of CEMS
should be sufficient. We have taken the
recommendation that the correlation
test be permanently
waived in cases
where the data are auto-correlated or
have a signal-to-noise ratio less than 4
and have made this change in PS-16.
G.
Use of Portable Analyzers for the
Relative
Accuracy Audit
Several commenters opposed the use
of portable analyzers for the quarterly
relative accuracy audits. They felt the
analyzers lacked sufficient accuracy to
evaluate
PEMS. Two commenters cited
the report
"Evaluation of Portable
Analyzers for Use
in Quality Assuring
Predictive Emission Monitoring Systems
for NO
x
"
(a report prepared for EP
Ns
Clean Air Markets Division,
Washington,
DC, September 8,2004) as
proof of this inadequacy. They note that
in the report the only analyzer that
achieved accuracy better than 10
percent was the more sophisticated
analyzer using the reference method
methodology. Additionally, a
commenter suggested that sampling
problems related to sampling point
location, sample conditioning, high-
moisture and volume, particulate, and
high temperatures would render
portable analyzers ineffective. Another
commenter thought that portable
analyzers,
which were believed to be
accurate to
within 20 percent, would
not be able to show that PEMS are
accurate to
within 10 percent.
Three commenters asked that the
quarterly audit requirements be
removed altogether. One commenter
stated that helshe did not see any added
value in the audits because PEMS were
thought to be inherently reliable, and
two commenters urged a return to the
Web site performance specification
requirement to conduct biannual
relative accuracy test audits instead of
quarterly relative accuracy audits.
We are not aware of and commenters
did not present any data that supports
the idea that PEMS are inherently
accurate such that their perfonnance is
guaranteed over long periods of time.
The performance of PEMS, like CEMS,
depends on a number of criteria that are
subject to change over time. The
summary and findings of the noted
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12579
report on portable analyzers state that
"The portable analyzers produced
results that were comparable to those of
the CEMS and Method 7E for the two
natural gas-fired combustion sources
and low concentrations tested." Portable
analyzers are offered as a cheaper
testing option to
add flexibility to the
relative accuracy audits. However,
reference methods
may also be used in
place of portable analyzers for the
relative accuracy audit. A relative
accuracy audit for a validated
PEMS
would not be valueless but would
confirm that such a PEMS is still
functioning properly. Therefore,
quarterly relative accuracy audits are
retained
and may be performed using a
portable analyzer
or a reference method.
H.
Potential Overlap Between PS-16
and PS-17
Three commenters asked that we
specifically state that
PS-16 will not
apply to parametric monitoring systems.
We were asked to clarify that PS-16
would not cover parametric systems that
are already covered
under PS-17.
Performance
Specification 17 applies
to parametric monitoring systems
(i.e.,
those that have associated parametric
limits), Performance Specification 16
applies to predictive emission
monitoring systems
(i.e.,
those that have
associated emission limits). This
difference has been noted in PS-16.
1.
Reduced Relative Accuracy Audit
Frequency for Good Performance
One commenter proposed that
quarterly relative accuracy audit tests be
required for the first year after initial
certification.
If
all tests are passed
through the second year relative
accuracy test audit (without tuning or
additional training),
the second year of
relative accuracy audits would be
waived. In cases of failed relative
accuracy audit or relative accuracy test
audit attempts during the year or
any
PEMS retraining that triggers
recertification
would nullify this option
until the subsequent year. The
commenter felt this waiver option was
important to the viability
of PEMS use
at remote sites.
We believe the commenter's
suggestion has merit
but think that at
least a semiannual test at a time
approximately one-half year from
the
previous RATA is needed to prevent
extended malfunctions. We have
therefore revised
P5-16 to allow a single
RAA
or RATA midway the second year
if three prior quarters
of RAA and a
second annual RATA are passed
without PEMS training or tuning.
VI. 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 U.S. Court of Appeals
for the District
of Columbia Circuit by
May 26, 2009. 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 established by
this action may not be challenged
separately
in any civil or criminal
proceedings brought by EPA to enforce
these requirements.
vn. Statutory and Executive Order
Reviews
A. Executive Order
12866:
Regulatory
Planning
and Review
This action is not a "significant
regulatory action"
under the terms of
Executive Order 12866 (58 FR 51735.
October 4,1993) and is, therefore, not
subject to review
under the Executive
Order.
B. Paperwork Reduction Act
This action does not impose an
information collection burden under the
provisions of the
Paperwork Reduction
Act.
44 U.S.C. 3501
et seq.
Burden is
defined at 5
CFR 1320.3(b). This final
rule does not add information collection
requirements beyond those currently
required
under the applicable
regulations. This final rule adds
performance requirements
and amends
testing
and monitoring requirements as
necessary.
C.
Regulatory Flexibility Act
The Regulatory Flexibility Act (RF A)
generally requires
an agency to prepare
a regulatory flexibility analysis
of any
rule subject to notice and comment
rulemaking requirements
under the
Administrative Procedure Act or any
other statute unless the agency certifies
that the rule will not have a significant
economic impact on a substantial
number
of small entities. Small entities
include small businesses. small
organizations.
and small governmental
jurisdictions.
For purposes
of assessing the impacts
of this rule on small entities, small
entity is defined
as:
(1)
A small business
whose parent company has fewer
than
100 or 1,000 employees. or fewer than
4 billion kilawatt-hr per
yea~
of
electricity usage, depending on the size
defmition for the affected North
American Industry Classification
System code;
(2) a small governmental
jurisdiction
that is a government of a
city,
county, town. school district or
special district
with a population of less
than
50.000; and (3) a small
organization
that is any not-for-profit
enterprise
which is independently
owned and operated and is not
dominant in its field.
After considering the economic
impacts of this final rule on small
entities. I certify
that this action will not
have a significant economic impact on
a substantial
number of small entities.
This final rule will
not impose any
requirements on small entities because
it does not impose
any additional
regulatory requirements.
D. Unfunded Mandates Reform Act
This action contains no Federal
mandates
under the provisions of Title
II of the Unfunded Mandates Reform
Act of 1995
(UMRA). 2 U.S.C. 1531-
1538 for State. local. or tribal
governments or the private sector. This
action imposes no enforceable
duty on
any State. local or tribal governments
of
the private sector. Therefore, this action
is not subject
to the requirements of
sections 202
or 205 of the UMRA. This
action is also not subject
to the
requirements
of section 203 of UMRA
because
it
contains no regulatory
requirements
that might significantly or
uniquely affect small governments. This
action adds procedures that
apply when
applicable parties choose to use a
different monitoring tool than
what is
currently required. Other amendments
are made to correct various errors in
testing provisions.
E. Executive Order
13132:
FederaHsm
Executive Order 13132 entitled
"Federalism" (64 FR 43255. August 10.
1999) requires EPA to develop an
accountable process to ensure
"meaningful
and timely input by State
and local officials in the development of
regulatory policies that have federalism
implications." "Policies that have
federalism
implications" is defined in
the Executive Order to include
regulations that 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."
This final rule 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, as specified in
Executive Order 13132. This rule will
benefit State
and local governments by
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Federal Register/Vol. 74, No. 56/Wednesday, March 25, 2009/Rules and Regulations
providing performance specifications
they can use to evaluate PEMS. Other
amendments being made will correct
P5-11, Procedures 1 and 2, Method 24,
and Method 303. No added
responsibilities or increase in
implementation efforts or costs for State
and local governments are being added
by this action. Thus, Executive Order
13132 does not apply to this rule.
F. Executive Order
13175:
Consultation
and Coordination
with
Indian Tribal
Governments
This action does not have tribal
implications, as specified in Executive
Order 13175 [65 FR 67249, November 9,
2000). This action adds an optional
monitoring tool to
the monitoring
provisions
that have already been
mandated. Thus, Executive
Order 13175
does
not apply to this action.
G.
Executive Order 13045: Protection of
Children From Environmental Health
Risks and Safety Risks
EPA interprets EO 13045 [62 FR
19885, April 23, 1997) as
applying only
to those regulatory actions that concern
health or safety risks, such that the
analysis required under section 5-501 of
the EO has the potential to influence the
regulation. This action is not subject to
EO 13045 because it does not establish
an environmental standard intended to
mitigate
health or safety risks.
H.
Executive Order
13211:
Actions
Concerning Regulations That
significantly Affect Energy Supply,
Distribution,
or
Use
This rule is not subject to Executive
Order 13211 [66 FR 28355 [May 22,
2001)), because it is not a significant
regulatory action
under Executive Order
12866.
1.
National Technology Transfer and
Advancement Act
Section 12[d) of the National
Technology Transfer
and Advancement
Act of 1995 ["NTTAA"), Public Law No.
104-113, 12[d) [15 U.S.c. 272 note)
directs
EPA to use voluntary consensus
standards in its regulatory activities
unless to do so would be inconsistent
with applicable law or otherwise
impractical. Voluntary consensus
standards are technical standards
(e.g.,
materials specifications, test methods,
sampling procedures, and business
practices)
that are developed or adopted
by voluntary consensus standards
bodies. NTTAA directs EPA to
provide
Congress, through OMB, explanations
when the Agency decides not to use
available and applicable voluntary
consensus standards.
This action does
not involve technical
standards. Therefore, EPA did not
consider the use of any voluntary
consensus standards.
/.
Executive Order
12898:
Federal
Actions To Address Environmental
Justice in Minority Populations and
Low-Income Populations.
Executive Order [EO) 12898 [59 FR
7629 [Feb. 16, 1994)) establishes Federal
executive policy
on environmental
justice. Its main provision directs
federal agencies, to
the greatest extent
practicable
and permitted by law, to
make environmental justice part of their
mission by identifying and addressing,
as appropriate,
disproportionately high
and adverse human health or
environmental effects of their programs,
policies,
and activities on minority
populations and low-income
populations in the United States.
EPA has determined that this final
rule
will not have disproportionately
high
and adverse human health or
environmental effects on minority or
low-income
populations because it does
not affect the level of protection
provided to human health or the
environment. This final rule does not
relax the control measures on sources
regulated
by the rule and, therefore, will
not cause emissions increases from
these sources.
K.
Congressional Review Act
The Congressional Review Act, 5
U.S.C. 801
et seq.,
as added by the Small
Business Regulatory Enforcement
Fairness
Act of 1996, generally provides
that before a rule may take effect, the
agency promulgating the rule must
submit a rule report, which includes a
copy of
the rule, to each House of the
Congress and to the Comptroller General
of the United States.
EPA
will submit a
report containing
this rule and other
required information to
the U.S. Senate,
the U.S. House of Representatives, and
the Comptroller General of the United
States prior to publication of the rule in
the Federal Register. A Major rule
cannot take effect until 60 days after
it
is published in the Federal Register.
This action is
not a "major rule" as
defined by 5 U.S.C. 804(2). This rule
will be effective April 24, 2009.
List of Subjects
40 CFR Part 60
Administrative practice and
procedures. Air pollution control,
Intergovernmental relations, Reporting
and recordkeeping requirements.
40 CFR Part 63
Environmental protection, Air
pollution control, Hazardous
substances, Reporting
and
recordkeeping requirements.
Dated: March ]6, 2009.
Lisa
Jackson,
Administrator.
• For the reasons set out in the
preamble, title 40, chapter I of the Code
of Federal Regulations is amended as
follows:
PART 60-STANDARDS OF
PERFORMANCE FOR NEW
STATIONARY SOURCES
•
I. The authority citation for Part 60
continues to read as follows:
Authority: 23
V.S.C.
101; 42
V.S.c. 7401-
7671q.
• 2. Section 6.7 is added to Method 24
of
Appendix A-7 to read as follows:
Appendix A-7 to Part 60-Test
Methods 19 through 25E
•
•
•
•
•
Method 24-Determination of Volatile
Matter Content, Water Content, Density.
Volume Solids, and Weight Solids
of Surface
Coatings
•
•
•
•
•
6.7 ASTM D 64]9-00, Test Method for
Volatile Content of Sheet-Fed
and Coldset
Web Offset Printing Inks.
•
•
•
•
• 3. Performance Specification 11 of
Appendix B is amended as follows:
• a. By revising Section 3.4.
• b. By revising Section 6.6,
introductory text.
• c. By revising paragraphs [l)[ii),
[l)[iii), (2), (4),
and (5) of Section 12.3
• d. By revising paragraph (3)[ii) of
Section 12.4.
• e. By revising paragraphs (2) and (3)
of Section 13.2.
• f. By adding Sections 16.8 and 16.9.
• g. By revising Table 1 of Section 17.0
to read as follows:
Appendix B to Part 50-Performance
Specifications
•
•
•
•
•
Performance Specificatiun 11-
Specifications and Test Procedures for
Particulate Matter Continuous Emission
Monitoring
Systems at Stationary Sources
•
•
•
•
•
3.4 "Confidence Interval Half Range (CI),'
is a statistical term and means one-half of the
width of the
95 percent confidence interval
Ill'OtUld the predicted mean PM concentration
(y
value) calculated at the PM CEMS
response value (x value) where the
confidence interval is narrowest. Procedures
for calculating
CI are specified
in
section
12.3. The CI as a percent of the emission
limit value
(CI%J is calculated at the
appropriate
PM CEMS response value and
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12581
must satisfy the criteria specified
in
Section
13.2 (2).
•
•
•
•
•
B.6 How do I conduct my PM GEMS
correlation lest? You must conduct the
correlation test according to the proceduxe
giVE;lD
in paragraphs (1) through (5) of this
section.
If
you need multiple correlations,
you must conduct testing and collect at least
15
sets of reference method and PM CEMS
data for calculating each separate correlation.
•
•
•
•
•
12.3 How do I detennine my PM GEMS
correlation?
.
(1)
.
11
.
11
..
(ii) Calculate the half range of the 95
percent confidence interval (GI) for the
predicted PM concentration {yJ at the mean
value of x, using Equation 11-8:
Cl
=
t
dr
.
l-n/2 . SL
V;;
IT
(Eq. 11-8)
Where:
CI
=
the half range of the 95 percent
confidence interval for the predicted PM
concentration at the mean x value.
4Jr,[.a/2
=
the value for the
t
statistic provided
in Table 1 for df
=
(n - 2), and
51, = the scatter or deviation of y values about
the correlation curve,
which is
determined using Equation 11-9:
(Eq. 11-9)
Calculate the confidence interval half range
for the predicted PM concentration
(:y)
at the
mean x value as a percentage of the emission
limit (CI%) using Equation 11-10:
CI
CI%
= _.
100%
EL
(Eq.II-IO)
Where:
CI
=
the half range of the 95 percent
confidence interval for the predicted PM
concentration at the mean x value, and
EL =
PM emission limit, as described in
section 13.2.
(iii) Calculate the half range of the
tolerance interval (TIl for the predicted PM
concentration (5') at the mean
x
value using
Equation 11-11:
(Eq. II-II)
Where:
TI
=
the half range of the tolerance interval
for the predicted PM concentration (5') at
the mean x value,
kT
=
as calculated using Equation 11-12, and
5
L
= as calculated using Equation 11-9:
(Eq.II-12)
Where:
n'
=
the number of test runs (n],
u,,- = the tolerance factor for 75 percent
coverage at
95 percent confidence
provided in Table
1 for df
=
(n - 2), and
Vdf = the value from Table
1
for df = (n - 2).
[
OS,S,]
A=S,S,S"
S, s, S,
S, = I,(x;),S, = i(xn,s, =i(xij,s, =i(x:j
;",1
;=1
;=1
;=1
Calculate the half range of the tolerance
interval for
the predicted PM concentration
(:9") at the mean x value as a percentage of the
emission limit
(n%)
using Equation 11-13:
TI
TI%
= - .
100%
EL
Where:
(Eq.II-I3)
11
=
the half range of the tolerance interval
for the predicted
PM
concentration (5') at
the mean x value, and
EL
=
PM emission limit, as described in
section 13.2 .
•
•
•
•
•
(2) How do I eV8luate a polynomial
correlation for
my correlation test d8ta? To
evaluate a polynomial correlation, follow the
procedwes described in paragraphs
(2)(0
through (iv) of this section.
(i) Calcul8te
the polynomial correlation
equation. which is indicated by Equation 11-
16, using Equations 11-17 through 11-22:
(Eq. 11-16)
Where:
y
=
the PM CEM:S concentration predicted by
the polynomial correlation equation,
and
b
o
,
b L. b:z =
the coefficients determined from
the solution to ilie matrix equation Ab=B
Where:
(Eq.I1-17)
(Eq. 11-18)
Where:
Xi
=
the PM CEMS response for run i,
Y
L
=
the reference method PM concentration
for run
i,
and
n
=
the number of test runs_
Calculate the polynomi81 correlation curve
coefficients
(bo,
bl.
and
b
z)
using Equations
11-19 through 11-21, respectively:
b
=
(S, .S, .S, +S, .S, .S, +S, .S, .S, -S, .S, .S, -S, .S, .S, -S, .S, .S,)
o
det
A
(Eq. 11-19)
b
=
(n.S,
.S, +S, .S, .S, +S, .S, .S, -S, .S, .S, -S, .S,
.n-S,
.S, .S,)
,
det
A
(Eq. 11-20)
b
=
(n.S,
.S, +S, .S, .S, +S, .S, .S, -S, .S, .S, -S, .S,
.n-S,
.S, .S,)
,
det
A
(Eq.I1-21)
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Where:
det
A
~
n'S, -S, -S, -S, .S,
+SI
.S, .S, -S, .S, .n+S,
A
.S, -S,
,SI,SI
(Eq. 11-22)
(iiJ Calculate the 95 percent confidence
C coefficients (Co to C,) using Equations 11-
interval halfrange (GI) by fust calculating the 23 and 11-24:
Co
(S,.S,-Sil
C
I
(S, S, - SI'
S, )
C,=
(SI' S,- Sn
D
D
,
C,
(nS, - Sn
C,
(SI' S, - nS,)
C,
(nS, - s;j
(Eq. 11-23)
D
D
D
Where:
D
=
n(
S,
.S, -S;)
+SI
(S, .S,
-SI
.S,)+
S, (SI
.S, -S;)
(Eq.II-24)
Calculate 11 using Equation 11-25 for each x
value:
Determine
the x value that corresponds to the
minimum value of 11 (6
m
l
n
).
DBtCrnllne the
scatter or deviation ofyvalues about the
Calculate the half range of the 95 percent
confidence interval
(el)
for the predicted PM
concentration
(y)
at the x value that
corresponds to
.6.,,,ln using Equation 11-27:
(Eq. 11-27)
Where:
df = (n-3), and
tdf
=
as listed
in
Table 1 (see section 17).
Calculate
the half range of the 95 percent
confidence interval for the predicted PM
concentration at
the x value that corresponds
to dmin as a percentage of the emission limit
(CI%) using Equation 11-28:
CI
CI%=-.lOO%
EL
Where:
(Eq. 11-28)
CI
=
the half range of the 95 percent
confidence interval for the predicted PM
concentration at the x value that
corresponds to .6.
min,
and
EL
=
PM emission limit, as described
in
section 13.2.
polynomial correlation
curve
(Sp)
using
Equation 11-26:
(Eq. 11-25)
(Eq.II-26)
(iii) Calculate the tolerance interval half
range (TIl for the predicted PM concentration
at the x value that corresponds to 6
m
in, as
indicated
in
Equation 11-29 for the
polynomial correlation, using Equations 11-
30 and 11-31:
Tl="-r'Sp
(Eq. 11-29)
Where:
(Eq.11-30)
n'=-
11
(Eq.11-31)
Un' =
the value indicated in Table 1 for df
=
(n'-3). and
vdf
=
the value indicated
in
Table 1 for df
= (n'-3).
Calculate the tolerance interval half range for
the predicted PM concentration at the x value
that corresponds to 6.
min
as a percentage of
the emission limit (TI%) using Equation 11-
32:
TI%
Where:
=
Tl.lOO
EL
(Eq.l1-32)
TI
=
the tolerance interval half range for the
predicted PM concentration at the x
value that corresponds to
dmin, and
EL
=
PM emission limit, as described in
section 13.2.
(iv) Calculate
the polynomial correlation
coefficient (rl using Equation
11-33:
r
=
~I
_
S~
S,
(Eq.11-33)
Where:
81' =
as calculated using Equation 11-26, Wld
Sy =
as calculated using Equation 11-15.
•
*
*
•
•
(4) How do 1 evaluate an exponential
correlation for my correlation test data? To
evaluate
Wl exponential correlation, which
has the form indicated by Equation 11-37,
follow the procedures described in
paragraphs (4)(i) through (v) of this section:
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* * * * * * PC # 17 * * * * * *
Federal Register/Vol. 74, No. 56/Wednesday, March 25, 2009/Rules and Regulations
12583
(Eq, 11-37)
(i)
Perform a logarithmic transformation of
each PM concentration measurement
(y
values) using Equation 11-38:
y;'
= Ln
(y;)
(Eq. 11-38)
Where:
y'.
=
is the transfonned value of Yi. and
Ln(Yi)
=
the natural logarithm of the PM
concentration measurement for run
i.
(ii)
Using the values for y';
in
place of the
values for
Yi.
perfonTI the same procedures
used to develop the linear correlation
equation described
in
paragraph (l)(i) of this
section. The resulting equation will have the
form indicated by Equation] 1-39,
(Eq.11-39)
Where:
r
=
the predicted log PM concentration
value,
b' 0
=
the natural logarithm of bo, and the
variables bOt bit and x are as defined
in
paragraph (t){O of this section.
(iii) Using the values for
Y'I
in place of the
values for Yit calculate the half range of the
95 percent confidence interval
(CY),
as
described
in paragraph (l)(ii) of this section
for
CI. Note that CI' is on the log scale. Next,
calculate
the upper and lower 95 percent
confidence limits for the mean value
t
using
Equations 11-40 and 11-41;
LCL'
= r'
-Ci'
(Eq. II-40)
VCL'
= y' +
Ci'
(Eq. 11-41)
Where;
LeL'
=
the lower 95 percent confidence limit
for
the mean value
t.
UCL'
=
the upper 95 percent confidence limit
for the mean value
t.
t
=
the mean value of ilie log-transformed
PM concentrations, and
CI'
=
the half range of the 95 percent
confidence interval for the predicted
PM
concentration
(f),
as calculated in
Equation 11-8.
Calculate the halfnmge of the 95 percent
confidence interval (CI) on the original PM
concentration scale using Equation 11-42;
CI
=
UCL'
LeL'
e
-e
(Eq.
Il-42)
2
Where:
CI
=
the half range of the 95 percent
confidence interval on the original PM
concentration scale, and UCL' and LCL'
are as defined previously.
Calculate
the half range of the 95 percent
confidence interval for the predicted PM
concentration corresponding to the mean
value of x as a percentage of the emission
limit (CI%) using Equation 11-10.
(iv) Using the values for y' ; in place of
the values for
y;.
calculate the half range
tolerance interval
(Tl1,
as described in
paragraph (l)[ili) of this section for 11. Note
that TI' is on the log scale. Next, calculate the
half range tolerance limits for the mean value
'l
using Equations 11-43 and 11-44:
LTL' = r' - TI'
UTL' = y' +TI'
Where:
(Eq. 11-43)
(Eq. II-44)
LTL'
=
the lower 95 percent tolerance limit
for
the mean value
i,
UTL'
=
the upper 95 percent tolerance limit
for the mean value y',
t.
=
the mean value of ilie log-transformed
PM concentrations, and
TI'
=
the half range of the 95 percent
tolerance interval for the predicted PM
concentration
W),
as calculated in
Equation 11-11.
Calculate the half range tolerance interval
(TI) on the original PM concentration scale
using Equation 11-45:
UTl:
LTV
TI=e -e
2
(Eq. 11-45)
TI
=
the half range of the 95 percent tolerance
interval
on the original PM scale, and
UTL' and LTL' are as dermed previously.
Calculate
the tolerance interval half range for
the predicted PM concentration
corresponding to
the mean value of x as a
percentage
of the emission limit (TI%) using
Equation 11-13.
(v) Using the values for
y' f
in place of the
values for
y ...
calculate the correlation
coefficient (r)
using the procedure described
in paragraph (1)(iv) of this section.
(5) How do I evaluate a power correlation
for my correlation
test data? To evaluate a
power correlation, which has the form
indicated by Equation 11-46, follow the
procedures described in paragraphs (5)[i)
through (v) of this section.
(Eq_ 11-46)
(i) Perform logarithmic transformations of
each PM CEMS response (x values) and each
PM concentration measurement (yvalues)
using Equations 11-35 and 11-3B,
respectively.
(ti) Using the values for x'/ in place of the
values for x" and the values for
y';
in place
of the values for
Yf,
perform the same
procedures used to develop the linear
correlation equation described
in paragraph
(1)[i)
of this section. The resulting equation
will have the form indicated by Equation 11-
47:
Y
=
b;
+
b,x'
(Eq. 11-47)
Whero:
f =
the predicted log PM concentration
value,
and
x'
=
the natural logarithm of the PM CEMS
response values.
b'o
=
the natural logarithm of 1>0, and the
variables
ho.
hi,
and x are as defined in
paragraph (1)(i) of this sectioD.
(iii)
Using the same procedure described
for
exponential models in paragraph (4)(iii)
of this section, calculate the half range of the
95 percent confidence interval for the
predicted PM concentration corresponding to
the mean value of x' as a percentage of the
emission limit.
{iv) Using the same procedure described
for exponential models
in
paregraph (4)(iv) of
this section, calculate the tolerance interval
half range for the predicted PM concentration
corresponding to the
mean value of
x
as a
percentage
of the emission limit.
(v)
Using the values for
y'/
in place of the
values for
Y;,
calculate the correlation
coefficient (r) using
the procedure described
in paragraph (1)(iv) of this section.
Note:
PS-11 does not address the
application of correlation equations to
calculate
PM emission concentrations using
PM CEMS response data during normal
operations of a PM CEMS. However, we will
provide guidance on the use of spocific
correlation
models (i.e., logarithmic,
exponential.
and power models) to calculate
PM concentrations in an operating PM CEMS
in situations when the PM CEMS response
values are equal to
or less than zero, and the
correlation model is undefined.
12.4
What correlation model should I
use?
•
•
•
•
•
(3) * *
(il) Calculate the minimum value using
Equation 11-4B.
mmormax=--
•
hI
2h,
(Eq. 11-48)
•
•
•
•
•
13.2 What performance criteria must my
PM CEMS correlation satisfy?
•
•
•
•
(2) The confidence interval half range must
satisfy the applicable criterion specified in
paragraph (2)(i), (lil, or (iii) of this section.
based
on the type of correlation model.
(1) For linear or logarithmic correlations,
the 95 percent confidence interval halfrnnge
at the mean PM CEMS response value from
the correlation test must be within 10 percent
of the PM emission limit value specified in
the applicable regulation. Therefore, the CI%
calculated using Equation 11-10 must be less
than or equal to 10 percent.
(il) For polynomial correlations, the 95
percent confidence interval half range at the
PM CEMS response value from the
correlation test that corresponds to the
minimum value for
fl
must be within 10
percent of the PM emission limit value
specified
in the applicable regulation.
Therefore,
the CI% calculated using Equation
11-28 must be less than or equal to 10
percent.
(iii) For exponential or power correlations,
the 95 percent confidence interval half range
at
the mean of the logarithm of the PM CEMS
response values from the correlation test
must be within 10 percent of the PM
emission limit value specified in the
applicable regulation. Therefore, the CI%
calculated
using Equation 11-10 must bo less
than or equal to 10 percent.
(3) The tolerance interval half range must
satisfy the applicable criterion specified in
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Federal Register/Vol. 74, No. 56/Wednesday, March 25, 2009/Rules and Regulations
paragraph (3)(i),
(ii),
or (iii)
of this
section,
based on the type of correlation model.
(0 For linear or logarithmic correlations,
the
half range tolerance interval
with
95
percent confidence and 75 percent coverage
at the mean PM GEMS response value from
the correlation test must be within 25 percent
of the PM emission limit value specified in
the applicable regulation. Therefore, the TI%
calculated using Equation 11-13 must be less
than or equal to 25 percent.
(ii)
For polynomial correlations, tho half
range tolerance interval with 95 percent
confidence and 75 percent coverage at the
PM GEMS response value from the
correlation test that corresponds to the
minimum value for 11 mllst be within 25
percent of the PM emission limit value
specified in the applicable regulation.
Therefore, the TI% calculated using Equation
11-32 must be less than or equal to 25
percent.
(iii) For exponential or power correlations,
the
half range
tolerance interval with 95
percent confidence and 75 percent coverage
at the mean of the logarithm of the PM CEMS
response values from the correlation test
must be within 25 percent of the PM
emission limit value specified in the
applicable regulation. Therefore,
the 11%
calculated
using Equation 11-13 must be less
than or equal to 25 percent.
•
•
•
•
•
16.0 Which references are relevant to this
perfonnance specification?
•
•
•
•
•
16.8 Snedecor, George W. and Cochran,
William
G. (1989), Statistical Methods,
Eighth Edition, Iowa
State University Press.
16.9 Wallis, W. A. (1951)
"Tolerance
Intervals for Linear Regression," in Second
Berkeley Symposium on Mathematical
Statistics and Probability, ed.
J.
Neyman,
Berkeley:
University of California Press, pp.
43-51.
17.0
* * '*
TABLE 1-FACTORS FOR CALCULATION OF CONFIDENCE AND TOLERANCE INTERVAL HALF RANGES
Tolerance interval with 75% coverage and 95%
df
Student's t, ilr
confidence level
Vdf
(95
c
/c)
Un' (75%)
kT
3 ...................................................................................................................... .
3.182
2.920
1.266
3.697
4 ...................•.............••.......................••...........................................................
2.776
2.372
1.247
2.958
5 .......................................................................................................... .
2.571
2.089
1.233
2.576
6 ...................................................................................................................... .
2.447
1.915
1.223
2.342
7 ...................................................................................................................... .
2.365
1.797
1.214
2.183
8 ..................................................................................................................... .
2.306
1.711
1.208
2.067
9 ...................................................................................................................... .
2.262
1.645
1.203
1.979
10 ................................................................................................................... .
2.228
1.593
1.198
1.909
11 .................................................................................................................... .
2.201
1.551
1.195
1.853
12 .................................................................................................................... .
2.179
1.515
1.192
1.806
13 ................................................................................................................... .
2.160
1.485
1.189
1.766
14 .................................................................................................................... .
2.145
1.460
1.186
1.732
15 .................................................................................................................... .
2.131
1.437
1,184
1.702
16 .................................................................................................................. .
2.120
1.418
1.182
1.676
17 .................................................................................................................... .
2.110
1.400
1.181
1.653
18 ................................................................................................................... .
2.101
1.384
1.179
1.833
19 ................................................................................................................... .
2.093
1.370
1.178
1.614
20 .................................................................................................................... .
2.066
1.358
1.177
1.597
21 .................................................................................................................... .
2.080
1.346
1.175
1.582
22 ................................................................................................................... .
2.074
1.335
1.174
1.568
23 ......................................................
' ........................................................... .
2.069
1.326
1.173
1.555
24 .................................................................................................................... .
2.064
1.316
1.172
1.544
25 .................................................................................................................... .
2.060
1.308
1.172
1.533
26 .................................................................................................................... .
2.056
1.300
1.171
1.522
27 .................................................................................................................... .
2.052
1.293
1.170
1.513
28 ................................................................................................................... .
2.048
1.286
1.170
1.504
29 ....................................................................................................... .
2.045
1.280
1.169
1.496
30 .................................................................................................................... .
2.042
1.274
1.168
1.488
31 .................................................................................................................... .
2.040
1.268
1.168
1.481
32 .................................................................................................................... .
2.037
1.263
1.167
1.474
33 .................................................................................................................... .
2.035
1.258
1.167
1.467
34 .................................................................................................................... .
2.032
1.253
1.166
1.461
35 .................................................................................................................. .
2.030
1.248
1.166
1.455
36 .................................................................................................................... .
2.028
1.244
1.165
1.450
37 .................................................................................................................... .
2.026
1.240
1.165
1.444
38 ................................................................................................................... .
2.024
1.236
1.165
1.439
39 .................................................................................................................... .
2.023
1.232
1.164
1.435
40 ...................................................................................................... .
2.021
1.228
1.164
1.430
41 ................................................................................................................... .
2.020
1.225
1.164
1.425
42 .................................................................................................................... .
2.018
1.222
1.183
1.421
43 .................................................................................................................... .
2.017
1.218
1.183
1.417
44 ................................................................................................................... .
2.015
1.215
1.163
1.413
45 .................................................................................................................... .
2.014
1.212
1.163
1.410
46 .................................................................................................................... .
2.013
1.210
1.162
1.406
47 .................................................................................................................... .
2.012
1.207
1.162
1.403
48 .................................................................................................................... .
2.011
1.204
1.162
1.399
49 .................................................................................................................... .
2.010
1.202
1.162
1.396
50 .................................................................................................................... .
2.009
1.199
1.161
1.393
51. ................................................................................................................... .
2.008
1.197
1.161
1.390
52 .................................................................................................................... .
2.007
1.195
1.161
1.387
53 .................................................................................................................... .
2.006
1.192
1.161
1.384
54 .................................................................................................................... .
2.005
1.190
1.161
1.381
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* * * * * * PC # 17 * * * * * *
Federal Register/VoL 74, No. 56/Wednesday, March 25, 2009/Rules and Regulations
12585
TABLE 1-FACTORS FOR CALCULATION OF CONFIDENCE AND TOLERANCE INTERVAL HALF RANGES-Continued
Tolerance interval with 75% coverage and 95%
df
Student's I, t!r
1-____
--,CO,-"_fi_de_n_c_e_l_ev_o_I,-____ _
55 .................................................................................................................... .
2.004
2.003
2.002
2.002
2.001
2.000
56 ................................................................................................................... ..
57 .................................................................................................................... .
58 ...................................................................................................................
..
59 .................................................................................................................... .
60 .................................................................................................................... .
References 16.8 (I values) and 16.9 (Vdf and Un' values) .
• 4.
In
Appendix B, Performance
Specification 16 is added to read as
follows:
Appendix B to Part 60-Performance
Specifications
•
•
•
•
•
PERFORMANCE SPECIFICATION 16--
SPECIFICATIONS AND TEST
PROCEDURES
FOR PREDICTIVE EMISSION
MONITORING SYSTEMS
IN STATIONARY
SOURCES
1.0 Scope and Application
1,1 Does this performance specification
apply to me?
If
you, the source owner or
operator, intend to usc (with any necessary
approvals) a predictive emission monitoring
system (PEMS) to show compliance with
your emission limitation under 40 CFR 60.
61, or 63, you must use the procedures in this
perfonnance
specification (PS) to determine
whether your
PEMS is acceptable for use in
demonstrating compliance with applicable
requirements.
Usc these procedures to certify
your
PEMS after initial installation and
periodically thereafter to ensure the
PEMS is
operating properly.
If
your PEMS contains a
diluent
(0
2
or CO
2)
measuring component
and your emissions limitation is in
WlitS that
require a diluent measurement
(e.g.lbs/mm
Btu), the diluent component must be tested
as well. These speCifications apply to PEMS
that arc installed under 40 CFR 60, 61, and
63 after the effective date of this performance
specification. These specifications do not
apply
to parametric monitoring systems,
these are covered under
PS-17.
1.1.1 How
do! certjfy
my
PEMS after it
is installed?
PEMS must pass a relative
accuracy
(RA)
test and accompanying
statistical tests in the initial certification test
to
be
acceptable for use
in
demonstrating
compliance with applicable requirements.
Ongoing quality assurance tests also must be
conducted
to ensure the PEMS is operating
properly.
An
ongoing sensor evaluation
procedure must be
in place before the PEMS
certification is complete. The amount of
testing and data validation that is required
depends upon the regulatory needs,
i.e.,
whether precise quantification of emissions
will be needed or whether indication
of
exceedances of some regulatory threshold
will suffice.
PerformWlce criteria are more
rigorous for
PEMS used
in
determining
continual compliance with an emission limit
than those used to measure excess emissions.
You must perform the initial certification test
on your PEM:S before reporting any PEMS
data as quality-assured.
1.1.2 Is other testing required after
certification?
After you initially certify your
PEMS, you must pass additional periodic
performance checks to ensure the long-term
quality of data. These periodiC checks are
listed
in
the table in Section 9. You are
always responsible for properly maintaining
and operating your
PEMS.
2.0 Summary of Perfonnance Specification
The following performance tests are
required
in addition to other equipment and
measurement location requirements.
2.1 Initial PEMS Certification.
2.1.1 Excess Emissions PEMS. For a
PEMS that is used for excess emission
reporting, the owner or operator must
perform a minimum
9-nm, 3-level (3 runs at
each level)
RA
test (see Section
8.2).
2.1.2 Compliance PEMS. For
n
PEMS that
is usod for continual compliance standards,
the owner or operator must perform a
minimum 27-run, 3-level
(9
runs at each
level) RA test (see Section 8.2). Additionally.
the data must be evaluated for bias and by
F-test and correlation analysis.
2.2
Periodic Quality Assurance (QA)
Assessments. Owners and operators of all
PEMS are required to conduct quarterly
relative accuracy audits
(RAA)
and yearly
relative accuracy test audits
(RATA) to assess
ongoing
PEMS operation. The frequency of
these periodic assessments may be shortened
by successful operation during a prior year.
3.0 Definitions
The following definitions apply:
3.1 Centroidal Area
moans that area in
the center
of the stack (or duct) comprising
no more than
1
percent of the stack cross-
sectional area and having the same geometric
shape
as the stack.
3.2 Data Recorder
means the equipment
that provides a permanent record
of the
PEM:S output. The data recorder may include
automatic data reduction capabilities and
may include electronic data records, paper
records,
or a combination of electronic data
and paper records.
3.3 Defective sensor
means a sensor that
is responsible for
PEMS malfunction or that
operates outside the approved operating
envelope. A defective sensor may be
functioning properly.
but because
it
is
operating outside the approved operating
envelope, the resulting predicted emission is
not validated.
1.188
1.186
1.184
1.182
1.180
1.179
Un' (75%)
1.160
1.160
1.160
1.160
1.160
1.160
1.379
1.376
1.374
1.371
1.369
1.367
3.4 Dj1uent
PEMS
means the total
equipment required to predict a diluent gas
concentration or emission rate.
3.5 Operating envelope
means the
defined range of a parameter
input that is
established during
PEMS development.
Emission data generated from parameter
inputs that
are beyond the operating
envelope are not considered quality assured
and
are therefore unacceptable.
3.6 PEMS
means all of the equipment
required
to predict an emission concentration
or emission rate. The system may consist of
any
of the following major subsystems:
sensors and sensor interfaces, emission
model, algorithm, or equation that uses
process data
to generate an output that is
proportional to
tho emission concentration or
emission rate, diluent emission modeJ, data
recorder, and senser evaluation system.
Systems that use fewer thWl 3 variables do
not qualify
as PEMS Wlless the system has
been specifically approved by the
Administrator for usc as a
PEMS.
A
PEMS
may predict emissions data that are corrected
for diluent if the relative accuracy and
relevant
QA tests are passed in the emission
WlitS corrected for diluent. Parametric
monitoring systems that serve as indicators of
compliance and have
parametric
limits but
do not predict emissions
to comply with an
emissjons
limit are not included in this
definition.
3.7 PEMS
trajningmeans the process of
developing or confirming the operation of the
PEMS against a reference method under
specified conditions.
3.6 Quarter
means a quarter of a calendar
year in which there are at least
168 Wlit
operating hours.
3.9 Reconciled Process Data
means
substitute data that
are generated by a sensor
evaluation system
to replace that of a failed
sensor. Reconciled process data may not be
used without approval [rom the
Administrator.
3.10
Relative Accuracy
means the
accuracy of the
PEMS when compared to a
reference method
(RM) at the source. The
RA
is the average difference between the
pollutant
PEMS and RM data for a specified
number of comparison runs plus a 2.5
percent confidence coefficient, divided by
the average of the
RM tests. For a diluent
PEMS, the RA may be expressed as a
percentage
of absolute difference between the
PEMS and RM. Alternative specifications are
given for units that have very low emissions.
3.11
Relative Accuracy Audit
means a
quarterly audit
of the PEMS against a
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portable analyzer meeting the requirements
of ASTM D6522-00 or a RM for a specified
number
of runs. A RM may be used in place
oftha portable analyzer for the RAA.
3.12 Relative Accuracy Test Audit
means
a
RA
test that is performed at least Once every
four calendar quarters after the initial
certification test while the
PEMS is operating
at the normal operating level.
3.13 Reference Value
means a PEMS
baseline value that may be established by RM
testing under conditions when all sensors are
functioning properly. This reference value
may then be used
in the sensor evaluation
system or
in
adjusting new sensors.
3.14 Sensor Evaluation System
means the
equipment
or procedure used to periodically
assess the quality of sensor
input data. This
system may be a sub-model that periodically
cross-checks sensor inputs among themselves
or any other procedure that checks sensor
integrity at least daily (when operated for
more
than one hour in any calendar day).
3.15 Sensors and Sensor Interface
means
the equipment that measures the process
input signals and transports them to the
emission prediction system.
4.0 Interferences [Reserved]
5.0
Safety [Reserved}
6.0
Equipment and Supplies
6.1 PEMS Design. You must detail the
design
of your PEMS and make this available
in reports
and for on-site inspection. You
If PEMS is measuring.
Uncontrolled emissions, such as
NOx at the
stack of a natural gas-fired boiler.
Uncontrolled emissions, such as
NOx at the
stack of a natural gas-fired boiler.
Controlled emissions ......................................... .
Continual compliance emiSSions for an applica-
ble regulation.
6.1.7 Sensor Location and Repair. We
recommend you install sensors in an
accessible location in order to perfonn
repairs
and replacements. PennanenUy
installed platfonns or ladders may not be
needed.
If
you install sensors in an area that
is not accessible, you may be required to shut
down the emissions unit to repair or replace
a sensor. Conduct a new RATA after
replacing a sensor. All sensors must be
calibrated as often
as needed but at least as
often as recommended by the manufacturers.
6.1.S Sensor Evaluation System. Your
PEMS must be designed to perform automatic
or manual detennination of defective sensors
on at least a daily basis. This sensor
evaluation system may consist
of a sensor
validation sub-model, a comparison of
redundant sensors, a spot check of sensor
input readings at a reference value,
operation, or emission level, or other
procedure that
detects faulty or failed
sensors.
Some sensor evaluation systems
generate substitute values (reconciled data)
that are used
when a sensor is perceived to
must also establish the following, as
applicable:
6.1.1 Number
of Input Parameters.
An
acceptable PEMS will nonnally use three or
more
input parameters. You must obtain the
Administrator's permission
on a case-by-case
basis
if you desire to use a PEM:S having
fewer than three
input parameters.
6.1.2
Parameter Operating Envelopes.
Before you evaluate your
PEMS through the
certification test, you must specify the
input
parameters your PEM:S uses, define their
range of minimum and maximum values
(operating envelope),
and demonstrate the
integrity of the
parameter operating envelope
using graphs
and data from the PEMS
development process, vendor information, or
engineering calculations, as appropriate.
If
you operate the PEMS beyond these
envelopes at
any time after the certification
test, the data generated during this condition
will not be acceptable
for use in
demonstrating compliance with applicable
requirements.
If
these parameter operating
envelopes are
not clearly defined and
supported
by development data, the PEMS
operation will be limited to the range of
parameter inputs encountered during the
certification test until the
PEMS has a new
operating envelope established.
6.1.3
Source-Specific Operating
Conditions. Identify any source-specific
operating conditions, such as fuel type, that
affect the output
of your PEMS. You may
only usc the
PEMS under the source-specific
operating conditions
it
was certified for.
And
if. ..
No other regulation sets an upper limit for the
data recorder's range.
Another regulation sets an upper
limit for the
data recorder's range.
have failed. You must obtain prior approval
before using reconciled data.
6.1.9 Parameter Envelope Exceedances.
Your
PEMS must include a plan to detect and
notify the operator of parameter envelope
exceedances. Emission data collected
outside
the ranges of the sensor envelopes will not
be considered quality assured.
6.2 Recordkeeping. All valid data
recorded by the
PEMS must be used to
calculate the emission value.
7.0 Reagents and Standards [ReSOlVed]
8.0 Sample Collection, Preservation,
Storage. and Transport
8.1 Initial Certification. Use the following
procedure to certify your
PEMS. Complete all
PEMS training before the certification begins.
8.2 Relative Accuracy Test.
8.2.1 Reference Methods. Unless
otherwise specified
in the applicable
regulations, you
must use the test methods in
Appendix A of this part for the RM test.
Conduct
the RM tests at three operating
levels of the key
parameter that most affects
6.1.4 Ambient Conditions.
You must
explain whether and how ambient conditions
and seasonal changes affect your
PEMS.
Some
parameters such as absolute ambient
hUmidity cannot be manipulated during a
test. The effect
of ambient conditions such as
humidity on the pollutant concentration
must
be
detennined and this effect
extrapolated to include future anticipated
conditions. Seasonal changes
and their
effects on the
PEMS must be evaluated unless
you can
show that such effects are negligible.
6.1.5
PEMS Principle of Operation.
If
your PEMS is developed on the basis of
known physical principles, you
must identify
the specific physical assumptions or
mathematical manipulations that support its
operation.
If
your PEMS is developed on the
basis
of linear or nonlinear regression
analysis, you must make available the paired
data (preferably
in graphic form] used to
develop
or train the model.
6.1.6 Data Recorder
Scale.
If
you are not
using a digital recorder, you must choose a
recorder scale that accurately captures the
desired range of potential emissions. The
lower limit of your data recorder's range
must be no eater than 20 percent of the
applicable emission standard
(if subject to an
emission standard). The upper limit of your
data recorder'S range must be determined
using the following table.
If
you obtain
approval first, you may use other lower and
upper recorder limits.
Then your upper limit.
Must be 1.25 to 2 times the
average
potential
emission
level
Must follow the other regulatlon
Must be 1.5 to
2.0 times concentration of the
emission standard that applies to your
emission
unit
Must be 1.1 to 1.5 times the concentration of
the emission standard that applies to your
emission unit
emissions
(e.g ..
load level). Conduct the
specified number of
RM tests at the low
(minimum to
50 percent of maximum), mid
(an intermediary level between the low
and
bigb levels), and high (80 percent to
maximum) key parameter opemting levels, as
practicable.
If
these levels are not practicahle,
vary the key parameter range as
much as
possible over three levels.
8.2.2 Number of
RM Tests for Excess
Emission
PEMS. For PEMS used for excess
emission reporting, conduct at least the
folJowing number of
RM tests at the
following key parameter operating levels:
(1) Three at a low level.
(2) Three at a mid level.
(3) Three at a high level.
You may choose to perform more than
nine
total RM tests.
If
you perform more than nine
tests, you may reject a maximwn of three
tests as long as the total number of test
results used to determine tho
RA is nine or
greater and each operating level has at least
three tests. You must report all data,
including the rejected data.
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* * * * * * PC # 17 * * * * * *
Federal Register/Vol. 74, No. 56/Wednesday, March 25, 2009/Ru\es end Regulations
12587
8.2.3 Number of RM Tests for Continual
Compliance
PEMS.
For PEMS used to
detennine compliance, conduct at least the
following
number of RM tests at the
following key parameter operating levels:
(1) Nine at a low level.
(2) Nine at a mid level.
(3) Nine at a high level.
You
may choose to perform more than 9
RM runs at each operating level.
If
you
perform more than 9 runs, you may reject a
maximum
of three runs per level as long as
the total
number of runs used to determine
the RA at each operating level is 9 or greater.
8.2.4 Reference Method Measurement
Location. Select an accessible measurement
point for the RM that will ensure you
measure emissions representatively. Ensure
the location is at least two equivalent stack
diameters downstream and half an equivalent
diameter upstream from the nearest flow
disturbance
such as the control device, point
of pollutant generation, or other place where
the pollutant concentration
or emission rate
can change. You may
use a half diameter
downstream instead
of the two diameters
if
you meet both of the following conditions:
{1J Changes in the pollutant concentration
are caused solely by diluent leakage, such as
leaks from air heaters.
(2) You measure pollutants and diluents
Simultaneously at
the same locations.
If ...
8.2.5 Traverse Points. Select traverse
points that
ensure representative samples.
Conduct all
RM tests within 3 em of each
selected traverse
point but no closer than 3
em to the stack or duct walL The minimum
requirement for traverse points are as
follows:
(1) Establish a measurement line across the
stack that passes through the center and
in
the direction of any expected stratification.
(2) Locate a minimum of three traverse
points on the line at 16.7,50.0, and 83.3
percent
of the stack inside diameter.
(3) Alternatively, if the stack inside
diameter is greater than 2.4 meters, you may
locate
the three traverse points on the Hne at
0.4,1.2,
and 2.0 meters from the stack or duct
wall. You may not use this alternative option
after wet scrubbers
or at points where two
streams with different pollutant
concentrations are combined. You
may select
different traverse points
if you demonstrate
and prOvide verification that it provides a
representative sample.
You may also use tho
traverse point speCifications given the RM.
8.2.6 Relative Accuracy Procedure.
Perform the number of RA tests at the levels
required
in Sections 8.2.2 and 8.2.3. For
integrated samples
(e.g .•
Method 3A or 7E),
make a sample traverse of at least 21 minutes,
sampling for 7 minutos at each traverse point.
For grab samples
(e.g.,
Method 3 or 7), take
Then ...
The AM has an instrumental or integrated non- Directly compare AM and PEMS results.
instrumental
sampling technique.
The AM has a grab
sampling technique ..... ...... Average the results from all grab samples
taken during the lest run. The test run must
include ::::3 separate grab measurements.
Use the paired PEMS and RM data and the
equations
in
Section 12.2 to calculate the RA
in the units oftha applicable emission
standard. For this 3-level
RA test, calculate
the
RA at each operation level.
8.3 Statistical Tests for
PEMS that are
Used for Continual Compliance.
In
addition
to the
RA determination. evaluate the paired
RA and PEMS data using the following
statistical tests.
8.3.1 Bias Test. From the
RA data taken
at the mid-level, determine if a bias exists
between the
RM Wld PEMS. Use the
equations
in Section ]2.3.1.
8.3.2 F-test.
Perfonn a separate F-test for
the
RA paired data from each operating level
to determine
if the RM and PEMS variances
differ by more than might be expected from
chance. Use
the equations in Section 12.3.2.
8.3.3 Correlation Analysis. Perform a
correlation analysis using
the RA paired data
from all operating levels combined to
determine
how well the RM and PEMS
correlate. Use the equations in Section 12.3.3.
The correlation is waived
if
the process
cannot be varied to produce a concentration
change sufficient for a successful correlation
Test
test because of its technical deSign. In such
cases, should a subsequent RATA identify a
variation in
the RM measured values by more
than
30 percent, the waiver will not apply,
and a correlation analysis test must be
perfonDed at the next RATA.
8.4 Reporting. Summarize in tabular form
the results
of the RA and statistical tests.
Include all data sheets, calculations,
and
charts (records of PEMS responses) necessary
to verify that your
PEMS meets the
performance speCifications. Inc1ude in the
report the documentation used to establish
your
PEMS parameter envelopes.
a.5 Reevaluating Your PEMS After a
Failed Test, Change
in Operations, or Change
in Critical
PEMS Parameter. After initial
certification,
if
your PEMS fails to pass a
quarterly RAA or yearly RATA,
or
if
changes
occur or are
made that could result in a
significant change
in
the emission rate
(e.g.,
turbine aging, process modification, new
process operating modes, or changes to
emission controls), your
PEMS must be
recertified using the
tests and procodures in
Section 8.1. For example,
if you initially
developed your
PEMS for the emissions unit
ONGOING QUALITY ASSURANCE TESTS
PEMS regulatory purpose
Sensor Evaluation ........ ...................... ..... All ........................................................... .
one sample at each traverse point, scheduling
the grab samples so that they are taken
simultaneously (within
a 3-minute period) or
at an equal interval of time apart over a 21-
minute period. A test run for grab samples
must be made up of at least three separate
measurements. Where multiple fuels arc
used
in the monitored unit and the fuel type
affects
the predicted emissions, determine a
RA for each fuel unless the effects of the
alternative fuel
on predicted emissions or
diluent were addressed in the model training
process.
The unit may only use fuels that
have been evaluated this way.
8.2.7 Correlation
ofRM and PEMS Data.
Mark the beginning
and end of each RM test
run (including the exact time of day) on the
permanent record of
PEMS output. Correlate
the
PEMS and the RM test data by the time
and duration using
the following steps:
A. Detennine the integrated pollutant
concentration for
the PEMS for each
corresponding
RM test period.
B. Consider system response time,
if
important, and confirm that the pair of
results is
on a consistent moisture,
temperature, and
diluent concentration basis.
c. Compare each average PEMS value to
the corresponding .average
RM value. Use the
following guidelines to make these
comparisons.
And then ...
Compare this average AM result with the
PEMS result obtained during the run.
operating at 80-100 percent of its range, you
would have perfonned the initial test under
these conditions. Later,
if
you wanted to
operate the emission unit at 50-100 percent
of its range, you must conduct another RA
test and statistical tests, as applicable, to
verify that the
new conditions of 50-100
percent of range are functionaL These tests
must demonstrate that your PEMS prOVides
acceptable data when operating in the new
range or with the new critical PEMS
parameter(s). The requirements of Section 8.1
must be completed by the earlier of 60 unit
operating days or 180 calendar days after the
failed RATA or after
the change that caused
a significant change
in
emission rate.
9.0
Quality
Control
You must incorporate a QA plan beyond
the initial PEMS certification test to verify
that your system
is generating quality-
assured data.
The QA plan must include the
components of this section.
9.1 QAlQC
Summary. Conduct the
applicable ongoing tests listed below.
Acceptability
Frequency
Daily
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* * * * * * PC # 17 * * * * * *
12588
Federal RegisterlVol. 74, No.
56/Wednesday,
March 25,
2009/Rules
and Regulations
ONGOING QUALITY ASSURANCE TESTS-Continued
Test
PEMS regulatory purpose
Acceptability
Frequency
RAA .......................................................... Compliance .............................................. 3-1e51 average :s;10% of simultaneous Each quarter
except
quarter
when
RATA per.
formed
PEMS
average.
RATA ........................................................ AIl ............................................................. Same as for RA in Sec. 13.1 ................. . Yearly in
quarter
when RAA
not per-
formed
Bias Correction ......................................... All ............................................................. If
days
~
lccl ............................................. . Bias test
passed (no
correction
factor
needed)
PEMS Training .........................................
All............................................................. If
Fo::ritical
~F
r
~O.6
.................................. ..
Optional after
initial and
subsequent
RATAs
Sensor Evaluation Alert Test (optional)... All ............................................................. See Section 6.1.8 ................................... .
After each
PEMS
training
9.2 Daily Sensor Evaluation Check. Your
sensor evaluation system must check the
integrity
of each PEMS input at least daily.
9.3 Quarterly Relative Accuracy Audits.
In the first year of operation after the initial
certification, perform a
RAA consisting of at
least three 30-minuto portable analyzer or
RM determinations each quarter a RAT A is
not performed. The average
of the 3 portable
analyzer or
RM determinations must not
differ from the simultaneous
PEMS average
value by more than
]0 percent of the analyzer
or
RM value or the test is failed.
If
a PEMS
passes all quarterly RAAs in the first year
and also passes the subsequent yearly RATA
in
the second year, you may elect to perform
a single mid-year
RAA in the second year
in
place of the quarterly RAAs. This option may
be repeated, but only until the
PEMS fails
either a
mid.year RAA or a yearly RATA.
When such a failure occurs, you must resume
quarterly
RAAs in the quarter follOwing the
failure and continue conducting quarterly
MAs
until the PEMS successfully passes
both a year of quarterly RAAs and a
subsequent
RATA.
9.4 Yearly Relative Accuracy Test Audit.
Perform a minimum 9-run
RATA at the
normal operating level
on a yearly basis
in
the quarter that the RAA is not performed.
10.0 Calibraaon and Standardization
[Reserved]
11.0 Analytical Procedure [Reserved]
12.0 Calculations and Data Analysis
12.1 Nomenclature
B
=
PEMS bias adjustment factor.
cc
=
Confidence coefficient.
d
l
=
Difference between each RM and PEMS
run.
d
=
Arithmetic mean of differences for all
runs.
ei
=
Individual measurement provided by the
PEMS or RM at a particular level.
em
=
Mean of the PEMS or RM measurements
at a particular level.
e
p
=
Individual measurement provided by the
PEMS.
e
v
=
Individual measurement provided by the
RM.
F
=
Calculated F-value.
n
=
Number ofRM runs.
PEMSi
=
Individual measurement provided
by the PEMS.
PEMSiAdjusted
=
Individual measurement
provided
by the PEMS adjusted for bias.
PEMS
=
Mean of the values provided by the
PEMS at the normal operating range during
the bias test.
r
=
Coefficient of correlation.
RA
=
Relative accuracy.
RAA
=
Relative accuracy audit.
RM
=
Average RM value (or in the case of the
RAA. the average portable analyzer value).
In cases where the average emissions for
the test
arc less than 50 percent of the
applicable standard, substitute the
emission standard value here
in place of
the average RM value.
Sd
=
Standard deviation of differences.
S2
=
Variance of your PEMS or RM.
10.025
=
t-value for a one-sided, 97.5 percent
confidence interval (see Table 16-1).
12.2 Relative Accuracy Calculations.
Calculate the mean of the
RM values.
Calculate the differences between the pairs
of
observations for the
RM:
and the PEMS
output sets. Finally, calculate the mean of the
differences. standard deviation, confidence
coefficient,
and PEMS RA, using Equations
]6-],16-2. ]6-3, and ]6-4, respectively. For
compliance
PEMS, calculate the RA at each
test level. The
PEMS must pass the RA
criterion at each test level.
12.2.] Arithmetic Mean.
Calculate the
arithmetic mean of the differences between
paired
RM and PEMS observations using
Equation 16-1.
d
=
IA
Eq. 16-1
n
1=1
12.2.2 Standard Deviation. Calculate the
standard deviation
of the differences using
Equation
]6-2 (positive square root).
Eq. 16-2
12.2.3 Confidence Coefficient. Calculate
the confidence coefficient using Equation
]6-
3 and Tablo 16-].
S,
ee
=
t
o
.
025
J;,
Eq.16-3
12.2.4 Relative Accuracy. Calculate the
RA of your data using Equation ]6-4.
RA=
Iill + Iccl
xIOO
RM
Eq. 16-4
12.3 Compliance PEMS Statistical Tests.
If
your PEMS will be used for continual
compliance purposes. conduct the following
tests using the information obtained during
the
RA tests. For the pollutant measurements
at
anyone test level, if the mean value of the
RM is less than either 10 ppm or 5 percent
of the emission standard, all statistical tests
are waived at that specific test level. For
diluent measurements at
anyone test level,
if the mean value of the RM is less than 3
percent
of span, all statistical tests are
waived for that specific test level.
]2.3.] Bias Test. Conduct a bias test to
determine
if your PEMS is biased relative to
the
RM. Determine the PEMS bias by
comparing the confidence coefficient
obtained from Equation
]6-3 to the
Electronic Filing - Received, Clerk's Office, July 6, 2009
* * * * * * PC # 17 * * * * * *
Federal Register
IVaI.
74, No. 56/Wednesday, March 25, 2009/Rules and Regulations
12589
arithmetic mean of the differences
detennined
in
Equation 16-1.lfthe
arithmetic mean of the differences
(a)
is
greater
than the absolute value of the
confidence coefficient (cc), your PEMS must
incorporate a bias factor to adjust future
PEMS values as
in
Equation 16-5.
PEMSiAdj~,,,,
=
PEMS,
X
B
Where:
Eq. 16-5
B=l+
Illl
PEMS
Eq. 16-6.
12.3.2 F-test. Conduct an F-test for each
oftha three
RA
data sets collected at different
test levels. Calculate the variances of the
PEMS and the RM using Equation 16-6.
r
12.4 Relative Accuracy Audit. Calculate
the quarterly RAA using Equation 16-4.
13.0 Method Performance
13.1 PEMS Relative Accuracy. The RA
must not exceed 10 percent
if
the PEMS
measurements are greater than 100 ppm or
0.2 Ibs/mrn Btu. The RA must not exceed 20
percent if the PEMS measurements 8I'e
between 100 ppm (or 0.2 Ib/nun Btu) and 10
ppm (or 0.05 Ib/mm Btu). For measurements
below
10 ppm, the absolute mean difference
between
the PEMS measurements and the
RM measurements must not exceed 2 pppm.
For
diluent PEMS, an alternative criterion of
±
1 percent absolute difference between the
PEMS and RM may be used
if
less stringent.
L(e,
"
-e.)
,
S'
.!'"=',----
n-I
Eg. 16-6
Determine if the variance of the PEMS data
is significantly different from
that of the RM
data at each level by calculating the F.value
using Equation 16-7.
F
S'
PEMS
S'RM
Eq.16-7
Compare the calculated F-value with the
critical value
of F at the 95 percent
confidence level with
n-1 degrees of
freedom.
The critical value is obtained from
Table
16-2 or a simil8l' table for F.
distribution.
If
the calculated F-value is
greater than the critical value at any level,
your proposed PEMS 1s unacceptable. For
Lepev-(LepHLev)/ n
pollutant PEMS measurements, if the
standard deviation of the RM is less than
either 3 percent of the span or 5 ppm, usc
aRM standBJ'd deviation of either 5 ppm or
3 percent of span. For diluent
PEMS
measurements, if the standard deviation of
the reference method is less than 3 percent
of span, use a RM stand8l'd deviation of 3
percent of span.
12.3.3 Correlation Analysis. Calculate
the
correlation coefficient either manually using
Eq.
16-8, on a graph, or by computer using
all of the paired data points from all
operating levels. Your
PEMS correlation must
be
O.B
or greater to be acceptable.
If
during
the initial certification test, your
PEMS data
are determined to be
auto.correlated
according to the procedures in 40 CFR
75.41(b)(2), or
if
the signal.to.noise ratio of
the data is less than 4, then the correlation
analysis is permanently waived.
Eg. 16-8
RAA= PEMS-RM
X
100
RM
Eq. 16-9
13.2 PEMS Bias. Your PEMS data is
considered biased and must be adjusted if the
arithmetic mean
(d) is greater than the
absolute value of the confidence coefficient
(cc)
in
Equations 16.1 and 16.3. In such
cases, a bias factor
must be used to correct
your
PEMS data.
13.3
PEMS Variance. Your calculated F.
value must not be greater than the critical F.
value at the 95-percent confidence level for .
your
PEMS to be acceptable.
13.4
PEMS Correlation. Your calculated r-
value must be greater than or equal to 0.8 for
your PEMS to be acceptable.
13.5 Relative Accuracy Audits. The
average of the 3 portable analyzer or RM
determinations must not differ from the
simultaneous
PEMS average value by more
than
10 percent of the analyzer or RM value.
14.0 Pollution Prevention {Reserved]
15.070 Waste Management {Reserved/
16.0 References (Reserved]
17.0 Tables, Diagmms, Flowcharts, and
Validation Data
TABLE 16-1-T-VALUES FOR ONE-SIDED, 97.5 PERCENT CONFIDENCE INTERVALS FOR SELECTED SAMPLE SIZES'
0-1
10.""
0-1
10.""
2 ................................................................................................................................................. .
12.706
16
2.131
3 ................................................................................................................................................... .
4.303
17
2.120
4 ...•...................•...................................................................•.•.................••.........•...........•...........
3.182
18
2.110
5 ................................................................................................................................................. .
2.776
19
2.101
6 .................................................................................................................................................. .
2.571
20
2.093
7 .................................................................................................................................................. .
2.447
21
2.096
8 .................................................................................................................................................. .
2.365
22
2.080
9 ................................................................................................................................................. .
2.306
23
2.074
10 ................................................................................................................................................ .
2.262
24
2.069
11 .............................................................................................................................................. .
2.228
25
2.064
12 ................................................................................................................................................ .
2.201
26
2.080
13 ............................................................................................................................................... .
2.179
27
2.056
14 ............................................................................................................................................... .
2.160
28
2.052
15 ................................................................................................................................... .
2.145
>
29
t-Table
* Use n equal to the number of data points (n-1 equals the degrees of freedom).
Electronic Filing - Received, Clerk's Office, July 6, 2009
* * * * * * PC # 17 * * * * * *
12590
Federal Register
I
Vol. 74, No. 56/Wednesday, March 25,
2009/Rules
and Regulations
TABLE 16-2. F-VALUES FOR CRITICAL VALUE OF F AT THE 95 PERCENT CONFIDENCE LEVEL
d.f. for
S'nM
1
2
3
1 ...............
161
199
215
.4
.5
2 ...............
18
19
51
00
3 ...............
10
9.5
13
52
4 ...............
7.7
6.9
09
44
5 ...............
6.6
5.7
08
86
6 ...............
5.9
5.1
87
43
7 ...............
5.5
4.7
91
34
8 ...............
5.3
4.4
18
59
9 ...............
5.1
4.2
17
57
10 .............
4.9
4.1
65
03
11 .............
4.8
3.9
44
82
12 .............
4.7
3.8
47
85
.5.
In
Procedure 1 of Appendix F,
paragraph (3) of Section 5.1.2 and
Section 8 is revised as follows:
.7
19
16
9.2
77
6.5
91
5.4
10
4.7
57
4.3
47
4.0
66
3.8
63
3.7
09
3.5
87
3.4
90
Appendix F to Part 60-Quality Assurance
Procedures
Procedure 1. Quality Assurance
Requirements for Cns Continuous Emission
Monitoring Systems Used for Compliance
Determination
•
•
•
•
•
...
5.1,2
(3)
U.se
Cylinder
Certified
Gas
Reference
Audit
(eGA).
Materials
(eRM's)
(See
Citation 1) audit
gases
that
have
been certified by comparison to National
Institute
of Standards and Technology (NIST)
or EPA Traceability Protocol Materials
(ETPM's)
following the most recent edition of
EPA's Traceability Protocol No.1 (See
Citation Z). Procedures for preparation of
CRM's are described in Citation
1.
Procedures for preparation of ETPM's are
described
in Citation 2. As an altemati ve to
CRM's or ETPM gases, Method 205 (See
Citation 3) may be used. 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.
•
•
•
•
•
8. Bibliography
1. "A Procedure for Establishing
Traceability
of Gas Mixtures to Certain
d.f. for SlpF.MS
4
5
6
7
8
9
10
11
12
224
230
234
236
238
240
241
243
243
.6
.2
.0
.8
19
19
19
19
25
30
33
35
9.1
9.0
8.9
8.8
17
14
41
87
6.3
6.2
6.1
6.0
88
56
63
94
5.1
5.0
4.9
4.8
92
50
50
76
4.5
4.3
4.2
4.2
34
87
84
07
4.1
3.9
3.8
3.7
20
71
66
87
3.8
3.6
3.5
3.5
38
88
81
01
3.6
3.4
3.3
3.2
33
82
74
93
3.4
3.3
3.2
3.1
78
26
17
36
3.3
3.2
3.0
3.0
57
04
95
12
3.2
3.1
2.9
2.9
59
06
96
13
National Bureau of Standards Standard
Reference Materials." Joint publication by
NBS and EPA-600/7-81-010, Revised 1989.
Available from
the U.S. Environmental
Protection Agency. Quality Assurance
Division (MD-77). Research Triangle Park,
NC 27711.
2. "EPA Traceability Protocol For Assay
And Certification Of Gaseous Calibration
Standards."
EPA-600!R-97/121,
September
1997. Available from
EPA's Emission
Measurement Center at
http://www.epa.gov/
ttn/eme.
3. Method 205, "Verification
of Gas
Dilution Systems for Field Instrument
Calibrations,"
40 ern 51, Appendix M.
•
•
•
•
•
.6.
In
Procedure 2 of Appendix F,
Section 10.1, paragraph (3) of Section
10.4,
and paragraph (2) of Section 12.0
are revised as follows:
Procedure 2-Quality Assurance
Requirements
for Particulate Matter
Continuous Emission Monitoring
Systems at Stationary Sources
•
•
•
•
•
10.1 When should I use paired trains
for .reference method testing? Although
not required,
we recommend that you
should use paired-train reference
method testing to generate data used to
develop your PM GEMS correlation and
for RCA testing. Guidance on the use of
.9
.5
.8
.0
.9
19
19
19
19
19
37
38
50
40
41
8.8
8.8
8.7
8.7
8.7
45
12
86
63
45
6.0
5.9
5.9
5.9
5.9
41
99
64
35
12
4.8
4.7
4.7
4.7
4.6
18
73
35
03
78
4.1
4.0
4.0
4.0
4.0
47
99
60
27
00
3.7
3.6
3.6
3.6
3.5
26
77
37
03
75
3.4
3.3
3.3
3.3
3.2
38
88
47
12
84
3.2
3.1
3.1
3.1
3.0
30
97
37
02
73
3.0
3.0
2.9
2.9
2.9
72
20
78
42
13
2.9
2.8
2.8
2.8
2.7
48
96
54
17
88
2.8
2.7
2.7
2.7
2.6
49
96
53
17
87
paired sampling trains can be found in
the PM GEMS Knowledge Document
(see section 16.5 of
PS-11).
•
•
•
•
•
10.4 What are my limits for
excessive audit inaccuracy?
•
•
•
•
(3) What are the criteria for excessive
AGA error? Your PM GEMS is out of
control
if
the results of any ACA exceed
±
10 percent ofthe average audit value,
as calculated using Equation 2-1a, or
7.5 percent of the applicable standard,
as calculated using Equation 2-1b,
whichever is greater.
•
•
•
•
12.0 What calculations and data
analysis must I perfonn
for my PM
GEMS?
•
•
•
•
•
(2) How do I calculate AGA accuracy?
You must use either Equation 2-1a or 2-
Ib to calculate ACA accuracy for each
of the three audit points. However,
when calculating ACA accuracy for the
first audit point (0 to 20 percent of
measurement range), you must use
Equation 2-1 b to calculate AGA
accuracy if the reference standard value
(Rv) equals zero.
ACA Accuracy
=
IR
CEM
-R
V
I
xl 00%
Rv
Eq.2-1a
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1
Vol. 74, No. 56/Wednesday, March 25,
20091
Rules and Regulations
12591
Where:
Where:
ACA Accuracy; The ACA accuracy at
each audit point. in percent,
CCEM =
The PM concentration that
corresponds
to your PM CEMS
response to the reference standard,
as calculated using
the correlation
equation for
your PM CEMS,
CRY =
The PM concentration that
corresponds
to the reference
standard value in units consistent
with CCEM, and
C~
=
The PM concentration that
corresponds to the applicable
emission limit in units consistent
withC
CEM
.
•
•
•
•
•
Part 63-[Amendedl
• 7. The authority citation for Part 63
continues to read as follows:
Authority: 42 U.S.c. 7401
et seq.
.8. In Method 303 of Appendix A, add
a sentence to the end of Section 1.1 to
read as follows:
Appendix A to Part 63-Test Methods
Method 303-Detennination of Visible
Emissions From By-Product Coke Oven
Batteries
1.1 Applicability.
* * * In
order for the
test method results to be indicative of plant
performance.
the time of day of the run
should vary,
[FR Doc. E9-6275 Filed 3-24-09; 8:45 am]
Bil-UNG CODe
~
ENVIRONMENTAL PROTECTION
AGENCY
40 CFR Part 63
[EPA-R09-0AR-20ll~759;
FRL-8783-7]
Delegation of National Emission
Standards
for Hazardous Air Pollutants
for Source Categories; State of
California; Amador County Air
Pollution Control District, San Diego
County
Air Pollution Control District
AGENCY:
Environmental Protection
Agency (EPA).
AcnON:
Direct final rule.
SUMMARV:
EPA is amending certain
regulations to reflect the current
delegation status
of national emission
ACA Accuracy
=
The ACA accuracy at
each audit point,
in
percent.
ACA Accuracy
=
I
c
CEM
-c
RV
I
X I 00%
C
s
.
Eq.2-1b
standards for hazardous air pollutants in
California. Amador County Air
Pollution Control District and San Diego
County Air Pollution Control District
requested delegation of these federal
standards as they apply to non-major
sources.
Their delegation requests were
approved by letter on September 4,
2008. The purpose of this action is to
update the listing in the Code of Federal
Regulations,
EPA Region IX is also
waiving
the need for duplicate reporting
after a California district is delegated
these federal standards applicable to
non-major sources.
DATES:
This rule is effective on May
26.
2009 without fwther notice. unless EPA
receives relevant adverse comments by
April 24, 2009.
If
EPA receives such
comments, then it will publish a timely
withdrawal
in the Federal Register
informing the public that this rule will
not take effect.
ADDRESSES:
Submit comments,
identified by docket number EPA-R09-
OAR-2008--D759, by one of the
following methods:
1.
Federol eRulemaking Portal:
www.reguJations.gov,
Follow the on-line
instructions.
2. E-mail: steckeJ.andreW@epa.gov,
3. Mail or deliver:
Andrew Steckel
(Air-4), U.S. Environmental Protection
Agency Region IX, 75 Hawthorne Street,
San Francisco, CA 94105-3901.
Instructions:
All comments will be
included in the public docket without
change and may be made available
online at
www.regu/ations.gov,
including any personal information
provided. unless the comment includes
Confidential Business Information (CBI)
or other information whose disclosure is
restricted by statute. Information that
you consider
eBI
or othenNise protected
should be clearly identified as such and
should not be submitted through
www.regulations.govor
e-mail.
www,regulations.govis
an "anonymous
access" system, and EPA will not know
your identity or contact information
unless you provide
it in
the body of
your comment. If you send e-mail
directly to EPA, your e-mail address
will be automatically captured and
included as part of the public comment.
If
EPA cannot read your comment due
to technical difficulties and cannot
contact you for clarification, EPA may
R
CEM
; Your PM CEMS response to the
reference standard. and
Rv
=
The reference standard value.
not
be able to consider your comment.
Electronic files
should avoid the use of
special characters, any form of
encryption. and be free of any defects or
viruses.
Docket:
The index to the docket for
this action is available electronically at
www,regu]ations.govand
in hard copy
at EPA Region IX, 75 Hawthorne Street,
San Francisco, California. While all
documents in the docket are listed in
the index. some information may be
publicly available only
at the hard copy
location (e.g., copyrighted material), and
some may not be publicly available in
either location (e.g.,
CBI). To inspect the
hard copy materials. please schedule an
appointment during normal business
hours with the contact listed in the
FOR
FURTHER (NFORMA nON CONTACT
section.
FOR FURTHER INFORMATION CONTACT; Mae
Wang, EPA Region
IX, (415) 947-4124,
wang.mae@epa.gov.
SUPPLEMENTARY INFORMATION:
Throughout this document "we," "us,"
and "our" refer to EPA.
Table of Contents
I.
Background
A. Delegation of NESHAP
B.
California Delegations
C. Area Source Delegation Requests
II. EPA Action
A. Area Source Delegation Requests
B. Waiver of Duplicate Reporting
III.
Statutory and Executive Order Reviews
I.
Background
A. Delegation of NESHAP
Section 112(1) of the Clean Air Act, a.
amended in 1990 (CAA). authorizes
EPA to delegate to State or local air
pollution control agencies
tJ18
authority
to implement and enforce the standards
set out in Title 40 of the Code of Federal
Regulations (CFR), Part 63. National
Emission Standards for Hazardous Air
Pollutants for Source Categories
(NESHAP). On November 26,1993, EPA
promulgated regulations, codified at 40
CFR part 63, subpart E (hereinafter
referred to as "Subpart E"), establishing
procedures for EPA's approval of State
rules or programs
under CM 112(1)
(see
58 FR 62262). The procedures of
Subpart E were later amended on
September 14, 2000
(see
65 FR 55810).
Any request for approval under
eAA
section 112(1) must meet the approval
criteria in 112(1)(5) and Subpart E. To
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* * * * * * PC # 17 * * * * * *
STATE OF ILLINOIS
COUNTY OF SANGAMON
)
)
)
)
SS
CERTIFICATE OF SERVICE
I, the undersigned, an attorney, state that I have served electronically the attached
FIRST-NOTICE COMMENTS OF THE ILLINOIS ENVIRONMENTAL
PROTECTION AGENCY, upon the following person:
John Therriault
Assistant
Clerk
Illinois Pollution Control Board
James R. Thompson Center
100 West Randolph
St., Suite 11-500
Chicago, IL 60601
and electronically to the following persons:
SEE ATTACHED SERVICE LIST
Dated: July 6, 2009
1021 North Grand Avenue East
Springfield, Illinois 62794-9276
(217) 782-5544
ILLINOIS ENVIRONMENTAL
PROTECTION AGENCY,
Gina
~~
Roccaforte
Assistant Counsel
Division
of Legal Counsel
Electronic Filing - Received, Clerk's Office, July 6, 2009
* * * * * * PC # 17 * * * * * *
SERVICE LIST 08-19
Timothy J. Fox
Hearing Officer
Illinois Pollution Control Board
100 W. Randolph St., Suite 11-500
Chicago, IL 6060 I
foxt@ipcb.state.il.us
Virginia Yang
Deputy Legal Counsel
Illinois Department
of Natural Resources
One Natural Resources Way
Springfield, IL 62702-1271
virginia.yang@illinois.gov
Katherine D. Hodge
Monica T. Rios
Hodge Dwyer
&
Driver
3150 Roland Ave.
P.O. Box 5776
Springfield,
IL 62705-5776
khodge@hddattorneys.com
mrios@hddattorneys.com
Christina
L.
Archer
Associate General Counsel
ArcelorMittal
USA, Inc.
I
South Dearborn Street, 19
th
Floor
Chicago,
IL 60603
christina.archer@arcelormittal.com
Gerald T. Karr
Senior Assistant Attorney General
Environmental Bureau
Office
of the Attorney General
69 W. Washington
St., Suite 1800
Chicago,
IL 60602
gkarr@atg.state.il.us
Kathleen
C. Bassi
Stephen
J. Bonebrake
Schiff Hardin LLP
6600 Sears Tower
233
S. Wacker Drive
Chicago, IL 60606-6473
kbassi@schiffhardin.com
sbonebrake@schiffhardin.com
Alec M. Davis
General Counsel
Illinois Environmental Regulatory Group
215 E. Adams
St.
Springfield, IL 62701
adavis@ierg.org
Electronic Filing - Received, Clerk's Office, July 6, 2009
* * * * * * PC # 17 * * * * * *