[Federal Register Volume 80, Number 13 (Wednesday, January 21, 2015)]
[Proposed Rules]
[Pages 2871-2885]
From the Federal Register Online via the Government Publishing Office [www.gpo.gov]
[FR Doc No: 2014-30388]
-----------------------------------------------------------------------
ENVIRONMENTAL PROTECTION AGENCY
40 CFR Part 63
[EPA-HQ-OAR-2006-0790; FRL-9919-36-OAR]
RIN 2060-AS10
National Emission Standards for Hazardous Air Pollutants for Area
Sources: Industrial, Commercial, and Institutional Boilers
AGENCY: Environmental Protection Agency.
ACTION: Proposed rule; request for public comment.
-----------------------------------------------------------------------
SUMMARY: On February 1, 2013, the Environmental Protection Agency (EPA)
finalized amendments to the National Emission Standards for Hazardous
Air Pollutants for Area Sources: Industrial, Commercial, and
Institutional Boilers (Area Source Boilers Rule). Subsequently, the EPA
received three petitions for reconsideration of the final rule. The EPA
is announcing reconsideration of and requesting public comment on five
issues raised in the petitions for reconsideration, as detailed in the
SUPPLEMENTARY INFORMATION section of this document.
In this action, the EPA is also proposing a limited number of
technical corrections and amendments to the final rule to correct
inadvertent errors and to clarify some applicability and implementation
issues raised by stakeholders subject to the final rule. Also, we
propose to delete rule provisions for an affirmative defense for
malfunction in light of a recent court decision on the issue.
The EPA is seeking comment only on the five issues being
reconsidered, the proposed deletion of the affirmative defense and on
the technical corrections and amendments described in the preceding
paragraph. The EPA will not respond to any comments addressing any
other issues or any other provisions of the final rule.
DATES: Comments. Comments must be received on or before March 9, 2015,
or 30 days after date of public hearing, if later.
Public Hearing. If anyone contacts us requesting to speak at a
public hearing by January 26, 2015, a public hearing will be held on
February 5, 2015. If you are interested in attending the public
hearing, contact Ms. Pamela Garrett at (919) 541-7966 to verify that a
hearing will be held.
ADDRESSES: Submit your comments, identified by Docket ID No. EPA-HQ-
OAR-2006-0790, by one of the following methods:
www.regulations.gov: Follow the on-line instructions for
submitting comments.
Email: [email protected].
Fax: (202) 566-1741.
Mail: Environmental Protection Agency, EPA Docket Center
(EPA/DC), Mail code: 28221T, Attention Docket ID No. EPA-HQ-OAR-2006-
0790, 1200 Pennsylvania Ave. NW., Washington, DC 20460. The EPA
requests a separate copy also be sent to the contact person identified
below (see FOR FURTHER INFORMATION CONTACT).
Hand/Courier Delivery: EPA Docket Center (EPA/DC), Room
3334, EPA WJC West Building, 1301 Constitution Avenue NW., Washington,
DC 20004. Such deliveries are only accepted during the Docket's normal
hours of operation, and special arrangements should be made for
deliveries of boxed information.
Instructions: Direct your comments to Docket ID No. EPA-HQ-OAR-
2006-0790. The EPA's policy is that all comments received will be
included in the public docket without change and may be made available
on-line at www.regulations.gov, including any personal information
provided, unless the comment includes information claimed to be
Confidential Business Information (CBI) or other information whose
disclosure is restricted by statute. Do not submit information that you
consider to be CBI or otherwise protected through www.regulations.gov
or email. The www.regulations.gov Web site is an ``anonymous access''
system, which means the EPA will not know your identity or contact
information unless you provide it in the body of your comment. If you
send an email comment directly to the EPA without going through
www.regulations.gov, your email address will be automatically captured
and included as part of the comment that is placed in the public docket
and made available on the Internet. If you submit an electronic
comment, the EPA recommends that you include your name and other
contact information in the body of your comment and with any disk or
CD-ROM you submit. If the EPA cannot read your comment due to technical
difficulties and cannot contact you for clarification, the EPA may 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.
Public Hearing: If anyone contacts the EPA requesting a public
hearing by January 26, 2015, the public hearing will be held on
February 5, 2015 at the
[[Page 2872]]
EPA's campus at 109 T.W. Alexander Drive, Research Triangle Park, North
Carolina. The hearing will begin at 10:00 a.m. (Eastern Standard Time)
and conclude at 5:00 p.m. (Eastern Standard Time). There will be a
lunch break from 12:00 p.m. to 1:00 p.m. Please contact Ms. Pamela
Garrett at (919) 541-7966 or at [email protected] to register to
speak at the hearing or to inquire as to whether or not a hearing will
be held. The last day to pre-register in advance to speak at the
hearing will be February 2, 2015. Additionally, requests to speak will
be taken the day of the hearing at the hearing registration desk,
although preferences on speaking times may not be able to be fulfilled.
If you require the service of a translator or special accommodations
such as audio description, please let us know at the time of
registration. If you require an accommodation we ask that you pre-
register for the hearing, as we may not be able to arrange such
accommodations without advance notice. The hearing will provide
interested parties the opportunity to present data, views or arguments
concerning the proposed action. The EPA will make every effort to
accommodate all speakers who arrive and register. Because the hearing
is being held at a U.S. government facility, individuals planning to
attend the hearing should be prepared to show valid picture
identification to the security staff in order to gain access to the
meeting room. Please note that the REAL ID Act, passed by Congress in
2005, established new requirements for entering federal facilities. If
your driver's license is issued by Alaska, American Samoa, Arizona,
Kentucky, Louisiana, Maine, Massachusetts, Minnesota, Montana, New
York, Oklahoma, or the state of Washington, you must present an
additional form of identification to enter the federal building.
Acceptable alternative forms of identification include: Federal
employee badges, passports, enhanced driver's licenses and military
identification cards. In addition, you will need to obtain a property
pass for any personal belongings you bring with you. Upon leaving the
building, you will be required to return this property pass to the
security desk. No large signs will be allowed in the building, cameras
may only be used outside of the building and demonstrations will not be
allowed on federal property for security reasons. The EPA may ask
clarifying questions during the oral presentations, but will not
respond to the presentations at that time. Written statements and
supporting information submitted during the comment period will be
considered with the same weight as oral comments and supporting
information presented at the public hearing.
Docket: All documents in the docket are listed in the
www.regulations.gov index. Although listed in the index, some
information is not publicly available, e.g., CBI or other information
whose disclosure is restricted by statute. Certain other material, such
as copyrighted material, will be publicly available only in hard copy.
Publicly available docket materials are available either electronically
in www.regulations.gov or in hard copy at the EPA Docket Center (EPA/
DC), Room 3334, EPA WJC West Building, 1301 Constitution Ave. NW.,
Washington, DC. 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, and the telephone
number for the Air Docket is (202) 566-1742.
FOR FURTHER INFORMATION CONTACT: Ms. Mary Johnson, Energy Strategies
Group, Sector Policies and Programs Division (D243-01), Environmental
Protection Agency, Research Triangle Park, North Carolina 27711;
telephone number: (919) 541-5025; facsimile number: (919) 541-5450;
email address: [email protected].
SUPPLEMENTARY INFORMATION: Organization of this Document. The following
outline is provided to aid in locating information in the preamble.
I. General Information
A. What is the source of authority for the reconsideration
action?
B. What entities are potentially affected by the reconsideration
action?
C. What should I consider as I prepare my comments for the EPA?
II. Background
III. Discussion of the Issues under Reconsideration
A. Definitions of Startup and Shutdown
B. Alternative Particulate Matter Standard for New Oil-fired
Boilers that Combust Low-sulfur Oil
C. Establishment of a Subcategory and Separate Requirements for
Limited-use Boilers
D. Establishment of a Provision that Eliminates Further
Performance Testing for Particulate Matter for Certain Boilers Based
on their Initial Compliance Test
E. Establishment of a Provision that Eliminates Further Fuel
Sampling for Mercury for Certain Coal-fired Boilers Based on their
Initial Compliance Demonstration
IV. Technical Corrections and Clarifications
V. Affirmative Defense
VI. Solicitation of Public Comment and Participation
VII. Statutory and Executive Order Reviews
A. Executive Order 12866: Regulatory Planning and Review and
Executive Order 13563: Improving Regulation and Regulatory Review
B. Paperwork Reduction Act (PRA)
C. Regulatory Flexibility Act (RFA)
D. Unfunded Mandates Reform Act (UMRA)
E. Executive Order 13132: Federalism
F. Executive Order 13175: Consultation and Coordination with
Indian Tribal Governments
G. Executive Order 13045: Protection of Children from
Environmental Health Risks and Safety Risks
H. Executive Order 13211: Actions Concerning Regulations that
Significantly Affect Energy Supply, Distribution, or Use
I. National Technology Transfer and Advancement Act (NTTAA)
J. Executive Order 12898: Federal Actions to Address
Environmental Justice in Minority Populations and Low-Income
Populations
A red-line version of the regulatory language that incorporates
the proposed changes in this action is available in the docket for
this action (Docket ID No. EPA-HQ-OAR-2006-0790).
I. General Information
A. What is the source of authority for the reconsideration action?
The statutory authority for this action is provided by sections 112
and 307(d)(7)(B) of the Clean Air Act (CAA) as amended (42 U.S.C. 7412
and 7607(d)(7)(B)).
B. What entities are potentially affected by the reconsideration
action?
Categories and entities potentially regulated by this action
include:
------------------------------------------------------------------------
Examples of regulated
Industry category NAICS code \a\ entities
------------------------------------------------------------------------
Any area source facility using 321 Wood product
a boiler as defined in the 11 manufacturing.
final rule. Agriculture,
greenhouses.
311 Food manufacturing.
327 Nonmetallic mineral
product manufacturing.
424 Wholesale trade,
nondurable goods.
531 Real estate.
[[Page 2873]]
611 Educational services.
813 Religious, civic,
professional, and
similar organizations.
92 Public administration.
722 Food services and
drinking places.
62 Health care and social
assistance.
22111 Electric power
generation.
------------------------------------------------------------------------
\a\ North American Industry Classification System.
This table is not intended to be exhaustive, but rather provides a
guide for readers regarding entities likely to be affected by this
action. To determine whether your boiler is regulated by this action,
you should examine the applicability criteria in 40 CFR 63.11193 of
subpart JJJJJJ (National Emission Standards for Hazardous Air
Pollutants for Industrial, Commercial, and Institutional Boilers Area
Sources). If you have any questions regarding the applicability of this
action to a particular entity, consult either the air permitting
authority for the entity or your EPA regional representative, as listed
in 40 CFR 63.13 of subpart A (General Provisions).
C. What should I consider as I prepare my comments for the EPA?
Submitting CBI. Do not submit this information to the EPA through
regulations.gov or email. Clearly mark the part or all of the
information that you claim to be CBI. For CBI information in a disk or
CD ROM that you mail to the EPA, mark the outside of the disk or CD ROM
as CBI and then identify electronically within the disk or CD ROM the
specific information that is claimed as CBI. In addition to one
complete version of the comment that includes information claimed as
CBI, a copy of the comment that does not contain the information
claimed as CBI must be submitted for inclusion in the public docket.
Information so marked will not be disclosed except in accordance with
procedures set forth in 40 CFR part 2. Send or deliver information
identified as CBI to only the following address: Ms. Mary Johnson, c/o
OAQPS Document Control Officer (Room C404-02), U.S. EPA, Research
Triangle Park, NC 27711, Attention Docket ID No. EPA-HQ-OAR-2006-0790.
Docket. The docket number for this action is Docket ID No. EPA-HQ-
OAR-2006-0790.
World Wide Web (WWW). In addition to being available in the docket,
an electronic copy of this document will be posted on the WWW.
Following signature, the EPA will post a copy of this document at
http://www.epa.gov/airquality/combustion/actions.html and http://www.epa.gov/ttn/atw/boiler/boilerpg.html.
II. Background
The EPA finalized the Area Source Boilers Rule on March 21, 2011
(76 FR 15554). The EPA received eight petitions for reconsideration of
the March 2011 rulemaking. On December 23, 2011 (76 FR 80532), the EPA
granted the petitions for reconsideration on certain issues, and
proposed revisions to the March 2011 final rule in response to the
reconsideration petitions and to address four issues the EPA previously
identified in the March 21, 2011, action as warranting reconsideration.
On February 1, 2013, the EPA promulgated amendments to the Area
Source Boiler Rule (78 FR 7488). Following promulgation of the February
1, 2013, final Area Source Boiler Rule, the EPA received three
petitions for reconsideration pursuant to section 307(d)(7)(B) of the
CAA. The EPA received a petition dated April 1, 2013, from the American
Forest and Paper Association, on their behalf and on behalf of the
American Wood Council, National Association of Manufacturers, Biomass
Power Association, Corn Refiners Association, National Oilseed
Processors Association, Rubber Manufacturers Association, Southeastern
Lumber Manufacturers Association and U.S. Chamber of Commerce. The EPA
received a petition dated April 2, 2013, from the Council of Industrial
Boiler Owners and the American Chemistry Council. Finally, the EPA
received a petition dated April 2, 2013, from Earthjustice, on behalf
of the Sierra Club, Clean Air Council, Partnership for Policy
Integrity, Louisiana Environmental Action Network and Environmental
Integrity Project. The petitions are available for review in the
rulemaking docket (see document numbers EPA-HQ-OAR-2006-0790-2523, EPA-
HQ-OAR-2006-0790-2524 and EPA-HQ-OAR-2006-0790-2525). On August 5,
2013, the EPA issued letters to the petitioners granting
reconsideration on five specific issues raised in the petitions for
reconsideration and indicating that the agency would issue a Federal
Register notice regarding the reconsideration process. This action
requests comment on the five issues for which the EPA granted
reconsideration. Section III of this preamble summarizes these issues
and discusses our proposed responses to each issue.
We are also proposing a limited number of clarifying changes and
corrections to the final rule. These amendments would clarify some
applicability and implementation issues raised by stakeholders subject
to the final rule and correct inadvertent errors promulgated in the
final rule. Section IV of this preamble describes the clarifying
changes and corrections and provides the rationale for these
amendments. In addition, we are proposing to amend the final rule to
remove the affirmative defense provisions. Section V of this preamble
provides the rationale for the change.
III. Discussion of the Issues Under Reconsideration
The February 1, 2013, amendments, among other things, revised the
definitions of ``startup'' and ``shutdown.'' In addition, the
amendments established a subcategory and separate requirements for
certain boilers that operate on a limited basis. The amendments also
established an alternative particulate matter (PM) standard for new
oil-fired boilers that combust low-sulfur oil, and new monitoring
provisions that eliminate further stack testing for PM and further fuel
sampling for mercury (Hg) under certain circumstances based on initial
compliance demonstrations. The EPA received petitions for
reconsideration with respect to these specific components of the
amendments and granted reconsideration of the following five issues on
August 5, 2013, to provide an additional opportunity for public
comment:
The definitions of startup and shutdown periods;
Alternative particulate matter standard for new oil-fired
boilers that combust low-sulfur oil;
Establishment of a subcategory for limited-use boilers and
the applicable standards for that subcategory;
Provision that eliminates further performance testing for
particulate
[[Page 2874]]
matter for boilers whose initial compliance test shows that its
particulate matter emissions are equal to or less than half of the
particulate matter emission limit; and
Provision that eliminates fuel sampling at coal-fired
boilers that demonstrate compliance with the mercury emission limit by
fuel analysis based on the results of the boiler's initial compliance
demonstration.
The reconsideration petitions stated that the public lacked
sufficient opportunity to comment on these provisions. Although these
provisions were established after consideration of public comments
received on the proposed rule, the EPA has granted reconsideration on
these issues in order to allow an additional opportunity for comment.
These issues are discussed in more detail in the following sections.
With regard to the startup and shutdown provisions, the EPA is
proposing certain revisions to the definitions of startup and shutdown.
The proposed revision to the definition of startup is the addition of
an alternate definition of startup.
A. Definitions of Startup and Shutdown
The February 1, 2013, final rule revised the definitions of
``startup'' and ``shutdown,'' as proposed on December 23, 2011. In
December 2011, we proposed defining ``startup'' as the period between
the state of no combustion in the boiler to the period where the boiler
first achieves 25-percent load (i.e., a cold start) and ``shutdown'' as
the period that begins when a boiler last operates at 25-percent load
and ending with a state of no fuel combustion in the boiler. A number
of commenters indicated that the proposed load specifications (i.e.,
25-percent load) within the definitions of ``startup'' and ``shutdown''
were inconsistent with either safe or normal (proper) operation of the
various types of boilers encountered within the source category. As the
basis for defining periods of startup and shutdown, a number of
commenters suggested alternative load specifications based on the
specific considerations of their boilers; other commenters suggested
the achievement of various steady-state conditions.
We determined adjustments in the definitions of ``startup'' and
``shutdown'' to be appropriate and, as explained in the preamble to the
February 1, 2013, final rule, made adjustments that we believed
addressed the comments and were appropriate based on the fact that
industrial boilers function to provide steam or, in the case of
cogeneration units, electricity; therefore, industrial boilers should
be considered subject to applicable standards at all times steam of the
proper pressure, temperature, and flow rate is being supplied to a
common header system or energy user(s) for use as either process steam
or for the cogeneration of electricity. In the February 1, 2013, final
rule, startup and shutdown were defined based on the time during which
fuel is fired in a boiler for the purpose of supplying steam or heat
for heating and/or producing electricity or for any other purpose. We
defined startup as the period between either the first-ever firing of
fuel in the boiler or the firing of fuel in the boiler after a shutdown
and when the boiler first supplies steam or heat. We defined shutdown
as the period between either when none of the steam or heat from the
boiler is supplied or no fuel is being fired in the boiler, whichever
is earlier, and when there is no steam and no heat being supplied and
no fuel being fired in the boiler. The EPA received two petitions
asserting that the public lacked an opportunity to comment on the
amended startup and shutdown definitions.
We are soliciting comment on the definition of startup and shutdown
that were promulgated in the February 1, 2013, final rule, with the
clarifying revisions explained below. We are proposing to revise the
definitions of startup and shutdown in this reconsideration action as
set forth in 40 CFR 63.11237. Petitioners asserted that the final
rule's definitions of startup and shutdown were not sufficiently clear.
Although the EPA revised the definitions of startup and shutdown
included in the February 1, 2013, final rule, in response to comments,
we have granted reconsideration on this issue to provide an opportunity
for comment on those amended definitions, as well as the adjustments we
are now proposing to make to the definitions of startup and shutdown.
1. Startup and Shutdown Periods
Petitioners assert that the terms ``supplying'' and ``or for any
other purpose'' in both the startup and shutdown definitions are too
open-ended and could be read to mean that steam and heat supplied for
uses within the boiler itself will end the startup period or delay
onset of the shutdown period. Petitioners explain that many boilers use
steam to drive rotating equipment such as feedwater pumps, to preheat
feedwater and to operate de-aerators, and that some of these uses
(e.g., operating feedwater pumps and preheating feedwater) begin in the
early stages of starting a boiler and continue until the boiler is
cooled down. Petitioners assert that the terms ``supplying'' and ``or
for any other purpose'' in effect limit the use of energy during
startup and shutdown periods and inappropriately truncate these
periods. Petitioners state that efficient and cost-effective internal
uses of steam and heat for operating the boiler should not be
discouraged by definitions that necessarily limit the duration of the
startup and shutdown periods and that may require costly retrofits to
boilers with no commensurate environmental benefit.
2. Startup
In addition to soliciting public comment on the definition of
startup contained in the February 1, 2013, final rule, the EPA is
proposing to add an alternate definition to the definition of startup
that is in the February 1, 2013, final rule. We are proposing to allow
sources to use either definition of startup when complying with the
startup requirements. As explained in more detail below, under the
alternate definition, startup would end 4 hours after the unit begins
supplying useful thermal energy.
Specifically, the EPA is proposing the alternate definition to
clarify that, in terms of the first-ever firing of fuel, startup begins
when fuel is fired for the purpose of supplying useful thermal energy
(such as steam or hot water) for heating, cooling, or process purposes
or producing electricity and to clarify that startup ends 4 hours after
when the boiler makes useful thermal energy. The proposed clarification
regarding the end of startup would apply to first-ever startups as well
as startups occurring after shutdown events. With regard to when
startup begins after a shutdown event, the alternate definition is the
same as the definition in the February 1, 2013, final rule. That is,
startup begins with the firing of fuel in a boiler for any purpose
after a shutdown event.
In this alternate definition, we are proposing the clarification
regarding the first-ever firing of fuel to address implementation
issues regarding ``pre-startup'' activities that are done as part of
installing a new boiler. Under the February 1, 2013, definition of
``startup,'' a new boiler would be considered to have started up, and
subject to the rule, when it first fires fuel ``for any purpose.''
However, a newly installed unit needs to be tested to ensure that it
was properly installed and will operate as it was designed and that all
associated components were also properly installed and will operate as
designed. The EPA did not intend for the startup period to begin when a
[[Page 2875]]
newly installed unit first fires fuel for testing or other pre-startup
purposes because such firing of fuel does not represent normal
operation of the unit.
The EPA is also proposing in the alternate definition to replace
``steam and heat'' in the February 1, 2013, definition of startup with
``useful thermal energy.'' This proposed revision would apply to first-
ever startups as well as startups after shutdown events and is intended
to address the issue raised by petitioners that the language in the
February 1, 2013, definition regarding the end of the startup period is
ambiguous since once fuel is fired some steam or heat is generated, but
not in useful or controllable quantities. The petitioners comment that
it takes time for steam to be heated to adequate temperatures and
pressures for beneficial use and that steam or heat should not be
construed to be supplied until it is of adequate temperature and
pressure. The EPA agrees with petitioners that the startup period
should not end until such time as fuel is fired resulting in steam or
hot water that is useful thermal energy because it takes time for steam
to be heated to adequate temperatures and pressures for beneficial use
and we believe the appropriate criteria for ending startup in the
definition should be when useful steam is supplied. This proposed
change doesn't alter the EPA's determination that it is not technically
feasible to require stack testing--in particular, to complete the
multiple required test runs--during periods of startup and shutdown due
to physical limitations and the short duration of startup and shutdown
periods.
In order to clarify the term ``useful thermal energy,'' we are
proposing to define ``useful thermal energy'' as energy (i.e., steam or
hot water) that meets the minimum operating temperature and/or pressure
required by any energy use system that uses energy provided by the
affected boiler.
The EPA received two petitions for reconsideration of the
definition of startup in the February 1, 2013, final rule. Petitioners
assert that the amended definition of startup does not account for a
wide range of boilers that operationally are still in startup mode even
after some steam or heat is supplied to the plant. Petitioners assert
that some boilers begin to supply steam or heat for some purposes
onsite before they have achieved necessary temperature or load to
engage emission controls. Petitioners cite the example where a boiler
provides steam to a lumber kiln that is starting up. The boiler must
preheat the metal steam lines, which is necessary in cold climates
where a rush of steam can cause the metal to expand too quickly,
resulting in catastrophic damage. Petitioners point out that, according
to the final rule, a boiler supplying even a small amount of steam
would no longer be in startup and would be required at that point in
time to engage emission controls. Petitioners explain that, according
to equipment specifications and established safe boiler operations, a
source operator should not engage emission controls until specific
parameters are met.
Petitioners state that they previously urged the EPA to revise the
startup definition to allow facilities to determine the minimum stable
operating load on a unit-specific basis and include the minimum stable
operating load and the proper procedures to follow during startup and
shutdown in a site-specific plan. Petitioners assert that the amended
definition of startup still does not account for the broad range of
boiler and fuel types, operational methodologies and facility demands
placed on boilers. For this reason, petitioners continue to urge the
EPA to adopt a startup definition that allows sources to identify
startup periods on a site-specific and unit-specific basis. Petitioners
assert that only with this degree of flexibility will the rule account
for the multiple design and operational variables of the diverse boiler
population regulated in a way that allows safe and effective operation
with assurance of compliance with the standard.
Petitioners express that, above all, the boiler operator's primary
concern during startup is safety. The startup procedures must ensure
that the equipment is brought up to normal operating conditions in a
safe manner, and startup ends when the boiler and its controls are
fully functional. The end of startup occurs when safe, stable operating
conditions are reached, after emissions controls are properly
operating. The startup provisions should not include requirements that
could affect safe operating practices.
The EPA agrees with petitioners that the startup period should not
end until such time that all control devices have reached stable
conditions. The EPA has very limited information specifically for
industrial boilers on the hours needed for controls to reach stable
conditions after the start of supplying useful thermal energy. However,
the EPA does have information for electric utility steam generating
units (EGUs) on the hours to stable control operation after the start
of electricity generation. Using hour-by-hour emissions and operation
data for EGUs reported to the agency under the Acid Rain Program, we
found that controls used on the best performing 12 percent EGUs reach
stable operation within 4 hours after the start of electricity
generation.\1\ Since the types of controls used on EGUs are similar to
those used on industrial boilers and the start of electricity
generation is similar to the start of supplying useful thermal energy,
we believe that the controls on the best performing industrial boilers
would also reach stable operation within 4 hours after the start of
supplying useful thermal energy and have included this timeframe in the
proposed alternate definition.\2\ This conclusion is supported by the
very limited information (13 units) the EPA does have on industrial
boilers and by information submitted by the Council of Industrial
Boiler Owners obtained from an informal survey of its members on the
time needed to reach stable conditions during startup.\3\
---------------------------------------------------------------------------
\1\ See technical support document titled ``Assessment of
Startup Period at Coal-Fired Electric Generating Units--Revised'' in
the docket.
\2\ It is important to remember that the hour at which startup
ends is the hour at which reporting for the purpose of determining
compliance begins. Therefore, sources must collect and report
operating limit data following the end of startup. These data are
used in calculating whether a source is in compliance with the 30-
day average operating limits.
\3\ See attachments to the following Email messages included in
the docket: Robert Bessette, CIBO, to Robert Wayland, EPA, dated May
6, 2014; Amy Marshall, URS, to Jim Eddinger, EPA, dated June 10,
2014; and Reynaldo Forte, EPA, to Jim Eddinger, EPA, dated May 7,
2014.
---------------------------------------------------------------------------
The EPA is seeking comment on the definition of startup in the
February 1, 2013, final rule, as well as this action's proposed
revision to the February 1, 2013, definition of startup to include an
alternate definition of startup.
3. Shutdown
In this action, the EPA is proposing to revise the definition of
shutdown in the February 1, 2013, final rule. Specifically, the EPA is
proposing to clarify that shutdown begins when the boiler no longer
makes useful thermal energy and ends when the boiler no longer makes
useful thermal energy and no fuel is fired in the boiler. The EPA is
also proposing to replace ``steam and heat'' in the February 1, 2013,
definition of shutdown with ``useful thermal energy'' to address the
same issue raised by petitioners regarding the language in the
definition of ``startup'' described above. The EPA intended for the
shutdown period to begin when fuel is no longer fired for the purpose
of creating useful thermal energy.
The EPA received one petition for reconsideration of the definition
of
[[Page 2876]]
shutdown in the February 1, 2013, final rule. Petitioners assert that
the amended definition of shutdown is problematic for units firing
solid fuels on a grate or in a fluidized bed combustor where the
residual material in the unit keeps burning after fuel feed to the unit
is stopped. Petitioners explain that, in such a case, fuel is still
burning (``being fired'') in the unit despite the fact that load
reduction is occurring, additional fuel is not being fed and the
shutdown process has clearly begun. For this reason, petitioners assert
that the shutdown definition should be revised to state that shutdown
begins either when none of the steam and heat from the boiler is
supplied for heating and/or producing electricity or when fuel is no
longer being fed to the boiler, and that shutdown ends when there is
both no steam or heat being supplied and no fuel being combusted in the
boiler.
The EPA agrees with the petitioners that, for certain types of
boilers where the fuel is combusted on a grate or bed, fuel firing may
be considered to continue even after fuel feed to the unit is stopped.
The EPA intended that the shutdown period would begin when fuel is no
longer being fired for the purpose of creating useful thermal energy.
Thus, we believe the proposed revisions to the definition of shutdown
that address this issue are appropriate.
The EPA is seeking comment on the February 1, 2013, definition of
shutdown, as well as the revisions to the definition of shutdown that
we are now proposing to make.
B. Alternative Particulate Matter Standard for New Oil-Fired Boilers
That Combust Low-Sulfur Oil
The February 1, 2013, final rule added a new provision that
specifies that new or reconstructed oil-fired boilers with heat input
capacity of 10 million Btu per hour (MMBtu/hr) or greater that combust
only oil that contains no more than 0.50 weight percent sulfur or a
mixture of 0.50 weight percent sulfur oil with other fuels not subject
to a PM emission limit under this subpart and that do not use a post-
combustion technology (except a wet scrubber) to reduce PM or sulfur
dioxide emissions meet generally available control technology (GACT)
for PM, providing the type of fuel combusted is monitored and recorded
on a monthly basis. After the December 23, 2011, reconsideration
proposal, the EPA received a number of comments urging that we provide
an exemption from the PM limit for units burning low-sulfur liquid fuel
as is provided in subpart Dc of 40 CFR part 60 (Standards of
Performance for Small Industrial-Commercial-Institutional Steam
Generating Units), which is also the basis for the PM emission limit to
which these new and reconstructed boilers are subject. Commenters
asserted that such an exemption is justified since the low sulfur
content indicates low PM emissions and that boilers firing low-sulfur
liquid fuel should only be subject to a requirement to maintain records
documenting the liquid fuel fired. We agreed that burning low-sulfur
liquid fuel can be an alternative method of meeting GACT for PM and
added the subpart Dc provision that would allow low-sulfur liquid fuel
burning boilers currently complying with subpart Dc to use the same
compliance approach to meet the Area Source Boiler Rule requirement for
PM.
The EPA received a petition asserting that the public lacked an
opportunity to comment on the new provision for low-sulfur liquid fuel
burning boilers as well as the definition of low-sulfur liquid fuel.
Petitioners object to this alternative standard because they assert
that the EPA has not shown that burning liquid fuels that qualify as
being low-sulfur under the final rule will actually control the urban
hazardous air pollutants (HAP) for which the category of sources was
listed. Petitioners also assert that the final rule's definition of
low-sulfur encompasses liquid fuels with extremely high sulfur content
and will allow emissions that exceed the numerical emission limit for
PM that the EPA determined was GACT. In addition, petitioners note that
the final rule allows use of liquid fuel up to 0.5 percent sulfur by
weight, which translates to about 5,000 parts per million (ppm), which
they assert is far higher than the generally accepted definition of low
sulfur content of 500 ppm.
Although the EPA added the alternative PM standard for new oil-
fired boilers that combust low-sulfur oil in the February 1, 2013,
final rule in response to comments and these comments related to a
proposed rule provision that adopted some, but not all, of the
provisions for PM control in 40 CFR part 60, subpart Dc, we have
granted reconsideration on this issue to provide an opportunity for
comment on the new provision. The EPA requests comment, along with
supporting information, on (1) whether and, if so, to what extent
burning liquid fuels that qualify as being low-sulfur, as defined under
the final rule, would control the urban metal HAP for which the
category of sources was listed and for which PM serves as a surrogate
(i.e., Hg, arsenic, beryllium, cadmium, lead, chromium, manganese,
nickel) and (2) whether the final rule's definition of low-sulfur would
allow emissions that exceed the final rule's numerical emission limit
for PM.
The EPA also solicits comment on an alternative PM standard for new
oil-fired boilers that combust ultra-low-sulfur liquid fuel. The
National Emission Standards for Hazardous Air Pollutants for
Reciprocating Internal Combustion Engines (RICE NESHAP) (78 FR 6674,
January 30, 2013) require certain stationary emergency compression
ignition RICE to use diesel fuel that meets the specifications of 40
CFR 80.510(b), which require that diesel fuel have a maximum sulfur
content of 15 ppm. This fuel is referred to as ultra-low sulfur diesel
fuel (ULSD). The RICE NESHAP final rule notes that information provided
to the EPA by commenters showed that the use of ULSD will significantly
reduce emissions of air toxics, including metallic HAP (e.g., nickel,
zinc, lead) (78 FR 6680, January 30, 2013). In addition, the National
Emission Standards for Hazardous Air Pollutants for Major Sources:
Industrial, Commercial, and Institutional Boilers and Process Heaters
(Boiler maximum achievable control technology (MACT)) (78 FR 7138,
January 31, 2013) include a provision for certain boilers or process
heaters that combust ultra-low-sulfur liquid fuel. The final rule
specifies that if an affected boiler or process heater is in the units
designed to burn light liquid subcategory and it combusts ultra-low-
sulfur liquid fuel, further performance tests do not need to be
conducted if the pollutants measured during the initial compliance
performance tests meet the emission limits, providing ongoing
compliance with the emissions limits is demonstrated by monitoring and
recording the type of fuel combusted on a monthly basis. (See 40 CFR
63.7515(h).) The Boiler MACT defines ultra-low-sulfur liquid fuel as a
distillate oil that has less than or equal to 15 ppm sulfur. (See 40
CFR 63.7575.)
Specifically, we request comment on an alternative provision to the
February 1, 2013, final rule's alternative PM standard for new oil-
fired boilers that combust low-sulfur oil that would specify that new
or reconstructed oil-fired boilers with heat input capacity of 10
MMBtu/hr or greater that combust only ultra-low-sulfur liquid fuel meet
GACT for PM providing the type of fuel combusted is monitored and
recorded on a monthly basis. Under this alternative provision, GACT
would not require initial compliance performance testing demonstrating
compliance with the PM emission limit because sufficient testing has
shown that ULSD contains
[[Page 2877]]
low levels of urban metal HAP that we can be assured that this
alternative standard is effective. The EPA also requests comment, along
with supporting information, on whether, and, if so, to what extent
burning ultra-low-sulfur liquid fuels, as described above, would
control the urban metal HAP for which the category of sources were
listed.
C. Establishment of a Subcategory and Separate Requirements for
Limited-Use Boilers
The February 1, 2013, final rule established a limited-use boiler
subcategory that includes any boiler that burns any amount of solid or
liquid fuels and has a federally enforceable average annual capacity
factor of no more than 10 percent. The final rule established separate
requirements for this subcategory of boilers that operate on a limited
basis. In response to the December 23, 2011, reconsideration proposal,
several commenters asserted that the EPA should also include a limited-
use subcategory in the Area Source Boiler Rule for the same reasons we
determined a seasonal boiler subcategory was appropriate. Commenters
suggested that we should apply the same 5-year tune-up cycle for
limited-use units such as auxiliary boilers that we proposed for
seasonally-operated units and small oil-fired units. Commenters
explained that in the electric utility industry, auxiliary boilers are
typically used to generate the steam necessary to bring a main EGU on
line during startup and, since auxiliary boilers are primarily operated
during unit startup, operation for many of these boilers is typically
very limited and sporadic. Commenters also pointed out that the Boiler
MACT includes a limited-use subcategory.
The EPA determined that a limited-use subcategory was appropriate
and included a limited-use subcategory along with separate standards in
the final Area Source Boiler Rule. Specifically, the final rule
specifies that limited-use boilers must complete a tune-up every 5
years. Such boilers are not subject to the emission limits, the energy
assessment requirements or the operating limits. In the February 1,
2013, final rule, we stated our belief that establishing a limited-use
subcategory was reasonable. First, we pointed out that boilers that
operate no more than 10 percent of the year (i.e., a limited-use
boiler) would operate for no more than 6 months in between tune-ups on
a 5-year tune-up cycle. We further pointed out that the brief period of
operations for these limited-use boilers is even less than the number
of operating months that seasonal boilers and full-time boilers will
operate between tune-ups. Next, we noted that the irregular schedule of
operations also makes it difficult to schedule more frequent tune-ups.
Finally, we noted that it is technically infeasible to test these
limited-use boilers since these units serve as back-up energy sources
and their operating schedules can be intermittent and unpredictable.
The EPA received a petition asserting that the public lacked an
opportunity to comment on the new limited-use boiler subcategory, as
well as the tune-up requirement established for the new subcategory.
Petitioners object to the EPA's decision to create a separate
subcategory for these boilers and to the EPA's rationale for requiring
nothing more than one tune-up every 5 years for these boilers.
Specifically, petitioners assert that limited-use boilers differ from
other boilers only in that they are operated for fewer total hours over
the course of a year and that the EPA has not explained why this is a
distinction that justifies differential treatment.
The EPA disagrees with the petitioners' claim that we have not
explained why limited-use boilers should have separate regulatory
requirements. As described above, we fully explained our rationale for
establishing a limited-use boiler subcategory and separate requirements
for that subcategory in the February 1, 2013, final rule. However, in
consideration of the fact that the public lacked the opportunity to
comment on the new subcategory and requirements, we have granted
reconsideration to provide an opportunity for public comment on this
issue. The EPA requests comment regarding whether the separate
requirements for a limited-use boiler subcategory are necessary or
appropriate. Commenters should provide detailed information supporting
their comment. If, after evaluating all comments and data received on
this issue, the EPA determines that amendments to the limited-use
boiler subcategory and the separate requirements for that subcategory
may be appropriate, we will propose such amendments in a future
regulatory action.
D. Establishment of a Provision That Eliminates Further Performance
Testing for Particulate Matter for Certain Boilers Based on Their
Initial Compliance Test
The February 1, 2013, final rule added a new provision that
specifies that further PM emissions testing does not need to be
conducted if, when demonstrating initial compliance with the PM
emission limit, the performance test results show that the PM emissions
from the affected boiler are equal to or less than half of the
applicable PM emission limit. The EPA believes that inclusion of such a
provision promotes good PM performance from new boilers and could also
promote new technology development. In such instances, the owner or
operator must continue to comply with all applicable operating limits
and monitoring requirements to ensure that there are no changes in
operation of the boiler or air pollution control equipment that could
increase emissions. If the initial performance test results show that
the PM emissions are greater than half of the PM emission limit, the
owner or operator must conduct subsequent performance tests every 3
years as specified in the final rule. After the December 23, 2011,
reconsideration proposal, the EPA received comments asserting that the
most effective control strategy for small oil-fired boilers is the
tune-up required by the standards and that establishing a PM limit for
those boilers between 10 MMBtu/hr and 30 MMBtu/hr just ensures that
those boilers will do stack testing demonstrating that the boilers are
in compliance without the need for controls; a fact already known.
Commenters also asserted that establishing a PM limit imposes a stack
test obligation on small facilities with the least resources to deal
with the testing. After considering the comments, the EPA did not
eliminate or revise the PM limit for new oil-fired boilers with heat
input capacity between 10 MMBtu/hr and 30 MMBtu/hr. We did, however,
believe that adjustments to the PM performance test frequency, as
described above, were appropriate for boilers that demonstrate during
their initial performance test that their PM emissions are equal to or
less than half of the PM limit. We further stated our belief that the
performance test adjustment should not be potentially applicable to
only new oil-fired boilers with heat input capacity between 10 MMBtu/hr
and 30 MMBtu/hr, but to all new boilers subject to a PM emission limit.
The EPA received a petition asserting that the public lacked an
opportunity to comment on the new provision that eliminates further
performance testing for PM for certain boilers based on their initial
compliance test. Petitioners object to the EPA's decision to exempt
sources from PM performance testing indefinitely based on a single
performance test showing low emissions. Petitioners assert that because
the EPA determined that urban metal HAP emissions should be
[[Page 2878]]
controlled through a surrogate limit on PM emissions and that
compliance with the PM emission limit should be determined through
performance testing, the new provision, which fails to require
performance testing to determine compliance, is arbitrary. Petitioners
further assert that, because of variability in PM emissions, it is
arbitrary to conclude that a source that measures low emissions in one
test will have emissions below the limit forever thereafter.
Specifically, petitioners assert that emissions of PM from individual
sources are likely to be highly variable due to variations in
proportions of co-fired fuels within a given subcategory, changes in
fuel mix within a given fuel type and changes in fuel suppliers for a
given fuel type.
We have granted reconsideration on this issue to provide an
opportunity for comment on the new provision. The EPA requests comment,
along with supporting information, on the magnitude and range of
variability in PM and urban metal HAP emissions from individual
boilers. More specifically, we request comment on whether the emissions
variability at an individual boiler within a specific subcategory could
result in an exceedance of the applicable PM limit by such boiler whose
PM emissions are demonstrated to be equal to or less than half of the
applicable PM emission limit (i.e., a doubling or more of PM
emissions). We also request comment on to what extent a requirement to
burn only the fuel types and fuel mixtures used to demonstrate that a
boiler's PM emissions are equal to or less than half of the PM limit
would limit variability in the boiler's PM emissions.
The EPA also solicits comment on an alternative provision that
would specify less frequent performance testing for PM based on the
initial compliance test. Specifically, we request comment on an
alternative provision that would specify that when demonstrating
initial compliance with the PM emission limit, if the performance test
results show that the PM emissions from the affected boiler are equal
to or less than half of the applicable PM emission limit, additional PM
emissions testing would not need to be conducted for 5 years. In such
instances, the owner or operator would be required to continue to
comply with all applicable operating limits and monitoring requirements
to ensure that there are no changes in operation of the boiler or air
pollution control equipment that could increase emissions. We request
comment on also including a requirement that the owner or operator only
burn the fuel types and fuel mixtures used to demonstrate that the PM
emissions from the affected boiler are equal to or less than half of
the applicable PM emission limit. As long as the performance test
results show that the PM emissions from the affected boiler are equal
to or less than half of the applicable PM emission limit, the source
could continue conducting performance tests every 5 years. If the
initial performance test results or results from a subsequent
performance test show that the PM emissions are greater than half of
the PM emission limit, the owner or operator would be required to
conduct subsequent performance tests every 3 years, as specified in the
final rule.
E. Establishment of a Provision That Eliminates Further Fuel Sampling
for Mercury for Certain Coal-Fired Boilers Based on Their Initial
Compliance Demonstration
The February 1, 2013, final rule added a new provision that
specifies that further fuel analysis sampling does not need to be
conducted if, when demonstrating initial compliance with the Hg
emission limit based on fuel analysis, the Hg constituents in the fuel
or fuel mixture are measured to be equal to or less than half of the Hg
emission limit. The EPA believes that inclusion of such a provision
promotes use of low-Hg coal. In such instances, the owner or operator
must continue to comply with all applicable operating limits and
monitoring requirements, which include only burning the fuel types and
fuel mixtures used to demonstrate compliance and keeping monthly
records of fuel use. When demonstrating initial compliance with the Hg
emission limit, if the Hg constituents in the fuel or fuel mixture are
greater than half of the Hg emission limit, the owner or operator must
conduct quarterly sampling. After the December 23, 2011,
reconsideration proposal, the EPA realized that when the performance
stack testing frequency was revised from being required on an annual
basis in the June 4, 2010 (75 FR 31896) proposed rule to being required
on a triennial basis in the March 2011 final rule, we neglected to
revise the fuel analysis requirements. The June 2010 proposed rule
required a monthly fuel analysis. The February 1, 2013, final rule
requires quarterly fuel analysis if, when demonstrating initial
compliance with the Hg emission limit, the Hg constituents in the fuel
or fuel mixture are greater than half of the Hg emission limit.
The EPA received a petition asserting that the public lacked an
opportunity to comment on the new provision that eliminates further
fuel sampling for Hg for certain coal-fired boilers based on their
initial compliance demonstration. Petitioners object to the EPA's
decision to exempt sources from fuel sampling for Hg based on a single
fuel analysis. Petitioners assert that because the EPA determined that
Hg must be regulated based on the performance of maximum achievable
control technology and that compliance with the Hg emission limit can
be determined through fuel analysis, the new provision, which fails to
require fuel analysis to determine compliance, is arbitrary.
Petitioners further assert that the variability in the Hg content of
fuels available to coal-fired boilers at area sources is so great that
a single fuel analysis cannot show that a source will comply with the
standard in perpetuity. Petitioners claim that the February 1, 2013,
final rule defines coal-fired boilers subject to the standard broadly
and allows sources to burn highly non-homogenous fuels without changing
subcategories, which enables a high degree of variability in emissions.
Specifically, petitioners note that the final rule allows variation in
proportions of fuels co-fired (i.e., coal and biomass), changes in fuel
mix within a given fuel type and changes in fuel suppliers for a given
fuel type.
We have granted reconsideration on this issue to provide an
opportunity for comment on the new provision. The EPA requests comment,
along with supporting information, on the magnitude and range of
variability in Hg content in coal that is likely to be combusted in an
individual boiler. More specifically, we request comment on whether the
variability within a specific fuel type or fuel mixture could result in
an exceedance of the applicable Hg limit by a boiler in the coal
subcategory whose Hg content in their fuel or fuel mixture are
demonstrated to be equal to or less than half of the applicable Hg
emission limit (i.e., a doubling or more of Hg emissions).
The EPA also solicits comment on an alternative provision that
would specify less frequent fuel analysis sampling for Hg based on the
initial compliance demonstration. Specifically, we request comment on
an alternative provision that would specify that when demonstrating
initial compliance with the Hg emission limit based on fuel analysis,
if the Hg constituents in the fuel or fuel mixture are measured to be
equal to or less than half of the Hg emission limit, additional fuel
analysis sampling for Hg would not need to be conducted for 12 months.
In such instances, the owner or operator would be required to continue
to comply with all applicable operating limits and monitoring
requirements, which include
[[Page 2879]]
only burning the fuel types and fuel mixtures used to demonstrate
compliance and keeping monthly records of fuel use, to ensure that
there are no changes in operation of the boiler or air pollution
control equipment that could increase emissions. As long as the fuel
analysis sampling shows that the Hg constituents in the fuel or fuel
mixture are equal to or less than half of the Hg emission limit, the
source could continue fuel analysis sampling on an annual basis. If the
initial fuel analysis sampling or subsequent fuel analysis sampling
show that the Hg emissions are greater than half of the Hg emission
limit, the owner or operator would be required to conduct subsequent
fuel analysis sampling on a quarterly basis (i.e., every 3 months) as
specified in the final rule.
IV. Technical Corrections and Clarifications
We are proposing several clarifying changes and corrections to the
final rule. These proposed changes are described in Table 1 of this
preamble.
Table 1--Miscellaneous Proposed Changes and Corrections to 40 CFR Part
63, Subpart JJJJJJ
------------------------------------------------------------------------
Section of subpart JJJJJJ Description of proposed correction
------------------------------------------------------------------------
40 CFR 63.11195(k)........... Revise the language in this paragraph to
use the phrase ``as defined in this
subpart'' instead of ``covered by
subpart UUUUU of this part'' to clarify
that fossil fuel-fired EGUs are not
subject to the rule.
40 CFR 63.11210(j)........... Amend this paragraph to clarify that this
provision applies to existing affected
boilers that have not operated on any of
the fuels subject to subpart JJJJJJ
(i.e., ``on solid fossil fuel, biomass,
or liquid fuel'') between the rule's
effective date and compliance date.
40 CFR 63.11214(a)........... Amend this paragraph to clarify that the
requirement to submit a signed statement
in the Notification of Compliance Status
report that indicates that an initial
tune-up of the boiler was conducted only
applies to owners and operators of
existing coal-fired boilers with a heat
input capacity of less than 10 MMBtu/hr.
40 CFR 63.11214(b)........... Amend this paragraph to clarify that the
requirement to submit a signed statement
in the Notification of Compliance Status
report that indicates that an initial
tune-up of the boiler was conducted only
applies to owners and operators of
existing biomass-fired boilers and
existing oil-fired boilers.
40 CFR 63.11214(c)........... Amend this paragraph to clarify that the
energy assessment is also considered to
have been completed if the maximum
number of on-site technical hours
specified in the definition of energy
assessment applicable to the facility
has been expended.
40 CFR 63.11220(d)........... Amend this paragraph to clarify that this
provision applies to existing affected
boilers that have not operated on any of
the fuels subject to subpart JJJJJJ
(i.e., ``on solid fossil fuel, biomass,
or liquid fuel'') since the previous
compliance demonstration and more than 3
years have passed since the previous
compliance demonstration.
40 CFR 63.11221(c)........... Amend this paragraph to clarify that data
collected during periods of startup and
shutdown may not be used in calculations
used to report emissions or operating
levels.
40 CFR 63.11222(a)(2)........ Amend this paragraph to clarify that the
requirement to demonstrate that all fuel
types and mixtures of fuels burned would
result in lower emissions of Hg than the
applicable emission limit (if you
demonstrate compliance through fuel
analysis), or result in lower fuel input
of Hg than the maximum values calculated
during the last performance stack test
(if you demonstrate compliance through
performance stack testing) only applies
to owners and operators of boilers
subject to a Hg emission limit.
40 CFR 63.11224(a)(7)........ Amend this paragraph to clarify the
oxygen level set point for a source that
operates an oxygen trim system but is
not required to conduct a carbon
monoxide performance stack test.
40 CFR 63.11225(a)(4)........ Amend this paragraph to clarify that
owners and operators of new boilers
subject only to a requirement to conduct
a tune-up are not required to prepare
and submit a Notification of Compliance
Status for the tune-up.
40 CFR 63.11225(b)........... Amend this paragraph to clarify that
boilers subject only to energy
assessment and/or tune-up requirements
may submit only a biennial or 5-year
compliance report.
40 CFR 63.11225(c)(2)(iv).... Amend this paragraph to include the
requirement, as specified in Sec.
63.11210(e), that owners and operators
of new oil-fired boilers meeting the low
sulfur fuel requirements in Sec.
63.11210(e) must keep records, on a
monthly basis, of the type of fuel
combusted.
40 CFR 63.11225(e)(1)........ Amend this paragraph to clarify the EPA
point of contact for submittal of
confidential performance test
information.
40 CFR 63.11225(g)........... Revise the language in this paragraph to
(1) use the phrase ``due to a fuel
change that results in the boiler
meeting the definition of gas-fired
boiler, as defined in Sec. 63.11237''
instead of ``due to a change to 100
percent natural gas'' to clarify that
boilers switching out of subpart JJJJJJ
due to a fuel change are not only those
that change to 100-percent natural gas,
but include those for which the fuel
change results in the boiler meeting the
subpart JJJJJJ definition of ``Gas-fired
boiler,'' which encompasses those
boilers that change to 100-percent
natural gas; and (2) clarify that in
addition to a permit limit resulting in
a boiler becoming subject to the
subpart, a permit limit can also result
in a boiler no longer being subject to
the subpart.
40 CFR 63.11237.............. Add the definition of ``Annual capacity
factor'' to clarify its meaning within
the definition of ``Limited-use
boiler.''
Revise the definition of ``Coal'' to
clarify that coal derived liquids are
excluded from the definition of ``Coal''
and are considered to be a liquid fuel.
Revise the definition of ``Dry scrubber''
to delete the phrase ``and process
heaters.''
Add the definition of ``Fossil fuel'' to
clarify its meaning within the
definition of ``Electric utility steam
generating unit (EGU).''
[[Page 2880]]
Revise the definition of ``Gas-fired
boiler'' to clarify that the 48 hours of
liquid fuel usage allowed on an annual
calendar basis includes performing
maintenance and operator training. This
revision clarifies the intent of the
liquid fuel usage allowance in that
periodic testing, maintenance and
operator training activities are all
done to ensure that the boiler is
capable of operating properly on liquid
fuel when needed during periods of gas
curtailment, gas supply interruptions or
startups. This clarification does not
revise the amount of time that liquid
fuel can be used on an annual basis, but
clarifies when it can be used.
Revise the definition of ``Limited-use
boiler'' to delete the word ``average''
to eliminate confusion regarding its use
in the definition and maintain
consistent terminology within the
subpart.
Revise the definition of ``Load
fraction'' to clarify how load fraction
is determined for a boiler co-firing
natural gas with a solid or liquid fuel.
Revise the definition of ``Oxygen trim
system'' to include draft controller and
to clarify that it is a system that
maintains the desired excess air level
over its operating load range.
Table 1 to subpart JJJJJJ.... Revise item 6.b. to add ``(3-run average
or 10-day rolling average)'' to be
consistent with items 1.c. and 2.c. of
Table 1.
Table 2 to subpart JJJJJJ.... Revise item 16 to clarify that (1)
``operates under an energy management
program'' does not mean that the energy
management program must be implemented
in perpetuity, but, rather, for at least
one year between January 1, 2008, and
the compliance date specified in Sec.
63.11196; and (2) an energy management
program developed according to ENERGY
STAR guidelines would also satisfy the
requirement.
Table 6 to subpart JJJJJJ.... Revise item 2.(c) to clarify that ``load
fraction'' is as defined in Sec.
63.11237.
------------------------------------------------------------------------
V. Affirmative Defense
In several prior CAA section 112 and CAA section 129 rules,
including this rule, the EPA had included an affirmative defense to
civil penalties for violations caused by malfunctions in an effort to
create a system that incorporates some flexibility, recognizing that
there is a tension, inherent in many types of air regulation, to ensure
adequate compliance while simultaneously recognizing that despite the
most diligent of efforts, emission standards may be violated under
circumstances entirely beyond the control of the source. Although the
EPA recognized that its case-by-case enforcement discretion provides
sufficient flexibility in these circumstances, it included the
affirmative defense to provide a more formalized approach and more
regulatory clarity. See Weyerhaeuser Co. v. Costle, 590 F.2d 1011,
1057-58 (D.C. Cir. 1978) (holding that an informal case-by-case
enforcement discretion approach is adequate); but see Marathon Oil Co.
v. EPA, 564 F.2d 1253, 1272-73 (9th Cir. 1977) (requiring a more
formalized approach to consideration of ``upsets beyond the control of
the permit holder.''). Under the EPA's regulatory affirmative defense
provisions, if a source could demonstrate in a judicial or
administrative proceeding that it had met the requirements of the
affirmative defense in the regulation, civil penalties would not be
assessed. Recently, the United States Court of Appeals for the District
of Columbia Circuit vacated an affirmative defense in one of the EPA's
CAA section 112 regulations. NRDC v. EPA, 749 F.3d 1055 (D.C. Cir.,
2014) (vacating affirmative defense provisions in CAA section 112 rule
establishing emission standards for Portland cement kilns). The court
found that the EPA lacked authority to establish an affirmative defense
for private civil suits and held that under the CAA, the authority to
determine civil penalty amounts in such cases lies exclusively with the
courts, not the EPA. Specifically, the court found: ``As the language
of the statute makes clear, the courts determine, on a case-by-case
basis, whether civil penalties are `appropriate.' '' See NRDC, 2014
U.S. App. LEXIS 7281 at *21 (``[U]nder this statute, deciding whether
penalties are `appropriate' . . . is a job for the courts, not EPA.'').
In light of NRDC, the EPA is proposing to remove the regulatory
affirmative defense provision in the current rule.
In the event that a source fails to comply with the applicable CAA
section 112 standards as a result of a malfunction event, the EPA would
determine an appropriate response based on, among other things, the
good faith efforts of the source to minimize emissions during
malfunction periods, including preventative and corrective actions, as
well as root cause analyses to ascertain and rectify excess emissions.
The EPA would also consider whether the source's failure to comply with
the CAA section 112 standard was, in fact, ``sudden, infrequent, not
reasonably preventable'' and was not instead ``caused in part by poor
maintenance or careless operation.'' 40 CFR 63.2 (definition of
malfunction).
Further, to the extent the EPA files an enforcement action against
a source for violation of an emission standard, the source can raise
any and all defenses in that enforcement action and the federal
district court will determine what, if any, relief is appropriate. The
same is true for citizen enforcement actions. Cf. NRDC at 1064
(arguments that violation were caused by unavoidable technology failure
can be made to the courts in future civil cases when the issue arises).
Similarly, the presiding officer in an administrative proceeding can
consider any defense raised and determine whether administrative
penalties are appropriate.
VI. Solicitation of Public Comment and Participation
The EPA seeks full public participation in arriving at its final
decisions. The EPA requests public comment on the five issues under
reconsideration. At this time, other than the proposed revisions to the
startup and shutdown definitions, the EPA is not proposing any specific
revisions to the final rule with regard to the five reconsideration
issues. Nevertheless, we may retain or rescind the final rule
provisions or adopt an alternative discussed above based on comments
and information we receive.
Additionally, the EPA is making certain clarifying changes and
corrections to the final rule. We are soliciting comment on whether the
proposed changes provide the intended accuracy, clarity and
consistency. The EPA is also amending the final rule by
[[Page 2881]]
removing the affirmative defense provisions. We request comment on all
of these proposed changes.
The EPA is seeking comment only on the five issues, the clarifying
changes and corrections, and the amendments described above. The EPA
will not respond to any comments addressing any other issues or any
other provisions of the final rule or any other rule.
VII. Statutory and Executive Order Reviews
A. Executive Order 12866: Regulatory Planning and Review and Executive
Order 13563: Improving Regulation and Regulatory Review
This action is not a significant regulatory action and was
therefore not submitted to the Office of Management and Budget (OMB)
for review.
B. Paperwork Reduction Act (PRA)
This action does not impose any new information collection burden
under the PRA. The OMB has previously approved the information
collection requirements contained in the existing regulations and has
assigned OMB control number 2060-0668. The EPA is not proposing any new
information collection activities (e.g., monitoring, reporting,
recordkeeping) as part of this action. With this action, the EPA is
seeking additional comments on five aspects of the final Area Source
Boiler Rule (78 FR 7488, February 1, 2013). We are also proposing a
limited number of amendments that would clarify some applicability and
implementation issues raised by stakeholders subject to the final rule
and correct inadvertent errors promulgated in the final rule.
C. Regulatory Flexibility Act (RFA)
I certify that this action will not have a significant economic
impact on a substantial number of small entities under the RFA. This
action will not impose any requirements on small entities. This action
seeks comment on five aspects of the final Area Source Boiler Rule and
also proposes a limited number of clarifications and corrections to the
final rule.
D. Unfunded Mandates Reform Act (UMRA)
This action does not contain any unfunded mandate as described in
UMRA, 2 U.S.C. 1531-1538, and does not significantly or uniquely affect
small governments. The action imposes no enforceable duty on any state,
local or tribal governments or the private sector. This action seeks
comment on five aspects of the final Area Source Boiler Rule and also
proposes a limited number of clarifications and corrections to the
final rule.
E. Executive Order 13132: Federalism
This action does not have federalism implications. It will not have
substantial direct effects on the states, on the relationship between
the national government and the states, or on the distribution of power
and responsibilities among the various levels of government. This
action seeks comment on five aspects of the final Area Source Boiler
Rule and also proposes a limited number of clarifications and
corrections to the final 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. This action seeks comment on five aspects of the
final Area Source Boiler Rule and also proposes a limited number of
clarifications and corrections to the final rule. Thus, Executive Order
13175 does not apply to this action.
G. Executive Order 13045: Protection of Children From Environmental
Health Risks and Safety Risks
The EPA interprets Executive Order 13045 as applying to those
regulatory actions that concern environmental health or safety risks
that the EPA has reason to believe may disproportionately affect
children, per the definition of ``covered regulatory action'' in
section 2-202 of the Executive Order. This action is not subject to
Executive Order 13045 because it is does not concern an environmental
health risk or safety risk.
H. Executive Order 13211: Actions Concerning Regulations That
Significantly Affect Energy Supply, Distribution, or Use
This action is not subject to Executive Order 13211, because it is
not a significant regulatory action under Executive Order 12866.
I. National Technology Transfer and Advancement Act (NTTAA)
This action does not involve technical standards.
J. Executive Order 12898: Federal Actions To Address Environmental
Justice in Minority Populations and Low-Income Populations
The EPA believes the human health or environmental risk addressed
by this action will not have potential disproportionately high and
adverse human health or environmental effects on minority, low-income
or indigenous populations. This action seeks comment on five aspects of
the final Area Source Boiler Rule and also proposes a limited number of
clarifications and corrections to the final rule.
List of Subjects in 40 CFR Part 63
Environmental protection, Administrative practice and procedure,
Air pollution control, Hazardous substances, Intergovernmental
relations, Reporting and recordkeeping requirements.
Dated: December 1, 2014.
Gina McCarthy,
Administrator.
For the reasons stated in the preamble, title 40, chapter I, part
63 of the Code of Federal Regulations is proposed to be amended as
follows:
PART 63--NATIONAL EMISSION STANDARDS FOR HAZARDOUS AIR POLLUTANTS
FOR SOURCE CATEGORIES
0
1. The authority citation for part 63 continues to read as follows:
Authority: 42 U.S.C. 7401 et seq.
Subpart JJJJJJ--National Emission Standards for Hazardous Air
Pollutants for Industrial, Commercial, and Institutional Boilers
Area Sources
0
2. Section 63.11195 is amended by revising paragraph (k) to read as
follows:
Sec. 63.11195 Are any boilers not subject to this subpart?
* * * * *
(k) An electric utility steam generating unit (EGU) as defined in
this subpart.
0
3. Section 63.11210 is amended by revising paragraphs (j) introductory
text, (j)(1), and (j)(2) to read as follows:
Sec. 63.11210 What are my initial compliance requirements and by what
date must I conduct them?
* * * * *
(j) For existing affected boilers that have not operated on solid
fossil fuel, biomass, or liquid fuel between the effective date of the
rule and the compliance date that is specified for your source in Sec.
63.11196, you must comply with the applicable provisions as specified
in paragraphs (j)(1) through (3) of this section.
(1) You must complete the initial compliance demonstration, if
subject to the emission limits in Table 1 to this subpart, as specified
in paragraphs (a) and (b) of this section, no later than 180 days after
the re-start of the affected boiler on solid fossil fuel, biomass, or
[[Page 2882]]
liquid fuel and according to the applicable provisions in Sec.
63.7(a)(2).
(2) You must complete the initial performance tune-up, if subject
to the tune-up requirements in Sec. 63.11223, by following the
procedures described in Sec. 63.11223(b) no later than 30 days after
the re-start of the affected boiler on solid fossil fuel, biomass, or
liquid fuel.
* * * * *
0
4. Section 63.11214 is amended by revising paragraphs (a) through (c)
to read as follows:
Sec. 63.11214 How do I demonstrate initial compliance with the work
practice standard, emission reduction measures, and management
practice?
(a) If you own or operate an existing or new coal-fired boiler with
a heat input capacity of less than 10 million Btu per hour, you must
conduct a performance tune-up according to Sec. 63.11210(c) or (f), as
applicable, and Sec. 63.11223(b). If you own or operate an existing
coal-fired boiler with a heat input capacity of less than 10 million
Btu per hour, you must submit a signed statement in the Notification of
Compliance Status report that indicates that you conducted an initial
tune-up of the boiler.
(b) If you own or operate an existing or new biomass-fired boiler
or an existing or new oil-fired boiler, you must conduct a performance
tune-up according to Sec. 63.11210(c) or (f), as applicable, and Sec.
63.11223(b). If you own or operate an existing biomass-fired boiler or
existing oil-fired boiler, you must submit a signed statement in the
Notification of Compliance Status report that indicates that you
conducted an initial tune-up of the boiler.
(c) If you own or operate an existing affected boiler with a heat
input capacity of 10 million Btu per hour or greater, you must submit a
signed certification in the Notification of Compliance Status report
that an energy assessment of the boiler and its energy use systems was
completed according to Table 2 to this subpart and that the assessment
is an accurate depiction of your facility at the time of the assessment
or that the maximum number of on-site technical hours specified in the
definition of energy assessment applicable to the facility has been
expended.
* * * * *
0
5. Section 63.11220 is amended by revising paragraph (d) to read as
follows:
Sec. 63.11220 When must I conduct subsequent performance tests or
fuel analyses?
* * * * *
(d) For existing affected boilers that have not operated on solid
fossil fuel, biomass, or liquid fuel since the previous compliance
demonstration and more than 3 years have passed since the previous
compliance demonstration, you must complete your subsequent compliance
demonstration no later than 180 days after the re-start of the affected
boiler on solid fossil fuel, biomass, or liquid fuel.
0
6. Section 63.11221 is amended by revising paragraph (c) to read as
follows:
Sec. 63.11221 Is there a minimum amount of monitoring data I must
obtain?
* * * * *
(c) You may not use data collected during periods of startup and
shutdown, monitoring system malfunctions or out-of-control periods,
repairs associated with monitoring system malfunctions or out-of-
control periods, or required monitoring system quality assurance or
quality control activities in calculations used to report emissions or
operating levels. Any such periods must be reported according to the
requirements in Sec. 63.11225. You must use all the data collected
during all other periods in assessing the operation of the control
device and associated control system.
* * * * *
0
7. Section 63.11222 is amended by revising paragraph (a)(2) to read as
follows:
Sec. 63.11222 How do I demonstrate continuous compliance with the
emission limits?
(a) * * *
(2) If you have an applicable mercury or PM emission limit, you
must keep records of the type and amount of all fuels burned in each
boiler during the reporting period. If you have an applicable mercury
emission limit, you must demonstrate that all fuel types and mixtures
of fuels burned would result in lower emissions of mercury than the
applicable emission limit (if you demonstrate compliance through fuel
analysis), or result in lower fuel input of mercury than the maximum
values calculated during the last performance stack test (if you
demonstrate compliance through performance stack testing).
* * * * *
0
8. Section 63.11224 is amended by revising paragraph (a)(7) to read as
follows:
Sec. 63.11224 What are my monitoring, installation, operation, and
maintenance requirements?
(a) * * *
(7) You must operate the oxygen analyzer system at or above the
minimum oxygen level that is established as the operating limit
according to Table 6 to this subpart when firing the fuel or fuel
mixture utilized during the most recent CO performance stack test. If
your facility is not required to conduct a CO performance stack test,
you must set the oxygen level to the oxygen concentration measured
during the most recent tune-up to optimize CO to manufacturer's
specifications and you must operate the oxygen analyzer system at or
above that level. Operation of oxygen trim systems to meet these
requirements shall not be done in a manner which compromises furnace
safety.
* * * * *
0
9. Section 63.11225 is amended by revising paragraphs (a)(4)
introductory text, (b) introductory text, (c)(2)(iv), (e)(1) and (g)
introductory text to read as follows:
Sec. 63.11225 What are my notification, reporting, and recordkeeping,
requirements?
(a) * * *
(4) You must submit the Notification of Compliance Status no later
than 120 days after the applicable compliance date specified in Sec.
63.11196 unless you own or operate a new boiler subject only to a
requirement to conduct a biennial or 5-year tune-up or you must conduct
a performance stack test. If you own or operate a new boiler subject to
a requirement to conduct a tune-up, you are not required to prepare and
submit a Notification of Compliance Status for the tune-up. If you must
conduct a performance stack test, you must submit the Notification of
Compliance Status within 60 days of completing the performance stack
test. You must submit the Notification of Compliance Status in
accordance with paragraphs (a)(4)(i) and (vi) of this section. The
Notification of Compliance Status must include the information and
certification(s) of compliance in paragraphs (a)(4)(i) through (v) of
this section, as applicable, and signed by a responsible official.
* * * * *
(b) You must prepare, by March 1 of each year, and submit to the
delegated authority upon request, an annual compliance certification
report for the previous calendar year containing the information
specified in paragraphs (b)(1) through (4) of this section. You must
submit the report by March 15 if you had any instance described by
paragraph (b)(3) of this section. For boilers that are subject only to
the energy assessment requirement and/or a requirement to conduct a
biennial or
[[Page 2883]]
5-year tune-up according to Sec. 63.11223(a) and not subject to
emission limits or operating limits, you may prepare only a biennial or
5-year compliance report as specified in paragraphs (b)(1) and (2) of
this section.
* * * * *
(c) * * *
(2) * * *
(iv) For each boiler subject to an emission limit in Table 1 to
this subpart, you must keep records of monthly fuel use by each boiler,
including the type(s) of fuel and amount(s) used. For each new oil-
fired boiler that meets the requirements of Sec. 63.11210(e), you must
keep records, on a monthly basis, of the type of fuel combusted.
* * * * *
(e)(1) Within 60 days after the date of completing each performance
test (defined in Sec. 63.2) as required by this subpart you must
submit the results of the performance tests, including any associated
fuel analyses, required by this subpart to EPA's WebFIRE database by
using CEDRI that is accessed through EPA's CDX (www.epa.gov/cdx).
Performance test data must be submitted in the file format generated
through use of EPA's Electronic Reporting Tool (ERT) (see http://www.epa.gov/ttn/chief/ert/index.html). Only data collected using test
methods on the ERT Web site are subject to this requirement for
submitting reports electronically to WebFIRE. Owners or operators who
claim that some of the information being submitted for performance
tests is confidential business information (CBI) must submit a complete
ERT file including information claimed to be CBI on a compact disk or
other commonly used electronic storage media (including, but not
limited to, flash drives) to EPA. The electronic media must be clearly
marked as CBI and mailed to U.S. EPA/OAPQS/CORE CBI Office, Attention:
Group Leader, Measurement Policy Group, MD C404-02, 4930 Old Page Rd.,
Durham, NC 27703. The same ERT file with the CBI omitted must be
submitted to EPA via CDX as described earlier in this paragraph. At the
discretion of the delegated authority, you must also submit these
reports, including CBI, to the delegated authority in the format
specified by the delegated authority. For any performance test
conducted using test methods that are not listed on the ERT Web site,
the owner or operator shall submit the results of the performance test
in paper submissions to the Administrator at the appropriate address
listed in Sec. 63.13.
* * * * *
(g) If you have switched fuels or made a physical change to the
boiler and the fuel switch or change resulted in the applicability of a
different subcategory within this subpart, in the boiler becoming
subject to this subpart, or in the boiler switching out of this subpart
due to a fuel change that results in the boiler meeting the definition
of gas-fired boiler, as defined in Sec. 63.11237, or you have taken a
permit limit that resulted in you becoming subject to this subpart or
no longer being subject to this subpart, you must provide notice of the
date upon which you switched fuels, made the physical change, or took a
permit limit within 30 days of the change. The notification must
identify:
* * * * *
Sec. 63.11226 [Removed]
0
10. Remove Sec. 63.11226.
0
11. Section 63.11237 is amended as follows:
0
a. By adding, in alphabetical order, the definitions for ``Annual
capacity factor,'' ``Fossil fuel,'' and ``Useful thermal energy.''
0
b. By revising the definitions for ``Coal,'' ``Dry scrubber,'' ``Gas-
fired boiler,'' ``Limited-use boiler,'' ``Load fraction,'' ``Oxygen
trim system,'' ``Shutdown,'' and ``Startup.''
0
c. By removing the definition of ``Affirmative defense.''
The additions and revisions read as follows:
Sec. 63.11237 What definitions apply to this subpart?
* * * * *
Annual capacity factor means the ratio between the actual heat
input to a boiler from the fuels burned during a calendar year and the
potential heat input to the boiler had it been operated for 8,760 hours
during a year at the maximum steady state design heat input capacity.
* * * * *
Coal means all solid fuels classifiable as anthracite, bituminous,
sub-bituminous, or lignite by the American Society for Testing and
Materials in ASTM D388 (incorporated by reference, see Sec. 63.14),
coal refuse, and petroleum coke. For the purposes of this subpart, this
definition of ``coal'' includes synthetic fuels derived from coal
including, but not limited to, solvent-refined coal, coal-oil mixtures,
and coal-water mixtures. Coal derived gases and liquids are excluded
from this definition.
* * * * *
Dry scrubber means an add-on air pollution control system that
injects dry alkaline sorbent (dry injection) or sprays an alkaline
sorbent (spray dryer) to react with and neutralize acid gas in the
exhaust stream forming a dry powder material. Sorbent injection systems
used as control devices in fluidized bed boilers are included in this
definition. A dry scrubber is a dry control system.
* * * * *
Fossil fuel means natural gas, oil, coal, and any form of solid,
liquid, or gaseous fuel derived from such material.
* * * * *
Gas-fired boiler includes any boiler that burns gaseous fuels not
combined with any solid fuels and burns liquid fuel only during periods
of gas curtailment, gas supply interruption, startups, or for periodic
testing, maintenance, or operator training on liquid fuel. Periodic
testing, maintenance, or operator training on liquid fuel shall not
exceed a combined total of 48 hours during any calendar year.
* * * * *
Limited-use boiler means any boiler that burns any amount of solid
or liquid fuels and has a federally enforceable annual capacity factor
of no more than 10 percent.
* * * * *
Load fraction means the actual heat input of a boiler divided by
heat input during the performance test that established the minimum
sorbent injection rate or minimum activated carbon injection rate,
expressed as a fraction (e.g., for 50 percent load the load fraction is
0.5). For boilers that co-fire natural gas with a solid or liquid fuel,
the load fraction is determined by the actual heat input of the solid
or liquid fuel divided by heat input of the solid or liquid fuel fired
during the performance test (e.g., if the performance test was
conducted at 100 percent solid fuel firing, for 100 percent load firing
50 percent solid fuel and 50 percent natural gas, the load fraction is
0.5).
* * * * *
Oxygen trim system means a system of monitors that is used to
maintain excess air at the desired level in a combustion device over
its operating load range. A typical system consists of a flue gas
oxygen and/or carbon monoxide monitor that automatically provides a
feedback signal to the combustion air controller or draft controller.
* * * * *
Shutdown means the period in which cessation of operation of a
boiler is initiated for any purpose. Shutdown begins when the boiler no
longer makes useful thermal energy (such as steam or hot water) for
heating, cooling, or process purposes or generates
[[Page 2884]]
electricity, or when no fuel is being fed to the boiler, whichever is
earlier. Shutdown ends when the boiler no longer makes useful thermal
energy (such as steam or hot water) for heating, cooling, or process
purposes or generates electricity, and no fuel is being combusted in
the boiler.
* * * * *
Startup means:
(1) Either the first-ever firing of fuel in a boiler for the
purpose of supplying steam or heat for heating and/or producing
electricity, or for any other purpose, or the firing of fuel in a
boiler after a shutdown event for any purpose. Startup ends when any of
the steam or heat from the boiler is supplied for heating and/or
producing electricity, or for any other purpose, or
(2) The period in which operation of a boiler is initiated for any
purpose. Startup begins with either the first-ever firing of fuel in a
boiler for the purpose of supplying useful thermal energy (such as
steam or hot water) for heating, cooling or process purposes, or
producing electricity, or the firing of fuel in a boiler for any
purpose after a shutdown event. Startup ends four hours after when the
boiler makes useful thermal energy (such as steam or hot water) for
heating, cooling, or process purposes, or generates electricity,
whichever is earlier.
* * * * *
Useful thermal energy means energy (i.e., steam or hot water) that
meets the minimum operating temperature and/or pressure required by any
energy use system that uses energy provided by the affected boiler.
* * * * *
0
12. Table 1 to subpart JJJJJJ is amended by revising the entry for
``6.'' to read as follows:
Table 1 to Subpart JJJJJJ of Part 63--Emission Limits
* * * * * * *
------------------------------------------------------------------------
You must achieve less
than or equal to the
For the following following emission
If your boiler is in this pollutants . . . limits, except during
subcategory . . . periods of startup
and shutdown . . .
------------------------------------------------------------------------
* * * * * * *
6. Existing coal-fired boilers a. Mercury....... 2.2E-05 lb per MMBtu
with heat input capacity of b. CO............ of heat input.
10 MMBtu/hr or greater that 420 ppm by volume on
do not meet the definition of a dry basis
limited-use boiler. corrected to 3
percent oxygen (3-
run average or 10-
day rolling
average).
------------------------------------------------------------------------
0
13. Table 2 to subpart JJJJJJ is amended by revising the entry for
``16.'' to read and follows:
Table 2 to Subpart JJJJJJ of Part 63--Work Practice Standards, Emission
Reduction Measures, and Management Practices
* * * * * * *
------------------------------------------------------------------------
If your boiler is in this
subcategory . . . You must meet the following . . .
------------------------------------------------------------------------
* * * * * * *
16. Existing coal-fired, biomass- Must have a one-time energy
fired, or oil-fired boilers assessment performed by a qualified
(units with heat input capacity energy assessor. An energy
of 10 MMBtu/hr and greater), not assessment completed on or after
including limited-use boilers. January 1, 2008, that meets or is
amended to meet the energy
assessment requirements in this
table satisfies the energy
assessment requirement. Energy
assessor approval and qualification
requirements are waived in instances
where past or amended energy
assessments are used to meet the
energy assessment requirements. A
facility that operated under an
energy management program developed
according to the ENERGY STAR
guidelines for energy management or
compatible with ISO 50001 for at
least one year between January 1,
2008, and the compliance date
specified in Sec. 63.11196 that
includes the affected units also
satisfies the energy assessment
requirement. The energy assessment
must include the following with
extent of the evaluation for items
(1) to (4) appropriate for the on-
site technical hours listed in Sec.
63.11237:
(1) A visual inspection of the
boiler system,
(2) An evaluation of operating
characteristics of the affected
boiler systems, specifications of
energy use systems, operating and
maintenance procedures, and
unusual operating constraints,
(3) An inventory of major energy
use systems consuming energy from
affected boiler(s) and which are
under control of the boiler owner
or operator,
(4) A review of available
architectural and engineering
plans, facility operation and
maintenance procedures and logs,
and fuel usage,
(5) A list of major energy
conservation measures that are
within the facility's control,
[[Page 2885]]
(6) A list of the energy savings
potential of the energy
conservation measures identified,
and
(7) A comprehensive report detailing
the ways to improve efficiency, the
cost of specific improvements,
benefits, and the time frame for
recouping those investments.
------------------------------------------------------------------------
0
14. Table 6 to subpart JJJJJJ is amended by revising the entry for
``2.'' to read as follows:
Table 6 to Subpart JJJJJJ of Part 63--Establishing Operating Limits
* * * * * * *
----------------------------------------------------------------------------------------------------------------
And your
If you have an applicable operating According to the
emission limit for . . . limits are You must . . . Using . . . following
based on . . . requirements
----------------------------------------------------------------------------------------------------------------
* * * * * * *
2. Mercury................... Dry sorbent or Establish a site- Data from the (a) You must collect
activated specific minimum sorbent or sorbent or
carbon sorbent or activated carbon activated carbon
injection rate activated carbon injection rate injection rate data
operating injection rate monitors and the every 15 minutes
parameters. operating limit mercury performance during the entire
according to Sec. stack tests. period of the
63.11211(b). performance stack
tests;
(b) Determine the
average sorbent or
activated carbon
injection rate for
each individual
test run in the
three-run
performance stack
test by computing
the average of all
the 15-minute
readings taken
during each test
run.
(c) When your unit
operates at lower
loads, multiply
your sorbent or
activated carbon
injection rate by
the load fraction,
as defined in Sec.
63.11237, to
determine the
required injection
rate.
* * * * * * *
----------------------------------------------------------------------------------------------------------------
[FR Doc. 2014-30388 Filed 1-20-15; 8:45 am]
BILLING CODE 6560-50-P