[Federal Register: October 31, 2005 (Volume 70, Number 209)]
[Proposed Rules]
[Page 62264-62275]
[DOCID:fr31oc05-14]

=======================================================================
-----------------------------------------------------------------------

ENVIRONMENTAL PROTECTION AGENCY

40 CFR Part 63

[OAR-2002-0056; FRL-7990-2]
RIN 2060-AN32

National Emission Standards for Hazardous Air Pollutants for
Industrial, Commercial, and Institutional Boilers and Process Heaters

AGENCY: Environmental Protection Agency (EPA).

ACTION: Proposed rule; notice of reconsideration of final rule;
proposed amendments.

-----------------------------------------------------------------------

SUMMARY: On September 13, 2004, EPA promulgated national emission
standards for hazardous air pollutants (NESHAP) for industrial,
commercial, and institutional boilers and process heaters. In this
action, EPA is proposing a limited number of amendments to the NESHAP.
In response to a petition for reconsideration, EPA is proposing and

requesting comment on an amendment allowing for consolidated testing of
commonly vented boilers under the emission averaging provision. In
addition, EPA is proposing amendments and technical corrections to the
final rule to clarify some applicability and implementation issues
raised by stakeholders subject to the final rule.

DATES: Comments. Comments must be received on or before December 15,
2005.
    Public Hearing. If anyone contacts EPA requesting to speak at a
public hearing by November 10, 2005, a public hearing will be held on
November 15, 2005. For further information on the public hearing and
requests to speak, see the ADDRESSES section of this preamble.

ADDRESSES: Comments. Submit your comments, identified by Docket ID No.
OAR-2002-0058 (Legacy Docket ID No. A-96-47) by one of the following
methods:
     Federal eRulemaking Portal: http://www.regulations.gov.

Follow the on-line instructions for submitting comments.
     Agency Web site: http://www.epa.gov/docket. EDOCKET, EPA's

electronic public docket and comment system, is EPA's preferred method
for receiving comments. Follow the on-line instructions for submitting
comments.
     E-mail<EMAIL_ADDRESS>     Fax:<PHONE_NUMBER>.
     Mail: Air and Radiation Docket and Information. Center,
U.S. EPA, Mailcode: 6102T, 1200 Pennsylvania Avenue, NW., Washington,
DC 20460.
     Hand Delivery: Air and Radiation Docket and Information
Center, U.S. EPA, Room B102, 1301 Constitution Avenue, NW., Washington,
DC. 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. OAR-2022-0058
(Legacy Docket ID No. A-96-47). The EPA's policy is that all comments
received will be included in the public docket without change and may
be made available online at http://www/epa.gov/edocket, 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
EDOCKET, regulations.gov, or e-mail. The EPA EDOCKET and the Federal
regulations.gov websites are ``anonymous access'' systems, which means
that EPA will not know your identity or contact information unless you
provide it in the body of your comment. If you send an e-mail comment
directly to EPA without going through EDOCKET or regulations.gov, your
e-mail 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, 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 EPA cannot read your
comment due to technical difficulties and cannot contact you for
clarification, 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 a public hearing is held, it will be held on
November 15, 2005 at the EPA facility, Research Triangle Park, NC, or
an alternative site nearby. Persons interested in attending the hearing
or wishing to present oral testimony should notify Ms. Pamela Garrett
at least 2 days in advance of the public hearing (see FOR FURTHER
INFORMATION CONTACT section of this preamble). The public hearing will
provide interested parties the opportunity to present data, views, or
arguments concerning this notice.
    Docket. EPA has established an official public docket for today's
notice, including both Docket ID No. OAR-2002-0058 and Legacy Docket ID
No. A-96-47. The official public docket consists of the documents
specifically referenced in today's notice, any public comments
received, and other information related to the notice. All items may
not be listed under both docket numbers, so interested parties should
inspect both docket numbers to ensure that they have received all
materials relevant to today's notice. Although listed in the index,
some information is not publicly available, i.e., CBI or other
information whose disclosure is restricted by statute. Certain other
material, such as copyrighted material, is not placed on the Internet
and will be publicly available only in hard copy form. Publicly
available docket materials are available either electronically in
EDOCKET or in hard copy at the Air and Radiation Docket and Information
Center, U.S. EPA, Room B102, 1301 Constitution Avenue, 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
Pubic Reading Room is<PHONE_NUMBER>, and the telephone number for the
Air and Radiation Docket and Information Center is<PHONE_NUMBER>.

FOR FURTHER INFORMATION CONTACT: For general and technical information,
contact Mr. James Eddinger, Combustion Group, Emission Standards
Division, Mailcode: C439-01, U.S. EPA, Research Triangle Park, NC
27711; telephone number<PHONE_NUMBER>; fax number:<PHONE_NUMBER>; e-
mail address<EMAIL_ADDRESS>For questions about the public
hearing, contact Ms. Pamela Garrett, Combustion Group, Emission
Standards Division, Mailcode: C439-01, U.S. EPA, Research Triangle
Park, NC 27711; telephone number:<PHONE_NUMBER>; e-mail address:
<EMAIL_ADDRESS>

SUPPLEMENTARY INFORMATION:
    Outline: The information presented in this preamble is organized as
follows:

I. General Information
    A. Does this notice apply to me?
    B. How do I submit CBI?
    C. How do I obtain a copy of this document and other related
information?
II. Background
III. Today's Action
IV. Reconsideration of Emissions Averaging Provision
V. Proposed Clarifying Amendments and Technical Corrections
    A. What clarifications are proposed to the definitions?
    B. What are the proposed corrections?
    C. What are the impacts associated with the amendments?
VI. Statutory and Executive Order Reviews
    A. Executive Order 12866: Regulatory Planning and Review
    B. Paperwork Reduction Act
    C. Regulatory Flexibility Act
    D. Unfunded Mandates Reform Act
    E. Executive Order 13132: Federalism
    F. Executive Order 13175: Consultations and Coordination With
Indian Tribal Governments
    G. Executive Order 13045: Protection of Children from
Environmental Health and Safety Risks
    H. Executive Order 13211: Actions that Significantly Affect
Energy Supply, Distribution, or Use
    I. National Technology Transfer and Advancement Act

I. General Information

A. Does this notice apply to me?

    Categories and entities potentially affected by today's notice
include:

----------------------------------------------------------------------------------------------------------------
                                                                               Examples of potentially regulated
                 Category                    SIC  code \a\   NAICS  code \b\               entities
----------------------------------------------------------------------------------------------------------------
Any industry using a boiler or process                   24              321  Manufacturers of lumber and wood
 heater as defined in the final rule.                                          products.
                                                         26              322  Pulp and paper mills.
                                                         28              325  Chemical manufacturers.
                                                         29              324  Petroleum refineries, and
                                                                               manufacturers of coal products.
                                                         30    316, 326, 339  Manufacturers of rubber and
                                                                               miscellaneous plastic products.
                                                         33              331  Steel works.
                                                         34              332  Electroplating, plating,
                                                                               polishing, anodizing, and
                                                                               coloring.
                                                         37              336  Manufacturers of motor vehicle
                                                                               parts and accessories.
                                                         49              221  Electric, gas, and sanitary
                                                                               services.
                                                         80              622  Health services.
                                                         82              611  Educational services.
----------------------------------------------------------------------------------------------------------------
\a\ Standard Industrial Classification.
\b\ North American Industrial Classification System.

    This table is not intended to be exhaustive, but rather provides a
guide for readers regarding entities likely to be affected by today's
notice. To determine whether your facility is affected by today's
notice, you should examine the applicability criteria in 40 CFR 63.7485
of the final rule. If you have questions regarding the applicability of
today's notice to a particular entity, consult Mr. Jim Eddinger listed
in the preceding FOR FURTHER INFORMATION CONTACT section.

B. How do I submit CBI?

    Do not submit this information to EPA through EDOCKET,
regulations.gov or e-mail. Clearly mark the part or all of the
information that you claim to be CBI. For CBI in a disk or CD ROM that
you mail to 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 the 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.

C. How do I obtain a copy of this document and other related
information?

    In addition to being available in the docket, an electronic copy of
today's notice also will be available on the World Wide Web (WWW)
through EPA's Technology Transfer Network (TTN). Following the
Administrator's signature, a copy of this notice will be posted on the
TTN's policy and guidance page for newly proposed rules at http://www/epa.gov/ttn/oarpg.
 The TTN provides information and technology exchange

in various areas of air pollution control.

II. Background

    On September 13, 2004 (69 FR 55218), we promulgated the NESHAP for
industrial, commercial, and institutional boilers and process heaters
as subpart DDDDD of 40 CFR part 63. In accordance with section 112(d)
of the Clean Air Act (CAA), the NESHAP contains technology-based
emissions standards reflecting the maximum achievable control
technology (MACT) and health-based compliance alternative for certain
threshold pollutants. We proposed these standards for industrial,
commercial, and institutional boilers and process heaters on January
13, 2003 (68 FR 1660).
    In the preamble for the proposed rule, we discussed our
consideration of a bubbling compliance alternative and requested
comment on incorporating a bubbling compliance alternative (i.e.,
emission averaging) into the final rule as part of EPA's general policy
of encouraging the use of flexible compliance approaches where they can
be properly monitored and enforced. (See 68 FR 1686.) Industry trade
associations, owners/operators of boilers and process heaters, State
regulatory agencies, local government agencies, and environmental
groups submitted comments on the emissions averaging approach. We
received a total of 40 public comment letters regarding the emissions
averaging approach in the proposed rule during the comment period. We
summarized major public comments on the proposed emissions averaging
approach, along with our responses to those comments, in the preamble
to the final rule (69 FR 55238) and in the comment response memorandum
``Response to Public Comments on Proposed Industrial, Commercial, and
Institutional Boilers and Process Heaters NESHAP (Revised) (RTC
Memorandum) that was placed in the docket for the final rule.
    In the final rule, we adopted an emissions averaging provision for
existing large solid fuel boilers. The procedures that affected sources
must use to demonstrate compliance through emissions averaging were
promulgated in 40 CFR 63.7522. (See 69 FR 55257.) For each existing
large solid fuel boiler in the averaging group, the emissions are
capped at the emission level being achieved on the effective date of
the final rule (November 12, 2004). Under emissions averaging,
compliance must be demonstrated on a 12-month rolling average basis,
determined at the end of every calendar month. If a facility uses this
option, it must also develop and submit an implementation plan to the
applicable regulatory authority for review and approval no later than
180 days before the date that the facility intends to demonstrate
compliance.
    Following promulgation of the final rule, the Administrator
received petitions for reconsideration pursuant to section 307(d)(7)(B)
of the CAA from General Electric (GE), the Natural Resources Defense
Council (NRDC), and Environmental Integrity Project (EIP).\1\

Under this section, the Administrator is to initiate reconsideration
proceedings if the petitioner can show that it was impracticable to
raise an objection to a rule within the public comment period or that
the grounds for the objection arose after the public comment period.
---------------------------------------------------------------------------

    \1\ In addition to the petitions for reconsideration, two
petitions for judicial review of the final rule were filed with the
U.S. Court of Appeals for the District of Columbia by NRDC, Sierra
Club, and EIP (No. 04-1385, D.C. Cir.) and American Municipal
Power--Ohio and the Ohio cities of Dover, Hamilton, Orrville,
Painesville, Shelby, and St. Marys (No. 04-1386, D.C. Cir.). The two
cases have been consolidated. Eleven additional parties have filed
petitions to intervene: American Home Furnishings Alliance, Council
of Industrial Boiler Owners, American Forest and Paper Association,
American Chemistry Council, National Petrochemical and Refiners
Association, American Petroleum Institute, National Oilseed
Processors Association, Coke Oven Environmental Task Force, Utility
Air Regulatory Group, and Alliance of Automobile Manufacturers are
intervening with regard to the health-based compliance alternatives.
---------------------------------------------------------------------------

    GE requested that EPA reconsider portions of the emissions
averaging provision that it believes could not have been practicably
addressed during the public comment period. In the alternative, GE
requested clarification that the final rule already allows for
consolidated testing of commonly vented boilers.
    By a letter dated April 27, 2005, we informed GE that we intended
to grant their petition for reconsideration. We indicated in that
letter that we would respond to the petition by publishing this notice
of proposed rulemaking.

III. Today's Action

    Today, we are granting reconsideration of the issue raised in the
GE petition for reconsideration. We agree that it was impracticable for
GE to raise its concern about implementation of the emissions averaging
provision until after the public comment period when the final
regulatory text was promulgated. Although we believe we provided
adequate notice and opportunity to comment on the emissions averaging
alternative, the specific regulatory text in 40 CFR 63.7522 was not
included in the notice of proposed rulemaking. Thus, we believe it is
appropriate to grant reconsideration to provide the public with the
opportunity to comment on how the emissions averaging alternative can
be applied to sources where boilers and process heaters are vented to
common stacks. As a result, we are requesting comment on this issue and
a proposed amendment to 40 CFR 63.7522 that would clarify the emissions
averaging provision and allow consolidated testing of commonly vented
boilers.
    In a separate notice, we have granted reconsideration of several of
the issues raised in the NRDC and EIP petition for reconsideration.
(See 70 FR 36907, June 27, 2005.) In that notice, we requested comment
on provisions in appendix A of subpart DDDDD and the health-based
compliance alternative for total selected metals reflected in 40 CFR
63.7507(b).
    Also, today we are proposing amendments to the final rule to
address several issues that were raised related to applicability and
implementation of the requirements in subpart DDDDD of 40 CFR part 63.
The proposed amendments to the final rule address these issues, correct
other inconsistencies that were discovered following promulgation, and
clarify some common applicability questions.

IV. Reconsideration of Emissions Averaging Provision

    Through today's notice, we request comments on how the emissions
averaging compliance alternative should be implemented when boilers are
vented to common stack and on the proposed amendment to 40 CFR 63.7522
addressing consolidated testing of commonly vented existing solid fuel
boilers. Stakeholders who would like for us to reconsider comments
relevant to this issue that they submitted to us previously should
identify the relevant docket entry numbers and page numbers of their
comments to facilitate expeditious review during the reconsideration
process.

1. Background

    In the notice of proposed rulemaking, we described approaches that
we might use to implement an emissions averaging compliance
alternative. (See 68 FR 1686.) We discussed an emissions averaging
option that would allow owners and operators to set emissions limits
for each existing boiler in the same subcategory such that if these
limits are met, the total emissions from all existing boilers in the
subcategory would be less than or equal to the proposed emissions limit
for the subcategory. In addition, we also discussed that the emissions
averaging option would not be applicable to new sources and could only
be used between boilers in the same subcategory. We solicited comments
on the emissions averaging option and whether EPA should include the
emissions averaging option in the final rule.
    In the final rule, we included an emissions averaging provision
because we agreed with commenters that emissions averaging represents
an equivalent, more flexible, and less costly alternative to
controlling certain emission points to MACT levels. We also recognized
that we must ensure that any emissions averaging option can be
implemented and enforced, will be clear to sources, and most
importantly, will achieve no less emissions reductions than unit by
unit implementation of the MACT requirements.
    The emissions averaging provision in the final rule requires each
facility that intends to utilize emissions averaging to submit an
implementation plan for emissions averaging to the applicable
regulatory authority for review and approval. In this implementation
plan, the facility must include the identification of: (1) All units in
the averaging group; (2) the control technology installed; (3) the
process parameter that will be monitored; (4) the specific control
technology or pollution prevention measure to be used; (5) the test
plan for the measurement of particulate matter (or selected total
metals), hydrogen chloride, or mercury emissions; and (6) the operating
parameters to be monitored for each control device. The regulatory
authority will not approve emission averaging plans containing
averaging between emissions of different types of pollutants, averaging
between sources in different subcategories, or averaging that includes
new sources or unaffected sources.
    In the final rule, we established procedures for demonstrating
compliance by emissions averaging and codified them in 40 CFR 63.7522.
The preamble to the final rule also contained a summary of our response
to significant comments. (See 69 FR 55238.)
    GE's concerns regarding the emissions averaging provision relate to
the manner in which testing must be conducted to demonstrate
compliance. They believe the final rule could be read to impose
unreasonable limitations on the use of emissions averaging because the
equations used to demonstrate compliance employ a variable defined as
the emission rate for each boiler. GE is requesting that we reconsider
that the final rule be amended to allow the source to conduct one test
on a group of boilers that vents through a common stack rather than to
require individual tests on each boiler. In the alternative, GE also
requested clarification that the rule already allows for consolidated
testing of commonly vented boilers.

2. Proposed Action and Request for Comment

    We agree that the current language in the emissions averaging
options requires testing of each individual boiler in the averaging
group. However, our intent with regard to the emissions averaging
option in the final rule was to provide an equivalent, more flexible,
and less costly compliance alternative. Since testing emissions from a
common stack for a group of boilers would be equivalent to the average
emissions calculated from emissions tests on each individual boiler, we
are proposing to allow testing of emissions at the common stack under
specified situations. Specifically, we are

proposing to allow testing of a common stack only for the situations
where each of the units vented to the common stack are in the existing
solid fuel subcategory. This is because the emissions averaging
provision in 40 CFR 63.7522 is only applicable to existing large solid
fuel boilers. Therefore, testing of a common stack in these situations
will result in demonstrating the average emissions from this particular
averaging group of boilers, just as if each boiler was tested
individually and their emissions averaged.
    Allowing the testing of a common stack for only these specific
situations also satisfies the criteria discussed in the preamble to the
final rule (69 FR 55239) that EPA has generally imposed on the scope
and nature of emissions averaging programs. These criteria include: (1)
No averaging between different types of pollutants, (2) no averaging
between sources that are not part of the same major source, (3) no
averaging between sources within the same major source that are not
subject to the same NESHAP, and (4) no averaging between existing
sources and new sources. The proposed amendment fully satisfies each of
these criteria.
    GE is seeking clarification on two different common stack
situations. In one situation, the exhaust from three existing large
solid fuel boilers are combined and vented through a common emissions
control system to a common stack. In the other situation, the exhaust
from two existing large solid fuel boilers are each individually
controlled prior to being vented to a common stack.
    In the proposed regulatory provisions set forth below, we propose
to treat a group of boilers that vents through a common emissions
control system to a common stack as a single existing solid fuel boiler
for purposes of subpart DDDDD. The common control situation is more of
an applicability issue. This common control issue has been addressed in
past rulemakings (e.g., Standard of Performance for Primary Aluminum
Reduction Plants, 40 CFR 60.190) where the affected source was defined
as an uncontrolled unit, unit which is controlled individually, or a
group of units ducted to a common control system. A group of similar
units ducted through a common control system would be determined to be
a single controlled source for the purpose of demonstrating compliance.
Thus, we are proposing this amendment to address and clarify
applicability and implementation issues.
    However, we propose a slightly different approach for averaging
groups that vent to a common stack through more than one emissions
control system. These distinct approaches are necessary to ensure that
a source with more than one emissions control system can demonstrate
continuous compliance at each emissions control system.
    Where a group of boilers vents to a common stack through more than
one emission control system, continuous compliance will be demonstrated
according to the methods specified in table 8 to subpart DDDDD. If each
of the boilers venting to the common stack have an applicable opacity
operating limit, then a single continuous opacity monitoring system
(COMS) may be located in the common stack instead of each duct to the
common stack. If any of the boilers venting to the common stack do not
have an applicable opacity operating limit, then the appropriate
operating limit in tables 2 through 4 to subpart DDDDD that applies to
each boiler must be met.
    Testing of the common stack must be conducted when each boiler is
operated under representative testing conditions as specified in the
National Stack Testing Guidance issued by EPA on February 2, 2004.
    In addition, we are proposing that the common stack situations
described above may be treated as a separate single emission point for
purpose of including in a larger emissions averaging group with other
existing large solid fuel boilers located at the facility.
    We are not requesting comment on other aspects of the emissions
averaging provision.

V. Proposed Clarifying Amendments and Technical Corrections

    We identified minor drafting errors and inadvertent omissions after
promulgation of the industrial boiler and process heater NESHAP. Thus,
in addition to reconsidering the issue discussed above, we are
proposing to make the following definition clarifications and
corrections to 40 CFR part 63, subpart DDDDD.

A. What clarifications are proposed to the definitions?

    We are proposing to insert the word ``other'' in the definitions in
40 CFR 63.7575 for ``small gaseous fuel subcategory'' and ``small
liquid fuel subcategory,'' in order to make these definitions
consistent with the definition for ``small solid fuel subcategory.''
This omission has caused confusion in determining the applicability of
firetube boilers with heat input capacities greater than 10 million
British thermal units (Btu) per hour.
    In addition, we are proposing to amend the definitions in 40 CFR
63.7575 for ``large gaseous fuel subcategory,'' ``large liquid fuel
subcategory,'' and ``large solid fuel subcategory'' to make them
consistent with the definitions in 40 CFR 63.7575 for the various
``limited use'' subcategories. We are proposing to replace the phrase
``has an annual capacity factor of greater than 10 percent'' with the
phrase ``does not have a federally enforceable annual average capacity
factor of equal to or less than 10 percent'' to clarify that only large
units having a permit limitation on their annual average capacity
factor of 10 percent or less are considered in the limited use
subcategories.
    We are also proposing to amend the definitions of ``firetube
boiler'' and ``watertube boiler'' in 40 CFR 63.7575 to address boilers
designed with both firetubes and watertubes, commonly referred to as
``hybrid boilers.'' EPA is aware of three ``hybrid boiler'' designs:
(1) Watertube boilers that incorporate a secondary firetube section to
extract additional heat from the combustion gases; (2) firetube boilers
designed with watertubes that function to improve the operation and
efficiency of the firetube boiler, not to increase steam generating
capacity; and (3) boilers designed with both firetubes and watertubes,
in which both the firetubes and watertubes function for the purpose of
steam generation.
    We are proposing to classify watertube boilers that incorporate
firetubes for additional heat recovery as watertube boilers for the
purpose of the final rule since the unit combustion zone incorporates a
watertube design. As discussed in the proposal (68 FR 1671), it is the
design of the boiler's combustion zone that will influence the
formation of organic hazardous air pollutants (HAP) emissions and was
one of the bases for creating the subcategories.
    We are proposing to treat firetube boilers that are designed with
watertubes that function for purposes other than for steam generation,
for example to reduce maintenance, enhance efficiency, reduce
emissions, or increase fuel flexibility as firetube boilers for the
purpose of the final rule since the unit combustion zone incorporates a
firetube design. Again, it is the design of the boiler's combustion
zone that will influence the formation of organic HAP emissions and was
one of the bases for creating the subcategories.
    EPA is aware that there may be other hybrid designs that are not
specifically

addressed by the amended definitions we are proposing today.
Applicability determinations for designs other than those described
above should be addressed on a case-by-case basis.
    We are also proposing to add in 40 CFR 63.7575 a definition for the
term ``equivalent,'' as this term is used in table 6 to subpart DDDDD,
to address questions concerning what types of test methods are
considered equivalent. In addition, there is some confusion regarding
how the term ``equivalent,'' as used in table 6 to subpart DDDDD, is
different from the terms ``alternative analytical method'' used in 40
CFR 63.7521 and ``alternative test method,'' as defined in 40 CFR 63.2
of the MACT General Provisions. This has raised the question of whether
the definitions of intermediate, major, and minor changes to a test
method in 40 CFR 63.90, apply in determining delegable authorities. The
answer is that EPA intended for the determination of ``equivalent'' for
table 6 to subpart DDDDD purposes, to be a category I authority,
potentially delegable to the State. However, EPA neglected to clearly
convey that message or provide a clear definition of ``equivalent'' for
table 6 to subpart DDDDD purposes to assure national consistency.
Because there are a large number of fuel types it is not practical to
identify and list all acceptable (equivalent) combinations of methods
and fuels in table 6 to subpart DDDDD. We do believe, however, that if
we make mandatory the use of a voluntary consensus standard (VCS) or
EPA method that states it is intended to at least match the fuel matrix
(solid, liquid, or gas) central to the definition of equivalent (for
table 6 to subpart DDDDD), then this can be a category I delegable
authority. A negative finding of equivalent would then invoke the
definitions of minor, intermediate, or major changes to a test method.
Following this logic, we have developed a definition of ``equivalent''
to determine if an alternate fuel analysis procedure is equivalent for
table 6 to subpart DDDDD purposes. An alternative is any deviation or
modification from the published VCS or EPA method as written. These
must be specifically noted and the need or reason for the alternative
explained. In general, alternatives that are necessary or improve the
data quality will be given priority review while those of convenience
only will be reviewed as time permits. Because of the potential for a
large number of sample analysis plans containing equivalent and
alternative methods and procedures, we encourage the applicant to
clearly denote alternative requests from equivalent requests and to
provide a complete rationale in order to expedite review.

B. What are the proposed corrections?

    A list of boilers and process heaters that are not subject to
subpart DDDDD of 40 CFR part 63 are contained in 40 CFR 63.791. As
stated in the proposal preamble, our intention was to exempt from the
final rule any units that are already or will be subject to regulation
for HAP under another standard. (See 69 FR 1663.) In terms of electric
utility steam generating units, regulations for HAP were only under
development at proposal and promulgation of subpart DDDDD of 40 CFR
part 63 and, therefore, we were unable to cite the exemption for
electric utility steam generating units to a specific regulation. The
exemption cited in 40 CFR 63.7491(c) for electric utility steam
generating units is the definition of electric utility steam generating
units contained in section 112(a)(8) of the CAA. On March 29, 2005 (70
FR 15995), EPA revised the regulatory finding that it issued in
December 2000, removing electric utility steam generating units from
the CAA section 112 source category list. EPA instead established
standards of performance for mercury from new and existing electric
utility steam generating units under the authority of section 111 of
the CAA. These standards of performance (subparts Da and HHHH of 40 CFR
part 60) regulating mercury from electric utility steam generating
units were promulgated on May 18, 2005 in the Clean Air Mercury Rule.
(See 70 FR 28606.) After we promulgated that rule, it was brought to
our attention that the scope of the exemption in subpart DDDDD of 40
CFR part 63 for electric utility steam generating units was unclear.
Confusion has resulted because subparts Da and HHHH employ different
definitions to determine applicability, consistent with the historical
applicability and definition determinations under CAA section 111 and
Acid Raid Programs. (See 70 FR at 28609.) Thus, to clarify
applicability of the final rule, we are proposing to modify 40 CFR
63.7491(c) to exclude ``an electric utility steam generating unit
(including a unit covered by 40 CFR part 60, subpart Da) and a Mercury
(Hg) Budget unit covered by 40 CFR part 60, subpart HHHH.'' The term
``electric utility steam generating unit'' is defined in 40 CFR 63.7575
of subpart DDDDD in accordance with the statutory definition in section
1121(a)(8) of the CAA.
    In 40 CFR 63.7522, we inadvertently omitted the equation for
determining continuous compliance with the emission limits when using
emissions averaging. Under the emissions averaging provision,
continuous compliance is based on a 12-month rolling average. We
corrected this omission by adding equation 4A to 40 CFR 63.7522(f).
    In 40 CFR 63.7525, we inadvertently omitted the requirement for
installing and operation of an oxygen monitor. According to the work
practice standard for carbon monoxide (CO) in table 1 to subpart DDDDD,
a new affected source must correct the CO data to a certain percent
oxygen. However, 40 CFR 7525(a) never explicitly states that an oxygen
monitor is required. We received inquiries on whether an oxygen monitor
is required to be installed if no oxygen monitor is currently in place.
Since the CO standard is only applicable to new units, we assumed that
all new units above 100 million Btu per hour heat input would also be
subject to the new source performance standard (subpart Db of 40 CFR
part 60) for industrial boilers which requires an oxygen monitor as
part of its monitoring requirement. Thus, we amended 40 CFR 63.7525 to
clarify that a corresponding oxygen monitor is required when a CO
monitor is required.
    As suggested by the American Society for Testing and Materials
(ASTM), several of the listed ASTM test methods in table 6 to subpart
DDDDD are being amended with updated ASTM test methods.

C. What are the Impacts Associated With the Amendments?

    The proposed amendments contained in this action are corrections
that are intended to clarify, but not change, the coverage of the final
rule. The amendments will not affect the estimated emissions reductions
or the control costs for the final rule. The clarifications and
corrections should make it easier for owners and operators and for
local and State authorities to understand and implement the
requirements.

VI. Statutory and Executive Order Reviews

A. Executive Order 12866: Regulatory Planning and Review

    Under Executive Order 12866 (58 FR 51735, October 4, 1993), EPA
must determine whether the regulatory action is ``significant'' and,
therefore, subject to review by the Office of Management and Budget
(OMB) and the requirements of the Executive Order. The Executive Order
defines a ``significant regulatory

action'' as one that is likely to result in a rule that may:
    (1) Have an annual effect on the economy of $100 million or more or
adversely affect in a material way the economy, a sector of the
economy, productivity, competition, jobs, the environment, public
health or safety, or State, local, or tribal governments or
communities;
    (2) Create a serious inconsistency or otherwise interfere with an
action taken or planned by another agency;
    (3) Materially alter the budgetary impact of entitlement, grants,
user fees, or loan programs, or the rights and obligations of
recipients thereof; or
    (4) Raise novel legal or policy issues arising out of legal
mandates, the President's priorities, or the principles set forth in
the Executive Order.
    Pursuant to the terms of Executive Order 12866, it has been
determined that today's proposed amendments do not constitute a
``significant regulatory action'' because they do not meet any of the
above criteria. Consequently, this action was not submitted to OMB for
review under Executive Order 12866.

B. Paperwork Reduction Act

    The information collection requirements in the final rule were
submitted for approval to OMB under the provisions of the Paperwork
Reduction Act, 44 U.S.C. 3501 et seq. (Information Collection Request
No. 2028.01 and OMB Control Number 2060-0551). The information
collection requirements are not enforceable until OMB approves them.
    Today's notice of reconsideration imposes no new information
collection requirements on the industry. Because there is no additional
burden on the industry as a result of the notice, the ICR has not been
revised.
    Burden means the total time, effort, or financial resources
expended by persons to generate, maintain, retain, or disclose or
provide information to or for a Federal agency. This includes the time
needed to review instructions; develop, acquire, install, and utilize
technology and systems for the purposes of collecting, validating, and
verifying information, processing and maintaining information, and
disclosing and providing information; adjust the existing ways to
comply with any previously applicable instructions and requirements;
train personnel to be able to respond to a collection of information;
search data sources; complete and review the collection of information;
and transmit or otherwise disclose the information.
    An agency may not conduct or sponsor, and a person is not required
to respond to, a collection of information unless it displays a
currently valid OMB control number. The OMB control numbers for EPA's
regulations are listed in 40 CFR part 9 and 48 CFR chapter 15.

C. Regulatory Flexibility Act

    The Regulatory Flexibility Act generally requires an agency to
prepare a regulatory flexibility analysis of any rule subject to notice
and comment rulemaking requirements under the Administrative Procedure
Act or any other statute unless the agency certifies that the rule will
not have a significant economic impact on a substantial number of small
entities. Small entities include small businesses, small not-for-profit
enterprises, and small governmental jurisdictions.
    For purposes of assessing the impact of today's notice of
reconsideration on small entities, a small entity is defined as: (1) A
small business having no more than 500 to 750 employees, depending on
the business' NAICS code; (2) a small governmental jurisdiction that is
a government of a city, country, town, school district or special
district with a population of less than 50,000; and (3) a small
organization that is any not-for-profit enterprise which is
independently owned and operated and that is not dominant in its field.
    After considering the economic impacts of today's notice of
reconsideration on small entities, we certify that the notice will not
have a significant economic impact on a substantial number of small
entities. EPA has determined that none of the small entities will
experience a significant impact because the notice imposes no
additional regulatory requirements on owners or operators of affected
sources. We continue to be interested in the potential impacts of the
proposed rule on small entities and welcome comments on issues related
to such impacts.

D. Unfunded Mandates Reform Act

    Title II of the Unfunded Mandates Reform Act of 1995 (UMRA), Public
Law 104-4, establishes requirements for Federal agencies to assess the
effects of their regulatory actions on State, local, and tribal
governments and the private sector. Under section 202 of the UMRA, EPA
generally must prepare a written statement, including a cost-benefit
analysis, for proposed and final rules with ``Federal mandates'' that
may result in expenditures by State, local, and tribal governments, in
the aggregate, or by the private section, of $100 million or more in
any 1 year. Before promulgating an EPA rule for which a written
statement is needed, section 205 of the UMRA generally requires EPA to
identify and consider a reasonable number of regulatory alternatives
and adopt the least costly, most cost-effective, or least-burdensome
alternative that achieves the objectives of the rule. The provisions of
section 205 do not apply when they are inconsistent with applicable
law. Moreover, section 205 allows EPA to adopt an alternative other
than the least-costly, most cost-effective, or least-burdensome
alternative if the Administrator publishes with the final rule an
explanation why that alternative was not adopted. Before EPA
establishes any regulatory requirements that may significantly or
uniquely affect small governments, including tribal governments, it
must have developed, under section 203 of the UMRA, a small government
agency plan. The plan must provide for notifying potentially affected
small governments, enabling officials of affected small governments to
have meaningful and timely input in the development of EPA's regulatory
proposals with significant Federal intergovernmental mandates, and
informing, educating, and advising small governments on compliance with
the regulatory requirements.
    EPA has determined that today's notice of reconsideration does not
contain a Federal mandate that may result in expenditures of $100
million or more for State, local, and tribal governments, in the
aggregate, or the private sector in any one year. Although the final
rule had annualized costs estimated to range from $690 to $860 million
(depending on the number of facilities eventually demonstrating
eligibility for the health-based compliance alternatives), today's
notice does not add new requirements that would increase this cost.
Thus, today's notice of reconsideration is not subject to the
requirements of sections 202 and 205 of the UMRA. In addition, EPA has
determined that today's notice does not significantly or uniquely
affect small governments because it contains no requirements that apply
to such governments or impose obligations upon them. Therefore, today's
notice of reconsideration is not subject to section 203 of the UMRA.

E. Executive Order 13132: Federalism

    Executive Order 13132 (64 FR 43255, August 10, 1999) requires EPA
to develop an accountable process to ensure ``meaningful and timely
input by State and local officials in the development of regulatory
policies that have federalism implications.'' ``Policies that have
federalism implications'' are defined in the Executive Order to

include regulations that have ``substantial direct effects on the
States, on the relationship between the national government and the
States, or on the distribution of power and responsibilities among the
various levels of government.''
    Today's notice of reconsideration does not have federalism
implications. It will not have substantial direct effects on the
States, on the relationship between the national government and the
States, or on the distribution of power and responsibilities among the
various levels of government, as specified in Executive Order 13132.
The requirements discussed in today's notice will not supersede State
regulations that are more stringent. Thus, Executive Order 13132 does
not apply to today's notice of reconsideration.

F. Executive Order 13175: Consultation and Coordination With Indian
Tribal Governments

    Executive Order 13175 (65 FR 67249, November 6, 2000) requires EPA
to develop an accountable process to ensure ``meaningful and timely
input by tribal officials in the development of regulatory policies
that have tribal implications.'' ``Policies that have tribal
implications'' are defined in the Executive Order to include
regulations that have ``substantial direct effects on one or more
Indian tribes, on the relationship between the Federal government and
Indian tribes, or on the distribution of power and responsibilities
between the Federal government and Indian tribes.''
    Today's notice of reconsideration does not have tribal
implications. It will not have substantial direct effects on tribal
governments, on the relationship between the Federal government and
Indian tribes, or the distribution of power and responsibilities
between the Federal government and Indian tribes, as specified in
Executive Order 13175. No affected facilities are owned or operated by
Indian tribal governments. Thus, Executive Order 13175 does not apply
to today's notice of reconsideration.

G. Executive Order 13045: Protection of Children From Environmental
Health and Safety Risks

    Executive Order 13045 (62 FR 19885, April 23, 1997) applies to any
rule that: (1) Is determined to be ``economically significant,'' as
defined under Executive Order 12866, and (2) concerns an environmental
health or safety risk that EPA has reason to believe may have a
disproportionate effect of children. If the regulatory action meets
both criteria, EPA must evaluate the environmental health or safety
effects of the planned rule on children and explain why the planned
regulation is preferable to other potentially effective and reasonably
feasible alternatives considered by EPA.
    Today's notice of reconsideration is not subject to the Executive
Order because EPA does not have reasons to feel that the environmental
health or safety risks associated with the emissions addressed by this
notice present a disproportionate risk to children. This demonstration
is based on the fact that the noncancer human health values we used in
our analysis at promulgation (e.g., reference concentrations) are
determined to be protective of sensitive subpopulations, including
children. Also, while the cancer human health values do not always
expressly account for cancer effects in children, the cancer risks
posed by facilities that meet the eligibility criteria for the health-
based compliance alternatives will be sufficiently low so as not be a
concern for anyone in the population, including children. The public is
invited to submit or identify peer-reviewed studies and data, of which
the agency may not be aware, that assessed results of early life
exposure to [the product, substance or other vector proposed for
regulation.]

H. Executive Order 13211: Actions That Significantly Affect Energy
Supply, Distribution, or Use

    This rule is not subject to Executive Order 13211, ``Actions
Concerning Regulations That Significantly Affect Energy Supply,
Distribution, or Use'' (66 FR 28355 (May 22, 2001)) because it is not a
significant regulatory action under Executive Order 12866.

I. National Technology Transfer and Advancement Act

    As noted in the final rule, section 12(d) of the National
Technology Transfer and Advancement Act (NTTAA) of 1995 (Pub. L. No.
104-113; 15 U.S.C. 272 note) directs EPA to use voluntary consensus
standards in their regulatory and procurement activities unless to do
so would be inconsistent with applicable law or otherwise
impracticable. Voluntary consensus standards are technical standards
(e.g., material specifications, test methods, sampling procedures,
business practices) developed or adopted by one or more voluntary
consensus bodies. The NTTAA requires EPA to provide Congress, through
the OMB, with explanations when EPA decides not to use available and
applicable voluntary consensus standards.
    Today's amendments involve technical standards. EPA cites the
following standards in the proposed rulemaking: (1) American Society
for Testing and Materials (ASTM) D2013-04, ``Standard Practice for
Preparing Coal Samples for Analysis,'' (2) ASTM D2234-D2234M-03E01,
``Standard Practice for Collection of a Gross Sample of Coal,'' (3)
ASTM D6721-01, ``Standard Test Method for Determination of Chlorine in
Coal by Oxidative Hydroylsis Microcoulometry,'' (4) ASTM D3173-03,
``Standard Test Method for Moisture in the Analysis Sample of Coal and
Coke,'' (5) ASTM D4606-03, ``Standard Test Method for Determination of
Arsenic and Selenium in Coal by the Hydride Generation/Atomic
Absorption Method,'' (6) ASTM D6357-04, ``Standard Test Methods for
Determination of Trace Elements in Coal, Coke, and Combustion Residues
from Coal Utilization Processes by Inductively Coupled Plasma Atomic
Emission Spectrometry, Inductively Coupled Plasma Mass Spectrometry,
and Graphite Furnace Atomic Absorption Spectrometry,'' (7) ASTM D6722-
01, ``Standard Test Method for Total Mercury in Coal and Coal
Combustion Residues by the Direct Combustion Analysis,'' and (8) ASTM
D5865-04, ``Standard Test Method for Gross Clorific Value of Coal and
Coke.''
    During the development of the final rule, EPA searched for
voluntary consensus standards that might be applicable. The search
identified three voluntary consensus standards that were considered
practical alternatives to the specified EPA test methods. As assessment
of these and other voluntary consensus standards is presented in the
preamble to the final rule. (See 69 FR 55251, September 13, 2004.)
    Table 6 to subpart DDDDD of 40 CFR part 63 list the fuel analysis
methods included in the final rule. Under 40 CFR 63.7(f) in subpart A
of the General Provisions, a source may apply to EPA for permission to
use alternative test methods or alternative monitoring requirements in
place of any required testing methods, performance specifications, or
procedures.

List of Subject in 40 CFR Part 63

    Environmental protection, Administrative practice and procedures,
Air pollution control, Hazardous substances, Intergovernmental
relations, Reporting and recordkeeping requirements.

    Dated: October 21, 2005.
Stephen L. Johnson,
Administrator.
    For the reasons stated in the preamble, title 40, chapter 1, of the
code of Federal Regulations is proposed to be amended as follows:

PART 63--[AMENDED]

    1. The authority citation for part 63 continues to read as follows:

    Authority: 42 U.S.C. 7401, et seq.

Subpart A--[Amended]

    2. Section 63.14 is amended by adding paragraphs (b)(55) through
(62) to read as follows:

Sec.  63.14  Incorporation by reference.

* * * * *
    (b) * * *
    (55) ASTM D2013-04, Standard Practice for Preparing Coal Samples
for Analysis, IBR approved for Table 6 to subpart DDDDD of this part.
    (56) ASTM D2234-D2234M-03E01, Standard Practice for Collection of a
Gross Sample of Coal, IBR approved for Table 6 to subpart DDDDD of this
part.
    (57) ASTM D6721-01, Standard Test Method for Determination of
Chlorine in Coal by Oxidative Hydrolysis Microcoulometry, IBR approved
for Table 6 to subpart DDDDD of this part.
    (58) ASTM D3173-03, Standard Test Method for Moisture in the
Analysis Sample of Coal and Coke, IBR approved for Table 6 to subpart
DDDDD of this part.
    (59) ASTM D4606-03, Standard Test Method for Determination of
Arsenic and Selenium in Coal by the Hydride Generation/Atomic
Absorption Method, IBR approved for Table 6 to subpart DDDDD of this
part.
    (60) ASTM D6357-04, Standard Test Methods for Determination of
Trace Elements in Coal, Coke, and Combustion Residues from Coal
Utilization Processes by Inductively Coupled Plasma Atomic Emission
Spectrometry, Inductively Coupled Plasma Mass Spectrometry, and
Graphite Furnace Atomic Absorption Spectrometry, IBR approved for Table
6 to subpart DDDDD of this part.
    (61) ASTM D6722-01, Standard Test Method for Total Mercury in Coal
and Coal Combustion Residues by the Direct Combustion Analysis, IBR
approved for Table 6 to subpart DDDDD of this part.
    (62) ASTM D5865-04, Standard Test Method for Gross Calorific Value
of Coal and Coke, IBR approved for Table 6 to subpart DDDDD of this
part.
* * * * *

Subpart DDDDD--[Amended]

    3. Section 63.7491 is amended by revising paragraph (c) to read as
follows:

Sec.  63.7491  Are any boilers or process heaters not subject to this
subpart?

* * * * *
    (c) An electric utility steam generating unit (including a unit
covered by 40 CFR part 60, subpart Da) and a Hg Budget unit covered by
40 CFR part 60, subpart HHHH.
* * * * *
    4. Section 63.7522 is amended by revising paragraphs (b) and (c)
and by adding paragraphs (f)(3) and (h) through (k) to read as follows:

Sec.  63.7522  Can I use emission averaging to comply with this
subpart?

* * * * *
    (b) Separate stack requirements. For a group of two or more
existing large solid fuel boilers that each vent to a separate stack,
you may average particulate matter or TSM, HCl and mercury emissions to
demonstrate compliance with the limits in Table 1 of this subpart if
you satisfy the requirements in paragraphs (c), (d), (e), (f), and (g)
of this section.
    (c) For each existing large solid fuel boiler in the averaging
group, the emission rate achieved during the initial compliance test
for the HAP being averaged must not exceed the emission level that was
being achieved on November 12, 2004 or the control technology employed
during the initial compliance test must not be less effective for the
HAP being averaged than the control technology employed on November 12,
2004.
* * * * *
    (f) * * *
    (3) Until 12 monthly emission rates have been accumulated,
calculate and report only the monthly averages. Then, for each
subsequent calendar month, use Equation 4A of this section to calculate
the 12-month rolling average as a weighted average of the emission rate
for the current month and the emission rates for the previous 11
months.
[GRAPHIC] [TIFF OMITTED] TP31OC05.000

Where:

Eavg = 12-month rolling average emission rate, (pounds per
million Btu heat input)
ERi = Monthly emission rate, for month ``i'', (pounds per
million Btu heat input)
* * * * *
    (h) Common stack requirements. For a group of two or more existing
large solid fuel boilers, each of which vents through a single common
stack that does not receive emissions from units in other subcategories
or nonaffected units, you may average particulate matter or TSM, HCl
and mercury to demonstrate compliance with the limits in Table 1 of
this subpart if you satisfy the requirements in paragraphs (i) or (j)
of this section.
    (i) For a group of two or more existing large solid fuel boilers,
each of which vents through a common emissions control system to a
common stack you may treat such averaging group as a single existing
solid fuel boiler for purposes of subpart DDDDD and comply with the
requirements of this subpart as if the group were a single boiler.
    (j) For all other groups of boilers subject to paragraph (h) of
this section, the owner or operator shall:
    (1) Conduct performance tests according to procedures specified in
Sec.  63.7520 in the common stack; and
    (2) Conduct monitoring, as appropriate, according to requirements
specified in Sec.  63.7525 in the common stack; and
    (3) Meet the applicable operating limit specified in Sec.  63.7540
and table 8 for each emissions control system.
    (k) Combination requirements. The common stack of a group of two or
more boilers subject to paragraph (h) may be treated as a separate
stack for purposes of paragraph (b) of this section and included in an
emissions averaging group subject to paragraph (b) of this section.
    5. Section 63.7525 of subpart DDDDD is amended by revising
paragraphs (a) introductory text and (a)(1) to read as follows:

Sec.  63.7525  What are my monitoring, installation, operation, and
maintenance requirements?

    (a) If you have an applicable work practice standard for carbon
monoxide, and your boiler or process heater is in any of the large
subcategories and has a heat input capacity of 100 MMBtu per hour or
greater, you must install, operate, and maintain a continuous emission
monitoring system (CEMS) for carbon monoxide and oxygen according to
the procedures in paragraphs (a)(1) through (6) of this section by the
compliance date specified in Sec.  63.7495. The carbon monoxide and
oxygen shall be monitored at the same location at the outlet of the
boiler or process heater.
    (1) Each CEMS must be installed, operated, and maintained according
to the applicable procedures under Performance Specification (PS) 3 or
4A

of 40 CFR part 60, appendix B, and according to the site-specific
monitoring plan developed according to Sec.  63.7505(d).
* * * * *
    6. Section 63.7575 of subpart DDDDD is amended as follows:
    a. By adding a new definition in alphabetical order for
``Equivalent''.
    b. By revising the definitions for ``Firetube boiler'', ``Large
gaseous fuel subcategory'', ``Large liquid fuel subcategory'', ``Large
solid fuel subcategory'', ``Small gaseous fuel subcategory'', ``Small
liquid fuel subcategory'' and ``Watertube boiler''.

Sec.  63.7575  What definitions apply to this subpart?

* * * * *
    Equivalent means the following only when this term is used in Table
6 to subpart DDDDD:
    (1) An equivalent sample collection procedure means a published
voluntary consensus standard or practice (VCS) or EPA method that
includes collection of a minimum of three composite fuel samples, with
each composite consisting of a minimum of three increments collected at
approximately equal intervals over the test period.
    (2) An equivalent sample compositing procedure means a published
VCS or EPA method to systematically mix and obtain a representative
subsample (part) of the composite sample.
    (3) An equivalent sample preparation procedure means a published
VCS or EPA method that: Clearly states that the standard, practice or
method is appropriate for the pollutant and the fuel matrix or; is
cited as an appropriate sample preparation standard, practice or method
for the pollutant in the chosen VCS or EPA determinative or analytical
method.
    (4) An equivalent procedure for determining heat content means a
published VCS or EPA method to obtain gross calorific (or higher
heating) value.
    (5) An equivalent procedure for determining fuel moisture content
means a published VCS or EPA method to obtain moisture content. If the
sample analysis plan calls for determining metals (especially the
mercury, selenium, or arsenic) using an aliquot of the dried sample,
then the drying temperature must be modified to prevent vaporizing
these metals. On the other hand, if metals analysis is done on an ``as
received'' basis, a separate aliquot can be dried to determine moisture
content and the metals concentration mathematically adjusted to a dry
basis.
    (6) An equivalent pollutant (mercury, TSM, or total chlorine)
determinative or analytical procedure means a published VCS or EPA
method that clearly states that the standard, practice or method is
appropriate for the pollutant and the fuel matrix and has a published
detection limit equal or lower than the methods listed in Table 6 to
subpart DDDDD for the same purpose.
* * * * *
    Firetube boiler means a boiler in which hot gases of combustion
pass through the tubes and water contacts the outside surfaces of the
tubes. Firetube boilers that incorporate watertubes into their design
for purposes other than for steam generation, for example, to reduce
maintenance, enhance efficiency, reduce emissions, or increase fuel
flexibility are considered to be firetube boilers.
* * * * *
    Large gaseous fuel subcategory includes any watertube boiler or
process heater that burns gaseous fuels not combined with any solid
fuels, burns liquid fuel only during periods of gas curtailment or gas
supply emergencies, has a rated capacity of greater than 10 MMBtu per
hour heat input, and does not have a federally enforceable annual
average capacity factor of equal to or less than 10 percent.
    Large liquid fuel subcategory includes any watertube boiler or
process heater that does not burn any solid fuel and burns any liquid
fuel either alone or in combination with gaseous fuels, has a rated
capacity of greater than 10 MMBtu per hour heat input, and does not
have a federally enforceable annual average capacity factor of equal to
or less than 10 percent. Large gaseous fuel boilers and process heaters
that burn liquid fuel during periods of gas curtailment or gas supply
emergencies are not included in this definition.
    Large solid fuel subcategory includes any watertube boiler or
process heater that burns any amount of solid fuel either alone or in
combination with liquid or gaseous fuels, has a rated capacity of
greater than 10 MMBtu per hour heat input, and does not have a
federally enforceable annual average capacity factor of equal to or
less than 10 percent.
* * * * *
    Small gaseous fuel subcategory includes any firetube boiler that
burns gaseous fuels not combined with any solid fuels and burns liquid
fuel only during periods of gas curtailment or gas supply emergencies,
and any other boiler or process heater that burns gaseous fuels not
combined with any solid fuels, burns liquid fuel only during periods of
gas curtailment or gas supply emergencies, and has a rated capacity of
less than or equal to 10 MMBtu per hour heat input.
    Small liquid fuel subcategory includes any firetube boiler that
does not burn any solid fuel and burns any liquid fuel either alone or
in combination with gaseous fuels, and any other boiler or process
heater that does not burn any solid fuel and burns any liquid fuel
either alone or in combination with gaseous fuels, and has a rated
capacity of less than or equal to 10 MMBtu per hour heat input. Small
gaseous fuel boilers and process heaters that burn liquid fuel during
periods of gas curtailment or gas supply emergencies are not included
in this definition.
* * * * *
    Watertube boiler means a boiler in which water passes through the
tubes and hot gases of combustion pass over the outside surface of the
tubes. Watertube boilers that incorporate a secondary firetube section
to extract additional heat from the combustion gases are considered to
be watertube boilers. Boilers that incorporate both firetubes and
watertubes into their design, such that primary function of both the
firetubes and watertubes is steam generation, are considered watertube
boilers for the purpose of this subpart.
* * * * *
    7. Table 6 to subpart DDDDD is revised to read as follows:

    Table 6 to Subpart DDDDD of Part 63.--Fuel Analysis Requirements
    [As stated in Sec.   63.7521, you must comply with the following
       requirements for fuel analysis testing for existing, new or
                    reconstructed affected sources:]
------------------------------------------------------------------------
 To conduct a fuel analysis
      for the following            You must...            Using...
        pollutant...
------------------------------------------------------------------------
1. Mercury..................  a. Collect fuel       Procedure in Sec.
                               samples.              63.7521(c) or ASTM
                                                     D2234-D2234M-03E01
                                                     (for coal) (IBR,
                                                     see Sec.
                                                     63.14(b)) or ASTM
                                                     D6323-98 (2003)
                                                     (for biomass) (IBR,
                                                     see Sec.
                                                     63.14(b)) or
                                                     equivalent.
                              b. Composite fuel     Procedure in Sec.
                               samples.              63.7521(d) or
                                                     equivalent.
                              c. Prepare            SW-846-3050B (for
                               composited fuel       solid samples) or
                               samples.              SW-846-3020A (for
                                                     liquid samples) or
                                                     ASTM D2013-04 (for
                                                     coal) (IBR, see
                                                     Sec.   63.14(b)) or
                                                     ASTM D5198-92
                                                     (2003) (for
                                                     biomass) (IBR, see
                                                     Sec.   63.14(b)) or
                                                     equivalent.
                              d. Determine heat     ASTM D5865-04 (for
                               content of the fuel   coal) (IBR, see
                               type.                 Sec.   63.14(b)) or
                                                     ASTM E711-87 (1996)
                                                     (for biomass) (IBR,
                                                     see Sec.
                                                     63.14(b)) or
                                                     equivalent.
                              e. Determine          ASTM D3173-03 (IBR,
                               moisture content of   see Sec.
                               the fuel type.        63.14(b)) or ASTM
                                                     E871-82 (1998)
                                                     (IBR, see Sec.
                                                     63.14(b)) or
                                                     equivalent.
                              f. Measure mercury    ASTM D6722-01 (for
                               concentration in      coal) (IBR, see
                               fuel sample.          Sec.   63.14(b)) or
                                                     SW-846-7471A (for
                                                     solid samples) or
                                                     SW-846-7470A (for
                                                     liquid samples) or
                                                     equivalent.
                              g. Convert            ....................
                               concentrations into
                               units of pounds of
                               pollutant per MMBtu
                               of heat content.
2. Total Selected metals....  a. Collect fuel       Procedure in Sec.
                               samples.              63.7521(c) or ASTM
                                                     D2234-D2234M-03E01
                                                     (for coal) (IBR,
                                                     see Sec.
                                                     63.14(b)) or ASTM
                                                     D6323-98 (2003)
                                                     (for biomass) (IBR,
                                                     see Sec.
                                                     63.14(b)) or
                                                     equivalent.
                              b. Composite fuel     Procedure in Sec.
                               samples.              63.7521(d) or
                                                     equivalent.
                              c. Prepare            SW-846-3050B (for
                               composited fuel       solid samples) or
                               samples.              SW-846-3020A (for
                                                     liquid samples) or
                                                     ASTM D2013-04 (for
                                                     coal) (IBR, see
                                                     Sec.   63.14(b)) or
                                                     ASTM D5198-92
                                                     (2003) (for
                                                     biomass) (IBR, see
                                                     Sec.   63.14(b)) or
                                                     equivalent.
                              d. Determine heat     ASTM D5865-04 (for
                               content of the fuel   coal) (IBR, see
                               type.                 Sec.   63.14(b)) or
                                                     ASTM E711-87 (for
                                                     biomass) (IBR, see
                                                     Sec.   63.14(b)) or
                                                     equivalent.
                              e. Determine          ASTM D3173-03 (IBR,
                               moisture content of   see Sec.
                               the fuel type.        63.14(b)) or ASTM
                                                     E871 (IBR, see Sec.
                                                       63.14(b)) or
                                                     equivalent.
                              f. Measure total      SW-846-6010B or ASTM
                               selected metals       D6357-04 (for
                               concentration in      arsenic, beryllium,
                               fuel sample.          cadmium, chromium,
                                                     lead, manganese,
                                                     and nickel in coal)
                                                     and ASTM D4606-03
                                                     (for selenium in
                                                     coal) (IBR, see
                                                     Sec.   63.14(b)) or
                                                     ASTM E885-88 (1996)
                                                     (for biomass) (IBR,
                                                     see Sec.
                                                     63.14(b)) or
                                                     equivalent.
                              g. Convert            ....................
                               concentrations into
                               units of pounds of
                               pollutant per MMBtu
                               of heat content.
3. Hydrogen chloride........  a. Collect fuel       Procedure in Sec.
                               samples.              63.7521(c) or ASTM
                                                     D2234-D2234M-03E01
                                                     (for coal) (IBR,
                                                     see Sec.
                                                     63.14(b)) or ASTM
                                                     D6323-98 (2003)
                                                     (for biomass) (IBR,
                                                     see Sec.
                                                     63.14(b)) or
                                                     equivalent.
                              b. Composite fuel     Procedure in Sec.
                               samples.              63.7521(d) or
                                                     equivalent.
                              c. Prepare            SW-846-3050B (for
                               composited fuel       solid samples) or
                               samples.              SW-846-3020A (for
                                                     liquid samples) or
                                                     ASTM D2013-04 (for
                                                     coal) (IBR, see
                                                     Sec.   63.14(b)) or
                                                     ASTM D5198-92
                                                     (2003) (for
                                                     biomass) (IBR, see
                                                     Sec.   63.14(b)) or
                                                     equivalent.
                              d. Determine heat     ASTM D5865-04 (for
                               content of the fuel   coal) (IBR, see
                               type.                 Sec.   63.14(b)) or
                                                     ASTM E711-87 (1996)
                                                     (for biomass) (IBR,
                                                     see Sec.
                                                     63.14(b)) or
                                                     equivalent.
                              e. Determine          ASTM D3173-03 (IBR,
                               moisture content of   see Sec.
                               the fuel type.        63.14(b)) or ASTM
                                                     E871-82 (1998)
                                                     (IBR, see Sec.
                                                     63.14(b)) or
                                                     equivalent.

                              f. Measure chlorine   SW-846-9250 or ASTM
                               concentration in      D6721-01 (for coal)
                               fuel sample.          or ASTM E776-87
                                                     (1996) (for
                                                     biomass) (IBR, see
                                                     Sec.   63.14(b)) or
                                                     equivalent.
                              g. Convert            ....................
                               concentrations into
                               units of pounds of
                               pollutant per MMBtu
                               of heat content.
------------------------------------------------------------------------

[FR Doc. 05-21531 Filed 10-28-05; 8:45 am]

BILLING CODE 6560-50-P


[Federal Register Volume 84, Number 152 (Wednesday, August 7, 2019)]
[Notices]
[Pages 38621-38624]
[FR Doc No: 2019-16861]

-----------------------------------------------------------------------

DEPARTMENT OF ENERGY

Federal Energy Regulatory Commission

[Docket No. PF19-4-000]

Venture Global Delta LNG, LLC and Venture Global Delta Express,
LLC; Notice of Intent To Prepare an Environmental Impact Statement for
the Planned Delta LNG and Delta Express Pipeline Project, Request for
Comments on Environmental Issues, and Notice of Public Scoping Session

    The staff of the Federal Energy Regulatory Commission (FERC or
Commission) will prepare an environmental impact statement (EIS) that
will discuss the environmental impacts of the Delta LNG and Delta
Express Pipeline Project (Project) involving construction and operation
of facilities by Venture Global Delta LNG, LLC and Venture Global Delta
Express, LLC (collectively referred to as Delta LNG) in Plaquemines,
Richland, Franklin, Catahoula, Concordia, Avoyelles, St. Landry, Pointe
Coupee, West Baton Rouge, Iberville, Ascension, Assumption, Lafourche,
and Jefferson Parishes, Louisiana. The Commission will use this EIS in
its decision-making process to determine whether the Project is in the
public interest and public convenience and necessity.
    This notice announces the opening of the scoping process the
Commission will use to gather input from the public and interested
agencies about issues regarding the Project. The National Environmental
Policy Act (NEPA) requires the Commission to take into account the
environmental impacts that could result from its action whenever it
considers the issuance of an authorization. NEPA also requires the
Commission to discover concerns the public may have about proposals.
This process is referred to as ``scoping.'' The main goal of the
scoping process is to focus the analysis in the EIS on the important
environmental issues. By this notice, the Commission requests public
comments on the scope of issues to address in the EIS. To ensure that
your comments are timely and properly recorded, please submit your
comments so that the Commission receives them in Washington, DC on or
before 5:00 p.m. Eastern Time on August 29, 2019.
    You can make a difference by submitting your specific comments or
concerns about the Project. Your comments should focus on the potential
environmental effects, reasonable alternatives, and measures to avoid
or lessen environmental impacts. Your input will help the Commission
staff determine what issues they need to evaluate in the EIS.
Commission staff will consider all comments received during the
preparation of the EIS.
    If you sent comments on this Project to the Commission before the
opening of this docket on April 30, 2019 you will need to file those
comments in Docket No. PF19-4-000 to ensure they are considered as part
of this proceeding.
    This notice is being sent to the Commission's current environmental
mailing list for this Project. State and local government
representatives should notify their constituents of this planned
Project and encourage them to comment on their areas of concern.
    If you are a landowner receiving this notice, a pipeline company
representative may contact you about the acquisition of an easement to
construct, operate, and maintain the planned facilities. The company
would seek to negotiate a mutually acceptable pipeline easement
agreement. You are not required to enter into an agreement. However, if
the Commission approves the pipeline, that approval conveys with it the
right of eminent domain. Therefore, if you and the company do not reach
an easement agreement, the pipeline company could initiate condemnation
proceedings in court. In such instances, compensation would be
determined by a judge in accordance with state law.
    A document prepared by the FERC entitled An Interstate Natural Gas
Facility On My Land? What Do I Need To Know? is available for viewing
on the FERC website (www.ferc.gov) at https://www.ferc.gov/resources/guides/gas/gas.pdf. This document addresses a number of typically asked
questions, including the use of eminent domain and how to participate
in the Commission's proceedings.

Public Participation

    The Commission offers a free service called eSubscription which
makes it easy to stay informed of all issuances and submittals
regarding the dockets/projects to which you subscribe. These instant
email notifications are the fastest way to receive notification and
provide a link to the document files which can reduce the amount of
time you spend researching proceedings. To sign up go to www.ferc.gov/docs-filing/esubscription.asp.
    For your convenience, there are four methods you can use to submit
your comments to the Commission. The Commission encourages electronic
filing of comments and has staff available to assist you at (866) 208-
3676 or<EMAIL_ADDRESS>Please carefully follow these
instructions so that your comments are properly recorded.
    (1) You can file your comments electronically using the eComment
feature, which is located on the Commission's website (www.ferc.gov)
under the link to Documents and Filings. Using eComment is an easy
method for submitting brief, text-only comments on a project;
    (2) You can file your comments electronically by using the eFiling
feature, which is located on the Commission's website (www.ferc.gov)
under the link to Documents and Filings. With eFiling, you can provide
comments in a variety of formats by attaching them as a file with your
submission. New eFiling users must first create an account by clicking
on eRegister. You will be asked to select the type of filing you are
making; a comment on a particular project is considered a Comment on a
Filing; or
    (3) You can file a paper copy of your comments by mailing them to
the following address. Be sure to reference the Project docket number
(PF19-4-000) with your submission: Kimberly D. Bose, Secretary, Federal
Energy Regulatory Commission, 888 First Street NE, Room 1A, Washington,
DC 20426.
    (4) In lieu of sending written comments, the Commission invites you
to attend one of the public scoping

sessions its staff will conduct in the Project area, scheduled as
follows:

------------------------------------------------------------------------
            Date and time                           Location
------------------------------------------------------------------------
Monday, August 12, 2019, 4:30-7:30     Belle Chasse High School, 8346
 p.m.                                   Highway 23, Belle Chasse, LA.
Tuesday, August 13, 2019, 4:30-7:30    Donaldsonville High School, 100
 p.m.                                   Tiger Drive, Donaldsonville, LA.
Wednesday, August 14, 2019, 4:30-7:30  Pointe Coupee Historical Society,
 p.m.                                   Poydras Center, 500 West Main
                                        Street, New Roads, LA.
Thursday, August 15, 2019, 4:30-7:30   Jack Hammons Community Center,
 p.m.                                   810 Adams Street, Winnsboro, LA.
------------------------------------------------------------------------

    The primary goal of these scoping sessions is to have you identify
the specific environmental issues and concerns that should be
considered in the EIS. Individual verbal comments will be taken on a
one-on-one basis with a court reporter. This format is designed to
receive the maximum amount of verbal comments in a convenient way
during the timeframe allotted.
    Each scoping session is scheduled from 4:30 p.m. to 7:30 p.m.
Central Time. You may arrive at any time after 4:30 p.m. There will not
be a formal presentation by Commission staff when the session opens. If
you wish to speak, the Commission staff will hand out numbers in the
order of your arrival. Comments will be taken until 7:30 p.m. However,
if no additional numbers have been handed out and all individuals who
wish to provide comments have had an opportunity to do so, staff may
conclude the session at 7:00 p.m. Please see appendix 1 for additional
information on the session format and conduct.\1\
---------------------------------------------------------------------------

    \1\ The appendices referenced in this notice will not appear in
the Federal Register. Copies of the appendices were sent to all
those receiving this notice in the mail and are available at
www.ferc.gov using the link called eLibrary or from the Commission's
Public Reference Room, 888 First Street NE, Washington, DC 20426, or
call<PHONE_NUMBER>. For instructions on connecting to eLibrary,
refer to the last page of this notice.
---------------------------------------------------------------------------

    Your scoping comments will be recorded by a court reporter (with
FERC staff or representative present) and become part of the public
record for this proceeding. Transcripts will be publicly available on
FERC's eLibrary system (see the last page of this notice for
instructions on using eLibrary). If a significant number of people are
interested in providing verbal comments in the one-on-one settings, a
time limit of 5 minutes may be implemented for each commentor.
    It is important to note that written comments mailed to the
Commission and those submitted electronically are reviewed by staff
with the same scrutiny and consideration as the verbal comments given
at the public comment session. Therefore, you do not need to attend a
meeting in order for your comments to be considered.
    Although there will not be a formal presentation, Commission staff
will be available throughout the scoping session to answer your
questions about the environmental review process. Representatives from
Delta LNG will also be present to answer Project-specific questions.
    Please note this is not your only public input opportunity; please
refer to the review process flow chart in appendix 2.

Summary of the Planned Project

    The Project would involve the construction of a liquefied natural
gas (LNG) export terminal in Plaquemines Parish, Louisiana and two
parallel, 42-inch-diameter pipelines in a single approximately 283-
mile-long right-of-way in 14 parishes in Louisiana. Domestically
sourced natural gas would be transported by the Delta Express Pipeline
to the Delta LNG terminal which would produce, store, and deliver up to
24 million tons per annum of LNG to LNG carriers for export overseas.
More specifically, the Project would include the following facilities:
     The Delta LNG export terminal, consisting of:
    [cir] Pretreatment facilities;
    [cir] a liquefaction plant with 18 integrated single-mixed
refrigerant blocks and supporting facilities;
    [cir] four 200,000-cubic-meter aboveground full-containment LNG
storage tanks;
    [cir] three LNG carrier loading docks within a common LNG carrier
berthing area; and
    [cir] two 720-megawatt air-cooled electric power generation
facilities;
     the Delta Express Pipeline, consisting of:
    [cir] Two approximately 283-mile-long, 42-inch-diameter pipelines
beginning in Richland Parish and ending at the Delta LNG export
terminal;
    [cir] 4 natural gas-fired compressor stations in Richland,
Concordia, Pointe Coupee, and Lafourche Parishes;
    [cir] 16 mainline block valves;
    [cir] 4 pig launchers and receiver facilities; \2\
---------------------------------------------------------------------------

    \2\ A pig is a tool that the pipeline company inserts into and
pushes through the pipeline for cleaning the pipeline, conducting
internal inspections, or other purposes.
---------------------------------------------------------------------------

    [cir] 2 metering and regulation stations; and
    [cir] other pipeline-related facilities (e.g., access roads,
contractor and pipe yards).
    Delta LNG plans to construct the Project in two phases. Phase 1 at
the LNG export terminal site would generally include one-half of the
LNG processing and storage facilities, one-half of the electric power
generation facilities, and two LNG carrier loading docks. Phase 1 of
the Delta Express Pipeline would generally include one of the two
planned natural gas transmission pipelines and all four planned
compressor stations. Phase 2 of the Project would be based on market
conditions and would include construction of the remaining facilities
at the LNG export terminal, the second of the two planned natural gas
transmission pipelines, and modifications to the four planned
compressor stations. The EIS will disclose the environmental impacts of
each phase of the Project as well as the total impacts of the Project
at completion.
    The general location of the Project facilities is shown in appendix
3.

Land Requirements for Construction

    Construction and operation of the planned LNG terminal facilities
would disturb about 500 acres. Construction of the planned pipeline
facilities, including aboveground facilities, would disturb about 6,000
acres. Following construction of the pipeline facilities, Delta LNG
would maintain about 2,744 acres for permanent operation of the
pipeline Project; the remaining acreage would be restored and revert to
former uses.

The EIS Process

    The EIS will discuss impacts that could occur as a result of the
construction and operation of the planned Project under these general
headings:
     Geology and soils;
     water resources and wetlands;
     vegetation, fisheries, and wildlife;

     threatened and endangered species;
     cultural resources;
     land use;
     socioeconomics;
     air quality and noise;
     public safety; and
     cumulative impacts.
    Commission staff will also evaluate possible alternatives to the
planned Project or portions of the Project, and make recommendations on
how to lessen or avoid impacts on the various resource areas.
    Although no formal application has been filed, Commission staff
have already initiated a NEPA review under the Commission's pre-filing
process. The purpose of the pre-filing process is to encourage early
involvement of interested stakeholders and to identify and resolve
issues before the Commission receives an application. As part of the
pre-filing review, Commission staff will contact federal and state
agencies to discuss their involvement in the scoping process and the
preparation of the EIS.
    The EIS will present Commission staffs' independent analysis of the
issues. The draft EIS will be available in electronic format in the
public record through eLibrary \3\ and the Commission's website
(https://www.ferc.gov/industries/gas/enviro/eis.asp). If eSubscribed,
you will receive instant email notification when the draft EIS is
issued. The draft EIS will be issued for an allotted public comment
period. After the comment period on the draft EIS, Commission staff
will consider all timely comments and revise the document, as
necessary, before issuing a final EIS. To ensure Commission staff have
the opportunity to consider and address your comments, please carefully
follow the instructions in the Public Participation section, beginning
on page 2.
---------------------------------------------------------------------------

    \3\ For instructions on connecting to eLibrary, refer to the
last page of this notice.
---------------------------------------------------------------------------

    With this notice, the Commission is asking agencies with
jurisdiction by law and/or special expertise with respect to the
environmental issues related to this Project to formally cooperate in
the preparation of the EIS.\4\ Agencies that would like to request
cooperating agency status should follow the instructions for filing
comments provided under the Public Participation section of this
notice.
---------------------------------------------------------------------------

    \4\ The Council on Environmental Quality regulations addressing
cooperating agency responsibilities are at Title 40, Code of Federal
Regulations, Part 1501.6.
---------------------------------------------------------------------------

Consultation Under Section 106 of the National Historic Preservation
Act

    In accordance with the Advisory Council on Historic Preservation's
implementing regulations for section 106 of the National Historic
Preservation Act, the Commission is using this notice to initiate
consultation with the applicable State Historic Preservation Office(s),
and to solicit their views and those of other government agencies,
interested Indian tribes, and the public on the Project's potential
effects on historic properties.\5\ The EIS for this Project will
document our findings on the impacts on historic properties and
summarize the status of consultations under section 106.
---------------------------------------------------------------------------

    \5\ The Advisory Council on Historic Preservation regulations
are at Title 36, Code of Federal Regulations, Part 800. Those
regulations define historic properties as any prehistoric or
historic district, site, building, structure, or object included in
or eligible for inclusion in the National Register of Historic
Places.
---------------------------------------------------------------------------

Currently Identified Environmental Issues

    Commission staff have already identified several issues that
deserve attention based on a preliminary review of the planned
facilities and the environmental information provided by Delta LNG.
This preliminary list of issues may change based on your comments and
our analysis.
     impacts on wetlands including coastal marsh and forested
wetlands;
     cumulative impacts on air quality, noise, wetlands,
socioeconomic systems and other resources associated with construction
and operation of the planned Delta LNG export terminal and the nearby
proposed Plaquemines LNG export terminal and other large projects at
various stages of planning in the region;
     LNG terminal site alternatives;
     Delta Express Pipeline route alternatives; and
     alternative construction methods and workspace
configurations that would avoid or reduce impacts.

Environmental Mailing List

    The environmental mailing list includes federal, state, and local
government representatives and agencies; elected officials;
environmental and public interest groups; Native American Tribes; other
interested parties; and local libraries and newspapers. This list also
includes all affected landowners (as defined in the Commission's
regulations) who are potential right-of-way grantors, whose property
may be used temporarily for Project purposes, or who own homes within
certain distances of aboveground facilities, and anyone who submits
comments on the Project. Commission staff will update the environmental
mailing list as the analysis proceeds to ensure that Commission notices
related to this environmental review are sent to all individuals,
organizations, and government entities interested in and/or potentially
affected by the planned Project.
    A Notice of Availability of the draft EIS will be sent to the
environmental mailing list and will provide instructions to access the
electronic document on the FERC's website (www.ferc.gov). If you need
to make changes to your name/address, or if you would like to remove
your name from the mailing list, please return the attached Mailing
List Update Form (appendix 4).

Becoming an Intervenor

    Once Delta LNG files its application with the Commission, you may
want to become an intervenor which is an official party to the
Commission's proceeding. Only intervenors have the right to seek
rehearing of the Commission's decision and be heard by the courts if
they choose to appeal the Commission's final ruling. An intervenor
formally participates in the proceeding by filing a request to
intervene pursuant to Rule 214 of the Commission's Rules of Practice
and Procedures (18 CFR 385.214). Motions to intervene are more fully
described at http://www.ferc.gov/resources/guides/how-to/intervene.asp.
Please note that the Commission will not accept requests for intervenor
status at this time. You must wait until the Commission receives a
formal application for the Project, after which the Commission will
issue a public notice that establishes an intervention deadline.

Additional Information

    Additional information about the Project is available from the
Commission's Office of External Affairs, at (866) 208-FERC, or on the
FERC website (www.ferc.gov) using the eLibrary link. Click on the
eLibrary link, click on General Search and enter the docket number in
the Docket Number field, excluding the last three digits (i.e., PF19-
4). Be sure you have selected an appropriate date range. For
assistance, please contact FERC Online Support at
<EMAIL_ADDRESS>or toll free at<PHONE_NUMBER>, or for TTY,
contact<PHONE_NUMBER>. The eLibrary link also provides access to the
texts of all formal documents issued by the Commission, such as orders,
notices, and rulemakings.

    Public sessions or site visits will be posted on the Commission's
calendar located at www.ferc.gov/EventCalendar/EventsList.aspx along
with other related information.

    Dated: July 30, 2019.
Kimberly D. Bose,
 Secretary.
[FR Doc. 2019-16861 Filed 8-6-19; 8:45 am]
 BILLING CODE 6717-01-P