Nitrate/nitrite as N (mg/L).............               4               3
------------------------------------------------------------------------

* * * * *
    (2)(i) For any electric generating unit with a total nameplate
capacity of less than or equal to 50 megawatts, that is an oil-fired
unit, or for which the owner has submitted a certification pursuant to
Sec.  423.19(f), the quantity of pollutants discharged in FGD
wastewater shall not exceed the quantity determined by multiplying the
flow of FGD wastewater times the concentration listed for TSS in Sec.
423.12(b)(11).
    (ii) For FGD wastewater discharges from a high FGD flow facility,
the quantity of pollutants in FGD wastewater shall not exceed the
quantity determined by multiplying the flow of FGD wastewater times the
concentration listed in the table following this paragraph (g)(2)(ii).
Dischargers must meet the effluent limitations for FGD wastewater in
this paragraph by a date determined by the permitting authority that is
as soon as possible beginning October 13, 2021, but no later than
December 31, 2023. These effluent limitations apply to the discharge of
FGD wastewater generated on and after the date determined by the
permitting authority for meeting the effluent limitations, as specified
in this paragraph.

                     Table 6 to Paragraph (g)2)(ii)
------------------------------------------------------------------------
                                             BAT effluent limitations
                                         -------------------------------
                                                            Average of
                                                           daily values
     Pollutant or pollutant property        Maximum for       for 30
                                             any 1 day      consecutive
                                                          days shall not
                                                              exceed
------------------------------------------------------------------------
Arsenic, total (ug/L)...................              11               8
Mercury, total (ng/L)...................             788             356
------------------------------------------------------------------------

    (iii) For FGD wastewater discharges from a low utilization electric
generating unit, the quantity of pollutants in FGD wastewater shall not
exceed the quantity determined by multiplying the flow of FGD
wastewater times the concentration listed in the table following
paragraph (g)(2)(ii). Dischargers must meet the effluent limitations
for FGD wastewater in this paragraph by a date determined by the
permitting authority that is as soon as possible beginning October 13,
2021, but no later than December 31, 2023. These effluent limitations
apply to the discharge of FGD wastewater generated on and after the
date determined by the permitting authority for meeting the effluent
limitations, as specified in this paragraph.
    (3)(i) For dischargers who voluntarily choose to meet the effluent
limitations for FGD wastewater in this paragraph, the quantity of
pollutants in FGD wastewater shall not exceed the quantity determined
by multiplying the flow of FGD wastewater times the concentration
listed in the table following this paragraph (g)(3)(i). Dischargers who
choose to meet the effluent limitations for FGD wastewater in this
paragraph must meet such limitations by December 31, 2028. These
effluent limitations apply to the discharge of FGD wastewater generated
on and after December 31, 2028.

                     Table 7 of Paragraph (g)(3)(i)
------------------------------------------------------------------------
                                             BAT effluent limitations
                                         -------------------------------
                                                            Average of
                                                           daily values
     Pollutant or pollutant property        Maximum for       for 30
                                             any 1 day      consecutive
                                                          days shall not
                                                              exceed
------------------------------------------------------------------------
Arsenic, total (ug/L)...................               5              NA
Mercury, total (ng/L)...................              23              10
Selenium, total (ug/L)..................              10              NA
Nitrate/Nitrite (mg/L)..................             2.0             1.2
Bromide (mg/L)..........................             0.2              NA
TDS (mg/L)..............................             306             149
------------------------------------------------------------------------

* * * * *
    (k)(1)(i) Bottom ash transport water. Except for those discharges
to which paragraph (k)(2) of this section applies, or when the bottom
ash transport water is used in the FGD scrubber, there shall be no
discharge of pollutants in bottom ash transport water. Dischargers must
meet the discharge limitation in this paragraph by a date determined by
the permitting authority that is as soon as possible beginning October
13, 2021, but no later than December 31, 2025. This limitation applies
to the discharge of bottom ash transport water generated on and after
the date determined by the permitting authority for meeting the
discharge limitation, as specified in this paragraph. Except for those
discharges to which paragraph (k)(2) of this section applies, whenever
bottom ash transport water is used in any other plant process or is
sent to a treatment system at the plant (except when it is used in the
FGD scrubber), the resulting effluent must comply with the discharge
limitation in this paragraph. When the bottom ash transport water is
used in the FGD scrubber, it ceases to be bottom ash transport water,
and instead is FGD wastewater, which must meet the requirements in
paragraph (g) of this section.
* * * * *
    (2)(i)(A) The discharge of pollutants in bottom ash transport water
from a properly installed, operated, and maintained bottom ash system
is authorized under the following conditions:
    (1) To maintain system water balance when precipitation-related
inflows are generated from storm events exceeding a 10-year storm event
of 24-hour or longer duration (e.g., 30-day storm event) and cannot be
managed by installed spares, redundancies, maintenance tanks, and other
secondary bottom ash system equipment; or
    (2) To maintain system water balance when regular inflows from
wastestreams other than bottom ash transport water exceed the ability
of the bottom ash system to accept recycled water and segregating these
other wastestreams is not feasible; or
    (3) To maintain system water chemistry where installed equipment at
the facility is unable to manage pH, corrosive substances, substances
or conditions causing scaling, or fine particulates to below levels
which impact system operation or maintenance; or
    (4) To conduct maintenance not otherwise included in paragraphs
(k)(2)(i)(A) (1), (2), or (3) of this section and not exempted from the
definition of transport water in Sec.  423.11(p), and when water
volumes cannot be managed by installed spares, redundancies,
maintenance tanks, and other secondary bottom ash system equipment.

    (B) The total volume that may be discharged for the above
activities shall be reduced or eliminated to the extent achievable
using control measures (including best management practices) that are
technologically available and economically achievable in light of best
industry practice. The total volume of the discharge authorized in this
subsection shall be determined on a case-by-case basis by the
permitting authority and in no event shall such discharge exceed a 30-
day rolling average of ten percent of the primary active wetted bottom
ash system volume. The volume of daily discharges used to calculate the
30-day rolling average shall be calculated using measurements from flow
monitors.
    (ii) For any electric generating unit with a total nameplate
generating capacity of less than or equal to 50 megawatts, that is an
oil-fired unit, or for which the owner has certified to the permitting
authority that it will cease combustion of coal pursuant to Sec.
423.19(f), the quantity of pollutants discharged in bottom ash
transport water shall not exceed the quantity determined by multiplying
the flow of the applicable wastewater times the concentration for TSS
listed in Sec.  423.12(b)(4).
    (iii) For bottom ash transport water generated by a low utilization
electric generating unit, the quantity of pollutants discharged in
bottom ash transport water shall not exceed the quantity determined by
multiplying the flow of the applicable wastewater times the
concentration for TSS listed in Sec.  423.12(b)(4), and shall
incorporate the elements of a best management practices plan as
described in (k)(3) of this section.
    (3) Where required in paragraph (k)(2)(iii) of this section, the
discharger shall prepare, implement, review, and update a best
management practices plan for the recycle of bottom ash transport
water, and must include:
    (i) Identification of the low utilization coal-fired generating
units that contribute bottom ash to the bottom ash transport system.
    (ii) A description of the existing bottom ash handling system and a
list of system components (e.g., remote mechanical drag system, tanks,
impoundments, chemical addition). Where multiple generating units share
a bottom ash transport system, the plan shall specify which components
are associated with low utilization generating units.
    (iii) A detailed water balance, based on measurements, or estimates
where measurements are not feasible, specifying the volume and
frequency of water additions and removals from the bottom ash transport
system, including:
    (A) Water removed from the BA transport system:
    (1) To the discharge outfall.
    (2) To the FGD scrubber system.
    (3) Through evaporation
    (4) Entrained with any removed ash
    (5) To any other mechanisms not specified above.
    (B) Water entering or recycled to the BA transport system:
    (1) Makeup water added to the BA transport water system.
    (2) Bottom ash transport water recycled back to the system in lieu
of makeup water.
    (3) Any other mechanisms not specified above.
    (iv) Measures to be employed by all facilities:
    (A) Implementation of a comprehensive preventive maintenance
program to identify, repair and replace equipment prior to failures
that result in the release of bottom ash transport water.
    (B) Daily or more frequent inspections of the entire bottom ash
transport water system, including valves, pipe flanges and piping, to
identify leaks, spills and other unintended bottom ash transport water
escaping from the system, and timely repair of such conditions.
    (C) Documentation of preventive and corrective maintenance
performed.
    (v) Evaluation of options and feasibility, accounting for the
associated costs, for eliminating or minimizing discharges of bottom
ash transport water, including:
    (A) Segregation of bottom ash transport water from other process
water.
    (B) Minimization of the introduction of stormwater by diverting
(e.g., curbing, using covers) storm water to a segregated collection
system.
    (C) Recycling bottom ash transport water back to the bottom ash
transport water system.
    (D) Recycling bottom ash transport water for use in the FGD
scrubber.
    (E) Optimization of existing equipment (e.g., pumps, pipes, tanks)
and installing new equipment where practicable to achieve the maximum
amount of recycle.
    (F) Utilization of ``in-line'' treatment of transport water (e.g.,
pH control, fines removal) where needed to facilitate recycle.
    (vi) Description of the bottom ash recycle system, including all
technologies, measures, and practices that will be used to minimize
discharge.
    (vii) A schedule showing the sequence of implementing any changes
necessary to achieve the minimized discharge of bottom ash transport
water, including the following:
    (A) The anticipated initiation and completion dates of construction
and installation associated with the technology components or process
modifications specified in the plan.
    (B) The anticipated dates that the discharger expects the
technologies and process modifications to be fully implemented on a
full-scale basis, which in no case shall be later than December 31,
2023.
    (C) The anticipated change in discharge volume and effluent quality
associated with implementation of the plan.
    (viii) Description establishing a method for documenting and
demonstrating to the permitting/control authority that the recycle
system is well operated and maintained.
    (ix) Performance of weekly flow monitoring for the following:
    (A) Make up water to the bottom ash transport water system.
    (B) Bottom ash transport water sluice flow rate (e.g., to the
surface impoundment(s), dewatering bins(s), tank(s), remote mechanical
drag system).
    (C) Bottom ash transport water discharge to surface water or POTW.
    (D) Bottom ash transport water recycle back to the bottom ash
system or FGD scrubber.
* * * * *
    (o)(1) Transfer between applicable limitations in a permit. Where,
in the permit, the permitting authority has included alternative limits
subject to eligibility requirements, upon timely notification to the
permitting authority under Sec.  423.19(i), a facility can become
subject to the alternative limits under the following circumstances:
    (i) On or before December 31, 2023 a facility may convert:
    (A) From limitations for electric generating units permanently
ceasing coal combustion under paragraphs (g)(2)(i) or (k)(2)(ii) of
this section to limitations for low utilization electric generating
units under paragraphs (g)(2)(iii) or (k)(2)(iii) of this section; or
    (B) From voluntary incentives program limitations under paragraph
(g)(3)(i) of this section or generally applicable limitations under
paragraph (k)(1)(i) of this section to limitations for low utilization
electric generating units under paragraphs (g)(2)(iii) or (k)(2)(iii)
of this section.
    (ii) On or before December 31, 2025 a facility may convert
    (A) From voluntary incentives program limitations under paragraph
(g)(3)(i) of this section to limitations for

electric generating units permanently ceasing coal combustion under
paragraph (g)(2)(i) of this section; or
    (B) From limitations for electric generating units permanently
ceasing coal combustion under paragraphs (g)(2)(i) or (k)(2)(ii) of
this section to voluntary incentives program limitations under
paragraphs (g)(3)(i) of this section or generally applicable
limitations under (k)(1)(i) of this section; or
    (C) From limitations for low utilization electric generating units
under paragraphs (g)(2)(iii) or (k)(2)(iii) of this section to
generally applicable limitations under paragraphs (g)(1)(i) or
(k)(1)(i) of this section; or
    (D) From limitations for low utilization electric generating units
under paragraphs (g)(2)(iii) or (k)(2)(iii) of this section to
voluntary incentives program limitations under paragraphs (g)(3)(i) of
this section or generally applicable limitations under paragraph
(k)(1)(i) of this section; or
    (E) From limitations for low utilization electric generating units
under paragraphs (g)(2)(iii) or (k)(2)(iii) of this section to
limitations for electric generating units permanently ceasing coal
combustion under paragraphs (g)(2)(i) and (k)(2)(ii) of this section.
    (2) A facility must be in compliance with all of its currently
applicable requirements to be eligible to file a notice under Sec.
423.19(i) and to become subject to a different set of applicable
requirements under paragraph (o)(1) of this section.
    (3) Where a facility seeking a transfer under paragraph (o)(1)(ii)
of this section is currently subject to more stringent limitations than
the limitations being sought, the facility must continue to meet those
more stringent limitations.
    2. Amend Sec.  423.16 by revising paragraphs (e) and (g) to read as
follows:

Sec.  423.16  Pretreatment standards for existing sources (PSES).

* * * * *
    (e)(1) FGD wastewater. Except as provided for in paragraph (e)(2)
of this section, for any electric generating unit with a total
nameplate generating capacity of more than 50 megawatts, that is not an
oil-fired unit, and that the owner has not certified to the permitting
authority that it will cease the coal combustion pursuant to Sec.
423.19(f), the quantity of pollutants in FGD wastewater shall not
exceed the quantity determined by multiplying the flow of FGD
wastewater times the concentration listed in table 3 to this paragraph
(e)(1). Dischargers must meet the standards in this paragraph by
October 13, 2023 except as provided for in paragraph (e)(2) of this
section. These standards apply to the discharge of FGD wastewater
generated on and after October 13, 2023.

                       Table 3 to Paragraph (e)(1)
------------------------------------------------------------------------
                                                       PSES
                                         -------------------------------
                                                            Average of
                                                           daily values
     Pollutant or pollutant property        Maximum for       for 30
                                             any 1 day      consecutive
                                                          days shall not
                                                              exceed
------------------------------------------------------------------------
Arsenic, total (ug/L)...................              18               8
Mercury, total (ng/L)...................             103              34
Selenium, total (ug/L)..................              70              29
Nitrate/nitrite as N (mg/L).............               4               3
------------------------------------------------------------------------

    (2)(i) For FGD wastewater discharges from a low utilization
electric generating unit, the quantity of pollutants in FGD wastewater
shall not exceed the quantity determined by multiplying the flow of FGD
wastewater times the concentration listed in the table 4 to paragraph
(e)(2)(ii). Dischargers must meet the standards in this paragraph by
October 13, 2023.
    (ii) If any low utilization electric generating unit fails to
timely recertify that the two year average capacity utilization rating
of such a electric generating unit is below 10 percent per year as
specified in Sec.  423.19(e), regardless of the reason, within two
years from the date such a recertification was required, the quantity
of pollutants in FGD wastewater shall not exceed the quantity
determined by multiplying the flow of FGD wastewater times the
concentration listed in the Table 3 to paragraph (e)(1).

                     Table 4 to Paragraph (e)(2)(ii)
------------------------------------------------------------------------
                                                       PSES
                                         -------------------------------
                                                            Average of
                                                           daily values
     Pollutant or pollutant property        Maximum for       for 30
                                             any 1 day      consecutive
                                                          days shall not
                                                              exceed
------------------------------------------------------------------------
Arsenic, total (ug/L)...................              11               8
Mercury, total (ng/L)...................             788             356
------------------------------------------------------------------------

* * * * *
    (g)(1) Except for those discharges to which paragraph (g)(2)
applies, or when the bottom ash transport water is used in the FGD
scrubber, for any electric generating unit with a total nameplate
generating capacity of more than 50 megawatts, that is not an oil-fired
unit, that is not a low utilization electric generating unit, and that
the owner has not certified to the permitting authority that the
electric generating unit will cease the cessation of coal combustion
pursuant to Sec.  423.19(f), there shall be no discharge of pollutants
in bottom ash

transport water. This standard applies to the discharge of bottom ash
transport water generated on and after October 13, 2023. Except for
those discharges to which paragraph (g)(2) of this section applies,
whenever bottom ash transport water is used in any other plant process
or is sent to a treatment system at the plant (except when it is used
in the FGD scrubber), the resulting effluent must comply with the
discharge standard in this paragraph. When the bottom ash transport
water is used in the FGD scrubber, the quantity of pollutants in bottom
ash transport water shall not exceed the quantity determined by
multiplying the flow of bottom ash transport water times the
concentration listed in the table in paragraph (e) of this section.
    (2)(i) The discharge of pollutants in bottom ash transport water
from a properly installed, operated, and maintained bottom ash system
is authorized under the following conditions:
    (A) To maintain system water balance when precipitation-related
inflows are generated from a 10-year storm event of 24-hour or longer
duration (e.g., 30-day storm event) and cannot be managed by installed
spares, redundancies, maintenance tanks, and other secondary bottom ash
system equipment; or
    (B) To maintain system water balance when regular inflows from
wastestreams other than bottom ash transport water exceed the ability
of the bottom ash system to accept recycled water and segregating these
other wastestreams is feasible; or
    (C) To maintain system water chemistry where current operations at
the facility are unable to currently manage pH, corrosive substances,
substances or conditions causing scaling, or fine particulates to below
levels which impact system operation or maintenance; or
    (D) To conduct maintenance not otherwise included in paragraphs
(g)(2)(i)(A)(1), (2), or (3) of this section and not exempted from the
definition of transport water inSec.  423.11(p), and when water volumes
cannot be managed by installed spares, redundancies, maintenance tanks,
and other secondary bottom ash system equipment.
    (ii) The total volume that may be discharged to a POTW for the
above activities shall be reduced or eliminated to the extent
achievable as determined by the control authority. The control
authority may also include control measures (including best management
practices) that are technologically available and economically
achievable in light of best industry practice. In no event shall the
total volume of the discharge exceed a 30-day rolling average of ten
percent of the primary active wetted bottom ash system volume. The
volume of daily discharges used to calculate the 30-day rolling average
shall be calculated using measurements from flow monitors.
    (iii) For bottom ash transport water generated by a low utilization
electric generating unit, the quantity of pollutants discharged in
bottom ash transport water shall incorporate the elements of a best
management practices plan as described in Sec.  423.13(k)(3).

0
5. Add Sec.  423.18 to read as follows.

Sec.  423.18  Permit conditions.

    All permits subject to this part shall include the following permit
conditions:
    (a) An electric generating unit shall qualify as a low utilization
electric generating unit or permanently ceasing the combustion of coal
by December 31, 2028, if such qualification would have been
demonstrated absent the following qualifying event:
    (1) An emergency order issued by the Department of Energy under
Section 202(c) of the Federal Power Act,
    (2) A reliability must run agreement issued by a Public Utility
Commission, or
    (3) Any other reliability-related order or agreement issued by a
competent electricity regulator (e.g., an independent system operator)
which results in that electric generating unit operating in a way not
contemplated when the certification was made; or
    (4) The operation of the electric generating unit was necessary for
load balancing in an area subject to a declaration under 42 U.S.C. 5121
et seq., that there exists:
    (i) An ``Emergency,'' or
    (ii) A ``Major Disaster,'' and
    (iii) That load balancing was due to the event that caused the
``Emergency'' or ``Major Disaster'' in paragraph (a)(4) of this section
to be declared,
    (b) Any facility providing the required documentation pursuant to
Sec.  423.19(g) may avail itself of the protections of this permit
condition.

0
6. Add Sec.  423.19 to read as follows.

Sec.  423.19  Reporting and recordkeeping requirements.

    (a) Discharges subject to this part must comply with the following
additional reporting requirements.
    (b) Signature and certification. Unless otherwise provided below,
all certifications and recertifications required in this part must be
signed and certified pursuant to 40 CFR 122.22 for direct dischargers
or 40 CFR 403.12(l) for indirect dischargers.
    (c) Requirements for facilities discharging bottom ash transport
water pursuant to Sec.  423.13(k)(2)(i) or 423.16(g)(2)(i).
    (1) Initial Certification Statement. For sources seeking to
discharge bottom ash transport water pursuant to Sec.  423.13(k)(2)(i)
or 423.16(g)(2)(i), an initial certification shall be submitted to the
permitting authority by the as soon as possible date determined under
Sec.  423.11(t), or the control authority by October 13, 2023 in the
case of an indirect discharger.
    (2) Signature and certification. The certification statement must
be signed and certified by a professional engineer.
    (3) Contents. An initial certification shall include the following:
    (A) A statement that the professional engineer is a licensed
professional engineer.
    (B) A statement that the professional engineer is familiar with the
regulation requirements.
    (C) A statement that the professional engineer is familiar with the
facility.
    (D) The primary active wetted bottom ash system volume in Sec.
423.11(aa).
    (E) Material assumptions, information, and calculations used by the
certifying professional engineer to determine the primary active wetted
bottom ash system volume.
    (F) A list of all potential discharges under Sec.
423.13(k)(2)(i)(A)(1) through (4) or Sec.  423.16(g)(2)(i)(A) through
(D), the expected volume of each discharge, and the expected frequency
of each discharge.
    (G) Material assumptions, information, and calculations used by the
certifying professional engineer to determine the expected volume and
frequency of each discharge including a narrative discussion of why
such water cannot be managed within the system and must be discharged.
    (H) A list of all wastewater treatment systems at the facility
currently, or otherwise required by a date certain under this section.
    (I) A narrative discussion of each treatment system including the
system type, design capacity, and current or expected operation.
    (d) Requirements for a bottom ash best management practices plan.
    (1) Initial and annual certification statement. For sources
required to develop and implement a best management practices plan
pursuant to Sec.  423.13(k)(3), an initial certification shall be made
to the permitting authority with a permit application or within two
years of October 13, 2021, whichever is later, or to the control
authority no later than October 13, 2023 in the case of an indirect
discharger, and an annual recertification shall be made to the
permitting authority, or control

authority in the case of an indirect discharger, within 60 days of the
anniversary of the original plan.
    (2) Signature and certification. The certification statement must
be signed and certified by a professional engineer.
    (3) Contents for initial certification. An initial certification
shall include the following:
    (A) A statement that the professional engineer is a licensed
professional engineer.
    (B) A statement that the professional engineer is familiar with the
regulation requirements.
    (C) A statement that the professional engineer is familiar with the
facility.
    (D) The best management practices plan.
    (E) A statement that the best management practices plan is being
implemented.
    (4) Additional contents for annual certification. In addition to
the required contents of the initial certification in paragraph (c)(3)
of this section an annual certification shall include the following:
    (A) Any updates to the best management practices plan.
    (B) An attachment of weekly flow measurements from the previous
year.
    (C) The average amount of recycled bottom ash transport water in
gallons per day.
    (D) Copies of inspection reports and a summary of preventative
maintenance performed on the system.
    (E) A statement that the plan and corresponding flow records are
being maintained at the office of the plant.
    (e) Requirements for low utilization electric generating units.
    (1) Notice of Planned Participation. For sources seeking to qualify
as a low utilization electric generating units, a Notice of Planned
Participation shall be submitted to the permitting authority or control
authority no later than October 13, 2021.
    (2) Contents. A Notice of Planned Participation shall identify the
potential low utilization electric generating unit. The notice shall
also include a statement of at least two years' capacity utilization
rating data for the most recent two years of operation of each low
utilization electric generating unit and a statement that the facility
has a good faith belief that each low utilization electric generating
unit will continue to operate at the required capacity utilization
rating. Where the most recent capacity utilization rating does not meet
the low utilization electric generating unit requirement, a discussion
of the projected future utilization shall be provided, including
material data and assumptions used to make that projection.
    (3) Initial and annual certification statement. For sources seeking
to qualify as a low utilization electric generating unit under this
part, an initial certification shall be made to the permitting
authority, or to the control authority in the case of an indirect
discharger, no later than December 31, 2023, and an annual
recertification shall be made to the permitting authority, or control
authority in the case of an indirect discharger, within 60 days of
submitting annual electricity production data to the Energy Information
Administration.
    (4) Contents. A certification or annual recertification shall be
based on the information submitted to the Energy Information
Administration and shall include copies of the underlying forms
submitted to the Energy Information Administration, as well as any
supplemental information and calculations used to determine the two
year average annual capacity utilization rating.
    (f) Requirements for units that will achieve permanent cessation of
coal combustion by December 31, 2028.
    (1) Notice of Planned Participation. For sources seeking to qualify
as an electric generating unit that will achieve permanent cessation of
coal combustion by December 31, 2028, under this part, a Notice of
Planned Participation shall be made to the permitting authority, or to
the control authority in the case of an indirect discharger, no later
than October 13, 2021.
    (2) Contents. A Notice of Planned Participation shall identify the
electric generating units intended to achieve the permanent cessation
of coal combustion. A Notice of Planned Participation shall include the
expected date that each electric generating unit is projected to
achieve permanent cessation of coal combustion, whether each date
represents a retirement or a fuel conversion, whether each retirement
or fuel conversion has been approved by a regulatory body, and what the
relevant regulatory body is. The Notice of Planned Participation shall
also include a copy of the most recent integrated resource plan for
which the applicable state agency approved the retirement or repowering
of the unit subject to the ELGs, certification of electric generating
unit cessation under 40 CFR 257.103(b), or other documentation
supporting that the electric generating unit will permanently cease the
combustion of coal by December 31, 2028. The Notice of Planned
Participation shall also include, for each such electric generating
unit, a timeline to achieve the permanent cessation of coal combustion.
Each timeline shall include interim milestones and the projected dates
of completion.
    (3) Annual Progress Report. Annually after submission of the Notice
of Planned Participation in paragraph (f)(1) of this section, a
progress report shall be filed with the permitting authority, or
control authority in the case of an indirect discharger.
    (4) Contents. An Annual Progress Report shall detail the completion
of any interim milestones listed in the Notice of Planned Participation
since the previous progress report, provide a narrative discussion of
any completed, missed, or delayed milestones, and provide updated
milestones.
    (g) Requirements for facilities seeking the protections of Sec.
423.18.
    (1) Certification statement. For sources seeking to apply the
protections of the permit conditions in paragraph Sec.  423.18, and for
each instance that Sec.  423.18 is applied, a one-time certification
shall be submitted to the permitting authority, or control authority in
the case of an indirect discharger, no later than:
    (A) In the case of an order or agreement under Sec.  423.18(a)(1),
30 days from receipt of the order or agreement attached pursuant to
paragraph (g)(2)(B) of this section; or
    (B) In the case of an ``Emergency'' or ``Major Disaster'' under
Sec.  423.18(a)(2), 30 days from the date that a load balancing need
arose.
    (2) Contents. A certification statement must include the following:
    (A) The qualifying event from the list in Sec.  423.18(a), the
individual or entity that issued or triggered the event, and the date
that such an event was issued or triggered.
    (B) A copy of any documentation of the qualifying event from the
individual or entity listed under paragraph (g)(2)(A) of this section,
or, where such documentation does not exist, other documentation with
indicia of reliability for the permitting authority to confirm the
qualifying event.
    (C) An analysis and accompanying narrative discussion which
demonstrates that a electric generating unit would have qualified for
the subcategory at issue absent the event detailed in paragraph
(g)(2)(A), including the material data, assumptions, and methods used.
    (3) Termination of need statement. For sources filing a
certification statement under paragraph (g)(1) above, and for each such
certification statement, a one-time termination of need statement shall
be submitted to the permitting authority, or control authority in the
case of an indirect

discharger, no later than 30 days from when the source is no longer
subject to increased production from the qualifying event.
    (4) Contents. A termination of need statement must include a
narrative discussion including the date the qualifying event
terminated, or if it has not terminated, why the source believes the
capacity utilization will no longer be elevated to a level requiring
the protection of Sec.  423.18.
    (h) Requirements for facilities voluntarily meeting the limits in
423.13(g)(3)(i).
    (1) Notice of Planned Participation. For sources opting to comply
with the Voluntary Incentives Program requirements of section
423.13(g)(3)(i) by December 31, 2028, a Notice of Planned Participation
shall be made to the permitting authority no later than October 13,
2021.
    (2) Contents. A Notice of Planned Participation shall identify the
facility opting to comply with the Voluntary Incentives Program
requirements of 423.13(g)(3)(i), specify what technology or
technologies are projected to be used to comply with those
requirements, and provide a detailed engineering dependency chart and
accompanying narrative demonstrating when and how the system(s) and any
accompanying disposal requirements will be achieved by December 31,
2028.
    (3) Annual progress report. After submission of the Notice of
Planned Participation in paragraph (h)(1), a progress report shall be
filed with the permitting authority, or control authority in the case
of an indirect discharger.
    (4) Contents. An Annual Progress Report shall detail the completion
of interim milestones presented in the engineering dependency chart
from the Notice of Planned Participation since the previous progress
report, provide a narrative discussion of completed, missed, or delayed
milestones, and provide updated milestones.
    (5) Rollover certification. Where, prior to the effective date, a
discharger has already provided a notice to the permitting authority of
opting to comply with the Voluntary Incentives Program requirements of
Sec.  423.13(g)(i), such notice will satisfy paragraph (h)(1) of this
section. However, where details required by (h)(2) of this sectionwere
missing from the previously provided notice, those details must be
provided in the first Annual Progress Report, no later than October 13,
2021.
    (i) Requirements for facilities seeking to transfer between
applicable limitations in a permit under Sec.  423.13(o).
    (1) Notice of Planned Participation. For sources which have filed a
Notice of Planned Participation under paragraphs (e)(1), (f)(1), or
(h)(1) of this section and intend to make changes that would qualify
them for a different set of requirements under Sec.  423.13(o), a
Notice of Planned Participation shall be made to the permitting
authority, or to the control authority in the case of an indirect
discharger, no later than the dates stated in Sec.  423.13(o)(1).
    (2) Contents. A Notice of Planned Participation shall include a
list of the electric generating units for which the source intends to
change compliance alternatives. For each such electric generating unit,
the notice shall list the specific provision under which this transfer
will occur, the reason such a transfer is warranted, and a narrative
discussion demonstrating that each electric generating unit will be
able to maintain compliance with the relevant provisions.
    (j) Notice of material delay. (1) Notice. Within 30 days of
experiencing a material delay in the milestones set forth in paragraphs
(f)(2) or (h)(2) of this section and where such a delay may preclude
permanent cessation of coal combustion or compliance with the voluntary
incentives program limitations by December 31, 2028, a facility shall
file a notice of material delay with the permitting authority, or
control authority in the case of an indirect discharger.
    (2) Contents. The contents of such a notice shall include the
reason for the delay, the projected length of the delay, and a proposed
resolution to maintain compliance.

[FR Doc. 2020-19542 Filed 10-9-20; 8:45 am]
 BILLING CODE 6560-50-P


[Federal Register Volume 77, Number 227 (Monday, November 26, 2012)]
[Rules and Regulations]
[Pages 70372-70373]
[FR Doc No: 2012-28127]

=======================================================================
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DEPARTMENT OF HOMELAND SECURITY

Coast Guard

33 CFR Part 117

[Docket No. USCG-2012-0930]
RIN 1625-AA09

Drawbridge Operation Regulation; Shark River (South Channel),
Avon Township, NJ

AGENCY: Coast Guard, DHS.

ACTION: Final rule.

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

SUMMARY: The Coast Guard is removing the existing drawbridge operation
regulation that governs the opening of the S35 Bridge, mile 0.9, across
Shark River (South Channel) at Avon Township, NJ. The existing
regulation contains a drawbridge operation schedule for the S35 Bridge.
However, the existing bridge was modified in 2006 from a movable bridge
to a fixed bridge. Since the bridge is no longer a movable bridge, the
regulation controlling the opening and closing of the bridge is no
longer necessary.

DATES: This rule is effective November 26, 2012.

ADDRESSES: Documents indicated in this preamble as being available in
the docket, are part of docket USCG-2012-0930 and are available by
going to http://www.regulations.gov, inserting USCG-2012-0930 in the
``Keyword'' box, and then clicking ``Search.'' This material is also
available for inspection or copying at the Docket Management Facility
(M-30), U.S. Department of Transportation, West Building Ground Floor,
Room W12-140, 1200 New Jersey Avenue SE., Washington, DC 20590, between
9 a.m. and 5 p.m., Monday through Friday, except Federal holidays.

FOR FURTHER INFORMATION CONTACT: If you have questions on this rule,
call or email Jim Rousseau, Bridge Management Specialist, Fifth Coast
Guard District; telephone<PHONE_NUMBER>, email
<EMAIL_ADDRESS>If you have questions on viewing or
submitting material to the docket, call Renee V. Wright, Program
Manager, Docket Operations, telephone<PHONE_NUMBER>.

SUPPLEMENTARY INFORMATION:

Table of Acronyms

CFR Code of Federal Regulations
DHS Department of Homeland Security
FR Federal Register
NPRM Notice of Proposed Rulemaking
Sec.  Section Symbol
U.S.C. United States Code

A. Regulatory History and Information

    The Coast Guard is issuing this final rule without prior notice and
opportunity to comment pursuant to authority under section 4(a) of the
Administrative Procedure Act (APA) (5 U.S.C. 553(b)). This provision
authorizes an agency to issue a rule without prior notice and
opportunity to comment when the agency for good cause finds that those
procedures are ``impracticable, unnecessary, or contrary to the public
interest.'' Under 5 U.S.C. 553(b)(B), the Coast Guard finds that good
cause exists for not publishing a notice of proposed rulemaking (NPRM)
with respect to this rule because the S35 bridge that once required
draw operations as outlined in 33 CFR 117.751 was modified from a
movable bridge to a fixed bridge. As such, the bridge no longer opens
for the passage of vessels. Therefore, the regulation is no longer
applicable and should be removed from publication. It is unnecessary to
publish an NPRM because this regulatory action does not purport to
place any restrictions on mariners but rather removes a restriction
that has no further use or value.
    Under 5 U.S.C. 553(d)(1), a rule that relieves a restriction is not
required to provide the 30 day notice period before its effective date.
Since the purpose of this rule is to remove the S35 Bridge operation
requirements under 33 CFR 117.751, the Coast Guard is removing a
regulatory restriction currently imposed on the public. As such, the
Coast Guard finds that good cause exists for making this rule effective
in less than 30 days after publication in the Federal Register. The
bridge has been a fixed bridge for 6 years and this rule merely
requires an administrative change to the Federal Register, in order to
omit a regulatory requirement that is no longer applicable or
necessary. The modification has already taken place and the removal of
the regulation will not affect mariners currently operating on this
waterway.

B. Basis and Purpose

    On June 25, 1999, a Coast Guard Bridge Permit (1-99-5) was issued
to the New Jersey Department of Transportation (NJDOT) to replace the
existing bascule bridge, which carries S35 over Shark River (South
Channel) at Avon Township NJ, with a new fixed bridge. NJDOT completed
construction for a new fixed bridge in June 2006. The elimination of
this drawbridge necessitates the removal of the drawbridge operation
regulation, in 33 CFR 117.751 that contains an operating schedule
pertaining to the former drawbridge.

C. Discussion of the Final Rule

    The Coast Guard is changing the regulation in 33 CFR part 117
without publishing an NPRM. The change removes the regulation governing
a movable bridge that was modified to a fixed bridge. Specifically,
this rule will remove the section of 33 CFR 117.751 that refers to the
S35 Bridge at mile 0.9, from the Code of Federal Regulations since it
governs a bridge that is no longer able to be opened.

D. Regulatory Planning and Review

    We developed this rule after considering numerous statutes and
executive orders related to rulemaking. Below we summarize our analyses
based on a number of these statutes or executive orders.

1. Regulatory Analysis

    This rule is not a ``significant regulatory action'' under section
3(f) of Executive Order 12866, Regulatory Planning and Review, as
supplemented by Executive Order 13653, and does not require an
assessment of potential costs and benefits under section 6(a)(3) of
Order 12866 or under section 1 of Executive Order 13563. The Office of
Management and Budget has not reviewed it under those Orders. We
reached this conclusion based on the fact that a special operating
regulation exists for movable bridges and as this bridge has been
modified to a fixed bridge, the regulation is unnecessary.

2. Impact on Small Entities

    The Regulatory Flexibility Act of 1980 (RFA), 5 U.S.C. 601-612, as
amended, requires federal agencies to consider the potential impact of
regulations on small

entities during rulemaking. The term ``small entities'' comprises small
businesses, not-for-profit organizations that are independently owned
and operated and are not dominant in their fields, and governmental
jurisdictions with populations of less than 50,000. The Coast Guard
certifies under 5 U.S.C. 605(b) that this rule will not have a
significant economic impact on a substantial number of small entities.
This final rule would affect the following entities, some of which
might be small entities: None. Due to the fact that the bridge has been
a fixed bridge for 6 years, this final rule will not have a significant
economic impact on a substantial number of small entities.

3. Collection of Information

    This rule calls for no new collection of information under the
Paperwork Reduction Act of 1995 (44 U.S.C. 3501-3520.).

4. Federalism

    A rule has implications for federalism under Executive Order 13132,
Federalism, if it has a substantial direct effect on State or local
governments and would either preempt 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.
We have analyzed this rule under that Order and have determined that it
does not have implications for federalism.

5. Protest Activities

    The Coast Guard respects the First Amendment rights of protesters.
Protesters are asked to contact the person listed in the FOR FURTHER
INFORMATION CONTACT section to coordinate protest activities so that
your message can be received without jeopardizing the safety or
security of people, places or vessels.

6. Unfunded Mandates Reform Act

    The Unfunded Mandates Reform Act of 1995 (2 U.S.C. 1531-1538)
requires Federal agencies to assess the effects of their discretionary
regulatory actions. In particular, the Act addresses actions that may
result in the expenditure by a State, local, or tribal government, in
the aggregate, or by the private sector of $100,000,000 or more in any
one year. Though this rule will not result in such an expenditure, we
do discuss the effects of this rule elsewhere in this preamble.

7. Taking of Private Property

    This rule will not affect a taking of private property or otherwise
have taking implications under Executive Order 12630, Governmental
Actions and Interference with Constitutionally Protected Property
Rights.

8. Civil Justice Reform

    This rule meets applicable standards in sections 3(a) and 3(b)(2)
of Executive Order 12988, Civil Justice Reform, to minimize litigation,
eliminate ambiguity, and reduce burden.

9. Protection of Children

    We have analyzed this rule under Executive Order 13045, Protection
of Children from Environmental Health Risks and Safety Risks. This rule
is not an economically significant rule and does not create an
environmental risk to health or risk to safety that might
disproportionately affect children.

10. Indian Tribal Governments

    This rule does not have tribal implications under Executive Order
13175, Consultation and Coordination with Indian Tribal Governments,
because it would not have a substantial direct effect 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.

11. Energy Effects

    We have analyzed this rule under Executive Order 13211, Actions
Concerning Regulations That Significantly Affect Energy Supply,
Distribution, or Use. We have determined that it is not a ``significant
energy action'' under that order because it is not a ``significant
regulatory action'' under Executive Order 12866 and is not likely to
have a significant adverse effect on the supply, distribution, or use
of energy. The Administrator of the Office of Information and
Regulatory Affairs has not designated it as a significant energy
action. Therefore, it does not require a Statement of Energy Effects
under Executive Order 13211.

12. Technical Standards

    This rule does not use technical standards. Therefore, we did not
consider the use of voluntary consensus standards.

13. Environment

    We have analyzed this rule under Department of Homeland Security
Management Directive 023-01 and Commandant Instruction M16475.lD, which
guides the Coast Guard in complying with the National Environmental
Policy Act of 1969 (NEPA) (42 U.S.C. 4321-4370f), and have concluded
that this action is one of a category of actions which do not
individually or cumulatively have a significant effect on the human
environment. This rule is categorically excluded, under figure 2-1,
paragraph (32)(e), of the Instruction.
    Under figure 2-1, paragraph (32)(e), of the Instruction, an
environmental analysis checklist and a categorical exclusion
determination are not required for this rule.

List of Subjects in 33 CFR Part 117

    Bridges.

    For the reasons discussed in the preamble, the Coast Guard amends
33 CFR part 117 as follows:

PART 117--DRAWBRIDGE OPERATION REGULATIONS

0
1. The authority citation for part 117 continues to read as follows:

    Authority: 33 U.S.C. 499; 33 CFR 1.05-1; Department of Homeland
Security Delegation No. 0170.1.

0
2. Revise the introductory text and paragraph (a) of Sec.  117.751 to
read as follows:

Sec.  117.751  Shark River (South Channel).

    The draws of the S71 Bridge, mile 0.8, and the Railroad Bridge,
mile 0.9, both at Avon, operate as follows:
    (a) The bridges operate as one unit. The owners shall provide
signal systems so connected that the operator of either bridge may
simultaneously notify the operator of the other bridge. The operator of
the first bridge to be passed shall be responsible for observing the
approach vessels, for receiving and acknowledging signals, and for
coordinating the opening of the other draw.
* * * * *

    Dated: October 25, 2012.
Steven H. Ratti,
Rear Admiral, United States Coast Guard, Commander, Fifth Coast Guard
District.
[FR Doc. 2012-28127 Filed 11-23-12; 8:45 am]
BILLING CODE 9110-04-P


[Federal Register Volume 79, Number 164 (Monday, August 25, 2014)]
[Notices]
[Pages 50639-50640]
[FR Doc No: 2014-20063]

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

DEPARTMENT OF ENERGY

Federal Energy Regulatory Commission

[Docket No. RD14-5-000]

Proposed Agency Information Collection

AGENCY: Federal Energy Regulatory Commission.

ACTION: Comment request.

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

SUMMARY: In compliance with the requirements of the Paperwork Reduction
Act of 1995, 44 U.S.C. 3507(a)(1)(D), the Federal Energy Regulatory
Commission (Commission or FERC) is submitting the information
collection in Docket No. RD14-5-000 to the Office of Management and
Budget (OMB) for review of the information collection requirements. Any
interested person may file comments directly with OMB and should
address a copy of those comments to the Commission as explained below.
The Commission issued a Notice in the Federal Register (79 FR 27588, 5/
14/2014) requesting public comments. FERC received no comments in
response to that notice and has made this notation in its submission to
OMB.

DATES: Comments on the collection of information are due by September
24, 2014.

ADDRESSES: Comments filed with OMB, identified by the docket number,
should be sent via email to the Office of Information and Regulatory
Affairs<EMAIL_ADDRESS>Attention: Federal Energy Regulatory
Commission Desk Officer. The Desk Officer may also be reached via
telephone at<PHONE_NUMBER>.
    A copy of the comments should also be sent to the Federal Energy
Regulatory Commission, identified by the Docket No. RD14-5-000, by
either of the following methods:
     eFiling at Commission's Web site: http://www.ferc.gov/docs-filing/efiling.asp.
     Mail/Hand Delivery/Courier: Federal Energy Regulatory
Commission, Secretary of the Commission, 888 First Street NE.,
Washington, DC 20426.
    Instructions: All submissions must be formatted and filed in
accordance with submission guidelines at: http://www.ferc.gov/help/submission-guide.asp. For user assistance contact FERC Online Support
by email at<EMAIL_ADDRESS>or by phone at:<PHONE_NUMBER>
(toll-free), or<PHONE_NUMBER> for TTY.
    Docket: Users interested in receiving automatic notification of
activity in this docket or in viewing/downloading comments and
issuances in this docket may do so at http://www.ferc.gov/docs-filing/docs-filing.asp.

FOR FURTHER INFORMATION: Ellen Brown may be reached by email at
<EMAIL_ADDRESS>by telephone at<PHONE_NUMBER>, and by fax at
(202) 273-0873.

SUPPLEMENTARY INFORMATION: The proposed information collection in
Docket No. RD14-5-000 relates to the proposed Reliability Standards
MOD-032-1 (Data for Power System Modeling and Analysis) and MOD-033-1
(Steady-State and Dynamics System Model Validation), developed by the
North American Electric Reliability Corporation (NERC), and submitted
to the Commission for approval. NERC's petition related to the proposed
Reliability Standards MOD-032-1 and MOD-033-1 was approved on May 1,
2014, pursuant to the relevant authority delegated to the Director,
Office of Electric Reliability under 18 CFR 375.303.
    Reliability Standard MOD-032-1 consolidates NERC-approved
Reliability Standards MOD-011-0, MOD-013-1 and MOD-014-0, as well as,
Commission approved Reliability Standards MOD-010-0 and MOD-012-0, into
one standard.\1\ Reliability Standard MOD-032-1 requires data
submission by applicable data owners to their respective transmission
planners and planning coordinators to support the interconnection model
building process in their interconnection. Reliability Standard MOD-
033-1 is a new standard that requires each planning coordinator to
implement a documented process to perform model validation within its
planning area. The purpose of the Reliability Standards is to establish
comprehensive modeling data requirements, reporting procedures, and
validation requirements necessary to accurately model the
interconnected transmission system for the near-term transmission
planning horizon and the long-term transmission planning horizon.
---------------------------------------------------------------------------

    \1\ In Order No. 693, the Commission approved Reliability
Standards MOD-010 and MOD-012. Regarding Reliability Standards MOD-
011, MOD-013, MOD-014, and MOD-015, the Commission in Order No. 693
did not approve or remand the standards, pending the receipt of
additional information. Mandatory Reliability Standards for the
Bulk-Power System, Order No. 693, 72 FR 16416 (Apr. 4, 2007), at PP
1131-1222, order on reh'g, Order No. 693-A, 120 FERC ] 61,053
(2007).
---------------------------------------------------------------------------

    Burden Statement: The number of respondents is based on the NERC
Registry as of April 30, 2014. Public reporting burden for this
proposed collection is estimated as:

                                                                        MOD-032-1
                                                      [Data for power system modeling and analysis]
--------------------------------------------------------------------------------------------------------------------------------------------------------
                                                                  Number of    Average burden
            FERC-725L\2\               Number of respondents    responses per     hours per     Total annual             Total annual cost \4\
                                                \3\              respondent       response      burden hours
                                      (1)....................             (2)             (3)     (1) x (2) x
                                                                                (3)
--------------------------------------------------------------------------------------------------------------------------------------------------------
Develop data requirements and         200 (PA, TP)...........               1               8           1,600  $96,000 one-time ($60/hr).
 reporting procedures.
Data Submittal......................  1,355 (BA, GO, LSE, PA,               1               8          10,840  $650,400 ($60/hr).
                                       RP, TO, TP, TSP).
Evidence Retention..................  1,355 (BA, GO, LSE, PA,               1               1           1,355  $43,360 ($32/hr).
                                       RP, TO, TP, TSP).
                                                              ------------------------------------------------------------------------------------------
    Total...........................  .......................  ..............  ..............          13,795  $789,760.
--------------------------------------------------------------------------------------------------------------------------------------------------------

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

    \2\ In the May 14 public notice we listed the FERC Collection as
FERC-725A. It is corrected to FERC-725L in this notice.
    \3\ PA = Planning Authority, GO = Generator Owner, TP =
Transmission Planner, BA = Balancing Authority, LSE = Load Serving
Entity, RP = Resource Planner, TSP = Transmission Service Provider,
RC = Reliability Coordinator, TOP = Transmission Operator.
    \4\ The estimates for cost per hour (rounded to the nearest
dollar) are derived as follows:
     $60/hour, the average salary plus benefits per engineer
(from Bureau of Labor Statistics at http://bls.gov/oes/current/naics3_221000.htm).
     $32/hour, the salary plus benefits per information and
record clerks (from Bureau of Labor Statistics at http://bls.gov/oes/current/naics3_221000.htm).

                                                                        MOD-033-1
                                                   [Steady-state and dynamics system model validation]
--------------------------------------------------------------------------------------------------------------------------------------------------------
                                                                  Number of    Average burden
              FERC-725L                Number of respondents    responses per     hours per     Total annual             Total annual cost \4\
                                                \3\              respondent       response      burden hours
                                      (1)....................             (2)             (3)     (1) x (2) x
                                                                                (3)
--------------------------------------------------------------------------------------------------------------------------------------------------------
Develop data validation procedures..  75 (PA)................               1               8             600  $36,000 one-time ($60/hr)
Data Submittal......................  196 (RC, TOP)..........               1               8           1,568  $94,080 ($60/hr).
Evidence Retention..................  200 (PA, RC, TOP)......               1               1             200  $6,400 ($32/hr).
                                                              ------------------------------------------------------------------------------------------
    Total...........................  .......................  ..............  ..............           2,368  $136,480.
--------------------------------------------------------------------------------------------------------------------------------------------------------

    Dated: August 18, 2014.
Kimberly D. Bose,
Secretary.
[FR Doc. 2014-20063 Filed 8-22-14; 8:45 am]
BILLING CODE 6717-01-P


[Federal Register Volume 79, Number 101 (Tuesday, May 27, 2014)]
[Notices]
[Page 30204]
[FR Doc No: 2014-12310]

=======================================================================
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SECURITIES AND EXCHANGE COMMISSION

Sunshine Act Meeting.

    Notice is hereby given, pursuant to the provisions of the
Government in the Sunshine Act, Public Law 94-409, that the Securities
and Exchange Commission will hold a Closed Meeting on May 29, 2014 at
3:00 p.m.
    Commissioners, Counsel to the Commissioners, the Secretary to the
Commission, and recording secretaries will attend the Closed Meeting.
Certain staff members who have an interest in the matters also may be
present.
    The General Counsel of the Commission, or her designee, has
certified that, in her opinion, one or more of the exemptions set forth
in 5 U.S.C. 552b(c)(3), (5), (7), 9(B) and (10) and 17 CFR
200.402(a)(3), (5), (7), 9(ii) and (10), permit consideration of the
scheduled matter at the Closed Meeting.
    Commissioner Stein, as duty officer, voted to consider the items
listed for the Closed Meeting in closed session.
    The subject matter of the Closed Meeting will be: institution and
settlement of injunctive actions; institution and settlement of
administrative proceedings; and other matters relating to enforcement
proceedings.
    At times, changes in Commission priorities require alterations in
the scheduling of meeting items.
    For further information and to ascertain what, if any, matters have
been added, deleted or postponed, please contact the Office of the
Secretary at<PHONE_NUMBER>.

    Dated: May 21, 2014.
Kevin M. O'Neill,
Deputy Secretary.
[FR Doc. 2014-12310 Filed 5-22-14; 4:15 pm]
BILLING CODE 8011-01-P


[Federal Register: August 11, 2010 (Volume 75, Number 154)]
[Notices]
[Page 48665]
[DOCID:fr11au10-49]

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

DEPARTMENT OF ENERGY

Federal Energy Regulatory Commission

[Docket No. ER10-2078-000]

White Oak Energy LLC; Supplemental Notice That Initial Market-
Based Rate Filing Includes Request for Blanket Section 204
Authorization

August 4, 2010.
    This is a supplemental notice in the above-referenced proceeding,
of White Oak Energy LLC's application for market-based rate authority,
with an accompanying rate schedule, noting that such application
includes a request for blanket authorization, under 18 CFR part 34, of
future issuances of securities and assumptions of liability.
    Any person desiring to intervene or to protest should file with the
Federal Energy Regulatory Commission, 888 First Street, NE.,
Washington, DC 20426, in accordance with Rules 211 and 214 of the
Commission's Rules of Practice and Procedure (18 CFR 385.211 and
385.214). Anyone filing a motion to intervene or protest must serve a
copy of that document on the Applicant.
    Notice is hereby given that the deadline for filing protests with
regard to the applicant's request for blanket authorization, under 18
CFR part 34, of future issuances of securities and assumptions of
liability is August 24, 2010.
    The Commission encourages electronic submission of protests and
interventions in lieu of paper, using the FERC Online links at http://
www.ferc.gov. To facilitate electronic service, persons with Internet
access who will eFile a document and/or be listed as a contact for an
intervenor must create and validate an eRegistration account using the
eRegistration link. Select the eFiling link to log on and submit the
intervention or protests.
    Persons unable to file electronically should submit an original and
14 copies of the intervention or protest to the Federal Energy
Regulatory Commission, 888 First St., NE., Washington, DC 20426.
    The filings in the above-referenced proceeding(s) are accessible in
the Commission's eLibrary system by clicking on the appropriate link in
the above list. They are also available for review in the Commission's
Public Reference Room in Washington, DC. There is an eSubscription link
on the Web site that enables subscribers to receive email notification
when a document is added to a subscribed dockets(s). For assistance
with any FERC Online service, please e-mail<EMAIL_ADDRESS>
or call<PHONE_NUMBER> (toll free). For TTY, call<PHONE_NUMBER>.

Nathaniel J. Davis, Sr.,
Deputy Secretary.
[FR Doc. 2010-19775 Filed 8-10-10; 8:45 am]
BILLING CODE 6717-01-P


 Forwarded by Pam Long/ RTP/ USEPA/ US on 10/ 06/ 2003 11: 34 AM  Dave Svendsgaard 08/ 22/ 2003 01: 47 PM To: Amy_ L._ Farrell@ omb. eop. gov cc: Bill Wehrum/ DC/ USEPA/ US@ EPA, Jeff Holmstead/ DC/ USEPA/ US@ EPA , Lynn Hutchinson/ RTP/ USEPA/ US@ EPA, Racqueline Shelton/ RTP/ USEPA/ US@ EPA, Bill Harnett/ RTP/ USEPA/ US@ EPA, Arthur_ G._ Fraas@ omb. eop. gov, ( bcc: Pam Long/ RTP/ USEPA/ US) Subject: 8/ 22 Revision of ERP Preamble and Rule Amy, Attached are the revised Rule and Preamble files for the ERP and corresponding redline versions. The redlined versions are compared against the 8/ 19 versions.

We wanted to give you a heads up on one item that we are tracking here at OAQPS. Since the decision to add into the preamble several industry specific process unit definitions that were submitted by commenters, we've had our technical folks review them to see if they had concerns with the proposed definitions. This review will not conclude until later today, but in one or two cases so far, we've heard concerns with how the commenter's proposed definition would work within the framework of our rule. We'll have more information on where we stand on this issue when we re convene ( presumably Monday), and we can share our thoughts with you and the rest of the review team then.

dave Positions or views expressed do not represent official EPA policy or guidance and are CONFIDENTIAL.


species. orig stage year impinged. est entrained. est junk junk  999  999  999 atlantic. menhaden age01 1985 8,176 na bay. anchovy age01 1985 1,694 na mummichog age01 1985 5,432 na inland. silverside age01 1985 350 na atlantic. silverside age01 1985 2,562 na white. perch age01 1985 28 na spot age01 1985 308 na atlantic. croaker age01 1985 826 na winter. flounder age01 1985 98 na blue. crab. hard age01 1985 53,102 na blue. crab. soft age01 1985 70 na american. eel age01 1985 42 na alewife age01 1985 14 na gizzard. shad age01 1985 266 na brown. trout age01 1985 70 na goldfish age01 1985 14 na spottail. shiner age01 1985 364 na catfish. spp age01 1985 84 na brown. bullhead age01 1985 14 na striped. cusk. eel age01 1985 14 na striped. killifish age01 1985 14 na silverside age01 1985 126 na pumpkinseed age01 1985 14 na sunfish. spp age01 1985 28 na yellow. perch age01 1985 14 na notes comments QC junk junk junk Table 3 6 of 34695 AM Table 3 6 of 34695 AM Table 3 6 of 34695 AM Table 3 6 of 34695 AM Table 3 6 of 34695 AM Table 3 6 of 34695 AM Table 3 6 of 34695 AM Table 3 6 of 34695 AM Table 3 6 of 34695 AM Table 3 6 of 34695 AM Table 3 6 of 34695 AM Table 3 3 of 34695, scaled to annual total AM Table 3 3 of 34695, scaled to annual total AM Table 3 3 of 34695, scaled to annual total AM Table 3 3 of 34695, scaled to annual total AM Table 3 3 of 34695, scaled to annual total AM Table 3 3 of 34695, scaled to annual total AM Table 3 3 of 34695, scaled to annual total AM Table 3 3 of 34695, scaled to annual total AM Table 3 3 of 34695, scaled to annual total AM Table 3 3 of 34695, scaled to annual total AM Table 3 3 of 34695, scaled to annual total AM Table 3 3 of 34695, scaled to annual total AM Table 3 3 of 34695, scaled to annual total AM Table 3 3 of 34695, scaled to annual total AM Impingement and entrainment losses data for the Baltimore RESCO Facility ( Phase 2) For the project Intake Jennifer Hazen July 15, 2005 Facility is located in Baltimore, near the upper Middle Branch of Baltimore Harbor ( estuarine). QC by Anton Miescher Impingement Collected 3 samples at 8hour intervals over a 24 hour period. When full 8 hours not sampled the count was extrapolated by scaling up to an 8 hour sample equivalen Counts added from 3 samples within a day to get 24hour total count. 2 sampling days in each of 13 4 week periods.

4 week period total calculated by summing total for 2 days, dividing by 2 and multiplying by 28. Annual total is sum of the 13 4 week totals.

Check. Atlantic Menhaden 10 Jul 85 24 Jul 85 total caught4 week extrapolation 38 5 43 602 * matches their estimate.

584 8176 Same formula applied to total gets annual. assigned number 34695 Intake lent. name. as. entered species. orig species. lh stage. as. enterestage year atlantic. menhaden atlantic. menhaden atlantic. menhaden2 na age01 1985 bay. anchovy bay. anchovy bay. anchovy na age01 1985 mummichog mummichog non. ris. forage2 na age01 1985 inland. silverside inland. silverside non. ris. forage2 na age01 1985 atlantic. silverside atlantic. silverside atlantic. silverside na age01 1985 white. perch white. perch white. perch2 na age01 1985 spot spot spot2 na age01 1985 atlantic. croaker atlantic. croaker atlantic. croaker2 na age01 1985 winter. flounder winter. flounder winter. flounder. mid na age01 1985 blue. crab. hard blue. crab. hard blue. crab na age01 1985 blue. crab. soft blue. crab. soft blue. crab na age01 1985 american. eel american. eel non. ris. com na age01 1985 alewife alewife alewife2 na age01 1985 gizzard. shad gizzard. shad non. ris. com na age01 1985 brown. trout brown. trout non. ris. forage na age01 1985 goldfish goldfish carp na age01 1985 spottail. shiner spottail. shiner non. ris. forage2 na age01 1985 catfish. spp catfish. spp channel. catfish na age01 1985 brown. bullhead brown. bullhead non. ris. com na age01 1985 striped. cusk. eel striped. cusk eel non. ris. rec na age01 1985 striped. killifish striped. killifish striped. killifish na age01 1985 silverside. spp silverside atlantic. silverside na age01 1985 pumpkinseed pumpkinseed non. ris. forage2 na age01 1985 sunfish. spp sunfish. spp sunfish na age01 1985 yellow. perch yellow. perch non. ris. com na age01 1985 impinged. est entrained. est notes comments 8,176 na Table 3 6 of 34695 1,694 na Table 3 6 of 34695 5,432 na Table 3 6 of 34695 350 na Table 3 6 of 34695 2,562 na Table 3 6 of 34695 28 na Table 3 6 of 34695 308 na Table 3 6 of 34695 826 na Table 3 6 of 34695 98 na Table 3 6 of 34695 53,102 na Table 3 6 of 34695 70 na Table 3 6 of 34695 42 na Table 3 3 of 34695, scaled to annual total 14 na Table 3 3 of 34695, scaled to annual total 266 na Table 3 3 of 34695, scaled to annual total 70 na Table 3 3 of 34695, scaled to annual total 14 na Table 3 3 of 34695, scaled to annual total 364 na Table 3 3 of 34695, scaled to annual total 84 na Table 3 3 of 34695, scaled to annual total 14 na Table 3 3 of 34695, scaled to annual total 14 na Table 3 3 of 34695, scaled to annual total 14 na Table 3 3 of 34695, scaled to annual total 126 na Table 3 3 of 34695, scaled to annual total 14 na Table 3 3 of 34695, scaled to annual total 28 na Table 3 3 of 34695, scaled to annual total 14 na Table 3 3 of 34695, scaled to annual total QC Species annual impingement source atlantic. menhaden 8176 Table 3 6 of 34695 bay. anchovy 1694 Table 3 6 of 34695 mummichog 5432 Table 3 6 of 34695 inland. silverside 350 Table 3 6 of 34695 atlantic. silverside 2562 Table 3 6 of 34695 white. perch 28 Table 3 6 of 34695 spot 308 Table 3 6 of 34695 atlantic. croaker 826 Table 3 6 of 34695 winter. flounder 98 Table 3 6 of 34695 blue. crab. hard 53102 Table 3 6 of 34695 blue. crab. soft 70 Table 3 6 of 34695 grass. shrimp 6454 Table 3 6 of 34695 american. eel 42 Table 3 3 of 34695, scaled to annual total alewife 14 Table 3 3 of 34695, scaled to annual total gizzard. shad 266 Table 3 3 of 34695, scaled to annual total brown. trout 70 Table 3 3 of 34695, scaled to annual total goldfish 14 Table 3 3 of 34695, scaled to annual total spottail. shiner 364 Table 3 3 of 34695, scaled to annual total catfish. spp 84 Table 3 3 of 34695, scaled to annual total brown. bullhead 14 Table 3 3 of 34695, scaled to annual total striped. cusk. eel 14 Table 3 3 of 34695, scaled to annual total striped. killifish 14 Table 3 3 of 34695, scaled to annual total silverside. spp 126 Table 3 3 of 34695, scaled to annual total pumpkinseed 14 Table 3 3 of 34695, scaled to annual total sunfish. spp 28 Table 3 3 of 34695, scaled to annual total yellow. perch 14 Table 3 3 of 34695, scaled to annual total species 10 Jul 85 24 Jul 85 8 Aug 85 21 Aug 85 4 Sep 85 17 Sep 85 american. eel 0 0 0 0 0 0 alewife 0 0 0 0 0 0 gizzard. shad 0 0 0 0 0 0 brown. trout 0 0 0 0 0 0 goldfish 0 0 0 0 0 0 spottail. shiner 4 0 0 0 0 0 catfish. spp 0 0 0 0 0 1 brown. bullhead 0 0 0 0 0 0 striped. cusk. eel 0 0 0 0 0 0 striped. killifish 0 0 0 0 0 0 silverside. spp 0 0 0 0 0 3 pumpkinseed 0 0 0 1 0 0 sunfish. spp 0 0 0 0 0 1 yellow. perch 0 0 0 0 0 0 2 Oct 85 16 Oct 85 29 Oct 85 15 Nov 85 26 Nov 85 11 Dec 85 23 Dec 85 7 Jan 86 21 Jan 86 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 8 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 8 0 0 0 0 0 0 1 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 0 0 0 0 0 0 0 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 3 3 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 0 0 0 0 0 0 0 0 0 4 Feb 86 18 Feb 86 4 Mar 86 18 Mar 86 2 Apr 86 16 Apr 86 29 Apr 86 13 May 86 29 May 86 0 0 0 0 1 2 0 0 0 0 0 0 0 1 0 0 0 0 1 4 0 4 0 0 2 0 0 0 0 0 0 0 5 0 0 0 0 1 0 0 0 0 0 0 0 5 2 0 5 0 0 0 0 0 0 0 0 0 0 5 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 0 0 0 0 0 0 10 Jun 86 24 Jun 86 Total Scaled annual using method from report. 0 0 3 42 0 0 1 14 0 0 19 266 0 0 5 70 0 0 1 14 0 0 26 364 0 0 6 84 0 0 1 14 0 0 1 14 1 0 1 14 0 0 9 126 0 0 1 14 0 0 2 28 0 0 1 14


[Federal Register Volume 86, Number 244 (Thursday, December 23, 2021)]
[Notices]
[Pages 72948-72949]
[FR Doc No: 2021-27776]

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DEPARTMENT OF ENERGY

Federal Energy Regulatory Commission

[Docket No. AD20-20-000]

Notice of Availability of Final Engineering Guidelines for the
Evaluation of Hydropower Projects: Chapter 15--Supporting Technical
Information Document and Digital Project Archive

    The staff of the Federal Energy Regulatory Commission (FERC or
Commission) has prepared a final ``Chapter 15--Supporting Technical
Information Document and Digital Project Archive'' of its Engineering
Guidelines for the Evaluation of Hydropower Projects (Guidelines). This
chapter supersedes the portions of ``Chapter 14--Dam Safety Performance
Monitoring Program'' that pertain to the Supporting Technical
Information Document, and is one of four new chapters of the Guidelines
intended to provide additional guidance related to 18 CFR part 12,
Safety of Water Power Projects and Project Works, Docket No. RM20-9-
000, Order No 880, issued by the Commission on December 16, 2021.
    On July 16, 2020, the Commission issued a Notice of Proposed
Rulemaking (NOPR) to revise its part 12 regulations. On the same day,
the Commission solicited public review and comment on four new draft
chapters of its Guidelines. Draft Chapter 15 was part of that issuance.
    The Commission received ten comment letters in response to draft
Chapter 15. Most of the comments were submitted by licensees and
individuals through trade associations, including National Hydropower
Association, Dam Safety Interest Group of CEATI International, and U.S.
Society on Dams, as well as the U.S. Army Corps of Engineers. Comments
were also received from individual licensees, corporations, and
individuals, including David L. Mathews, McMillen Jacobs Associates,
City of North Little Rock Electric, Alaska Electric Light and Power
Company, Central Nebraska Public Power and Irrigation District, and
Copper Valley Electric Association.
    In all, the ten comment letters consisted of approximately 105
discrete comments. The comments received were varied. Most comments
requested clarification of the information to include in the Supporting
Technical Information Document (STID), when STID updates should be
submitted, and how the information should be stored and filed.
Commenters asked the Commission to:
     Clarify the use of hyperlinks in the STID;
     Clarify when STID updates are to be submitted;
     Clarify the requirement for providing searchable
electronic documents from original hard copies;
     Consider adding the use of secured shared drives as a
storage option;
     Reconsider the need for a hard copy of the STID;
     Avoid the duplication of information included in the
Standard Operating Procedures section that is also included in other
sections of the STID;
     Provide additional guidance on the type of information and
reports to be included in each section of the engineering analyses; and
     Clarify the information to be included in the digital
references.
    Commission staff has considered all comments in finalizing Chapter
15 of the Engineering Guidelines. Based on the comments received,
Chapter 15 has been revised to:
     Provide additional guidance on the types of information to
include in the digital references, now termed the Digital Project
Archive (DPA);
     Clarify how to file the DPA;
     Clarify the purpose of the STID and the DPA;
     Clarify the contents and format of the STID;
     Provide a file structure and organization for the DPA; and
     Clarify when updates of the STID and DPA should be
submitted.
    All information related to ``Chapter 15--Supporting Technical
Information Document and Digital Project Archive,'' including the draft
chapter, all submitted comments, and the final chapter, can be found 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,
excluding the last three digits in the Docket Number field (i.e., AD20-
20). Be sure you have selected an appropriate date range. The
Commission also offers a free service called eSubscription which allows
you to keep track of all formal issuances and submittals in specific
dockets. This can reduce the amount of time you spend researching
proceedings by automatically providing you with electronic notification
of these filings and direct links to the documents. Go to the
Commission's website (www.ferc.gov), select the FERC Online option from
the left-hand column, and click on eSubscription. Users must be
registered in order to use eSubscription.
    The final version of Chapter 15 is also available on the
Commission's Division of Dam Safety and Inspections website at:
Engineering Guidelines for the Evaluation of Hydropower Projects [bond]
Federal Energy Regulatory Commission (ferc.gov).

Information Collection Statement

    Chapter 15 includes information collection activities for which the
Paperwork Reduction Act, 44 U.S.C. 3501-3521, requires approval by the
Office of Management and Budget (OMB). The Commission has included the
burden and cost estimates for information collection activities related
to this chapter in the rulemaking document (Docket No. RM20-9-000,
Order No. 880. The Commission has

designated the information collection activities in the rule as FERC-
517. Upon final approval of FERC-517, OMB will assign an OMB Control
Number and expiration date.
    Send written comments on FERC-517 to the Office of Management and
Budget (OMB) through www.reginfo.gov/public/do/PRAMain, Attention:
Federal Energy Regulatory Commission Desk Officer. Please identify the
OMB control number (1902-TBD) in the subject line. Your comments should
be sent within 30 days of publication of this notice in the Federal
Register. OMB submissions must be formatted and filed in accordance
with submission guidelines at www.reginfo.gov/public/do/PRAMain. Using
the search function under the ``Currently Under Review field,'' select
Federal Energy Regulatory Commission; click ``submit'' and select
``comment'' to the right of the subject collection.
    For assistance with any of the Commission's online systems, please
contact FERC Online Support at ferc.gov">[email protected]ferc.gov or toll free
at<PHONE_NUMBER>, or for TTY, contact<PHONE_NUMBER>.

    Dated: December 16, 2021.
Kimberly D. Bose,
Secretary.
[FR Doc. 2021-27776 Filed 12-22-21; 8:45 am]
BILLING CODE 6717-01-P


[Federal Register Volume 76, Number 246 (Thursday, December 22, 2011)]
[Notices]
[Page 79678]
[FR Doc No: 2011-32769]

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DEPARTMENT OF ENERGY

Federal Energy Regulatory Commission

 [Docket No. EL12-14-000]

Trans-Allegheny Interstate Line Company; Notice of Petition For
Declaratory Order

    Take notice that on December 14, 2011, pursuant to Rule 207 of the
Rules of Practice and Procedure of the Federal Energy Regulatory
Commission (Commission), 18 CFR 385.207 (2011), Trans-Allegheny
Interstate Line Company (TrAILCo) filed a Petition for Declaratory
Order, requesting that the Commission find that the payment by TrAILCo
of one or more dividends from paid-in capital, subject to proposed
safeguards, will not violate section 305(a) of the Federal Power Act.
    Any person desiring to intervene or to protest this filing must
file in accordance with Rules 211 and 214 of the Commission's Rules of
Practice and Procedure (18 CFR 385.211, 385.214). Protests will be
considered by the Commission in determining the appropriate action to
be taken, but will not serve to make protestants parties to the
proceeding. Any person wishing to become a party must file a notice of
intervention or motion to intervene, as appropriate. Such notices,
motions, or protests must be filed on or before the comment date. On or
before the comment date, it is not necessary to serve motions to
intervene or protests on persons other than the Applicant.
    The Commission encourages electronic submission of protests and
interventions in lieu of paper using the ``eFiling'' link at http://www.ferc.gov. Persons unable to file electronically should submit an
original and 14 copies of the protest or intervention to the Federal
Energy Regulatory Commission, 888 First Street NE., Washington, DC
20426.
    This filing is accessible on-line at http://www.ferc.gov, using the
``eLibrary'' link and is available for review in the Commission's
Public Reference Room in Washington, DC. There is an ``eSubscription''
link on the Web site that enables subscribers to receive email
notification when a document is added to a subscribed docket(s). For
assistance with any FERC Online service, please email
<EMAIL_ADDRESS>or call<PHONE_NUMBER> (toll free). For
TTY, call<PHONE_NUMBER>.
    Comment Date: 5 p.m. Eastern Time on December 23, 2011.

    Dated: December 16, 2011.
Kimberly D. Bose,
Secretary.
[FR Doc. 2011-32769 Filed 12-21-11; 8:45 am]
BILLING CODE 6717-01-P


[Federal Register Volume 86, Number 83 (Monday, May 3, 2021)]
[Notices]
[Pages 23411-23412]
[FR Doc No: 2021-09175]

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DEPARTMENT OF HOMELAND SECURITY

Federal Emergency Management Agency

[Internal Agency Docket No. FEMA-4591-DR; Docket ID FEMA-2021-0001]

Poarch Band of Creek Indians; Major Disaster and Related
Determinations

AGENCY: Federal Emergency Management Agency, DHS.

ACTION: Notice.

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SUMMARY: This is a notice of the Presidential declaration of a major
disaster for the Poarch Band of Creek Indians (FEMA-4591-DR), dated
March 28, 2021, and related determinations.

DATES: The declaration was issued March 28, 2021.

FOR FURTHER INFORMATION CONTACT: Dean Webster, Office of Response and
Recovery, Federal Emergency Management Agency, 500 C Street SW,
Washington, DC 20472,<PHONE_NUMBER>.

SUPPLEMENTARY INFORMATION: Notice is hereby given that, in a letter
dated March 28, 2021, the President issued a major disaster declaration
under the authority of the Robert T. Stafford Disaster Relief and
Emergency Assistance Act, 42 U.S.C. 5121 et seq. (the ``Stafford
Act''), as follows:

    I have determined that the emergency conditions associated with
the Poarch Band of Creek Indians resulting from the Coronavirus
Disease 2019 (COVID-19) pandemic beginning on January 20, 2020, and
continuing, are of sufficient severity and magnitude to warrant a
major disaster declaration under the Robert T. Stafford Disaster
Relief and Emergency Assistance Act, 42 U.S.C. 5121 et seq. (the
``Stafford Act''). Therefore, I declare that such a major disaster
exists for the Poarch Band of Creek Indians.
    In order to provide Federal assistance, you are hereby
authorized to allocate from funds available for these purposes such
amounts as you find necessary for Federal disaster assistance and
administrative expenses.
    You are authorized to provide Individual Assistance limited to
the Crisis Counseling Program and assistance for emergency
protective measures (Category B), including direct Federal
assistance, under the Public Assistance program for the Poarch Band
of Creek Indians. Consistent with the requirement that Federal
assistance be supplemental, any Federal funds provided under the
Stafford Act for Public Assistance will be limited to 75 percent of
the total eligible costs.
    Further, you are authorized to make changes to this declaration
for the approved assistance to the extent allowable under the
Stafford Act.

    The Federal Emergency Management Agency (FEMA) hereby gives notice
that pursuant to the authority vested in the Administrator, under
Executive Order 12148, as amended, Gracia B. Szczech, of FEMA is
appointed to act as the Federal Coordinating Officer for this major
disaster.
    The following areas of the Poarch Band of Creek Indians have been
designated as adversely affected by this major disaster:

    Individual Assistance limited to the Crisis Counseling Program
for the Poarch Band of Creek Indians.
    Emergency protective measures (Category B) not authorized under
other federal statutes, including direct federal assistance, under
the Public Assistance program for the Poarch Band of Creek Indians.

(The following Catalog of Federal Domestic Assistance Numbers (CFDA)
are to be used for reporting and drawing funds: 97.030, Community
Disaster Loans; 97.031, Cora Brown Fund; 97.032, Crisis Counseling;
97.033, Disaster Legal Services; 97.034, Disaster Unemployment
Assistance (DUA); 97.046, Fire Management Assistance Grant; 97.048,
Disaster Housing Assistance to Individuals and Households In
Presidentially Declared Disaster Areas; 97.049, Presidentially
Declared Disaster Assistance--Disaster Housing Operations for
Individuals and Households; 97.050, Presidentially Declared Disaster
Assistance to Individuals and Households--Other Needs; 97.036,
Disaster Grants--Public Assistance (Presidentially Declared
Disasters); 97.039, Hazard Mitigation Grant.)

Robert J. Fenton,
Senior Official Performing the Duties of the Administrator, Federal
Emergency Management Agency.
[FR Doc. 2021-09175 Filed 4-30-21; 8:45 am]
BILLING CODE 9111-23-P