[Federal Register Volume 82, Number 214 (Tuesday, November 7, 2017)]
[Notices]
[Page 51670]
[FR Doc No: 2017-24219]

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DEPARTMENT OF TRANSPORTATION

Federal Aviation Administration

Twenty First RTCA SC-227 Standards of Navigation Performance
Plenary

AGENCY: Federal Aviation Administration (FAA), U.S. Department of
Transportation (DOT).

ACTION: Twenty First RTCA SC-227 Standards of Navigation Performance
Plenary.

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SUMMARY: The FAA is issuing this notice to advise the public of a
meeting of Twenty First RTCA SC-227 Standards of Navigation Performance
Plenary.

DATES: The meeting will be held December 4-8, 2017, 9:00 a.m.-5:00 p.m.

ADDRESSES: The meeting will be held at: RTCA Headquarters, 1150 18th
Street NW., Suite 910, Washington, DC 20036.

FOR FURTHER INFORMATION CONTACT:  Rebecca Morrison at
[email protected] or<PHONE_NUMBER>, or The RTCA Secretariat, 1150 18th
Street NW., Suite 910, Washington, DC 20036, or by telephone at (202)
833-9339, fax at<PHONE_NUMBER>, or Web site at http://www.rtca.org.

SUPPLEMENTARY INFORMATION: Pursuant to section 10(a) (2) of the Federal
Advisory Committee Act (Pub. L. 92-463, 5 U.S.C., App.), notice is
hereby given for a meeting of the Twenty First RTCA SC-227 Standards of
Navigation Performance Plenary. The agenda will include the following:

Monday December 4, 2017, 9:00 a.m.-5:00 p.m.

1. Welcome and Administrative Remarks
2. Introduction
3. Review of Minutes from Meeting 20.
4. Agenda Overview
5. Schedule
6. New Business
7. Review and disposition comments received from Final Review and
Comment period
8. Review updated TOR

Tuesday December 5, 2017, 9:00 a.m.-5:00 p.m.

9. Continue Plenary Agenda

Wednesday December 8, 2017, 9:00 a.m.-5:00 p.m.

10. Continue Plenary Agenda

Thursday December 7, 2017, 9:00 a.m.-5:00 p.m.

11. Continue Plenary Agenda

Friday December 8, 2017, 9:00 a.m.-5:00 p.m.

12. Continue Plenary Agenda
13. Adjourn when Agenda is complete

    Attendance is open to the interested public but limited to space
availability. With the approval of the chairman, members of the public
may present oral statements at the meeting. Persons wishing to present
statements or obtain information should contact the person listed in
the FOR FURTHER INFORMATION CONTACT section. Members of the public may
present a written statement to the committee at any time.

    Issued in Washington, DC on November 2, 2017.
Mohannad Dawoud,
Management & Program Analyst, Partnership Contracts Branch, ANG-A17,
NextGen, Procurement Services Division, Federal Aviation
Administration.
[FR Doc. 2017-24219 Filed 11-6-17; 8:45 am]
 BILLING CODE 4910-13-P


[Federal Register Volume 88, Number 33 (Friday, February 17, 2023)]
[Notices]
[Pages 10343-10344]
[FR Doc No: 2023-03367]

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DEPARTMENT OF HEALTH AND HUMAN SERVICES

Food and Drug Administration

[Docket No. FDA-2022-N-2391]

Miles Laboratories Inc.; Withdrawal of Approval of an Abbreviated
New Drug Application for Alcohol and Dextrose Injection; 5 Milliliters/
100 Milliliters, 5 Grams/100 Milliliters

AGENCY: Food and Drug Administration, HHS.

ACTION: Notice.

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SUMMARY: The Food and Drug Administration (FDA or Agency) is
withdrawing approval of an abbreviated new drug application (ANDA) for
Alcohol and Dextrose Injection, 5 milliliters (mL)/100 mL, 5 grams (g)/
100 mL. The bases for the withdrawal are that the ANDA holder has
repeatedly failed to file required annual reports for this ANDA and
that the Agency has scientific data and experience to show that the
drug product under this ANDA is unsafe for use under the conditions of
use for which the product was approved.

DATES: Approval is withdrawn as of February 17, 2023.

FOR FURTHER INFORMATION CONTACT: Kaetochi Okemgbo, Center for Drug
Evaluation and Research, Food and Drug Administration, 10903 New
Hampshire Ave., Bldg. 51, Rm. 6224, Silver Spring, MD 20993-0002, 301-
796-1546, [email protected].

SUPPLEMENTARY INFORMATION: The holder of an approved ANDA to market a
new drug for human use is required to submit annual reports to FDA
concerning its approved ANDA under Sec. Sec.  314.81 and 314.98 (21 CFR
314.81 and 314.98). Additionally, under 21 CFR 314.161, FDA previously
determined that Alcohol and Dextrose Injection, 5 mL/100 mL, 5 g/100
mL, approved under ANDA 083483 was withdrawn from sale for safety and
effectiveness reasons (see 86 FR 72606, December 22, 2021) (this
determination also applied to other applications and to the 10 mL/100
mL, 5 g/100 mL strength of Alcohol and Dextrose Injection approved
under new drug application (NDA) 004589). As explained in our Federal
Register notice determining that Alcohol and Dextrose was withdrawn
from sale for safety and effectiveness reasons, Alcohol and Dextrose
Injection is indicated to provide increased caloric intake. The use of
Alcohol and Dextrose raises several safety concerns because there are
many risks associated with the exposure to alcohol. Alcohol is
contraindicated for use in patients with neurologic disorders, such as
seizures, who have current or past substance abuse problems, or who are
pregnant. It can cause intoxication, respiratory depression, and
disturbances in serum glucose levels. FDA-approved alternatives for
intravenous calorie supplementation that do not include alcohol were
approved after these Alcohol and Dextrose products and are available
today.
    In the Federal Register of October 24, 2022 (87 FR 64227), FDA
published a notice of opportunity for a hearing (NOOH) on a proposal to
withdraw approval of ANDA 083483, held by Miles Laboratories Inc., the
last holder of record, under Sec.  314.150(b)(1) (21 CFR 314.150(b)(1))
because the ANDA holder has repeatedly failed to submit the required
annual reports and under Sec.  314.150(a)(2)(i) because the Agency has
scientific data and experience to show that the drug product approved
under ANDA 083483, Alcohol and Dextrose Injection, 5 mL/100 mL, 5 g/100
mL, is unsafe for use under the conditions of use for which the product
was approved. The ANDA holder did not respond to the NOOH. Failure to
file a written notice of participation and request for hearing as
required by Sec.  314.200 (21 CFR 314.200) constitutes a waiver of the
opportunity for a hearing by the ANDA holder concerning the proposal to
withdraw approval of the ANDA and a waiver of any contentions
concerning the legal status of the drug product. Accordingly, FDA is
withdrawing approval of ANDA 083483.
    Therefore, for reasons discussed above, FDA finds that: (1) the
ANDA holder has failed to submit reports required under Sec. Sec.
314.81 and 314.98 and section 505(k) of the Federal Food, Drug, and
Cosmetic Act (FD&C Act) (21 U.S.C. 355(k)) and (2) the Agency has
scientific data and experience to show that the drug product approved
under ANDA 083483, Alcohol and Dextrose Injection, 5 mL/100 mL, 5 g/100
mL, is unsafe for use under the conditions of use for which the product
was approved. In addition, under Sec.  314.200, FDA finds that the ANDA
holder has waived its opportunity for a hearing and any contentions
concerning the legal status of the drug products. Therefore, based on
these findings and pursuant to the authority under section 505(e) of
the FD&C Act, approval of ANDA 083483 and all amendments and
supplements thereto is hereby withdrawn as of February 17, 2023.

    Dated: February 13, 2023.
Lauren K. Roth,
Associate Commissioner for Policy.
[FR Doc. 2023-03367 Filed 2-16-23; 8:45 am]
BILLING CODE 4164-01-P


[Federal Register Volume 82, Number 116 (Monday, June 19, 2017)]
[Notices]
[Pages 27822-27827]
[FR Doc No: 2017-12688]

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ENVIRONMENTAL PROTECTION AGENCY

[EPA-HQ-OAR-2014-0738; FRL-9963-44-OAR]

Notice of Final Approval for an Alternative Means of Emission
Limitation at Chevron Phillips Chemical Company LP

AGENCY: Environmental Protection Agency (EPA).

ACTION: Notice; final approval.

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SUMMARY: This notice announces our approval of the Alternative Means of
Emission Limitation (AMEL) request from Chevron Phillips Chemical
Company LP (CP Chem) under the Clean Air Act (CAA) to operate a multi-
point ground flare (MPGF) at their ethylene plant in Baytown, Texas,
and to operate an MPGF at their polyethylene plant in Old Ocean, Texas.
This approval notice specifies the operating conditions and monitoring,
recordkeeping, and reporting requirements that these facilities must
follow to demonstrate compliance with the approved AMEL.

DATES: The approval of the AMEL request for the MPGF at CP Chem's
ethylene plant in Baytown, Texas, and the MPGF at CP Chem's
polyethylene plant in Old Ocean, Texas, is effective on June 19, 2017.

ADDRESSES: The Environmental Protection Agency (EPA) has established a
docket for this action under Docket ID No. EPA-HQ-OAR-2014-0738. All
documents in the docket are listed on the http://www.regulations.gov
Web site. Although listed in the index, some information is not
publicly available, e.g., confidential business information (CBI) or
other information whose disclosure is restricted by statute. Certain
other material, such as copyrighted material, is not placed on the
Internet and will be publicly available only in hard copy form.
Publicly available docket materials are available either electronically
through http://www.regulations.gov, or in hard copy at the EPA Docket
Center, EPA WJC West Building, Room Number 3334, 1301 Constitution Ave.
NW., Washington, DC. The Public Reading Room hours of operation are
8:30 a.m. to 4:30 p.m. Eastern Standard Time (EST), Monday through
Friday. The telephone number for the Public Reading Room is (202) 566-
1744, and the telephone number for the Air Docket is<PHONE_NUMBER>.

FOR FURTHER INFORMATION CONTACT: For questions about this final action,
contact Mr. Andrew Bouchard, Sector Policies and Programs Division
(E143-01), Office of Air Quality Planning and Standards (OAQPS), U.S.
Environmental Protection Agency, Research Triangle Park, North Carolina
27711; telephone number:<PHONE_NUMBER>; fax number:<PHONE_NUMBER>;
and email address<EMAIL_ADDRESS>
SUPPLEMENTARY INFORMATION:
    Acronyms and Abbreviations. We use multiple acronyms and terms in
this notice. While this list may not be exhaustive, to ease the reading
of this notice and for reference purposes, the EPA defines the
following terms and acronyms here:

AMEL alternative means of emission limitation
Btu/scf British thermal units per standard cubic foot
CAA Clean Air Act
CBI confidential business information
CFR Code of Federal Regulations
CP Chem Chevron Phillips Chemical Company LP
EPA Environmental Protection Agency
Eqn equation
HAP hazardous air pollutants
HP high pressure
LFL lower flammability limit
LFLcz lower flammability limit of combustion zone gas
LFLvg lower flammability limit of flare vent gas
MPGF multi-point ground flare
NESHAP national emission standards for hazardous air pollutants
NHV net heating value
NHVcz net heating value of combustion zone gas
NHVvg net heating value of flare vent gas
NSPS new source performance standards
OAQPS Office of Air Quality Planning and Standards
scf standard cubic feet
VOC volatile organic compounds

    Organization of This Document. The information in this notice is
organized as follows:

I. Background
    A. Summary
    B. Regulatory Flare Requirements and CP Chem's AMEL Request
II. Summary of Public Comments on CP Chem's AMEL Request
III. Final Notice of Approval of CP Chem's AMEL Request and Required
Operating Conditions

I. Background

A. Summary

    In a Federal Register notice dated April 4, 2017, the EPA provided
public notice and solicited comment on CP Chem's AMEL request under the
CAA for the operation of an MPGF at an ethylene plant in Baytown,
Texas, and for the operation of an MPGF at a polyethylene plant in Old
Ocean, Texas (see 82 FR 16392).\1\ This action solicited comment on all
aspects of the AMEL request, including the operating conditions
specified in that action that are necessary to achieve a reduction in
emissions of volatile organic compounds (VOC) and organic hazardous air
pollutants (HAP) at least equivalent to the reduction in emissions
required by various standards in 40 CFR parts 60, 61, and 63 that apply
to emission sources that would be controlled by these MPGFs. These
standards incorporate the design and operating requirements for flares
in the General Provisions to parts 60 and 63 as part of the emission
reduction requirements. Because the two proposed MPGFs cannot meet the
velocity requirements in these General

Provisions, CP Chem requested an AMEL. In its request, CP Chem
demonstrates that the proposed AMEL for each of the two facilities
would achieve at least equivalent emissions reductions as flares that
meet the standards in the General Provisions.
---------------------------------------------------------------------------

    \1\ The MPGFs at both the ethylene plant and polyethylene plant
will utilize pressure-assisted burners on all the high pressure (HP)
stages; however, the first two stages on the MPGF at the
polyethylene plant will also be steam-assisted.
---------------------------------------------------------------------------

    This action provides a summary of the comments received as part of
the public review process, our response to those comments, and our
approval of the AMEL request received from CP Chem for use of MPGFs at
both their ethylene plant in Baytown, Texas, and polyethylene plant in
Old Ocean, Texas, along with the operating conditions they must follow
for demonstrating compliance with the approved AMEL.

B. Regulatory Flare Requirements and CP Chem's AMEL Request

    CP Chem submitted a complete MPGF AMEL request, following the MPGF
AMEL framework that was published in the Federal Register (see 81 FR
23480, April 21, 2016), to the EPA on November 28, 2016. CP Chem sought
an AMEL to operate an MPGF for use during limited HP maintenance,
startup, and shutdown events, as well as during upset events at their
ethylene plant in Baytown, Texas. In addition, CP Chem sought an AMEL
to operate an MPGF during certain routine operations (i.e., the first
two stages only), as well as during periods of maintenance, startup,
shutdown, and upset at their polyethylene plant in Old Ocean, Texas. In
its request, CP Chem cited various regulatory requirements in 40 CFR
parts 60, 61, and 63 that will apply to the flare vent gas streams that
will be collected and routed to their MPGFs at each of these two
plants. See Table 1 for a list of regulations, by subparts, that CP
Chem has identified as applicable to the two plants described above.
These new source performance standards (NSPS) and national emissions
standards for hazardous air pollutants (NESHAP) require that flares
subject to these subparts meet the flare design and operating
requirements in the General Provisions of part 60 and 63, respectively
(i.e., 40 CFR 60.18(b) and 63.11(b)). CP Chem is requesting that the
EPA approve the AMEL to be used by each of the two plants for complying
with the flare requirements in the relevant subparts as specified in
Table 1.

   Table 1--Summary of Applicable Rules that May Apply to Vent Streams Controlled by Multi-Point Ground Flares
----------------------------------------------------------------------------------------------------------------
                                                                       Rule citation from
Applicable rules with vent streams      CP chem          CP chem        Title 40 CFR that      Provisions for
    going to control device(s)       ethylene plant    polyethylene    allow for use of a   alternative means of
                                                          plant               flare          emission limitation
----------------------------------------------------------------------------------------------------------------
NSPS Subpart VV...................  ...............               X   60.482-10(d)........  60.484(a)-(f).
NSPS Subpart VVa..................               X   ...............  60.482-10a(d).......  60.484a(a)-(f).
NSPS Subpart DDD..................  ...............               X   60.562-1(a)(1)(i)(C)  CAA section
                                                                                111(h)(3).
NSPS Subpart NNN..................               X   ...............  60.662(b)...........  CAA section
                                                                                111(h)(3).
NSPS Subpart RRR..................               X   ...............  60.702(b)...........  CAA section
                                                                                111(h)(3).
NESHAP Subpart FF.................               X   ...............  61.349(a)(2)........  61.353(a); also see
                                                                                61.12(d).
NESHAP Subpart SS.................               X   ...............  63.982(b)...........  CAA section
                                                                                112(h)(3).
NESHAP Subpart UU.................               X   ...............  63.1034.............  63.1021(a)-(d).
NESHAP Subpart XX.................               X   ...............  63.1091.............  63.1097(b)(1).
                                                                      * Note--This subpart
                                                                       cross-references to
                                                                       NESHAP subpart FF
                                                                       above.
NESHAP Subpart YY.................               X   ...............  Table 7 to Sec.       63.1113.
                                                                       63.1103(e) cross-
                                                                       references to
                                                                       NESHAP subpart SS
                                                                       above.
NESHAP Subpart FFFF...............  ...............               X   63.2450(e)(2).......  63.2545(b)(1); also
                                                                                see 63.6(g).
----------------------------------------------------------------------------------------------------------------

    The provisions in each NSPS and NESHAP cited in Table 1 that ensure
flares meet certain specific requirements when used to satisfy the
requirements of the NSPS or NESHAP were established as work practice
standards pursuant to CAA sections 111(h)(1) or 112(h)(1). For
standards established according to these provisions, CAA sections
111(h)(3) and 112(h)(3) allow the EPA to permit the use of an AMEL by a
source if, after notice and opportunity for comment,\2\ it is
established to the Administrator's satisfaction that such AMEL will
achieve emission reduction at least equivalent to the reduction
required under the CAA section 111(h)(1) or 112(h)(1) standard. As
noted in Table 1, many of the NSPS and NESHAP in the table above also
include specific regulatory provisions allowing sources to request an
AMEL.
---------------------------------------------------------------------------

    \2\ CAA section 111(h)(3) specifically requires that the EPA
provide an opportunity for a public hearing. The EPA provided an
opportunity for a public hearing in the April 4, 2017, Federal
Register action. However, no public hearing was requested.
---------------------------------------------------------------------------

    CP Chem sought such an AMEL request because their MPGFs are not
designed to operate below the maximum permitted velocity requirements
for flares in the General Provisions of 40 CFR parts 60 and 63. CP Chem
provided information that the MPGFs they propose to use will achieve a
reduction in emissions at least equivalent to the reduction in
emissions for flares complying with these General Provisions
requirements (for further background information on the regulatory
flare requirements and a facility's ability to request an AMEL, see 82
FR 16392-16399, April 4, 2017).

II. Summary of Public Comments on CP Chem's AMEL Request

    The EPA received eight public comments on this action. The public
comments received fell into one of the following three bins: (1)
General support for CP Chem's AMEL request, (2) general opposition to
CP Chem's AMEL request, and (3) general comments outside the scope of
the action. None of the comments raised issues or otherwise mentioned
any specific aspect of the MPGFs (including any operating condition)
proposed for either of the two plants or the EPA's authority to approve
these AMEL under the CAA. None of the commenters who opposed the EPA's
proposal to approve the AMEL with the operating conditions specified in
the April 4, 2017, action asserted that the EPA lacked authority to
approve the AMEL or that the AMEL would not achieve at least equivalent

emissions reductions as flares that meet the standards in the General
Provisions. Additionally, the one commenter who generally opposed CP
Chem's AMEL request did not provide any substantive reason for why they
opposed the request, other than to note that existing regulations
should be followed. Therefore, no changes have been made to the
operating conditions specified in the April 4, 2017, action.

III. Final Notice of Approval of CP Chem's AMEL Request and Required
Operating Conditions

    Based on information the EPA received from CP Chem and the comments
received through the public comment period, we are approving CP Chem's
request for an AMEL and establishing operating requirements for the
MPGF at CP Chem's ethylene plant in Baytown, Texas, and the MPGF at CP
Chem's polyethylene plant in Old Ocean, Texas. The operating conditions
for CP Chem's MPGF that will achieve a reduction in emissions at least
equivalent to the reduction in emissions being controlled by a steam-
assisted, air-assisted, or non-assisted flare complying with the
requirements of either 40 CFR 63.11(b) or 40 CFR 60.18(b) are as
follows: (1) The MPGF system for all HP stages at CP Chem's ethylene
plant and for all HP stages excluding stage 1 and 2 for CP Chem's
polyethylene plant must be designed and operated such that the net
heating value of the combustion zone gas (NHVcz) is greater than or
equal to 800 British thermal units per standard cubic foot (Btu/scf) or
lower flammability limit of the combustion zone gas (LFLcz) is less
than or equal to 6.5 percent by volume. The MPGF system for HP stages 1
and 2 of CP Chem's polyethlene plant must be designed and operated such
that the NHVcz is greater than or equal to 600 Btu/scf or the LFLcz is
less than or equal to 8.0 percent by volume. Owners or operators must
demonstrate compliance with the NHVcz or LFLcz metric by continuously
complying with a 15-minute block average. Owners or operators must
calculate and monitor for the NHVcz or LFLcz according to the
following:
    (a) Calculation of NHVcz
    (i) The owner or operator shall determine the net heating value of
flare vent gas (NHVvg) by following the requirements of (1)(d)-(1)(e)
below. If an owner or operator elects to use a monitoring system
capable of continuously measuring (i.e., at least once every 15
minutes), calculating, and recording the individual component
concentrations present in the flare vent gas, NHVvg shall be calculated
using the following equation:
[GRAPHIC] [TIFF OMITTED] TN19JN17.000

Where:

NHVvg = Net heating value of flare vent gas, Btu/scf. Flare vent gas
means all gas found just prior to the MPGF. This gas includes all
flare waste gas (i.e., gas from facility operations that is directed
to a flare for the purpose of disposing of the gas), flare sweep
gas, flare purge gas and flare supplemental gas, but does not
include pilot gas.
i = Individual component in flare vent gas.
n = Number of components in flare vent gas.
xi = Concentration of component i in flare vent gas, volume
fraction.
NHVi = Net heating value of component i determined as the heat of
combustion where the net enthalpy per mole of offgas is based on
combustion at 25 degrees Celsius ([deg]C) and 1 atmosphere (or
constant pressure) with water in the gaseous state from values
published in the literature, and then the values converted to a
volumetric basis using 20 [deg]C for ``standard temperature.'' Table
2 summarizes component properties including net heating values.
    (ii) For all MPGF HP stages at CP Chem's ethylene plant and for all
MPGF HP stages, excluding stage 1 and 2 for CP Chem's polyethylene
plant, NHVvg = NHVcz.
    (iii) For HP stages 1 and 2 of CP Chem's polyethlene plant MPGF,
NHVcz shall be calculated using the following equation:
[GRAPHIC] [TIFF OMITTED] TN19JN17.001

Where:

NHVcz = Net heating value of combustion zone gas, Btu/scf.
NHVvg = Net heating value of flare vent gas for the 15-minute block
period as determined according to (1)(a)(i) above, Btu/scf.
Qvg = Cumulative volumetric flow of flare vent gas during the 15-
minute block period, standard cubic feet (scf).
Qs = Cumulative volumetric flow of total assist steam during the 15-
minute block period, scf.

    (b) Calculation of LFLcz
    (i) The owner or operator shall determine LFLcz from compositional
analysis data by using the following equation:
[GRAPHIC] [TIFF OMITTED] TN19JN17.002

Where:

LFLvg = Lower flammability limit of flare vent gas, volume percent
(vol %).
n = Number of components in the vent gas.
i = Individual component in the vent gas.
Xi = Concentration of component i in the vent gas, vol %.
LFLi = Lower flammability limit of component i as determined using
values published by the U.S. Bureau of Mines (Zabetakis, 1965), vol
%. All inerts, including nitrogen, are assumed to have an infinite
LFL (e.g., LFLN2 = [infin], so that XN2/LFLN2 = 0). LFL values for
common flare vent gas components are provided in Table 2.

    (ii) For all MPGF HP stages at CP Chem's ethylene plant and for all
MPGF HP stages, excluding stages 1 and 2 for CP Chem's polyethylene
plant, LFLvg = LFLcz.
    (iii) For HP stages 1 and 2 of CP Chem's polyethlene plant MPGF,
LFLcz shall be calculated using the following equation:

[GRAPHIC] [TIFF OMITTED] TN19JN17.003

Where:

LFLcz = Lower flammability limit of combustion zone gas, vol %.
LFLvg = Lower flammability limit of flare vent gas, vol %.
Qvg = Cumulative volumetric flow of flare vent gas during the 15-
minute block period, scf.
Qs = Cumulative volumetric flow of total assist steam during the 15-
minute block period, scf.

    (c) The operator of an MPGF system shall install, operate,
calibrate, and maintain a monitoring system capable of continuously
measuring the volumetric flow rate of flare vent gas (Qvg) and the
volumetric flow rate of total assist steam (Qs).
    (i) The flow rate monitoring systems must be able to correct for
the temperature and pressure of the system and output parameters in
standard conditions (i.e., a temperature of 20 [deg]C (68 [deg]F) and a
pressure of 1 atmosphere).
    (ii) Mass flow monitors may be used for determining volumetric flow
rate of flare vent gas provided the molecular weight of the flare vent
gas is determined using compositional analysis so that the mass flow
rate can be converted to volumetric flow at standard conditions using
the following equation:
[GRAPHIC] [TIFF OMITTED] TN19JN17.004

Where:

Qvol = Volumetric flow rate, scf per second.
Qmass = Mass flow rate, pounds per second.
385.3 = Conversion factor, scf per pound-mole.
MWt = Molecular weight of the gas at the flow monitoring location,
pounds per pound-mole.

    (iii) Mass flow monitors may be used for determining volumetric
flow rate of total assist steam. Use Equation 5 to convert mass flow
rates to volumetric flow rates. Use a molecular weight of 18 pounds per
pound-mole for total assist steam.
    (d) The operator shall install, operate, calibrate, and maintain a
monitoring system capable of continuously measuring (i.e., at least
once every 15 minutes), calculating, and recording the individual
component concentrations present in the flare vent gas or the owner or
operator shall install, operate, calibrate, and maintain a monitoring
system capable of continuously measuring, calculating, and recording
NHVvg (in Btu/scf).
    (e) For each measurement produced by the monitoring system used to
comply with (1)(d) above, the operator shall determine the 15-minute
block average as the arithmetic average of all measurements made by the
monitoring system within the 15-minute period.
    (f) The operator must follow the calibration and maintenance
procedures according to Table 3. Maintenance periods, instrument
adjustments, or checks to maintain precision and accuracy and zero and
span adjustments may not exceed 5 percent of the time the flare is
receiving regulated material.

                                    Table 2--Individual Component Properties
----------------------------------------------------------------------------------------------------------------
                                                                                NHV (British
                                                                  MW (pounds per   thermal units
               Component                    Molecular formula       pound-mole)    per standard   LFL (volume %)
                                                                                cubic foot)

----------------------------------------------------------------------------------------------------------------
Acetylene..............................  C2H2...................           26.04           1,404             2.5
Benzene................................  C6H6...................           78.11           3,591             1.3
1,2-Butadiene..........................  C4H6...................           54.09           2,794             2.0
1,3-Butadiene..........................  C4H6...................           54.09           2,690             2.0
iso-Butane.............................  C4H10..................           58.12           2,957             1.8
n-Butane...............................  C4H10..................           58.12           2,968             1.8
cis-Butene.............................  C4H8...................           56.11           2,830             1.6
iso-Butene.............................  C4H8...................           56.11           2,928             1.8
trans-Butene...........................  C4H8...................           56.11           2,826             1.7
Carbon Dioxide.........................  CO2....................           44.01               0         [infin]
Carbon Monoxide........................  CO.....................           28.01             316            12.5
Cyclopropane...........................  C3H6...................           42.08           2,185             2.4
Ethane.................................  C2H6...................           30.07           1,595             3.0
Ethylene...............................  C2H4...................           28.05           1,477             2.7
Hydrogen...............................  H2.....................            2.02             274             4.0
Hydrogen Sulfide.......................  H2S....................           34.08             587             4.0
Methane................................  CH4....................           16.04             896             5.0
Methyl-Acetylene.......................  C3H4...................           40.06           2,088             1.7
Nitrogen...............................  N2.....................           28.01               0         [infin]
Oxygen.................................  O2.....................           32.00               0         [infin]
Pentane+ (C5+).........................  C5H12..................           72.15           3,655             1.4
Propadiene.............................  C3H4...................           40.06           2,066            2.16
Propane................................  C3H8...................           44.10           2,281             2.1
Propylene..............................  C3H6...................           42.08           2,150             2.4
Water..................................  H2O....................           18.02               0         [infin]
----------------------------------------------------------------------------------------------------------------

             Table 3--Accuracy and Calibration Requirements
------------------------------------------------------------------------
                                     Accuracy           Calibration
           Parameter               requirements         requirements
------------------------------------------------------------------------
Flare Vent Gas Flow Rate......  20     Performance
                                 percent of flow    evaluation
                                 rate at            biennially (every 2
                                 velocities         years) and following
                                 ranging from 0.1   any period of more
                                 to 1 foot per      than 24 hours
                                 second.            throughout which the
                                5       flow rate exceeded
                                 percent of flow    the maximum rated
                                 rate at            flow rate of the
                                 velocities         sensor, or the data
                                 greater than 1     recorder was off
                                 foot per second.   scale. Checks of all
                                                    mechanical
                                                    connections for
                                                    leakage monthly.
                                                    Visual inspections
                                                    and checks of system
                                                    operation every 3
                                                    months, unless the
                                                    system has a
                                                    redundant flow
                                                    sensor.
                                                   Select a
                                                    representative
                                                    measurement location
                                                    where swirling flow
                                                    or abnormal velocity
                                                    distributions due to
                                                    upstream and
                                                    downstream
                                                    disturbances at the
                                                    point of measurement
                                                    are minimized.
Flow Rate for All Flows Other   5      Conduct a flow sensor
 Than Flare Vent Gas.            percent over the   calibration check at
                                 normal range of    least biennially
                                 flow measured or   (every two years);
                                 1.9 liters per     conduct a
                                 minute (0.5        calibration check
                                 gallons per        following any period
                                 minute),           of more than 24
                                 whichever is       hours throughout
                                 greater, for       which the flow rate
                                 liquid flow.       exceeded the
                                                    manufacturer's
                                                    specified maximum
                                                    rated flow rate or
                                                    install a new flow
                                                    sensor.
                                5      At least quarterly,
                                 percent over the   inspect all
                                 normal range of    components for
                                 flow measured or   leakage, unless the
                                 280 liters per     continuous parameter
                                 minute (10 cubic   monitoring system
                                 feet per           has a redundant flow
                                 minute),           sensor.
                                 whichever is
                                 greater, for gas
                                 flow.
                                5      Record the results of
                                 percent over the   each calibration
                                 normal range       check and
                                 measured for       inspection.
                                 mass flow.        Locate the flow
                                                    sensor(s) and other
                                                    necessary equipment
                                                    (such as
                                                    straightening vanes)
                                                    in a position that
                                                    provides
                                                    representative flow;
                                                    reduce swirling flow
                                                    or abnormal velocity
                                                    distributions due to
                                                    upstream and
                                                    downstream
                                                    disturbances.
Pressure......................  5      Review pressure
                                 percent over the   sensor readings at
                                 normal range       least once a week
                                 measured or 0.12   for straight-line
                                 kilopascals (0.5   (unchanging)
                                 inches of water    pressure and perform
                                 column),           corrective action to
                                 whichever is       ensure proper
                                 greater.           pressure sensor
                                                    operation if
                                                    blockage is
                                                    indicated.
                                                   Performance
                                                    evaluation annually
                                                    and following any
                                                    period of more than
                                                    24 hours throughout
                                                    which the pressure
                                                    exceeded the maximum
                                                    rated pressure of
                                                    the sensor, or the
                                                    data recorder was
                                                    off scale. Checks of
                                                    all mechanical
                                                    connections for
                                                    leakage monthly.
                                                    Visual inspection of
                                                    all components for
                                                    integrity,
                                                    oxidation, and
                                                    galvanic corrosion
                                                    every 3 months,
                                                    unless the system
                                                    has a redundant
                                                    pressure sensor.
                                                   Select a
                                                    representative
                                                    measurement location
                                                    that minimizes or
                                                    eliminates pulsating
                                                    pressure, vibration,
                                                    and internal and
                                                    external corrosion.
Net Heating Value by            2      Calibration
 Calorimeter.                    percent of span.   requirements should
                                                    follow
                                                    manufacturer's
                                                    recommendations at a
                                                    minimum.
                                                   Temperature control
                                                    (heated and/or
                                                    cooled as necessary)
                                                    the sampling system
                                                    to ensure proper
                                                    year-round
                                                    operation.
                                                   Where feasible,
                                                    select a sampling
                                                    location at least 2
                                                    equivalent diameters
                                                    downstream from and
                                                    0.5 equivalent
                                                    diameters upstream
                                                    from the nearest
                                                    disturbance. Select
                                                    the sampling
                                                    location at least 2
                                                    equivalent duct
                                                    diameters from the
                                                    nearest control
                                                    device, point of
                                                    pollutant
                                                    generation, air in-
                                                    leakages, or other
                                                    point at which a
                                                    change in the
                                                    pollutant
                                                    concentration or
                                                    emission rate
                                                    occurs.
Net Heating Value by Gas        As specified in    Follow the procedure
 Chromatograph.                  Performance        in PS 9 of 40 CFR
                                 Specification      part 60, appendix B,
                                 (PS) 9 of 40 CFR   except that a single
                                 part 60,           daily mid-level
                                 appendix B.        calibration check
                                                    can be used (rather
                                                    than triplicate
                                                    analysis), the multi-
                                                    point calibration
                                                    can be conducted
                                                    quarterly (rather
                                                    than monthly), and
                                                    the sampling line
                                                    temperature must be
                                                    maintained at a
                                                    minimum temperature
                                                    of 60 [deg]C (rather
                                                    than 120 [deg]C).
------------------------------------------------------------------------

    (2) The MPGF system shall be operated with a flame present at all
times when in use. Each burner on HP stages 1 and 2 of CP Chem's
polyethylene plant MPGF must have a pilot with a continuously lit pilot
flame. Additionally, each HP stage of CP Chem's ethylene plant MPGF and
all HP stages, excluding stages 1 and 2 for CP Chem's polyethylene
plant MPGF, must have at least two pilots with a continuously lit pilot
flame. Each pilot flame must be continuously monitored by a
thermocouple or any other equivalent device used to detect the presence
of a flame. The time, date, and duration of any complete loss of pilot
flame on any of the individual MPGF burners on HP stages 1 and 2 of CP
Chem's polyethylene plant MPGF, on any of the HP stages of CP Chem's
ethylene plant MPGF, and on any of the HP stages, excluding stages 1
and 2 of CP Chem's polyethylene plant MPGF, must be recorded. Each
monitoring device must be maintained or replaced at a frequency in
accordance with the manufacturer's specifications.
    (3) The MPGF system shall be operated with no visible emissions
except for periods not to exceed a total of 5 minutes during any 2
consecutive hours. A video camera that is capable of continuously
recording (i.e., at least one frame every 15 seconds with time and date
stamps) images of the flare flame and a reasonable distance above the
flare flame at an angle suitable for visible emissions observations
must be used to demonstrate compliance with this requirement. The owner
or operator must provide real-time video surveillance camera output to
the control room or other continuously manned location where the video
camera images may be viewed at any time.
    (4) The operator of an MPGF system shall install and operate
pressure monitor(s) on the main flare header, as well as a valve
position indicator monitoring system capable of monitoring and
recording the position for each staging valve to ensure that the MPGF
operates within the range of tested conditions or within the range of
the manufacturer's specifications. The

pressure monitor shall meet the requirements in Table 3. Maintenance
periods, instrument adjustments or checks to maintain precision and
accuracy, and zero and span adjustments may not exceed 5 percent of the
time the flare is receiving regulated material.
    (5) Recordkeeping Requirements.
    (a) All data must be recorded and maintained for a minimum of 3
years or for as long as required under applicable rule subpart(s),
whichever is longer.
    (6) Reporting Requirements.
    (a) The information specified in sections III (6)(b) and (c) of
this document below must be reported in the timeline specified by the
applicable rule subpart(s) for which the MPGF will control emissions.
    (b) Owners or operators shall include the following information in
their initial Notification of Compliance status report:
    (i) Specify flare design as a pressure-assisted MPGF. CP Chem's
polyethylene plant shall also clearly note that HP stages 1 and 2 are
also steam-assisted.
    (ii) All visible emission readings, NHVcz and/or LFLcz
determinations, and flow rate measurements. For MPGF, exit velocity
determinations do not need to be reported as the maximum permitted
velocity requirements in the General Provisions at 40 CFR 60.18(b) and
40 CFR 63.11(b) are not applicable.
    (iii) All periods during the compliance determination when a
complete loss of pilot flame on any stage of MPGF burners occurs, and,
for HP stages 1 and 2 of CP Chem's polyethylene plant MPGF, all periods
during the compliance determination when a complete loss of pilot flame
on an individual burner occurs.
    (iv) All periods during the compliance determination when the
pressure monitor(s) on the main flare header show the MPGF burners
operating outside the range of tested conditions or outside the range
of the manufacturer's specifications.
    (v) All periods during the compliance determination when the
staging valve position indicator monitoring system indicates a stage of
the MPGF should not be in operation and is or when a stage of the MPGF
should be in operation and is not.
    (c) The owner or operator shall notify the Administrator of periods
of excess emissions in their Periodic Reports. These periods of excess
emissions shall include:
    (i) Records of each 15-minute block for all HP stages of CP Chem's
ethylene plant MPGF and for all HP stages excluding stages 1 and 2 of
CP Chem's polyethylene plant MPGF during which there was at least 1
minute when regulated material was routed to the MPGF and a complete
loss of pilot flame on a stage of burners occurred, and, for HP stages
1 and 2 of CP Chem's polyethylene plant MPGF, records of each 15-minute
block during which there was at least 1 minute when regulated material
was routed to the MPGF and a complete loss of pilot flame on an
individual burner occurred.
    (ii) Records of visible emissions events (including the time and
date stamp) that exceed more than 5 minutes in any 2-hour consecutive
period.
    (iii) Records of each 15-minute block period for which an
applicable combustion zone operating limit (i.e., NHVcz or LFLcz) is
not met for the MPGF when regulated material is being combusted in the
flare. Indicate the date and time for each period, the NHVcz and/or
LFLcz operating parameter for the period and the type of monitoring
system used to determine compliance with the operating parameters
(e.g., gas chromatograph or calorimeter). For CP Chem's polyethylene
plant MPGF, also indicate which HP stages were in use.
    (iv) Records of when the pressure monitor(s) on the main flare
header show the MPGF burners are operating outside the range of tested
conditions or outside the range of the manufacturer's specifications.
Indicate the date and time for each period, the pressure measurement,
the stage(s) and number of MPGF burners affected, and the range of
tested conditions or manufacturer's specifications.
    (v) Records of when the staging valve position indicator monitoring
system indicates a stage of the MPGF should not be in operation and is
or when a stage of the MPGF should be in operation and is not. Indicate
the date and time for each period, whether the stage was supposed to be
open, but was closed or vice versa, and the stage(s) and number of MPGF
burners affected.

    Dated: June 1, 2017.
Stephen Page,
Director, Office of Air Quality Planning and Standards.
[FR Doc. 2017-12688 Filed 6-16-17; 8:45 am]
BILLING CODE 6560-50-P