Notice of Final Approval for an Alternative Means of Emission Limitation, 60157-60161 [2020-21042]
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Federal Register / Vol. 85, No. 186 / Thursday, September 24, 2020 / Notices
A. New Active Ingredient
1. File Symbols: 93778–R, 93778–E,
93778–G, and 93778–U. Docket ID
number: EPA–HQ–OPP–2020–0250.
Applicant: AgriMetis, LLC, c/o Wagner
Regulatory Associates Inc, P.O. Box 640,
Hockessin, DE 19707. Product names: LGlufosinate Ammonium Technical,
AgriMetis Glu-L280, AgriMetis Glu-L
280 SL, and AgriMetis Glu-L 280 SLX.
Active ingredient: Herbicide—LGlufosinate Ammonium at 77.62% (LGlufosinate Ammonium Technical) and
24.5% (AgriMetis Glu-L280, AgriMetis
Glu-L 280 SL, and AgriMetis Glu-L 280
SLX) Proposed uses: Banana; beet,
sugar; bushberry, subgroup 13–07B;
canola; corn, field; corn, sweet; cotton;
fruit, citrus, group 10–10; fruit, pome,
group 11–10; fruit, stone, group 12–12;
grape; juneberry; lingonberry; nut, tree,
group 14–12; non-crop, industrial areas
and residential outdoor uses; olive;
potato; salal and soybean. Contact: RD.
2. File Symbol: 94339–R. Docket ID
number: EPA–HQ–OPP–2020–0457.
Applicant: Better Air International
Limited, 1 Ha-Tsmikha St., High Tech
Park, Yokneam Illit 2069205, Israel (c/
o Environmental Consulting, 15616
Plain Dealing Place, Manassas, VA
20112). Product name: EB–8. Active
ingredients: Fungicide and
Bactericide—Bacillus subtilis strain 3 at
0.02%, Bacillus amyloliquefaciens
strain 298 at 0.02%, and Bacillus
subtilis strain 281 at 0.02%. Proposed
use: For the control or suppression of
odor-causing and discoloration-causing
bacterial and fungal growth in
commercial and residential areas.
Contact: BPPD.
Authority: 7 U.S.C. 136 et seq.
Dated: September 10, 2020.
Delores Barber,
Director, Information Technology and
Resources Management Division, Office of
Pesticide Programs.
[FR Doc. 2020–21109 Filed 9–23–20; 8:45 am]
BILLING CODE 6560–50–P
ENVIRONMENTAL PROTECTION
AGENCY
[EPA–HQ–OAR–2014–0738; FRL–10014–68–
OAR]
Notice of Final Approval for an
Alternative Means of Emission
Limitation
Environmental Protection
Agency (EPA).
ACTION: Notice; final approval.
AGENCY:
This document announces
our approval of the alternative means of
emission limitation (AMEL) request
SUMMARY:
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17:00 Sep 23, 2020
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under the Clean Air Act (CAA)
submitted by Lyondell Chemical
Company (Lyondell) to operate multipoint ground flares (MPGFs) at its
Channelview chemical plant in
Houston, Texas. The U.S.
Environmental Protection Agency (EPA)
received no adverse comments on the
request. This approval document
specifies the operating conditions and
monitoring, recordkeeping, and
reporting requirements that this facility
must follow to demonstrate compliance
with the approved AMEL.
DATES: The approval of the AMEL
request from Lyondell to operate MPGFs
at the Lyondell Channelview chemical
plant, as specified in this document, is
effective on September 24, 2020.
ADDRESSES: The 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 https://www.regulations.gov/
website. Although listed, some
information is not publicly available,
e.g., Confidential Business Information
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 https://
www.regulations.gov/.
Out of an abundance of caution for
members of the public and our staff, the
EPA Docket Center and Reading Room
are closed to the public, with limited
exceptions, to reduce the risk of
transmitting COVID–19. Our Docket
Center staff will continue to provide
remote customer service via email,
phone, and webform. For further
information and updates on EPA Docket
Center services, please visit us online at
https://www.epa.gov/dockets. The EPA
continues to carefully and continuously
monitor information from the Centers
for Disease Control, local area health
departments, and our Federal partners
so that we can respond rapidly as
conditions change regarding COVID–19.
FOR FURTHER INFORMATION CONTACT: For
questions about this final action, contact
Ms. Angie Carey, Sector Policies and
Programs Division (E143–01), Office of
Air Quality Planning and Standards,
U.S. Environmental Protection Agency,
Research Triangle Park, North Carolina
27711; telephone number: (919) 541–
2187; fax number: (919) 541–0516; and
email address: carey.angela@epa.gov.
SUPPLEMENTARY INFORMATION:
Preamble acronyms and
abbreviations. We use multiple
acronyms and terms in this preamble.
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60157
While this list may not be exhaustive, to
ease the reading of this preamble 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
CFR Code of Federal Regulations
EPA Environmental Protection Agency
Eqn equation
MPGF multi-point ground flare
NESHAP national emission standards for
hazardous air pollutants
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
POTBA propylene oxide tertiary butyl
alcohol unit
scf standard cubic feet
Organization of this document. The
information in this document is
organized as follows:
I. Background
A. Summary
B. Regulatory Flare Requirements
II. Summary of Public Comments on the
AMEL Request
III. AMEL for the MPGFs
I. Background
A. Summary
In a Federal Register notice published
on May 29, 2020, the EPA provided
public notice and solicited comment on
the request under the CAA by Lyondell
to operate MPGFs at its Channelview
chemical plant in Houston, Texas (see
85 FR 32382). In that document, the
EPA solicited comment on all aspects of
the AMEL request, including the
operating conditions specified in that
document that are necessary to achieve
a reduction in emissions of volatile
organic compounds and organic
hazardous air pollutants at least
equivalent to the reductions required
under the applicable CAA section
111(h)(1) or 112(h)(1) standards.
Lyondell requested the AMEL for
MPGFs to be used at a new propylene
oxide tertiary butyl alcohol (‘‘POTBA’’)
unit at its Channelview chemical plant.
According to Lyondell, the POTBA unit
is subject to the new source
performance standards (NSPS) and
national emission standards for
hazardous air pollutants (NESHAP) for
source categories identified in Table 1
below. These NSPS and NESHAP
incorporate the flare design and
operating requirements in the 40 CFR
parts 60 and 63 General Provisions (i.e.,
40 CFR 60.18(b) and 63.11(b)) into the
individual subparts. Lyondell submitted
an AMEL request to operate a flare with
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Federal Register / Vol. 85, No. 186 / Thursday, September 24, 2020 / Notices
B. Regulatory Flare Requirements
tip exit velocities greater than those
allowed in 40 CFR 60.18 and 63.11
while achieving ≥ 96.5-percent
combustion efficiency and 98-percent
destruction efficiency.
Provided below in Table 1 is a list of
regulations, by subpart, that Lyondell
has identified as applicable to the new
POTBA unit’s MPGFs described above.
The middle column identifies the
requirement in each cited NSPS or
This action provides a summary of
our approval of this AMEL request.
NESHAP that requires flares used to
satisfy the NSPS or NESHAP meet the
flare design and operating requirements
in the 40 CFR parts 60 and 63 General
Provisions (i.e., 40 CFR 60.18(b) and
63.11(b)). Lyondell is seeking an AMEL
for these flare requirements.
TABLE 1—SUMMARY OF APPLICABLE RULES TO EMISSIONS CONTROLLED BY MPGFS FOR THE POTBA
Applicable rules with vent streams going to control device(s)
Emission reduction requirements
(allowing for use of a flare)
NSPS subpart Kb ...............................................
NSPS subpart VV ...............................................
NSPS subpart VVa .............................................
NSPS subpart III ................................................
NSPS subpart NNN ............................................
NSPS subpart RRR ............................................
NESHAP subparts F, G .....................................
60.112b(a)(3)(ii) ...............................................
60.482–1, 60.482–10(d) ...................................
60.482–1a, 60.482–10a(d) ...............................
60.612(b) ..........................................................
60.662(b) ..........................................................
60.702(b) ..........................................................
63.102, 63.112(e), 63.113(a)(1)(i),
63.116(a)(2), 63.116(a)(3), 63.119(e)(1),
63.120(e)(1) through (4), 63.126(b)(2)(i),
63.128(b), 63.139(c)(3), 63.139(d)(3),
63.145(j).
63.162, 63.172(d), 63.180(e) ...........................
61.242–1, 61.242–11(d) ...................................
NESHAP subpart H ............................................
NESHAP subpart V ............................................
Lyondell is seeking an AMEL to
operate MPGFs during both routine and
emergency vent gas flows. Lyondell
provided the information specified in
the flare AMEL framework for pressure
assisted MPGFs that was published in
the Federal Register on April 21, 2016
(see 81 FR 23486), to support its AMEL
request. Accordingly, the request
followed the 2016 flare AMEL
framework.
II. Summary of Public Comments on the
AMEL Request
The Agency received no comments on
this action. No adverse comment was
received on the request.
III. AMEL for the MPGFs
The EPA is approving the AMEL
request by Lyondell to operate MPGFs
with tip exit velocities greater than
those allowed in 40 CFR 60.18 and
63.11 while achieving ≥96.5-percent
combustion efficiency and 98-percent
destruction efficiency. We are also
establishing in this document the
operating conditions for this MPGFs as
part of this approval. These operating
conditions, which are the same as those
set forth in the May 29, 2020, Federal
Register document, will ensure that
these flares will achieve emission
reductions at least equivalent to the
reductions required under the
applicable CAA section 111(h)(1) or
112(h)(1) standards. The operating
conditions are as follows:
Provisions for alternative means of emission
limitation
60.114b.
60.484.
60.484a.
63.6(g).
63.162(b), 63.177.
63.6(g).
(1) All MPGFs must be operated such
that the combustion zone gas net
heating value (NHVcz) is ≥800 British
thermal units per standard cubic foot
(BTU/scf). Owners or operators must
demonstrate compliance with the
applicable NHVcz on a 15-minute block
average. Owners or operators must
calculate and monitor for the NHVcz
according to the following:
(a) Calculation of NHVcz
(i) 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, the net heating value of flare vent
gas (NHVvg) shall be calculated using
the following equation:
(Eqn. 1)
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18:35 Sep 23, 2020
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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 (°C) and 1 atmosphere
(or constant pressure) with water in the
gaseous state from values published in
the literature, and then the values are
converted to a volumetric basis using 20
°C for ‘‘standard temperature.’’ Table 3
summarizes component properties
including net heating values.
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(ii) If the owner or operator uses a
continuous net heating value monitor,
the owner or operator may, at their
discretion, install, operate, calibrate,
and maintain a monitoring system
capable of continuously measuring,
calculating, and recording the hydrogen
concentration in the flare vent gas. The
owner or operator shall use the
following equation to determine NHVvg
for each sample measured via the net
heating value monitoring system.
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EN24SE20.001</GPH>
where:
NHVvg = Net heating value of flare vent gas,
BTU/scf.
Flare vent gas means all gas found just prior
to the tip. This gas includes all flare
waste gas (i.e., gas from facility
operations that is directed to a flare for
the purpose of disposing 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.
60159
Federal Register / Vol. 85, No. 186 / Thursday, September 24, 2020 / Notices
(Eqn. 2)
NHVvg = NHVmeasured+ 938xH2
where:
NHVvg = Net heating value of flare vent gas,
BTU/scf.
NHVmeasured = Net heating value of flare vent
gas stream as measured by the
continuous net heating value monitoring
system, scf.
xH2 = Concentration of hydrogen in flare vent
gas at the time the sample was input into
the net heating value monitoring system,
volume fraction.
938 = Net correction for the measured
heating value of hydrogen (1,212 –274),
BTU/scf.
(iii) NHVcz shall be calculated using
Equation 3.
(Eqn. 3)
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), BTU/
scf.
Qvg = Cumulative volumetric flow of flare
vent gas during the 15-minute block
period, scf.
Qag = Cumulative volumetric flow of assist
gas during the 15-minute block period,
standard cubic feet flow rate, scf.
NHVag = Net heating value of assist gas, BTU/
Q
scf; this is zero for air or for steam.
(b) For all flare systems specified in
this document, the operator shall install,
operate, calibrate, and maintain a
monitoring system capable of
continuously measuring the volumetric
flow rate of flare vent gas (Qvg), the
volumetric flow rate of total assist steam
(Qs), the volumetric flow rate of total
assist air (Qa), and the volumetric flow
rate of total assist gas (Qag).
(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 °C
(68 °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:
= Qmassx385.3
vol
(Eqn. 6)
MWt
where:
Qvol = Volumetric flow rate, scf/second (sec).
Qmass = Mass flow rate, pounds per sec.
385.3 = Conversion factor, scf per poundmole.
MWt = Molecular weight of the gas at the
flow monitoring location, pounds per
pound-mole.
(c) For each measurement produced
by the monitoring system used to
comply with (1)(a)(ii), 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.
(d) The operator must follow the
calibration and maintenance procedures
according to Table 3. Total time spent
on maintenance, 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
C2H2 ...............................................................
C6H6 ...............................................................
C4H6 ...............................................................
C4H6 ...............................................................
C4H10 .............................................................
C4H10 .............................................................
C4H8 ...............................................................
C4H8 ...............................................................
C4H8 ...............................................................
CO2 ................................................................
CO ..................................................................
C3H6 ...............................................................
C2H6 ...............................................................
C2H4 ...............................................................
H2 ...................................................................
H2S .................................................................
CH4 .................................................................
C3H4 ...............................................................
N2 ...................................................................
O2 ...................................................................
C5H12 .............................................................
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26.04
78.11
54.09
54.09
58.12
58.12
56.11
56.11
56.11
44.01
28.01
42.08
30.07
28.05
2.02
34.08
16.04
40.06
28.01
32.00
72.15
24SEN1
1,404
3,591
2,794
2,690
2,957
2,968
2,830
2,928
2,826
0
316
2,185
1,595
1,477
* 1,212
587
896
2,088
0
0
3,655
LFLi
(volume %)
2.5
1.3
2.0
2.0
1.8
1.8
1.6
1.8
1.7
∞
12.5
2.4
3.0
2.7
4.0
4.0
5.0
1.7
∞
∞
1.4
EN24SE20.003</GPH>
Acetylene ........................................................
Benzene ..........................................................
1,2-Butadiene ..................................................
1,3-Butadiene ..................................................
iso-Butane .......................................................
n-Butane ..........................................................
cis-Butene .......................................................
iso-Butene .......................................................
trans-Butene ....................................................
Carbon Dioxide ...............................................
Carbon Monoxide ............................................
Cyclopropane ..................................................
Ethane .............................................................
Ethylene ..........................................................
Hydrogen .........................................................
Hydrogen Sulfide ............................................
Methane ..........................................................
Methyl-Acetylene .............................................
Nitrogen ...........................................................
Oxygen ............................................................
Pentane+ (C5+) ..............................................
NHVi
(BTU/scf)
EN24SE20.002</GPH>
Molecular formula
EN24SE20.004</GPH>
MWi
(pounds per
pound-mole)
Component
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Federal Register / Vol. 85, No. 186 / Thursday, September 24, 2020 / Notices
TABLE 2—INDIVIDUAL COMPONENT PROPERTIES—Continued
MWi
(pounds per
pound-mole)
Component
Molecular formula
Propadiene ......................................................
Propane ...........................................................
Propylene ........................................................
Water ...............................................................
C3H4 ...............................................................
C3H8 ...............................................................
C3H6 ...............................................................
H2O ................................................................
40.06
44.10
42.08
18.02
NHVi
(BTU/scf)
LFLi
(volume %)
2,066
2,281
2,150
0
2.16
2.1
2.4
∞
* The theoretical net heating value for hydrogen is 274 BTU/scf, but for these flares, a net heating value of 1,212 BTU/scf shall be used.
TABLE 3—ACCURACY AND CALIBRATION REQUIREMENTS
Parameter
Accuracy requirements
Calibration requirements
Flare Vent Gas Flow Rate ...
±20 percent of flow rate at velocities ranging from 0.1
to 1 foot per sec.
±5 percent of flow rate at velocities greater than 1 foot
per sec.
Flow Rate for All Flows
Other Than Flare Vent
Gas.
±5 percent over the normal range of flow measured or
1.9 liters per minute (0.5 gallons per minute), whichever is greater, for liquid flow.
Evaluate performance biennially (every 2 years) and
following any period of more than 24 hours throughout which the flow rate exceeded the maximum rated
flow rate of the sensor, or the data recorder was off
scale. Check all mechanical connections for leakage
monthly. Visually inspect and check 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.
Conduct a flow sensor calibration check at least biennially (every 2 years); conduct a calibration check following any period of more than 24 hours throughout
which the flow rate exceeded the manufacturer’s
specified maximum rated flow rate or install a new
flow sensor.
At least quarterly, inspect all components for leakage,
unless the continuous parameter monitoring system
(CPMS) has a redundant flow sensor.
Record the results of each calibration check and inspection.
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.
Review pressure sensor readings at least once a week
for straight-line (unchanging) pressure and perform
corrective action to ensure proper pressure sensor
operation if blockage is indicated.
Evaluate performance 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. Check
all mechanical connections for leakage monthly. Visually inspect 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.
Calibrate according to manufacturer’s recommendations
at a minimum.
Temperature control (heated and/or cooled as necessary) the sampling system to ensure proper yearround 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.
±5 percent over the normal range of flow measured or
280 liters per minute (10 cubic feet per minute),
whichever is greater, for gas flow.
±5 percent over the normal range measured for mass
flow.
Pressure ...............................
±5 percent over the normal range measured or 0.12
kilopascals (0.5 inches of water column), whichever
is greater.
Net Heating Value by Calorimeter.
±2 percent of span ..........................................................
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Federal Register / Vol. 85, No. 186 / Thursday, September 24, 2020 / Notices
60161
TABLE 3—ACCURACY AND CALIBRATION REQUIREMENTS—Continued
Parameter
Accuracy requirements
Calibration requirements
Net Heating Value by Gas
Chromatograph.
As specified in Performance Standard (PS) 9 of 40
CFR part 60, appendix B.
Hydrogen Analyzer ..............
±2 percent over the concentration measured, or 0.1 volume, percent, whichever is greater.
Follow the procedure in PS 9 of 40 CFR part 60, appendix B, except that a single daily mid-level 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 °C (rather than 120 °C).
Specify calibration requirements in your site specific
CPMS monitoring plan. Calibrate according to manufacturer’s recommendations at a minimum.
Specify 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 occurs.
(2) The flare system must be operated
with a flame present at all times when
in use. Additionally, each stage 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 burners 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 the 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
flare 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. Total time
spent on maintenance periods,
instrument adjustments or checks to
maintain precision and accuracy, and
zero and span adjustments may not
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17:00 Sep 23, 2020
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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) below must be
reported in the timeline specified by the
applicable rule subpart(s) for which the
MPGFs will control emissions.
(b) Owners or operators shall include
the final AMEL operating requirements
for each flare in their initial Notification
of Compliance status report.
(c) The owner or operator shall notify
the Administrator of periods of excess
emissions in their Periodic Reports. The
notification shall include:
(i) Records of each 15-minute block
for both MPGFs during which there was
at least 1 minute when regulated
material was routed to the flare and a
complete loss of pilot flame on a stage
of burners occurred, and for both
MPGFs, records of each 15-minute block
during which there was at least 1
minute when regulated material was
routed to the flare 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) is not met for the flare when
regulated material is being combusted in
the flare. Indicate the date and time for
each period, the NHVcz operating
parameter for the period, the type of
monitoring system used to determine
compliance with the operating
parameters (e.g., gas chromatograph or
calorimeter), and also indicate which
high-pressure stages were in use.
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(iv) Records of when the pressure
monitor(s) on the main flare header
show the flare 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 flare 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 flare should not
be in operation and is or when a stage
of the flare 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 flare burners affected.
Dated: September 18, 2020.
Panagiotis Tsirigotis,
Director, Office of Air Quality Planning and
Standards.
[FR Doc. 2020–21042 Filed 9–23–20; 8:45 am]
BILLING CODE 6560–50–P
ENVIRONMENTAL PROTECTION
AGENCY
[EPA–HQ–OPPT–2015–0436; FRL–10012–
72–OMS]
Information Collection Request
Revision Submitted to OMB for Review
and Approval; Comment Request;
Generic Clearance for TSCA Section 4
Test Rules, Test Orders, Enforceable
Consent Agreements (ECAs),
Voluntary Data Submissions, and
Exemptions From Testing Requirement
Environmental Protection
Agency (EPA).
ACTION: Notice.
AGENCY:
The Environmental Protection
Agency (EPA) has submitted an
information collection request (ICR),
SUMMARY:
E:\FR\FM\24SEN1.SGM
24SEN1
]]>Agencies
[Federal Register Volume 85, Number 186 (Thursday, September 24, 2020)]
[Notices]
[Pages 60157-60161]
From the Federal Register Online via the Government Publishing Office [www.gpo.gov]
[FR Doc No: 2020-21042]
-----------------------------------------------------------------------
ENVIRONMENTAL PROTECTION AGENCY
[EPA-HQ-OAR-2014-0738; FRL-10014-68-OAR]
Notice of Final Approval for an Alternative Means of Emission
Limitation
AGENCY: Environmental Protection Agency (EPA).
ACTION: Notice; final approval.
-----------------------------------------------------------------------
SUMMARY: This document announces our approval of the alternative means
of emission limitation (AMEL) request under the Clean Air Act (CAA)
submitted by Lyondell Chemical Company (Lyondell) to operate multi-
point ground flares (MPGFs) at its Channelview chemical plant in
Houston, Texas. The U.S. Environmental Protection Agency (EPA) received
no adverse comments on the request. This approval document specifies
the operating conditions and monitoring, recordkeeping, and reporting
requirements that this facility must follow to demonstrate compliance
with the approved AMEL.
DATES: The approval of the AMEL request from Lyondell to operate MPGFs
at the Lyondell Channelview chemical plant, as specified in this
document, is effective on September 24, 2020.
ADDRESSES: The 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 https://www.regulations.gov/ website. Although listed,
some information is not publicly available, e.g., Confidential Business
Information 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 https://www.regulations.gov/.
Out of an abundance of caution for members of the public and our
staff, the EPA Docket Center and Reading Room are closed to the public,
with limited exceptions, to reduce the risk of transmitting COVID-19.
Our Docket Center staff will continue to provide remote customer
service via email, phone, and webform. For further information and
updates on EPA Docket Center services, please visit us online at
https://www.epa.gov/dockets. The EPA continues to carefully and
continuously monitor information from the Centers for Disease Control,
local area health departments, and our Federal partners so that we can
respond rapidly as conditions change regarding COVID-19.
FOR FURTHER INFORMATION CONTACT: For questions about this final action,
contact Ms. Angie Carey, Sector Policies and Programs Division (E143-
01), Office of Air Quality Planning and Standards, U.S. Environmental
Protection Agency, Research Triangle Park, North Carolina 27711;
telephone number: (919) 541-2187; fax number: (919) 541-0516; and email
address: [email protected].
SUPPLEMENTARY INFORMATION:
Preamble acronyms and abbreviations. We use multiple acronyms and
terms in this preamble. While this list may not be exhaustive, to ease
the reading of this preamble 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
CFR Code of Federal Regulations
EPA Environmental Protection Agency
Eqn equation
MPGF multi-point ground flare
NESHAP national emission standards for hazardous air pollutants
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
POTBA propylene oxide tertiary butyl alcohol unit
scf standard cubic feet
Organization of this document. The information in this document is
organized as follows:
I. Background
A. Summary
B. Regulatory Flare Requirements
II. Summary of Public Comments on the AMEL Request
III. AMEL for the MPGFs
I. Background
A. Summary
In a Federal Register notice published on May 29, 2020, the EPA
provided public notice and solicited comment on the request under the
CAA by Lyondell to operate MPGFs at its Channelview chemical plant in
Houston, Texas (see 85 FR 32382). In that document, the EPA solicited
comment on all aspects of the AMEL request, including the operating
conditions specified in that document that are necessary to achieve a
reduction in emissions of volatile organic compounds and organic
hazardous air pollutants at least equivalent to the reductions required
under the applicable CAA section 111(h)(1) or 112(h)(1) standards.
Lyondell requested the AMEL for MPGFs to be used at a new propylene
oxide tertiary butyl alcohol (``POTBA'') unit at its Channelview
chemical plant. According to Lyondell, the POTBA unit is subject to the
new source performance standards (NSPS) and national emission standards
for hazardous air pollutants (NESHAP) for source categories identified
in Table 1 below. These NSPS and NESHAP incorporate the flare design
and operating requirements in the 40 CFR parts 60 and 63 General
Provisions (i.e., 40 CFR 60.18(b) and 63.11(b)) into the individual
subparts. Lyondell submitted an AMEL request to operate a flare with
[[Page 60158]]
tip exit velocities greater than those allowed in 40 CFR 60.18 and
63.11 while achieving >= 96.5-percent combustion efficiency and 98-
percent destruction efficiency.
This action provides a summary of our approval of this AMEL
request.
B. Regulatory Flare Requirements
Provided below in Table 1 is a list of regulations, by subpart,
that Lyondell has identified as applicable to the new POTBA unit's
MPGFs described above. The middle column identifies the requirement in
each cited NSPS or NESHAP that requires flares used to satisfy the NSPS
or NESHAP meet the flare design and operating requirements in the 40
CFR parts 60 and 63 General Provisions (i.e., 40 CFR 60.18(b) and
63.11(b)). Lyondell is seeking an AMEL for these flare requirements.
Table 1--Summary of Applicable Rules to Emissions Controlled by MPGFS
for the POTBA
------------------------------------------------------------------------
Emission reduction
Applicable rules with vent requirements Provisions for
streams going to control (allowing for use of alternative means of
device(s) a flare) emission limitation
------------------------------------------------------------------------
NSPS subpart Kb............. 60.112b(a)(3)(ii)... 60.114b.
NSPS subpart VV............. 60.482-1, 60.482- 60.484.
10(d).
NSPS subpart VVa............ 60.482-1a, 60.482- 60.484a.
10a(d).
NSPS subpart III............ 60.612(b)........... ....................
NSPS subpart NNN............ 60.662(b)........... ....................
NSPS subpart RRR............ 60.702(b)........... ....................
NESHAP subparts F, G........ 63.102, 63.112(e), 63.6(g).
63.113(a)(1)(i),
63.116(a)(2),
63.116(a)(3),
63.119(e)(1),
63.120(e)(1)
through (4),
63.126(b)(2)(i),
63.128(b),
63.139(c)(3),
63.139(d)(3),
63.145(j).
NESHAP subpart H............ 63.162, 63.172(d), 63.162(b), 63.177.
63.180(e).
NESHAP subpart V............ 61.242-1, 61.242- 63.6(g).
11(d).
------------------------------------------------------------------------
Lyondell is seeking an AMEL to operate MPGFs during both routine
and emergency vent gas flows. Lyondell provided the information
specified in the flare AMEL framework for pressure assisted MPGFs that
was published in the Federal Register on April 21, 2016 (see 81 FR
23486), to support its AMEL request. Accordingly, the request followed
the 2016 flare AMEL framework.
II. Summary of Public Comments on the AMEL Request
The Agency received no comments on this action. No adverse comment
was received on the request.
III. AMEL for the MPGFs
The EPA is approving the AMEL request by Lyondell to operate MPGFs
with tip exit velocities greater than those allowed in 40 CFR 60.18 and
63.11 while achieving >=96.5-percent combustion efficiency and 98-
percent destruction efficiency. We are also establishing in this
document the operating conditions for this MPGFs as part of this
approval. These operating conditions, which are the same as those set
forth in the May 29, 2020, Federal Register document, will ensure that
these flares will achieve emission reductions at least equivalent to
the reductions required under the applicable CAA section 111(h)(1) or
112(h)(1) standards. The operating conditions are as follows:
(1) All MPGFs must be operated such that the combustion zone gas
net heating value (NHVcz) is >=800 British thermal units per
standard cubic foot (BTU/scf). Owners or operators must demonstrate
compliance with the applicable NHVcz on a 15-minute block
average. Owners or operators must calculate and monitor for the
NHVcz according to the following:
(a) Calculation of NHVcz
(i) 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, the net heating value of
flare vent gas (NHVvg) shall be calculated using the following
equation:
[GRAPHIC] [TIFF OMITTED] TN24SE20.001
where:
NHVvg = Net heating value of flare vent gas, BTU/scf.
Flare vent gas means all gas found just prior to the tip. This gas
includes all flare waste gas (i.e., gas from facility operations
that is directed to a flare for the purpose of disposing 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 are converted to a
volumetric basis using 20 [deg]C for ``standard temperature.'' Table
3 summarizes component properties including net heating values.
(ii) If the owner or operator uses a continuous net heating value
monitor, the owner or operator may, at their discretion, install,
operate, calibrate, and maintain a monitoring system capable of
continuously measuring, calculating, and recording the hydrogen
concentration in the flare vent gas. The owner or operator shall use
the following equation to determine NHVvg for each sample measured via
the net heating value monitoring system.
[[Page 60159]]
[GRAPHIC] [TIFF OMITTED] TN24SE20.004
where:
NHVvg = Net heating value of flare vent gas, BTU/scf.
NHVmeasured = Net heating value of flare vent gas stream as measured
by the continuous net heating value monitoring system, scf.
xH2 = Concentration of hydrogen in flare vent gas at the time the
sample was input into the net heating value monitoring system,
volume fraction.
938 = Net correction for the measured heating value of hydrogen
(1,212 -274), BTU/scf.
(iii) NHVcz shall be calculated using Equation 3.
[GRAPHIC] [TIFF OMITTED] TN24SE20.002
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), BTU/scf.
Qvg = Cumulative volumetric flow of flare vent gas during the 15-
minute block period, scf.
Qag = Cumulative volumetric flow of assist gas during the 15-minute
block period, standard cubic feet flow rate, scf.
NHVag = Net heating value of assist gas, BTU/scf; this is zero for
air or for steam.
(b) For all flare systems specified in this document, the operator
shall install, operate, calibrate, and maintain a monitoring system
capable of continuously measuring the volumetric flow rate of flare
vent gas (Qvg), the volumetric flow rate of total assist steam (Qs),
the volumetric flow rate of total assist air (Qa), and the volumetric
flow rate of total assist gas (Qag).
(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] TN24SE20.003
where:
Qvol = Volumetric flow rate, scf/second (sec).
Qmass = Mass flow rate, pounds per sec.
385.3 = Conversion factor, scf per pound-mole.
MWt = Molecular weight of the gas at the flow monitoring location,
pounds per pound-mole.
(c) For each measurement produced by the monitoring system used to
comply with (1)(a)(ii), 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.
(d) The operator must follow the calibration and maintenance
procedures according to Table 3. Total time spent on maintenance,
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
----------------------------------------------------------------------------------------------------------------
MW (pounds per
Component Molecular formula pound-mole) NHV (BTU/scf) LFL (volume %)
----------------------------------------------------------------------------------------------------------------
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 * 1,212 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
[[Page 60160]]
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]
----------------------------------------------------------------------------------------------------------------
* The theoretical net heating value for hydrogen is 274 BTU/scf, but for these flares, a net heating value of
1,212 BTU/scf shall be used.
Table 3--Accuracy and Calibration Requirements
------------------------------------------------------------------------
Accuracy Calibration
Parameter requirements requirements
------------------------------------------------------------------------
Flare Vent Gas Flow Rate.... 20 Evaluate performance
percent of flow biennially (every 2
rate at velocities years) and
ranging from 0.1 to following any
1 foot per sec. period of more than
5 24 hours throughout
percent of flow which the flow rate
rate at velocities exceeded the
greater than 1 foot maximum rated flow
per sec. rate of the sensor,
or the data
recorder was off
scale. Check all
mechanical
connections for
leakage monthly.
Visually inspect
and check 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 5 Conduct a flow
Other Than Flare Vent Gas. percent over the sensor calibration
normal range of check at least
flow measured or biennially (every 2
1.9 liters per years); conduct a
minute (0.5 gallons calibration check
per minute), following any
whichever is period of more than
greater, for liquid 24 hours throughout
flow. which the flow rate
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
minute (10 cubic parameter
feet per minute), monitoring system
whichever is (CPMS) has a
greater, for gas redundant flow
flow. sensor.
5 Record the results
percent over the of each calibration
normal range check and
measured for mass inspection.
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
column), whichever perform corrective
is greater. action to ensure
proper pressure
sensor operation if
blockage is
indicated.
Evaluate performance
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. Check all
mechanical
connections for
leakage monthly.
Visually inspect
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 Calibrate according
Calorimeter. percent of span. to 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.
[[Page 60161]]
Net Heating Value by Gas As specified in Follow the procedure
Chromatograph. Performance in PS 9 of 40 CFR
Standard (PS) 9 of part 60, appendix
40 CFR part 60, B, except that a
appendix B. single daily mid-
level 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).
Hydrogen Analyzer........... 2 Specify calibration
percent over the requirements in
concentration your site specific
measured, or 0.1 CPMS monitoring
volume, percent, plan. Calibrate
whichever is according to
greater. manufacturer's
recommendations at
a minimum.
Specify 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
occurs.
------------------------------------------------------------------------
(2) The flare system must be operated with a flame present at all
times when in use. Additionally, each stage 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 burners 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 the 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 flare
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. Total time spent on 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) below
must be reported in the timeline specified by the applicable rule
subpart(s) for which the MPGFs will control emissions.
(b) Owners or operators shall include the final AMEL operating
requirements for each flare in their initial Notification of Compliance
status report.
(c) The owner or operator shall notify the Administrator of periods
of excess emissions in their Periodic Reports. The notification shall
include:
(i) Records of each 15-minute block for both MPGFs during which
there was at least 1 minute when regulated material was routed to the
flare and a complete loss of pilot flame on a stage of burners
occurred, and for both MPGFs, records of each 15-minute block during
which there was at least 1 minute when regulated material was routed to
the flare 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) is
not met for the flare when regulated material is being combusted in the
flare. Indicate the date and time for each period, the NHVcz
operating parameter for the period, the type of monitoring system used
to determine compliance with the operating parameters (e.g., gas
chromatograph or calorimeter), and also indicate which high-pressure
stages were in use.
(iv) Records of when the pressure monitor(s) on the main flare
header show the flare 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 flare 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 flare should not be in operation and is
or when a stage of the flare 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 flare burners affected.
Dated: September 18, 2020.
Panagiotis Tsirigotis,
Director, Office of Air Quality Planning and Standards.
[FR Doc. 2020-21042 Filed 9-23-20; 8:45 am]
BILLING CODE 6560-50-P
