[Federal Register Volume 85, Number 104 (Friday, May 29, 2020)]
[Notices]
[Pages 32382-32389]
From the Federal Register Online via the Government Publishing Office [www.gpo.gov]
[FR Doc No: 2020-11541]
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ENVIRONMENTAL PROTECTION AGENCY
[EPA-HQ-OAR-2014-0738; FRL-10009-62-OAR]
Notice of Request for Approval of Alternative Means of Emission
Limitation
AGENCY: Environmental Protection Agency (EPA).
ACTION: Notice and request for comments.
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SUMMARY: This action provides public notice and solicits comment on the
alternative means of emission limitation (AMEL) request from Lyondell
Chemical Company (Lyondell), under the Clean Air Act (CAA), for the
multi-point ground flares (MPGFs) at its Channelview chemical plant in
Houston, Texas.
DATES:
Comments: Comments must be received on or before July 13, 2020.
Public hearing: If anyone contacts us requesting a public hearing
on or before June 3, 2020, the EPA will hold a virtual public hearing
on June 15, 2020. Please refer to the SUPPLEMENTARY INFORMATION section
for additional information on the public hearing.
ADDRESSES: You may send comments, identified by Docket ID No. EPA-HQ-
OAR-2014-0738, by any of the following methods:
Federal eRulemaking Portal: https://www.regulations.gov/
(our preferred method). Follow the online instructions for submitting
comments.
Email: [email protected]. Include Docket ID No. EPA-
HQ-OAR-2014-0738 in the subject line of the message.
Instructions. Submit your comments, identified by Docket ID No.
EPA-HQ-OAR-2014-0738, at https://www.regulations.gov/. Follow the
online instructions for submitting comments. Once submitted, comments
cannot be edited or removed from Regulations.gov, Regulations.gov is
our preferred method of receiving comments. All submissions received
must include the Docket ID No. for this rulemaking. For detailed
instructions on sending comments and additional information on the
rulemaking process, see the SUPPLEMENTARY INFORMATION section of
[[Page 32383]]
this document. Out of an abundance of caution for members of the public
and our staff, the EPA Docket Center and Reading Room was closed to
public visitors on March 31, 2020, to reduce the risk of transmitting
COVID-19. Our Docket Center staff will continue to provide remote
customer service via email, phone, and webform. We encourage the public
to submit comments via https://www.regulations.gov/ or email, as there
is a temporary suspension of mail delivery to the EPA, and no hand
deliveries are currently accepted. For further information on EPA
Docket Center services and the current status, please visit us online
at https://www.epa.gov/dockets.
If requested, the virtual hearing will be held on June 15, 2020.
The hearing will convene at 9:00 a.m. Eastern Standard Time (EST) and
will conclude at 3:00 p.m. EST. The EPA will announce further details
on the virtual public hearing website at https://www.epa.gov/stationary-sources-air-pollution/alternative-means-emission-limitation-flares. Refer to the SUPPLEMENTARY INFORMATION section below for
additional information.
FOR FURTHER INFORMATION CONTACT: For questions about this action,
contact Ms. Angela Carey, 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: (919) 541-2187; fax number: (919) 541-0516;
and email address: [email protected].
SUPPLEMENTARY INFORMATION:
Participation in virtual public hearing. Please note that the EPA
is deviating from its typical approach because the President has
declared a national emergency. Due to the current Centers for Disease
Control and Prevention (CDC) recommendations, as well as state and
local orders for social distancing to limit the spread of COVID-19, the
EPA cannot hold in-person public meetings at this time.
If a public hearing is requested, the EPA will begin pre-
registering speakers for the hearing upon publication of this document
in the Federal Register. To register to speak at the virtual hearing,
please use the online registration form available at https://www.epa.gov/stationary-sources-air-pollution/alternative-means-emission-limitation-flares or contact Virginia Hunt at 919-541-0832 or
by email at [email protected] to register to speak at the virtual
hearing. The last day to pre-register to speak at the hearing will be
June 11, 2020. On June 12, 2020, the EPA will post a general agenda for
the hearing that will list pre-registered speakers in approximate order
at: https://www.epa.gov/stationary-sources-air-pollution/alternative-means-emission-limitation-flares.
The EPA will make every effort to follow the schedule as closely as
possible on the day of the hearing; however, please plan for the
hearing to run either ahead of schedule or behind schedule.
Each commenter will have 5 minutes to provide oral testimony. The
EPA encourages commenters to provide the EPA with a copy of their oral
testimony electronically (via email) by emailing it to Angela Carey and
Virginia Hunt. The EPA also recommends submitting the text of your oral
testimony as written comments to the rulemaking docket.
The EPA may ask clarifying questions during the oral presentations
but will not respond to the presentations at that time. Written
statements and supporting information submitted during the comment
period will be considered with the same weight as oral testimony and
supporting information presented at the public hearing.
Please note that any updates made to any aspect of the hearing will
be posted online at https://www.epa.gov/stationary-sources-air-pollution/alternative-means-emission-limitation-flares. While the EPA
expects the hearing to go forward as set forth above, if requested,
please monitor our website or contact Virginia Hunt at 919-541-0832 or
[email protected] to determine if there are any updates. The EPA
does not intend to publish a document in the Federal Register
announcing updates.
If you require the services of a translator or a special
accommodation such as audio description, please pre-register for the
hearing with Virginia Hunt and describe your needs by June 5, 2020. The
EPA may not be able to arrange accommodations without advance notice.
Docket. The EPA has established a docket for this rulemaking under
Docket ID No. EPA-HQ-OAR-2014-0738. All documents in the docket are
listed in Regulations.gov. Although listed, 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. Publicly
available docket materials are available electronically in
Regulations.gov.
Instructions. Direct your comments to Docket ID No. EPA-HQ-OAR-
2014-0738. The EPA's policy is that all comments received will be
included in the public docket without change and may be made available
online at https://www.regulations.gov/, including any personal
information provided, unless the comment includes information claimed
to be CBI or other information whose disclosure is restricted by
statute. Do not submit electronically any information you consider to
be CBI or other information whose disclosure is restricted by statue.
This type of information should be submitted by mail as discussed
below.
The EPA may publish any comment received to its public docket.
Multimedia submissions (audio, video, etc.) must be accompanied by a
written comment. The written comment is considered the official comment
and should include discussion of all points you wish to make. The EPA
will generally not consider comments or comment contents located
outside of the primary submission (i.e., on the Web, cloud, or other
file sharing system). For additional submission methods, the full EPA
public comment policy, information about CBI or multimedia submissions,
and general guidance on making effective comments, please visit https://www.epa.gov/dockets/commenting-epa-dockets.
The https://www.regulations.gov/ website allows you to submit your
comment anonymously, which means the EPA will not know your identity or
contact information unless you provide it in the body of your comment.
If you send an email comment directly to the EPA without going through
https://www.regulations.gov/, your email address will be automatically
captured and included as part of the comment that is placed in the
public docket and made available on the internet. If you submit an
electronic comment, the EPA recommends that you include your name and
other contact information in the body of your comment and with any
digital storage media you submit. If the EPA cannot read your comment
due to technical difficulties and cannot contact you for clarification,
the EPA may not be able to consider your comment. Electronic files
should not include special characters or any form of encryption and be
free of any defects or viruses. For additional information about the
EPA's public docket, visit the EPA Docket Center homepage at https://www.epa.gov/dockets.
The EPA is temporarily suspending its Docket Center and Reading
Room for public visitors to reduce the risk of transmitting COVID-19.
Written
[[Page 32384]]
comments submitted by mail are temporarily suspended and no hand
deliveries will be accepted. Our Docket Center staff will continue to
provide remote customer service via email, phone, and webform. We
encourage the public to submit comments via https://www.regulations.gov/. 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 CDC, local area health departments, and our Federal partners
so that we can respond rapidly as conditions change regarding COVID-19.
Submitting CBI. Do not submit information containing CBI to the EPA
through https://www.regulations.gov/ or email. Clearly mark the part or
all of the information that you claim to be CBI. For CBI information on
any digital storage media that you mail to the EPA, mark the outside of
the digital storage media as CBI and then identify electronically
within the digital storage media the specific information that is
claimed as CBI. In addition to one complete version of the comments
that includes information claimed as CBI, you must submit a copy of the
comments that does not contain the information claimed as CBI directly
to the public docket through the procedures outlined in Instructions
section above. If you submit any digital storage media that does not
contain CBI, mark the outside of the digital storage media clearly that
it does not contain CBI. Information not marked as CBI will be included
in the public docket and the EPA's electronic public docket without
prior notice. Information marked as CBI will not be disclosed except in
accordance with procedures set forth in 40 Code of Federal Regulations
(CFR) part 2. Send or deliver information identified as CBI only to the
following address: OAQPS Document Control Officer (C404-02), OAQPS,
U.S. Environmental Protection Agency, Research Triangle Park, North
Carolina 27711, Attention Docket ID No. EPA-HQ-OAR-2014-0738. Note that
written comments containing CBI and submitted by mail may be delayed
and no hand deliveries will be accepted.
Acronyms and abbreviations. We use multiple acronyms and terms in
this document. While this list may not be exhaustive, to ease the
reading of this document 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
EPA Environmental Protection Agency
Eqn equation
HAP hazardous air pollutants
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
POTBA propylene oxide tertiary butyl alcohol unit scf standard cubic
feet
SKEC steam-assisted kinetic energy combustor
VOC volatile organic compounds
Organization of this document. The information in this document is
organized as follows:
I. Background
II. Request for AMEL
A. Propylene Oxide Tertiary Butyl Alcohol Unit (POTBA) MPGFs
B. Information Supporting AMEL Request for POTBA MPGFs
III. AMEL for the POTBA MPGFs
IV. Request for Comments
I. Background
In this action, the U.S. Environmental Protection Agency (EPA) is
soliciting comment on all aspects of this AMEL request by Lyondell,
including the corresponding operating conditions that would demonstrate
that the requested AMEL would achieve a reduction in emissions of
volatile organic compounds (VOC) and hazardous air pollutants (HAP) at
least equivalent to the reduction in emissions required by the
applicable standards in 40 CFR parts 60 and 63. Lyondell is requesting
an AMEL for the MPGFs to be used at a new propylene oxide tertiary
butyl alcohol (``POTBA'') unit at Lyondell's Channelview facility.
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.
This AMEL request was submitted to the EPA because the MPGFs for
the new POTBA unit would not be able to comply with the applicable
flare tip velocity requirements in the General Provisions to 40 CFR
parts 60 and 63. These maximum flare tip velocity requirements ensure
that the flame does not ``lift off'' or separate from the flare tip,
which could cause flame instability and/or potentially result in a
portion of the flare gas being released without proper combustion.
Proper combustion for flares is considered to be 98-percent destruction
efficiency or greater for organic HAP and VOC. The MPGFs in this AMEL
request are designed to operate 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.
Provided below in Table 1 is a list of regulations, by subparts,
that Lyondell has identified as applicable to the new POTBA unit's
MPGFs described in this section above. The middle column identifies the
requirement in each cited NSPS or NESHAP that flares used to satisfy
the NSPS or NESHAP must meet 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
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Applicable rules with vent streams going Emission reduction requirements Provisions for alternative means
to control device(s) (allowing for use of a flare) of emission limitation
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NSPS subpart VV.......................... 60.482-1 60.482-10(d)............ 60.484.
NSPS subpart VVa......................... 60.482-1a 60.482-10a(d).......... 60.484a.
NSPS subpart III......................... 60.612(b)........................ ..................................
NSPS subpart NNN......................... 60.662(b)........................ ..................................
NSPS subpart RRR......................... 60.702(b)........................ ..................................
NSPS subpart Kb.......................... 60.112b(a)(3)(ii)................ 60.114b.
NESHAP subpart V......................... 61.242-1 61.242-11(d)............ 63.6(g).
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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........................... 63.162(b).
63.172(d), 63.180(e)............. 63.177.
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The provisions in each NSPS and NESHAP Table 1, cited above, which
ensure that flares meet certain specific operating 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,\1\ it is established to the Administrator's satisfaction
that such an AMEL will achieve emissions reductions at least equivalent
to the reductions required under the applicable CAA section 111(h)(1)
or 112(h)(1) standards. As noted in Table 1 of this document, many of
the identified NSPS and NESHAP also include specific regulatory
provisions allowing sources to request an AMEL.
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\1\ CAA section 111(h)(3) requires that the EPA provide an
opportunity for a hearing.
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Lyondell submitted an AMEL request to operate above the applicable
maximum permitted velocity requirements for flares in the General
Provisions in 40 CFR parts 60 and 63. Lyondell provided information
that the flare designs for the POTBA MPGFs achieve a reduction in
emissions at least equivalent to the reduction in emissions for flares
complying with the applicable General Provisions requirements.
Lyondell's AMEL request was submitted on July 9, 2019, according to the
framework for pressure assisted MPGFs that was published in the Federal
Register on April 21, 2016 (see 81 FR 23486). The MPGF designs in this
request are multi-point tip designs which employ large numbers of tips
at heights close to ground level. The EPA has reviewed this request and
has deemed the application to be complete. For further information on
Lyondell's AMEL requests, see supporting materials from Lyondell at
Docket ID No. EPA-HQ-OAR-2014-0738.
II. Request for AMEL
A. Propylene Oxide Tertiary Butyl Alcohol Unit (POTBA) MPGFs
Lyondell is seeking an AMEL for operating MPGFs at its new POTBA
unit during both routine and emergency vent gas flows. Specifically,
the AMEL is for a small MPGF for routine vent gas flows, as well as a
separate larger MPGF for emergency vent gas flows.
Both MPGFs are designed as an integral part of a larger control
system that will control waste gases in stages. Vent gases are captured
and routed back into the process and/or fuel systems to minimize
environmental impact. Gases not returned back to process or to fuel gas
systems are directed to a control system with two separate
dispositions: A low pressure (LP) MPGF and a high pressure (HP) MPGF.
The LP continuous or routine stages for the POTBA MPGF will be in one
burner field and the HP emergency stages will be in a separate burner
field. The planned POTBA LP MPGF is designed to have two stages with a
total of 12 John Zink SKEC steam assist burners. Each steam assisted
burner will have a natural gas fired direct spark electronic ignition
pilot. Each stage will also have at least two pilots with a
continuously lit pilot flame. The planned POTBA HP MPGF is designed to
have nine stages with six John Zink SKEC steam assist burners and 694
John Zink LRGO-HC pressure assist burners. Each steam assisted burner
will have a natural gas fired direct spark electronic ignition pilot.
Each stage of the pressure assisted burners will have two continuously
lit pilots. As mentioned in section I above, both MPGFs are designed to
operate 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.
B. Information Supporting AMEL Request for POTBA MPGFs
As mentioned in section I above, Lyondell provided the information
specified in the 2016 flare AMEL framework to support its AMEL request.
The information provided by Lyondell includes: (1) Details on the
project scope and background; (2) information on applicable NSPS and
NESHAP; (3) flare test data on destruction efficiency/combustion
efficiency; (4) flare stability testing data; (5) flare cross-light
testing data; (6) information on flare reduction considerations; and
(7) information on appropriate flare monitoring and operating
conditions. (For further information on the supporting materials
provided, see Docket ID No. EPA-HQ-OAR-2014-0738.)
Information supplied by Lyondell indicates that both MPGFs can
achieve >=96.5-percent combustion efficiency and 98-percent destruction
efficiency if operated under certain conditions. Generally, testing of
burners for the vent gas mixture determined to be representative of the
flare operation was used to set the appropriate combustion zone net
heating value (NHVcz) minimum limit. However, EPA recently proposed
amendments to the Ethylene Production NESHAP, 40 CFR part 63, subpart
YY (84 FR 54278, October 9, 2019), and the Miscellaneous Organic NESHAP
(MON), 40 CFR part 63, subpart FFFF (84 FR 69182, December 17, 2019),
for MPGFs. These rules proposed that owners or operators of MPGF: (1)
Maintain an NHVcz >=800 British thermal units per standard cubic foot
(BTU/scf); (2) continuously monitor the NHVcz and flare vent gas flow
rate; (3) continuously monitor for the presence of a pilot flame, and
if cross-lighting is used on a particular stage of burners because
there is no pilot on each burner, then continuously monitor to ensure
that the stage has a minimum of two pilots per stage that will ignite
all flare vent gases sent to that stage; (4) operate the MPGF with no
visible emissions (except for 5 minutes during any 2 consecutive
hours); (5) maintain a distance of no greater than 6 feet between any
two burners in series on a stage of burners that do not have a
continuously lit pilot; and (6) monitor to ensure staging valves for
each stage of the MPGF operate properly so that the flare will control
vent gases within the proper flow and pressure ranges based on the
flare manufacturer's
[[Page 32386]]
recommendations. For the reasons stated in those two proposed rules, we
are including in this document these same requirements as operating
conditions for the requested AMEL, as specified in section III below.
III. AMEL for the POTBA MPGFs
Based upon our review of the AMEL request, we believe that, by
complying with the operating conditions specified in Table 2 and
accompanying paragraphs below, the MPGFs for the new POTBA at
Lyondell's Channelview facility will achieve emission reductions at
least equivalent to reduction in emissions being controlled by MPGFs
complying with the flare requirements under the applicable NSPS and
NESHAP identified in Table 1 of this document. We are seeking the
public's input on this request. Specifically, the EPA seeks the
public's input on the conditions specified in this document in the
following paragraphs.
Table 2--Proposed Alternative Operating Conditions
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Proposed alternative operating
AMEL submitted Company Affected facilities Flare type(s) conditions
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7/9/19............................. Lyondell.............. Channelview, TX, small MPGFs >=800 BTU/scf NHV.
MPGF for routine vent
gas flows; and a
separate larger MPGF
for emergency vent
gas flows.
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(1) All MPGFs must be operated such that the combustion zone gas
net heating value (NHVcz) is >=800 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, NHVvg shall be calculated
using the following equation:
[GRAPHIC] [TIFF OMITTED] TN29MY20.258
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.
NHV i = 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.
[GRAPHIC] [TIFF OMITTED] TN29MY20.259
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] TN29MY20.260
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] TN29MY20.261
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 4. Total time spent on maintenance,
instrument adjustments or checks to maintain precision and accuracy,
and zero and span adjustments may not exceed 5
[[Page 32387]]
percent of the time the flare is receiving regulated material.
Table 3--Individual Component Properties
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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
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]
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* The theoretical net heating value for hydrogen is 274 BTU/scf, but for these purposes flare, a net heating
value of 1,212 BTU/scf shall be used.
Table 4--Accuracy and Calibration Requirements
------------------------------------------------------------------------
Accuracy Calibration
Parameter requirements requirements
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Flare Vent Gas Flow Rate...... 20 Evaluate performance
percent of flow biennially (every 2
rate at years) and following
velocities any period of more
ranging from 0.1 than 24 hours
to 1 foot per throughout which the
sec. flow rate exceeded
5 the maximum rated
percent of flow flow rate of the
rate at sensor, or the data
velocities recorder was off
greater than 1 scale. Check all
foot per sec. 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 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 2 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 (CPMS) has a
minute), redundant flow
whichever is sensor.
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.
[[Page 32388]]
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.
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.
Net Heating Value by Gas As specified in Follow the procedure
Chromatograph. Performance in PS 9 of 40 CFR
Standard (PS) 9 part 60, appendix B,
of 40 CFR part except that a single
60, appendix B. 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 your
concentration site specific CPMS
measured, or 0.1 monitoring plan.
volume, percent, Calibrate according
whichever is to manufacturer's
greater. 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 4. 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.,
[[Page 32389]]
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.
IV. Request for Comments
We solicit comments on all aspects of Lyondell's requests for
approval of an AMEL for MPGFs to be used to comply with the standards
specified in Table 1 of this document. We specifically seek comment
regarding whether or not the MPGF operating requirements listed in
section III above will achieve emission reductions at least equivalent
to emissions being controlled by flares complying with the applicable
flare requirements in 40 CFR 60.18(b) and 63.11(b).
Dated: May 22, 2020.
Panagiotis Tsirigotis,
Director, Office of Air Quality Planning and Standards.
[FR Doc. 2020-11541 Filed 5-28-20; 8:45 am]
BILLING CODE 6560-50-P