[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: a-and-r-docket@epa.gov. 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: carey.angela@epa.gov.

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 hunt.virginia@epa.gov 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 
hunt.virginia@epa.gov 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
----------------------------------------------------------------------------------------------------------------
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).

[[Page 32385]]

 
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.
----------------------------------------------------------------------------------------------------------------

    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
--------------------------------------------------------------------------------------------------------------------------------------------------------
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.
--------------------------------------------------------------------------------------------------------------------------------------------------------

    (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
----------------------------------------------------------------------------------------------------------------
                                                                  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]
----------------------------------------------------------------------------------------------------------------
* 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
------------------------------------------------------------------------
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


