
[Federal Register Volume 82, Number 63 (Tuesday, April 4, 2017)]
[Notices]
[Pages 16392-16399]
From the Federal Register Online via the Government Publishing Office [www.gpo.gov]
[FR Doc No: 2017-06597]


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ENVIRONMENTAL PROTECTION AGENCY

[EPA-HQ-OAR-2014-0738; FRL-9960-13-OAR]


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

AGENCY: Environmental Protection Agency (EPA).

ACTION: Notice; 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 Chevron 
Phillips Chemical Company LP (CP Chem), requested under the Clean Air 
Act (CAA), to operate a multi-point ground flare (MPGF) at their new 
ethylene plant in Baytown, Texas, and an MPGF at their new polyethylene 
plant in Old Ocean, Texas.\1\ In this action, the Environmental 
Protection Agency (EPA) is soliciting comment on all aspects of this 
request for an AMEL and the alternative operating conditions that would 
be sufficient to achieve a reduction in emissions of volatile organic 
compounds (VOC) and

[[Page 16393]]

hazardous air pollutants (HAP) at least equivalent to the reduction in 
emissions required by various standards in 40 CFR parts 60, 61, and 63 
that apply to emission sources controlled by these MPGFs. These 
standards incorporate the design and operating requirements for flares 
in the General Provisions to parts 60 and 63, respectively, as part of 
the emission reduction requirements. The proposed MPGF designs cannot 
meet the velocity requirements in these General Provisions; however, CP 
Chem's request for an alternative means of emission limit demonstrates 
that the alternative proposed would achieve at least equivalent 
emissions reductions as flares that meet the standards in the General 
Provisions.
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    \1\ The MPGF at both the ethylene plant and polyethylene plant 
will utilize pressure-assisted burners on all the high pressure 
stages; however, the first two stages on the MPGF at the 
polyethylene plant will also be steam-assisted.

DATES: Comments. Comments must be received on or before May 4, 2017, 
unless a public hearing is requested by April 10, 2017. If a public 
hearing is requested on this action, written comments must be received 
by May 19, 2017.
    Public Hearing. If a public hearing is requested by April 10, 2017, 
we will hold a public hearing on April 19, 2017, from 1:00 p.m. 
[Central Daylight Time] to 5:00 p.m. [Central Daylight Time] in the 
Houston, Texas, area. We will provide details on the public hearing, if 
one is requested, on our Web site at: https://www3.epa.gov/ttn/atw/groundflares/groundflarespg.html. The EPA does not intend to publish 
another notice in the Federal Register announcing any updates on the 
request for a public hearing, so please be sure to check the Web site 
above for updates. Again, a public hearing will not be held unless 
someone specifically requests that the EPA hold a public hearing 
regarding these requests. Please contact Ms. Virginia Hunt, Sector 
Policies and Programs Division (E143-01), Office of Air Quality 
Planning and Standards, U.S. Environmental Protection Agency, Research 
Triangle Park, NC 27711; telephone number: (919) 541-0832; email 
address: hunt.virginia@epa.gov; to request a public hearing, to 
register to speak at the public hearing or to inquire as to whether a 
public hearing will be held. The last day to pre-register in advance to 
speak at the public hearing will be April 17, 2017.

ADDRESSES: Comments. Submit your comments, identified by Docket ID No. 
EPA-HQ-OAR-2014-0738, at http://www.regulations.gov. Follow the online 
instructions for submitting comments. Once submitted, comments cannot 
be edited or removed from Regulations.gov. The EPA may publish any 
comment received to its public docket. Do not submit electronically any 
information you consider to be Confidential Business Information (CBI) 
or other information whose disclosure is restricted by statute. 
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 http://www2.epa.gov/dockets/commenting-epa-dockets.
    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 http://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 information that you consider to be CBI or 
otherwise protected through http://www.regulations.gov or email. The 
http://www.regulations.gov Web site is an ``anonymous access'' system, 
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 http://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 disk or 
CD-ROM 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 http://www.epa.gov/dockets.
    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 the Regulations.gov index. Although listed in the index, some 
information is not publicly available, e.g., 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 either electronically in Regulations.gov or in 
hard copy at the EPA Docket Center, Room 3334, EPA WJC West Building, 
1301 Constitution Avenue NW., Washington, DC. The Public Reading Room 
is open from 8:30 a.m. to 4:30 p.m., Monday through Friday, excluding 
legal holidays. The telephone number for the Public Reading Room is 
(202) 566-1744, and the telephone number for the EPA Docket Center is 
(202) 566-1742.

FOR FURTHER INFORMATION CONTACT: For questions about this action, 
contact Mr. Andrew Bouchard, Sector Policies and Programs Division 
(E143-01), Office of Air Quality Planning and Standards (OAQPS), U.S. 
Environmental Protection Agency, Research Triangle Park, North Carolina 
27711; telephone number: (919) 541-4036; fax number: (919) 541-0246; 
and email address: bouchard.andrew@epa.gov.

SUPPLEMENTARY INFORMATION: 
    Acronyms and Abbreviations. We use multiple acronyms and terms in 
this notice. While this list may not be exhaustive, to ease the reading 
of this notice and for reference purposes, the EPA defines the 
following terms and acronyms here:

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


[[Page 16394]]


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

I. Background
    A. Regulatory Flare Requirements and CP Chem's AMEL Request
II. Requests for AMEL
    A. CP Chem's Ethylene Plant
    B. CP Chem's Polyethylene Plant
    C. Information Supporting CP Chem's MPGF AMEL Requests
III. AMEL for the Proposed MPGFs
IV. Request for Comments

I. Background

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

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

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

    The provisions in each NSPS and NESHAP cited above that ensure 
flares meet certain specific requirements when used to satisfy the 
requirements of the NSPS or NESHAP were established as work practice 
standards pursuant to CAA sections 111(h)(1) or 112(h)(1). For 
standards established according to these provisions, CAA sections 
111(h)(3) and 112(h)(3) allow the EPA to permit the use of an AMEL by a 
source if, after notice and opportunity for comment,\2\ it is 
established to the Administrator's satisfaction that such an AMEL will 
achieve emissions reductions at least equivalent to the reductions 
required under the CAA section 111(h)(1) or 112(h)(1) standard. As 
noted in Table 1, many of the NSPS and NESHAP also include specific 
regulatory provisions allowing sources to request an AMEL.
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    \2\ CAA section 111(h)(3) specifically requires that the EPA 
provide an opportunity for a hearing.
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    CP Chem submitted an AMEL request because their MPGFs are designed 
to operate above the maximum permitted velocity requirements for flares 
in the General Provisions in 40 CFR parts 60 and 63. CP Chem provided 
information that the MPGF designs they propose to use at both sites 
will achieve a reduction in emissions at least equivalent to the 
reduction in emissions for flares complying with these General 
Provisions requirements. For further information on CP Chem's specific 
AMEL request, see supporting materials from CP Chem at Docket ID No. 
EPA-HQ-OAR-2014-0738.

II. Requests for AMEL

A. CP Chem's Ethylene Plant

    CP Chem indicates in their MPGF AMEL request that they plan to 
construct and operate an MPGF at their Cedar Bayou ethylene plant in 
Baytown, Texas. This new ethylene plant will use ethane as a feedstock 
and be able to produce approximately 1.5 million metric tons per year 
of ethylene. CP Chem is proposing to use a staged flare design to 
control emissions of VOC and HAP from various process vents during 
normal operations, as well as during maintenance, startup, shutdown, 
and upset operating conditions. During normal operation and most of the 
routine maintenance activities, CP Chem will operate a low pressure 
steam-assisted ground flare consisting of eight Callidus MP4U burners. 
This low pressure stage of the flare is not specifically part of the 
AMEL request, because this flare can comply with the General Provisions 
requirements of 40 CFR 60.18(b) and 63.11(b), which are cross-
referenced in the applicable NSPS and NESHAP provisions. CP Chem has 
submitted an AMEL request to operate the 17 high pressure (HP) stages 
(i.e., 16 stages plus one spare stage) of the MPGF because the designed 
flaring scenarios for when this portion of the MPGF will be used (i.e., 
during limited HP maintenance, startup, and shutdown

[[Page 16395]]

events, as well as during upset events) will exceed the maximum 
permitted velocity requirements in the General Provisions at 40 CFR 
60.18(b) and 40 CFR 63.11(b). The HP stages will also use Callidus MP4U 
burners and have anywhere from 6 to 62 burners per stage (see 
supporting materials from CP Chem at Docket ID No. EPA-HQ-OAR-2014-0738 
for more details).

B. CP Chem's Polyethylene Plant

    CP Chem indicates in their MPGF AMEL request that they also plan to 
construct and operate an MPGF at their new polyethylene plant that will 
be located adjacent to their Sweeny Chemical and Natural Gas Liquids 
(NGL) Fractionation Plant in Old Ocean, Texas. The polyethylene plant 
consists of two polyethylene units, each capable of producing 500,000 
metric tons per year of polyethylene products. CP Chem is also 
proposing to use a staged flare design scheme to control emissions of 
VOC and HAP from various process vents during normal operations, as 
well as during maintenance, startup, shutdown, and upset operating 
conditions; however, the design, burner type and configuration of this 
flare differ from that of the MPGF at the ethylene plant in a few key 
ways. First, the low pressure stage of the flare will have four steam-
assisted Callidus LP-Expert tip burners. Similar to the design of CP 
Chem's ethylene plant MPGF, this low pressure stage is not specifically 
part of the AMEL request as it can comply with the flare General 
Provisions requirements of 40 CFR 60.18(b) and 40 CFR 63.11(b). Second, 
the MPGF will consist of 10 HP stages (i.e., nine stages plus one spare 
stage), with each stage using Callidus MP4U burners. Lastly, unlike CP 
Chem's ethylene plant MPGF, the first two stages of the HP side of this 
MPGF will operate pressure-assisted burners that will also be steam-
assisted and control emissions during certain routine operations, as 
well as during periods of startup, shutdown, maintenance, and upset 
conditions. CP Chem indicates in their AMEL request that this 
particular control scheme was chosen due to insufficient area in the 
plot plan to add additional flare burners on the low pressure side that 
could comply with the maximum permitted velocity requirements of 40 CFR 
60.18(b) and 40 CFR 63.11(b). Thus, in order to account for all 
potential routine flaring operation scenarios, CP Chem will operate the 
first two stages of the HP side of the MPGF as flexible, or ``swing'' 
stages that can operate in both a low pressure capacity as well as high 
pressure capacity. These first two stages will have a total of 18 
burners, which account for approximately 10 percent of the total number 
of flare burners on the HP side of the MPGF being proposed for use by 
CP Chem (see supporting materials from CP Chem at Docket ID No. EPA-HQ-
OAR-2014-0738 for more details).

C. Information Supporting CP Chem's MPGF AMEL Requests

    CP Chem provided all the information specified in the MPGF AMEL 
framework finalized on April 21, 2016 (see 81 FR 23480), to support 
their AMEL request. This information includes, but is not limited to: 
(1) Details on the project scope and background; (2) information on 
regulatory applicability; (3) MPGF test data on destruction efficiency/
combustion efficiency; (4) MPGF stability testing data, (5) MPGF cross-
light testing data; (6) information on flare reduction considerations; 
and (7) information on appropriate MPGF monitoring and operating 
conditions. In addition, because the MPGF AMEL framework did not 
specifically address an MPGF design that would utilize pressure-
assisted burners and that would also be steam-assisted (i.e., HP stages 
1 and 2 of CP Chem's polyethylene plant MPGF), CP Chem conducted 
additional performance testing on an n-butane/nitrogen vent gas mixture 
over a range of combustion zone net heating values (NHVcz), vent gas 
exit velocity regimes, and steam flow rate regimes in order to 
establish where the burners can achieve a destruction efficiency of n-
butane of 98 percent or greater.\3\ An n-butane vent gas mixture was 
tested because CP Chem indicated in their AMEL request that a cooling 
water failure would be their worst case upset design scenario from an 
MPGF perspective and that the vent gas sent to the flare would be 
predominantly isobutane. However, given that n-butane was more readily 
available than isobutane and given that they both have the same 
molecular formula (C4H10), the same lower 
flammability limits, and have almost identical net heating values, n-
butane was tested in lieu of isobutane (see Table 2 in section III. 
below for more details). In addition, each of the valid destruction 
efficiency test runs conducted lasted for a minimum of 10 minutes and 
none of these runs displayed any characteristics of flame instability 
(for further information on the supporting materials provided by CP 
Chem, see the docket at Docket ID No. EPA-HQ-OAR-2014-0738).
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    \3\ The EPA has previously concluded that flares operating in 
accordance with the General Provisions flare requirements of part 60 
and 63 destroy VOC and HAP with a destruction efficiency of 98 
percent or greater. Standard of Performance for New Stationary 
Sources: General Provisions; National Emission Standards for 
Hazardous Air Pollutants for Source Categories: General Provisions, 
63 FR 24436, 24437 (May 4, 1998).
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III. AMEL for the Proposed MPGFs

    We are seeking the public's input on CP Chem's request that the EPA 
approve an AMEL for the two MPGFs proposed to be used at CP Chem's 
ethylene plant in Baytown, Texas, and CP Chem's polyethylene plant in 
Old Ocean, Texas. Specifically, the EPA seeks the public's input on the 
requirements that will ensure that the AMEL will achieve emission 
reductions at least equivalent to the emission reductions achieved 
under the applicable NESHAP and NSPS identified in Table 1, all of 
which require compliance with 40 CFR 63.11(b) or 40 CFR 60.18(b), 
respectively, when using a flare.\3\ Based upon our review of the 
completed AMEL request and the available emissions test data submitted 
by CP Chem,\4\ we believe that, by complying with the following list of 
requirements, the two proposed MPGFs will achieve emission reductions 
at least equivalent to emission reductions achieved under 40 CFR 
63.11(b) and 40 CFR 60.18(b), as required by the applicable NESHAP and 
NSPS identified in Table 1:
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    \4\ For further information on the test data submitted by CP 
Chem to support their AMEL request, see ``CP Chemical AMEL Request 
for Multi-Point Ground Flares September 2015'' at Docket ID No. EPA-
HQ-OAR-2014-0738-0048, as well as ``CP Chemical Response to EPA 
November 2016'' at Docket ID No. EPA-HQ-OAR-2014-0738-0052.
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    (1) The MPGF system for all HP stages at CP Chem's ethylene plant 
and for all HP stages excluding stage 1 and 2 for CP Chem's 
polyethylene plant must be designed and operated such that the net 
heating value of the combustion zone gas (NHVcz) is greater than or 
equal to 800 British thermal units per standard cubic foot (Btu/scf) or 
lower flammability limit of the combustion zone gas (LFLcz) is less 
than or equal to 6.5 percent by volume. The MPGF system for HP stages 1 
and 2 of CP Chem's polyethlene plant must be designed and operated such 
that the NHVcz is greater than or equal to 600 Btu/scf or the LFLcz is 
less than or equal to 8.0 percent by volume. Owners or operators must 
demonstrate compliance with the NHVcz or LFLcz metric by continuously 
complying with a 15-minute block average. Owners or operators must 
calculate and monitor for the NHVcz or LFLcz according to the 
following:
    (a) Calculation of NHVcz

[[Page 16396]]

    (i) The owner or operator shall determine the net heating value of 
flare vent gas (NHVvg) by following the requirements of (1)(d)-(1)(e) 
below. If an owner or operator elects to use a monitoring system 
capable of continuously measuring (i.e., at least once every 15 
minutes), calculating, and recording the individual component 
concentrations present in the flare vent gas, NHVvg shall be calculated 
using the following equation:
[GRAPHIC] [TIFF OMITTED] TN04AP17.001

where:

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

    (ii) For all MPGF HP stages at CP Chem's ethylene plant and for all 
MPGF HP stages, excluding stage 1 and 2 for CP Chem's polyethylene 
plant, NHVvg = NHVcz.
    (iii) For HP stages 1 and 2 of CP Chem's polyethlene plant MPGF, 
NHVcz shall be calculated using the following equation:
[GRAPHIC] [TIFF OMITTED] TN04AP17.002

where:

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

    (b) Calculation of LFLcz
    (i) The owner or operator shall determine LFLcz from compositional 
analysis data by using the following equation:
[GRAPHIC] [TIFF OMITTED] TN04AP17.003

where:

LFLvg = Lower flammability limit of flare vent gas, volume percent 
(vol %).
n = Number of components in the vent gas.
i = Individual component in the vent gas.
[chi]i = Concentration of component i in the vent gas, vol %.
LFLi = Lower flammability limit of component i as determined using 
values published by the U.S. Bureau of Mines (Zabetakis, 1965), vol 
%. All inerts, including nitrogen, are assumed to have an infinite 
LFL (e.g., LFLN2 = [infin], so that [chi]N2/LFLN2 = 0). LFL values 
for common flare vent gas components are provided in Table 2.

    (ii) For all MPGF HP stages at CP Chem's ethylene plant and for all 
MPGF HP stages excluding stages 1 and 2 for CP Chem's polyethylene 
plant, LFLvg = LFLcz.
    (iii) For HP stages 1 and 2 of CP Chem's polyethlene plant MPGF, 
LFLcz shall be calculated using the following equation:
[GRAPHIC] [TIFF OMITTED] TN04AP17.004

where:

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

    (c) The operator of an MPGF system shall install, operate, 
calibrate, and maintain a monitoring system capable of continuously 
measuring the volumetric flow rate of flare vent gas (Qvg) and the 
volumetric flow rate of total assist steam (Qs).
    (i) The flow rate monitoring systems must be able to correct for 
the temperature and pressure of the system and output parameters in 
standard conditions (i.e., a temperature of 20 [deg]C 
(68[emsp14][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] TN04AP17.005

where:

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

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

[[Page 16397]]



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


             Table 3--Accuracy and Calibration Requirements
------------------------------------------------------------------------
                                     Accuracy           Calibration
           Parameter               requirements         requirements
------------------------------------------------------------------------
Flare Vent Gas Flow Rate......  20     Performance
                                 percent of flow    evaluation
                                 rate at            biennially (every 2
                                 velocities         years) and following
                                 ranging from 0.1   any period of more
                                 to 1 foot per      than 24 hours
                                 second.            throughout which the
                                                    flow rate exceeded
                                                    the maximum rated
                                                    flow rate of the
                                                    sensor, or the data
                                                    recorder was off
                                                    scale. Checks of all
                                                    mechanical
                                                    connections for
                                                    leakage monthly.
                                                    Visual inspections
                                                    and checks of system
                                                    operation every 3
                                                    months, unless the
                                                    system has a
                                                    redundant flow
                                                    sensor.
                                5      Select a
                                 percent of flow    representative
                                 rate at            measurement location
                                 velocities         where swirling flow
                                 greater than 1     or abnormal velocity
                                 foot per second.   distributions due to
                                                    upstream and
                                                    downstream
                                                    disturbances at the
                                                    point of measurement
                                                    are minimized.
Flow Rate for All Flows Other   5      Conduct a flow sensor
 Than Flare Vent Gas.            percent over the   calibration check at
                                 normal range of    least biennially
                                 flow measured or   (every two years);
                                 1.9 liters per     conduct a
                                 minute (0.5        calibration check
                                 gallons per        following any period
                                 minute),           of more than 24
                                 whichever is       hours throughout
                                 greater, for       which the flow rate
                                 liquid flow.       exceeded the
                                                    manufacturer's
                                                    specified maximum
                                                    rated flow rate or
                                                    install a new flow
                                                    sensor.
                                5      At least quarterly,
                                 percent over the   inspect all
                                 normal range of    components for
                                 flow measured or   leakage, unless the
                                 280 liters per     continuous parameter
                                 minute (10 cubic   monitoring system
                                 feet per           has a redundant flow
                                 minute),           sensor.
                                 whichever is
                                 greater, for gas
                                 flow.
                                5      Record the results of
                                 percent over the   each calibration
                                 normal range       check and
                                 measured for       inspection. Locate
                                 mass flow.         the flow sensor(s)
                                                    and other necessary
                                                    equipment (such as
                                                    straightening vanes)
                                                    in a position that
                                                    provides
                                                    representative flow;
                                                    reduce swirling flow
                                                    or abnormal velocity
                                                    distributions due to
                                                    upstream and
                                                    downstream
                                                    disturbances.
Pressure......................  5      Review pressure
                                 percent over the   sensor readings at
                                 normal range       least once a week
                                 measured or 0.12   for straight-line
                                 kilopascals (0.5   (unchanging)
                                 inches of water    pressure and perform
                                 column),           corrective action to
                                 whichever is       ensure proper
                                 greater.           pressure sensor
                                                    operation if
                                                    blockage is
                                                    indicated.

[[Page 16398]]

 
                                                   Performance
                                                    evaluation annually
                                                    and following any
                                                    period of more than
                                                    24 hours throughout
                                                    which the pressure
                                                    exceeded the maximum
                                                    rated pressure of
                                                    the sensor, or the
                                                    data recorder was
                                                    off scale. Checks of
                                                    all mechanical
                                                    connections for
                                                    leakage monthly.
                                                    Visual inspection of
                                                    all components for
                                                    integrity, oxidation
                                                    and galvanic
                                                    corrosion every 3
                                                    months, unless the
                                                    system has a
                                                    redundant pressure
                                                    sensor.
                                                   Select a
                                                    representative
                                                    measurement location
                                                    that minimizes or
                                                    eliminates pulsating
                                                    pressure, vibration,
                                                    and internal and
                                                    external corrosion.
Net Heating Value by            2      Calibration
 Calorimeter.                    percent of span.   requirements should
                                                    follow
                                                    manufacturer's
                                                    recommendations at a
                                                    minimum.
                                                   Temperature control
                                                    (heated and/or
                                                    cooled as necessary)
                                                    the sampling system
                                                    to ensure proper
                                                    year-round
                                                    operation.
                                                   Where feasible,
                                                    select a sampling
                                                    location at least 2
                                                    equivalent diameters
                                                    downstream from and
                                                    0.5 equivalent
                                                    diameters upstream
                                                    from the nearest
                                                    disturbance. Select
                                                    the sampling
                                                    location at least 2
                                                    equivalent duct
                                                    diameters from the
                                                    nearest control
                                                    device, point of
                                                    pollutant
                                                    generation, air in-
                                                    leakages, or other
                                                    point at which a
                                                    change in the
                                                    pollutant
                                                    concentration or
                                                    emission rate
                                                    occurs.
Net Heating Value by Gas        As specified in    Follow the procedure
 Chromatograph.                  Performance        in PS 9 of 40 CFR
                                 Specification      part 60, appendix B,
                                 (PS) 9 of 40 CFR   except that a single
                                 part 60,           daily mid-level
                                 appendix B.        calibration check
                                                    can be used (rather
                                                    than triplicate
                                                    analysis), the multi-
                                                    point calibration
                                                    can be conducted
                                                    quarterly (rather
                                                    than monthly), and
                                                    the sampling line
                                                    temperature must be
                                                    maintained at a
                                                    minimum temperature
                                                    of 60 [deg]C (rather
                                                    than 120 [deg]C).
------------------------------------------------------------------------

    (2) The MPGF system shall be operated with a flame present at all 
times when in use. Each burner on HP stages 1 and 2 of CP Chem's 
polyethylene plant MPGF must have a pilot with a continuously lit pilot 
flame. Additionally, each HP stage of CP Chem's ethylene plant MPGF and 
all HP stages excluding stages 1 and 2 for CP Chem's polyethylene plant 
MPGF must have at least two pilots with a continuously lit pilot flame. 
Each pilot flame must be continuously monitored by a thermocouple or 
any other equivalent device used to detect the presence of a flame. The 
time, date, and duration of any complete loss of pilot flame on any of 
the individual MPGF burners on HP stages 1 and 2 of CP Chem's 
polyethylene plant MPGF, on any of the HP stages of CP Chem's ethylene 
plant MPGF and on any of the HP stages excluding stages 1 and 2 of CP 
Chem's polyethylene plant MPGF must be recorded. Each monitoring device 
must be maintained or replaced at a frequency in accordance with the 
manufacturer's specifications.
    (3) The MPGF system shall be operated with no visible emissions 
except for periods not to exceed a total of 5 minutes during any 2 
consecutive hours. A video camera that is capable of continuously 
recording (i.e., at least one frame every 15 seconds with time and date 
stamps) images of the flare flame and a reasonable distance above the 
flare flame at an angle suitable for visible emissions observations 
must be used to demonstrate compliance with this requirement. The owner 
or operator must provide real-time video surveillance camera output to 
the control room or other continuously manned location where the video 
camera images may be viewed at any time.
    (4) The operator of an MPGF system shall install and operate 
pressure monitor(s) on the main flare header, as well as a valve 
position indicator monitoring system capable of monitoring and 
recording the position for each staging valve to ensure that the MPGF 
operates within the range of tested conditions or within the range of 
the manufacturer's specifications. The pressure monitor shall meet the 
requirements in Table 3. Maintenance periods, instrument adjustments or 
checks to maintain precision and accuracy, and zero and span 
adjustments may not exceed 5 percent of the time the flare is receiving 
regulated material.
    (5) Recordkeeping Requirements
    (a) All data must be recorded and maintained for a minimum of 3 
years or for as long as required under applicable rule subpart(s), 
whichever is longer.
    (6) Reporting Requirements
    (a) The information specified in section III (6)(b) and (c) below 
must be reported in the timeline specified by the applicable rule 
subpart(s) for which the MPGF will control emissions.
    (b) Owners or operators shall include the following information in 
their initial Notification of Compliance status report:
    (i) Specify flare design as a pressure-assisted MPGF. CP Chem's 
polyethylene plant shall also clearly note that HP stages 1 and 2 are 
also steam-assisted.
    (ii) All visible emission readings, NHVcz and/or LFLcz 
determinations, and flow rate measurements. For MPGF, exit velocity 
determinations do not need to be reported as the maximum permitted 
velocity requirements in the General Provisions at 40 CFR 60.18(b) and 
40 CFR 63.11(b) are not applicable.
    (iii) All periods during the compliance determination when a 
complete loss of pilot flame on any stage of MPGF burners occurs, and, 
for HP stages 1 and 2 of CP Chem's polyethylene plant MPGF, all periods 
during the compliance determination

[[Page 16399]]

when a complete loss of pilot flame on an individual burner occurs.
    (iv) All periods during the compliance determination when the 
pressure monitor(s) on the main flare header show the MPGF burners 
operating outside the range of tested conditions or outside the range 
of the manufacturer's specifications.
    (v) All periods during the compliance determination when the 
staging valve position indicator monitoring system indicates a stage of 
the MPGF should not be in operation and is or when a stage of the MPGF 
should be in operation and is not.
    (c) The owner or operator shall notify the Administrator of periods 
of excess emissions in their Periodic Reports. These periods of excess 
emissions shall include:
    (i) Records of each 15-minute block for all HP stages of CP Chem's 
ethylene plant MPGF and for all HP stages excluding stages 1 and 2 of 
CP Chem's polyethylene plant MPGF during which there was at least 1 
minute when regulated material was routed to the MPGF and a complete 
loss of pilot flame on a stage of burners occurred, and, for HP stages 
1 and 2 of CP Chem's polyethylene plant MPGF, records of each 15-minute 
block during which there was at least 1 minute when regulated material 
was routed to the MPGF and a complete loss of pilot flame on an 
individual burner occurred.
    (ii) Records of visible emissions events (including the time and 
date stamp) that exceed more than 5 minutes in any 2-hour consecutive 
period.
    (iii) Records of each 15-minute block period for which an 
applicable combustion zone operating limit (i.e., NHVcz or 
LFLcz) is not met for the MPGF when regulated material is 
being combusted in the flare. Indicate the date and time for each 
period, the NHVcz and/or LFLcz operating 
parameter for the period and the type of monitoring system used to 
determine compliance with the operating parameters (e.g., gas 
chromatograph or calorimeter). For CP Chem's polyethylene plant MPGF, 
also indicate which HP stages were in use.
    (iv) Records of when the pressure monitor(s) on the main flare 
header show the MPGF burners are operating outside the range of tested 
conditions or outside the range of the manufacturer's specifications. 
Indicate the date and time for each period, the pressure measurement, 
the stage(s) and number of MPGF burners affected, and the range of 
tested conditions or manufacturer's specifications.
    (v) Records of when the staging valve position indicator monitoring 
system indicates a stage of the MPGF should not be in operation and is 
or when a stage of the MPGF should be in operation and is not. Indicate 
the date and time for each period, whether the stage was supposed to be 
open, but was closed or vice versa, and the stage(s) and number of MPGF 
burners affected.

IV. Request for Comments

    We solicit comments on all aspects of CP Chem's request for 
approval of an AMEL for the standards specified in Table 1. We 
specifically seek comment regarding whether or not the alternative 
operating requirements listed in section III above will achieve 
emission reductions at least equivalent to the provisions in the NSPS 
and NESHAP presented in Table 1 that require flares to meet the 
requirements in 40 CFR 63.11(b) and 40 CFR 60.18(b).

    Dated: March 14, 2017.
Stephen Page,
Director, Office of Air Quality Planning and Standards.
[FR Doc. 2017-06597 Filed 4-3-17; 8:45 am]
 BILLING CODE 6560-50-P


