### 359 Environmental Protection Agency § 60.103a

the request as submitted until it is approved.

(iii) The request shall also be submitted to the following address: U.S.Environmental Protection Agency, Office of Air Quality Planning and Standards, Sector Policies and Programs Division, U.S. EPA Mailroom (E143–01), Attention: Refinery Sector Lead, 109T.W. Alexander Drive, Research Triangle Park, NC 27711. Electronic copiesin lieu of hard copies may also be submitted to refinerynsps@epa.gov.

(4) The approval process for a request for a facility-specific NO X emissions limit is described in paragraphs (i)(4)(i) through (iii) of this section.

(i) Approval by the Administrator of a facility-specific NO X emissions limitrequest will be based on the completeness, accuracy and reasonableness of the request. Factors that the EPA will consider in reviewing the request for approval include, but are not limited to, the following:

(A) A demonstration that the process
heater meets one of the four classes of process heaters outlined in paragraphs (i)(1) of this section;

(B) A description of the low-NO X burner designs and other combustion modifications considered for reducing
NO X emissions;

(C) The combustion modification option selected; and

(D) The operating conditions (firingrate, heater box temperature and excess oxygen concentration) at which
the NO X emission level was established.

(ii) If the request is approved by the Administrator, a facility-specific NO X emissions limit will be established at
the NO X emission level demonstrated in the approved request.

(iii) If the Administrator finds any deficiencies in the request, the request
must be revised to address the deficiencies and be re-submitted for approval.

[73 FR 35867, June 24, 2008, as amended at 77 FR 56466, Sep. 12, 2012]

§ 60.103a Design, equipment, work practice or operational standards.

(a) Except as provided in paragraph(g) of this section, each owner or operator that operates a flare that is subject to this subpart shall develop and implement a written flare management plan no later than the date specified in paragraph (b) of this section. The flaremanagement plan must include the information described in paragraphs (a)(1) through (7) of this section.

(1) A listing of all refinery process units, ancillary equipment, and fuel gas systems connected to the flare for
each affected flare.

(2) An assessment of whether discharges to affected flares from these process units, ancillary equipment and fuel gas systems can be minimized. The
flare minimization assessment must (at a minimum) consider the items in paragraphs (a)(2)(i) through (iv) of this section. The assessment must provideclear rationale in terms of costs (capital and annual operating), natural gas offset credits (if applicable), technical feasibility, secondary environmental impacts and safety considerations for
the selected minimization alternative(s) or a statement, with justifications, that flow reduction could not be achieved. Based upon the assessment, each owner or operator of an affected flare shall identify the minimization alternatives that it has implementedby the due date of the flare management plan and shall include a schedule for the prompt implementation of any
selected measures that cannot reasonably be completed as of that date.

(i) Elimination of process gas discharge to the flare through process operating changes or gas recovery at the

source.

(ii) Reduction of the volume of process gas to the flare through process operating changes.

(iii) Installation of a flare gas recovery system or, for facilities that arefuel gas rich, a flare gas recovery system and a co-generation unit or combined heat and power unit.

(iv) Minimization of sweep gas flow rates and, for flares with water seals, purge gas flow rates.

(3) A description of each affected flare containing the information in paragraphs (a)(3)(i) through (vii) of this
section.

(i) A general description of the flare,including the information in paragraphs (a)(3)(i)(A) through (G) of this
section.

(A) Whether it is a ground flare or elevated (including height).


### 360 40 CFR Ch. I (7–1–15 Edition) § 60.103a

(B) The type of assist system (e.g., air, steam, pressure, non-assisted).

(C) Whether it is simple or complex flare tip (e.g., staged, sequential).

(D) Whether the flare is part of a cascaded flare system (and if so, whether the flare is primary or secondary).

(E) Whether the flare serves as a backup to another flare.

(F) Whether the flare is an emergency flare or a non-emergency flare.

(G) Whether the flare is equipped with a flare gas recovery system.

(ii) Description and simple processflow diagram showing the interconnection of the following components of theflare: flare tip (date installed, manufacturer, nominal and effective tip diameter, tip drawing); knockout orsurge drum(s) or pot(s) (including dimensions and design capacities); flareheader(s) and subheader(s); assist system; and ignition system.

(iii) Flare design parameters, including the maximum vent gas flow rate;minimum sweep gas flow rate; minimum purge gas flow rate (if any); maximum supplemental gas flow rate; maximum pilot gas flow rate; and, if the flare is steam-assisted, minimum total
steam rate.

(iv) Description and simple processflow diagram showing all gas lines (including flare, purge (if applicable), sweep, supplemental and pilot gas) that
are associated with the flare. For purge, sweep, supplemental and pilotgas, identify the type of gas used. Designate which lines are exempt from sulfur, H 2 S or flow monitoring and why(e.g., natural gas, inherently low sulfur, pilot gas). Designate which linesare monitored and identify on the process flow diagram the location and type
of each monitor.

(v) For each flow rate, H 2 S, sulfur content, pressure or water seal monitor identified in paragraph (a)(3)(iv) of this section, provide a detailed description of the manufacturer’s specifications, including, but not limited to, make,model, type, range, precision, accuracy, calibration, maintenance and quality assurance procedures.

(vi) For emergency flares, secondary flares and flares equipped with a flare gas recovery system designed, sizedand operated to capture all flows except those resulting from startup,
shutdown or malfunction:

(A) Description of the water seal, including the operating range for the liquid level.

(B) Designation of the monitoring option elected (flow and sulfur monitoring or pressure and water seal liquid level monitoring).

(vii) For flares equipped with a flare gas recovery system:

(A) A description of the flare gas recovery system, including number ofcompressors and capacity of each compressor.

(B) A description of the monitoring parameters used to quantify the amount of flare gas recovered.

(C) For systems with staged compressors, the maximum time period required to begin gas recovery with thesecondary compressor(s), the monitoring parameters and procedures used
to minimize the duration of releasesduring compressor staging and a justification for why the maximum time period cannot be further reduced.

(4) An evaluation of the baseline flow
to the flare. The baseline flow to theflare must be determined after implementing the minimization assessment in paragraph (a)(2) of this section. Baseline flows do not include pilot gas flow or purge gas flow ( i.e., gas introduced after the flare’s water seal) provided these gas flows remain reasonably constant ( i.e., separate flow monitors for these streams are not required). Separate baseline flow ratesmay be established for different operating conditions provided that the management plan includes:

(i) A primary baseline flow rate that
will be used as the default baseline for all conditions except those specifically delineated in the plan;

(ii) A description of each special condition for which an alternate baseline is established, including the rationale for each alternate baseline, the daily
flow for each alternate baseline and theexpected duration of the special conditions for each alternate baseline; and

(iii) Procedures to minimize discharges to the affected flare during each special condition described inparagraph (a)(4)(ii) of this section, unless procedures are already developed for these cases under paragraph (a)(5)


### 361 Environmental Protection Agency § 60.103a

through (7) of this section, as applicable.

(5) Procedures to minimize or eliminate discharges to the flare during the planned startup and shutdown of the refinery process units and ancillary equipment that are connected to the affected flare, together with a schedule for the prompt implementation of any procedures that cannot reasonably beimplemented as of the date of the submission of the flare management plan.

(6) Procedures to reduce flaring in cases of fuel gas imbalance ( i.e., excess fuel gas for the refinery’s energy needs), together with a schedule for theprompt implementation of any procedures that cannot reasonably be implemented as of the date of the submission of the flare management plan.

(7) For flares equipped with flare gasrecovery systems, procedures to minimize the frequency and duration ofoutages of the flare gas recovery system and procedures to minimize thevolume of gas flared during such outages, together with a schedule for theprompt implementation of any procedures that cannot reasonably be implemented as of the date of the submission of the flare management plan.

(b) Except as provided in paragraph(g) of this section, each owner or operator required to develop and implement a written flare management plan as described in paragraph (a) of this section must submit the plan to theAdministrator as described in paragraphs (b)(1) through (3) of this section.

(1) The owner or operator of a newly
constructed or reconstructed flare must develop and implement the flare management plan by no later than the
date that the flare becomes an affected facility subject to this subpart, except
for the selected minimization alternatives in paragraph (a)(2) and/or the procedures in paragraphs (a)(5) though(a)(7) of this section that cannot reasonably be implemented by that date,which the owner or operator must implement in accordance with the schedule in the flare management plan. The owner or operator of a modified flare must develop and implement the flaremanagement plan by no later than November 11, 2015 or upon startup of the modified flare, whichever is later. (2) The owner or operator must comply with the plan as submitted by the date specified in paragraph (b)(1) ofthis section. The plan should be updated periodically to account for changes in the operation of the flare,
such as new connections to the flare or the installation of a flare gas recoverysystem, but the plan need be re-submitted to the Administrator only if the owner or operator adds an alternative baseline flow rate, revises an existing baseline as described in paragraph (a)(4) of this section, installs a flare gas recovery system or is required tochange flare designations and monitoring methods as described in §60.107a(g). The owner or operator mustcomply with the updated plan as submitted.

(3) All versions of the plan submitted
to the Administrator shall also be submitted to the following address: U.S.Environmental Protection Agency, Office of Air Quality Planning and Standards, Sector Policies and Programs Division, U.S. EPA Mailroom (E143–01), Attention: Refinery Sector Lead, 109T.W. Alexander Drive, Research Triangle Park, NC 27711. Electronic copiesin lieu of hard copies may also be submitted to refinerynsps@epa.gov.

(c) Except as provided in paragraphs (f) and (g) of this section, each owner or operator that operates a fuel gascombustion device, flare or sulfur recovery plant subject to this subpart shall conduct a root cause analysis and a corrective action analysis for each of the conditions specified in paragraphs (c)(1) through (3) of this section.

(1) For a flare: (i) Any time the SO 2 emissions exceed 227 kilograms (kg) (500 lb) in any 24-hour period; or

(ii) Any discharge to the flare in excess of 14,160 standard cubic meters (m 3 ) (500,000 standard cubic feet (scf))above the baseline, determined in paragraph (a)(4) of this section, in any 24- hour period; or

(iii) If the monitoring alternative in §60.107a(g) is elected, any period when the flare gas line pressure exceeds thewater seal liquid depth, except for periods attributable to compressor staging that do not exceed the staging time specified in paragraph (a)(3)(vii)(C) of
this section.


### 362 40 CFR Ch. I (7–1–15 Edition) § 60.103a

(2) For a fuel gas combustion device,each exceedance of an applicable shortterm emissions limit in §60.102a(g)(1) if
the SO 2 discharge to the atmosphere is 227 kg (500 lb) greater than the amount
that would have been emitted if the emissions limits had been met duringone or more consecutive periods of excess emissions or any 24-hour period,
whichever is shorter.

(3) For a sulfur recovery plant, each
time the SO 2 emissions are more than 227 kg (500 lb) greater than the amount
that would have been emitted if the
SO 2 or reduced sulfur concentration was equal to the applicable emissions limit in §60.102a(f)(1) or (2) during one or more consecutive periods of excessemissions or any 24-hour period, whichever is shorter.

(d) Except as provided in paragraphs (f) and (g) of this section, a root cause analysis and corrective action analysis must be completed as soon as possible,but no later than 45 days after a discharge meeting one of the conditions specified in paragraphs (c)(1) through(3) of this section. Special circumstances affecting the number of root cause analyses and/or correctiveaction analyses are provided in paragraphs (d)(1) through (5) of this section.

(1) If a single continuous discharge meets any of the conditions specified in paragraphs (c)(1) through (3) of this
section for 2 or more consecutive 24-hour periods, a single root cause analysis and corrective action analysis may
be conducted.

(2) If a single discharge from a flare triggers a root cause analysis based onmore than one of the conditions specified in paragraphs (c)(1)(i) through (iii) of this section, a single root cause analysis and corrective action analysis may be conducted.

(3) If the discharge from a flare is the result of a planned startup or shutdown of a refinery process unit or ancillary equipment connected to the affected flare and the procedures in paragraph (a)(5) of this section were followed, aroot cause analysis and corrective action analysis is not required; however,the discharge must be recorded as described in §60.108a(c)(6) and reported as described in §60.108a(d)(5).

(4) If both the primary and secondary flare in a cascaded flare system meet any of the conditions specified in paragraphs (c)(1)(i) through (iii) of this section in the same 24-hour period, a single root cause analysis and corrective action analysis may be conducted.

(5) Except as provided in paragraph (d)(4) of this section, if discharges occur that meet any of the conditions specified in paragraphs (c)(1) through(3) of this section for more than one affected facility in the same 24-hour period, initial root cause analyses shall be conducted for each affected facility.If the initial root cause analyses indicate that the discharges have the same root cause(s), the initial root cause analyses can be recorded as a singleroot cause analysis and a single corrective action analysis may be conducted.

(e) Except as provided in paragraphs (f) and (g) of this section, each owner or operator of a fuel gas combustion device, flare or sulfur recovery plant subject to this subpart shall implement the corrective action(s) identified inthe corrective action analysis conducted pursuant to paragraph (d) ofthis section in accordance with the applicable requirements in paragraphs (e)(1) through (3) of this section.

(1) All corrective action(s) must beimplemented within 45 days of the discharge for which the root cause andcorrective action analyses were required or as soon thereafter as practicable. If an owner or operator concludes that corrective action shouldnot be conducted, the owner or operator shall record and explain the basis
for that conclusion no later than 45days following the discharge as specified in §60.108a(c)(6)(ix).

(2) For corrective actions that cannot be fully implemented within 45 days following the discharge for which the
root cause and corrective action analyses were required, the owner or operator shall develop an implementationschedule to complete the corrective action(s) as soon as practicable.

(3) No later than 45 days following the discharge for which a root causeand corrective action analyses were required, the owner or operator shall


### 363 Environmental Protection Agency § 60.103a

record the corrective action(s) completed to date, and, for action(s) not already completed, a schedule for implementation, including proposed commencement and completion dates as specified in §60.108a(c)(6)(x).

(f) Modified flares shall comply with the requirements of paragraphs (c)through (e) of this section by November 11, 2015 or at startup of the modified flare, whichever is later. Modified
flares that were not affected facilities subject to subpart J of this part prior to becoming affected facilities under§60.100a shall comply with the requirements of paragraph (h) of this section and the requirements of §60.107a(a)(2) by November 11, 2015 or at startup of the modified flare, whichever is later.
Modified flares that were affected facilities subject to subpart J of this part prior to becoming affected facilities under §60.100a shall comply with the requirements of paragraph (h) of this section and the requirements of §60.107a(a)(2) by November 13, 2012 or atstartup of the modified flare, whichever is later, except that modified flares that have accepted applicabilityof subpart J under a federal consent decree shall comply with the subpart Jrequirements as specified in the consent decree, but shall comply with the requirements of paragraph (h) of this section and the requirements of§60.107a(a)(2) by no later than November 11, 2015.

(g) An affected flare subject to this subpart located in the Bay Area Air Quality Management District (BAAQMD) may elect to comply with both BAAQMD Regulation 12, Rule 11 and BAAQMD Regulation 12, Rule 12 as an alternative to complying with the requirements of paragraphs (a) through (e) of this section. An affected flare subject to this subpart located in the South Coast Air Quality ManagementDistrict (SCAQMD) may elect to comply with SCAQMD Rule 1118 as an alternative to complying with the requirements of paragraphs (a) through(e) of this section. The owner or operator of an affected flare must notify
the Administrator that the flare is in compliance with BAAQMD Regulation 12, Rule 11 and BAAQMD Regulation 12, Rule 12 or SCAQMD Rule 1118. The owner or operator of an affected flare shall also submit the existing flaremanagement plan to the following address: U.S. Environmental Protection Agency, Office of Air Quality Planning and Standards, Sector Policies and Programs Division, U.S. EPA Mailroom (E143–01), Attention: Refinery SectorLead, 109 T.W. Alexander Drive, Research Triangle Park, NC 27711. Electronic copies in lieu of hard copies may
also be submitted to refinerynsps@epa.gov.

(h) Each owner or operator shall not burn in any affected flare any fuel gas
that contains H 2 S in excess of 162 ppmv determined hourly on a 3-hour rolling average basis. The combustion in a flare of process upset gases or fuel gas
that is released to the flare as a resultof relief valve leakage or other emergency malfunctions is exempt from
this limit.

(i) Each owner or operator of a delayed coking unit shall depressure each coke drum to 5 lb per square inch gauge (psig) or less prior to discharging
the coke drum steam exhaust to the atmosphere. Until the coke drum pressure reaches 5 psig, the coke drum steam exhaust must be managed in an enclosed blowdown system and theuncondensed vapor must either be recovered (e.g., sent to the delayed coking unit fractionators) or vented to the fuel gas system, a fuel gas combustion
device or a flare.

(j) Alternative means of emission limitation. (1) Each owner or operator subject to the provisions of this section mayapply to the Administrator for a determination of equivalence for any means
of emission limitation that achieves a reduction in emissions of a specifiedpollutant at least equivalent to the reduction in emissions of that pollutant achieved by the controls required in
this section.

(2) Determination of equivalence to the design, equipment, work practiceor operational requirements of this section will be evaluated by the following guidelines:

(i) Each owner or operator applying for a determination of equivalence shall be responsible for collecting and verifying test data to demonstrate the equivalence of the alternative means of
emission limitation.


### 364 40 CFR Ch. I (7–1–15 Edition) § 60.104a

(ii) For each affected facility for which a determination of equivalence is requested, the emission reduction achieved by the design, equipment,work practice or operational requirements shall be demonstrated.

(iii) For each affected facility for which a determination of equivalence is requested, the emission reduction achieved by the alternative means of
emission limitation shall be demonstrated.

(iv) Each owner or operator applying for a determination of equivalence to a work practice standard shall commit inwriting to work practice(s) that provide for emission reductions equal to or greater than the emission reductions achieved by the required work practice.

(v) The Administrator will compare
the demonstrated emission reduction
for the alternative means of emission
limitation to the demonstrated emission reduction for the design, equipment, work practice or operational requirements and, if applicable, will consider the commitment in paragraph (j)(2)(iv) of this section.

(vi) The Administrator may condition the approval of the alternative
means of emission limitation on requirements that may be necessary to ensure operation and maintenance to
achieve the same emissions reductionas the design, equipment, work practice or operational requirements.

(3) An owner or operator may offer a unique approach to demonstrate the equivalence of any equivalent means of
emission limitation.

(4) Approval of the application for equivalence to the design, equipment,work practice or operational requirements of this section will be evaluated by the following guidelines:

(i) After a request for determinationof equivalence is received, the Administrator will publish a notice in the
F EDERAL R EGISTER and provide the opportunity for public hearing if the Administrator judges that the request may be approved.

(ii) After notice and opportunity for public hearing, the Administrator will determine the equivalence of a means of emission limitation and will publish
the determination in the F EDERAL R EG

ISTER

. (iii) Any equivalent means of emission limitations approved under this section shall constitute a required work practice, equipment, design oroperational standard within the meaning of section 111(h)(1) of the CAA.

(5) Manufacturers of equipment used to control emissions may apply to the
Administrator for determination of equivalence for any alternative means
of emission limitation that achieves a reduction in emissions achieved by theequipment, design and operational requirements of this section. The Administrator will make an equivalence determination according to the provisions of paragraphs (j)(2) through (4) of
this section.

[77 FR 56467, Sep. 12, 2012]

§ 60.104a Performance tests.

(a) The owner or operator shall conduct a performance test for each FCCU, FCU, sulfur recovery plant, flare andfuel gas combustion device to demonstrate initial compliance with each applicable emissions limit in §60.102a according to the requirements of §60.8. The notification requirements of§60.8(d) apply to the initial performance test and to subsequent performance tests required by paragraph (b) ofthis section (or as required by the Administrator), but does not apply to performance tests conducted for the purpose of obtaining supplemental databecause of continuous monitoring system breakdowns, repairs, calibration checks and zero and span adjustments.

(b) The owner or operator of a FCCU
or FCU that elects to monitor control device operating parameters according to the requirements in §60.105a(b), to use bag leak detectors according to the requirements in §60.105a(c), or to use COMS according to the requirements in§60.105a(e) shall conduct a PM performance test at least once every 12 months
and furnish the Administrator a written report of the results of each test.

(c) In conducting the performancetests required by this subpart (or as requested by the Administrator), the owner or operator shall use the test methods in 40 CFR part 60, Appendices A–1 through A–8 or other methods asspecified in this section, except as provided in §60.8(b).